Vistra (VST) 10-Q 2 Aug 19 2019 Q2 Quarterly report Financial data

Cover Page

Cover Page - shares	6 Months Ended
	Jun. 30, 2019	Jul. 31, 2019
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2019
Document Transition Report	false
Entity File Number	001-38086
Entity Registrant Name	Vistra Energy Corp.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	36-4833255
Entity Address, Address Line One	6555 Sierra Drive
Entity Address, City or Town	Irving,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	75039
City Area Code	(214)
Local Phone Number	812-4600
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		491,679,984
Entity Central Index Key	0001692819
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q2
Amendment Flag	false
Common stock, par value $0.01 per share
Document Information [Line Items]
Title of 12(b) Security	Common stock, par value $0.01 per share
Trading Symbol	VST
Security Exchange Name	NYSE
Warrants
Document Information [Line Items]
Title of 12(b) Security	Warrants
Trading Symbol	VST.WS.A
Security Exchange Name	NYSE

Condensed Statements Of Consoli

Condensed Statements Of Consolidated Income (Loss) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Income Statement [Abstract]
Operating revenues	$ 2,832	$ 2,574	$ 5,755	$ 3,338
Fuel, purchased power costs and delivery fees	(1,139)	(1,216)	(2,600)	(1,866)
Operating costs	(370)	(386)	(755)	(580)
Depreciation and amortization	(384)	(389)	(790)	(542)
Selling, general and administrative expenses	(210)	(352)	(392)	(514)
Operating income (loss)	729	231	1,218	(164)
Other income	13	7	39	18
Other deductions	(2)	(1)	(5)	(3)
Interest expense and related charges	(274)	(146)	(495)	(137)
Impacts of Tax Receivable Agreement	33	(64)	36	(82)
Equity in earnings of unconsolidated investments	3	4	10	4
Income (loss) before income taxes	502	31	803	(364)
Income tax (expense) benefit	(148)	74	(225)	163
Net income (loss)	354	105	578	(201)
Net loss attributable to noncontrolling interest	2	3	3	3
Net income (loss) attributable to Vistra Energy	$ 356	$ 108	$ 581	$ (198)
Weighted average shares of common stock outstanding:
Weighted average shares of common stock outstanding - basic	499,778,235	526,332,862	499,213,522	477,662,016
Weighted average shares of common stock outstanding - diluted	507,500,383	533,786,824	507,248,920	477,662,016
Net income (loss) per weighted average share of common stock outstanding:
Net income (loss) per weighted average share of common stock outstanding - basic	$ 0.71	$ 0.21	$ 1.16	$ (0.41)
Net income (loss) per weighted average share of common stock outstanding - diluted	$ 0.70	$ 0.20	$ 1.15	$ (0.41)

Condensed Statements Of Conso_2

Condensed Statements Of Consolidated Comprehensive Income (Loss) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 354	$ 105	$ 578	$ (201)
Other comprehensive income, net of tax effects:
Effects related to pension and other retirement benefit obligations (net of tax benefit of $— in all periods)	0	0	1	1
Total other comprehensive income	0	0	1	1
Comprehensive income (loss)	354	105	579	(200)
Comprehensive loss attributable to noncontrolling interest	2	3	3	3
Comprehensive income (loss) attributable to Vistra Energy	$ 356	$ 108	$ 582	$ (197)

Condensed Statements Of Conso_3

Condensed Statements Of Consolidated Comprehensive Income (Loss) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Statement of Comprehensive Income [Abstract]
Effects related to pension and other retirement benefit obligations (net of tax benefit of $— in all periods)	$ 0	$ 0	$ 0	$ 0

Condensed Statements Of Conso_4

Condensed Statements Of Consolidated Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Cash flows — operating activities:
Net income (loss)	$ 578	$ (201)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Depreciation and amortization	886	619
Deferred income tax (benefit) expense, net	217	(159)
Unrealized net (gain) loss from mark-to-market valuations of commodities	(703)	199
Unrealized net (gain) loss from mark-to-market valuations of interest rate swaps	199	(86)
Asset retirement obligation accretion expense	27	44
Impacts of Tax Receivable Agreement	(36)	82
Stock-based compensation	24	59
Other, net	73	(6)
Changes in operating assets and liabilities:
Margin deposits, net	112	(61)
Accrued interest	6	(74)
Accrued taxes	(67)	(112)
Accrued employee incentive	(72)	(31)
Other operating assets and liabilities	(362)	(302)
Cash provided by (used in) operating activities	882	(29)
Cash flows — financing activities:
Issuances of long-term debt	4,600	0
Repayments/repurchases of debt	(4,137)	(1,338)
Net borrowings under accounts receivable securitization program	91	0
Stock repurchase	(457)	(63)
Dividends paid to stockholders	(120)	0
Debt tender offer and other financing fees	(146)	(46)
Other, net	(1)	4
Cash used in financing activities	(170)	(1,443)
Cash flows — investing activities:
Capital expenditures, including LTSA prepayments	(247)	(153)
Nuclear fuel purchases	(20)	(28)
Development and growth expenditures	(36)	(21)
Cash acquired in the Merger	0	445
Proceeds from sales of nuclear decommissioning trust fund securities	292	93
Investments in nuclear decommissioning trust fund securities	(302)	(103)
Proceeds from sale of environmental allowances	31	0
Purchases of environmental allowances	(138)	(1)
Other, net	21	10
Cash (used in) provided by investing activities	(399)	242
Net change in cash, cash equivalents and restricted cash	313	(1,230)
Cash, cash equivalents and restricted cash — beginning balance	693	2,046
Cash, cash equivalents and restricted cash — ending balance	$ 1,006	$ 816

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 964	$ 636
Restricted cash	42	57
Trade accounts receivable — net	1,101	1,087
Inventories	476	412
Commodity and other derivative contractual assets	1,418	730
Margin deposits related to commodity contracts	253	361
Prepaid expense and other current assets	285	152
Total current assets	4,539	3,435
Investments	1,422	1,250
Investment in unconsolidated subsidiary	127	131
Property, plant and equipment — net	14,260	14,612
Operating lease right-of-use assets	34	0
Goodwill	2,082	2,068
Identifiable intangible assets — net	2,383	2,493
Commodity and other derivative contractual assets	124	109
Accumulated deferred income taxes	1,144	1,336
Other noncurrent assets	405	590
Total assets	26,520	26,024
Current liabilities:
Accounts receivable securitization program	430	339
Long-term debt due currently	161	191
Trade accounts payable	782	945
Commodity and other derivative contractual liabilities	1,514	1,376
Margin deposits related to commodity contracts	8	4
Accrued income taxes	12	10
Accrued taxes other than income	115	182
Accrued interest	82	77
Asset retirement obligations	232	156
Operating lease liabilities	13	0
Other current liabilities	308	345
Total current liabilities	3,657	3,625
Long-term debt, less amounts due currently	11,193	10,874
Operating lease liabilities	40	0
Commodity and other derivative contractual liabilities	404	270
Accumulated deferred income taxes	10	10
Tax Receivable Agreement obligation	384	420
Asset retirement obligation	2,133	2,217
Identifiable intangible liabilities - net	331	401
Other noncurrent liabilities and deferred credits	464	340
Total liabilities	18,616	18,157
Commitments and Contingencies
Total equity:
Common stock (par value — $0.01; number of shares authorized — 1,800,000,000) (shares outstanding: June 30, 2019 — 476,166,856; December 31, 2018 — 493,215,309)	5	5
Additional paid-in-capital	8,909	9,329
Retained deficit	(989)	(1,449)
Accumulated other comprehensive income (loss)	(21)	(22)
Stockholders' equity	7,904	7,863
Noncontrolling interest in subsidiary	0	4
Total equity	7,904	7,867
Total liabilities and equity	$ 26,520	$ 26,024

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Apr. 09, 2018	Dec. 31, 2017
Statement of Changes in Financial Position [Abstract]
Common stock, par or stated value per share	$ 0.01
Common stock, shares authorized	1,800,000,000		1,800,000,000
Common stock, shares outstanding	476,166,856	493,215,309	521,214,879	522,932,453	428,398,802

Business And Significant Accoun

Business And Significant Accounting Policies	6 Months Ended
	Jun. 30, 2019
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 Vistra Energy and/or its subsidiaries, as apparent in the context. See Glossary for defined terms. Vistra Energy is a holding company operating an integrated retail and generation business in markets throughout the U.S. Through our subsidiaries, we are engaged in competitive electricity market activities including power generation, wholesale energy sales and purchases, commodity risk management and retail sales of electricity to end users. Vistra Energy has six reportable segments: (i) Retail, (ii) ERCOT, (iii) PJM, (iv) NY/NE (comprising NYISO and ISO-NE), (v) MISO and (vi) Asset Closure. See Note 18 for further information concerning reportable business segments. Acquisition of Crius On July 15, 2019, an indirect, wholly owned subsidiary of Vistra Energy completed the acquisition of the equity interests of two wholly owned subsidiaries of Crius that indirectly own the operating business of Crius (Crius Transaction). Because the Crius Transaction closed on July 15, 2019, Vistra Energy's condensed consolidated financial statements and the notes related thereto for the period ending June 30, 2019 do not include the financial condition or the operating results of Crius and its subsidiaries. See Note 2 for a summary of the Crius Transaction. Dynegy Merger Transaction On the Merger Date, Vistra Energy and Dynegy completed the transactions contemplated by the Merger Agreement. Pursuant to the Merger Agreement, Dynegy merged with and into Vistra Energy, with Vistra Energy continuing as the surviving corporation. Because the Merger closed on April 9, 2018, Vistra Energy's condensed consolidated financial statements and the notes related thereto do not include the financial condition or the operating results of Dynegy prior to April 9, 2018. See Note 2 for a summary of the Merger transaction and business combination accounting. Basis of Presentation The condensed consolidated financial statements have been prepared in accordance with U.S. GAAP and on the same basis as the audited financial statements included in our annual report on Form 10-K for the year ended December 31, 2018. Adjustments (consisting of normal recurring accruals) necessary for a fair presentation of the results of operations and financial position have been included therein. All intercompany items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with U.S. GAAP have been omitted pursuant to the rules and regulations of the SEC. Because the condensed consolidated interim financial statements do not include all of the information and footnotes required by U.S. GAAP, they should be read in conjunction with the audited financial statements and related notes contained in our annual report on Form 10-K for the year ended December 31, 2018. The results of operations for an interim period may not give a true indication of results for a full year. All dollar amounts in the financial statements and tables in the notes are stated in millions of U.S. 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, estimates of expected obligations, judgment related to the potential timing of events and other estimates. 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. Leases At the inception of a contract we determine if it is or contains a lease, which involves the contract conveying the right to control the use of explicitly or implicitly identified property, plant, or equipment for a period of time in exchange for consideration. Right-of-use (ROU) assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. ROU assets and lease liabilities are recognized at the commencement date of the underlying lease based on the present value of lease payments over the lease term. We use our secured incremental borrowing rate based on the information available at the lease commencement date to determine the present value of lease payments. Operating leases are included in operating lease ROU assets, operating lease liabilities (current) and operating lease liabilities (noncurrent) on our condensed consolidated balance sheet. Finance leases are included in property, plant and equipment, other current liabilities and other noncurrent liabilities and deferred credits on our condensed consolidated balance sheet. Lease term includes options to extend or terminate the lease when it is reasonably certain that we will exercise the option. We have elected the practical expedient which permits us to not reassess under the new standard our prior conclusion about lease classification and initial direct costs. We have also elected the practical expedient to not separate lease and non-lease components for a majority of the lease asset classes. We have also elected the hindsight practical expedient to determine the lease term. Leases with an initial lease term of 12 months or less are not recorded on the balance sheet; we recognize lease expense for these leases on a straight-line basis over the lease term. We also present lessor sublease income on a net basis against the related lessee lease expense. Adoption of New Accounting Standards Leases — On January 1, 2019, we adopted Accounting Standards Update (ASU) 2016-02, Leases (Topic 842) and all related amendments (new lease standard) using the modified retrospective method with the cumulative-effect adjustment to the opening balance of retained earnings for all contracts outstanding at the time of adoption. The comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. We expect the impact of the adoption of the new lease standard to be immaterial to our net income on an ongoing basis. The impact of adopting the new lease standard primarily relates to recognition of lease liabilities and ROU assets for all leases classified as operating leases. Under the new lease standard, each ROU asset will be amortized over the lease term and liability settled at the end of the lease term. We recognized the effect of initially applying the new lease standard by recording ROU assets of $85 million and lease liabilities of $123 million in our condensed consolidated balance sheet. As of January 1, 2019, the cumulative effect of the changes made to our condensed consolidated balance sheet for the adoption of the new lease standard was as follows: December 31, 2018 Adoption of New Lease Standard January 1, 2019 Impact on condensed consolidated balance sheet: Assets Property, plant and equipment — net $ 14,612 $ 15 $ 14,627 Operating lease right-of-use assets — 70 70 Prepaid expense and other current assets 152 (2 ) 150 Accumulated deferred income taxes 1,336 1 1,337 Liabilities Other current liabilities 345 (1 ) 344 Operating lease liabilities — 109 109 Identifiable intangible liabilities 401 (36 ) 365 Other noncurrent liabilities and deferred credits 340 14 354 Equity Retained deficit (1,449 ) (2 ) (1,451 ) See Note 12 for the disclosures required by the new lease standard. Changes in Accounting Standards In August 2018, the Financial Accounting Standards Board (FASB) issued ASU 2018-13, Changes to the Disclosure Requirements for Fair Value Measurement. The ASU will be effective for fiscal years beginning after December 15, 2019 and early adoption is permitted. The ASU removes disclosure requirements for (a) the reasons for transfers between Level 1 and Level 2, (b) the policy for timing of transfers between levels and (c) the valuation processes for Level 3. The ASU will require new disclosures around (a) the changes in unrealized gains and losses for the period included in other comprehensive income for recurring Level 3 fair value measurements held at the end of the reporting period and (b) the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. We are currently evaluating the impact of this ASU on our disclosures. In August 2018, the FASB issued ASU 2018-15, Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract. The ASU will be effective for fiscal years beginning after December 15, 2019 and early adoption is permitted. The ASU requires a customer in a cloud hosting arrangement that is a service contract to determine which implementation costs to capitalize and which costs to expense based on the project stage of the implementation. The ASU also requires the customer to expense the capitalized implementation costs over the term of the hosting arrangement. The customer is required to apply the existing impairment and abandonment guidance on the capitalized implementation costs. We are currently evaluating the impact of this ASU on our financial statements.

Acquisition of Crius, Dynegy Me

Acquisition of Crius, Dynegy Merger Transaction and Business Combination Accounting (Notes)	6 Months Ended
	Jun. 30, 2019
Business Combinations [Abstract]
Merger Transaction [Text Block]	ACQUISITION OF CRIUS, DYNEGY MERGER TRANSACTION AND BUSINESS COMBINATION ACCOUNTING Acquisition of Crius On July 15, 2019 (Acquisition Date), Vienna Acquisition B.C. Ltd., an indirect, wholly owned subsidiary of Vistra Energy, completed the acquisition of the equity interests of two wholly owned subsidiaries of Crius that indirectly own the operating business of Crius. Crius is an energy retailer selling both electricity and natural gas products to residential and small business customers in 19 states and the District of Columbia. The Crius Transaction is expected to (i) reduce risk and expand into higher margin channels by improving Vistra Energy's match of its generation to load profile due to a high degree of overlap with Vistra Energy's generation fleet with Crius' approximately 11.6 TWh of annual load, (ii) establish a platform for future growth by leveraging Vistra Energy's existing retail marketing capabilities and Crius' experienced team and (iii) enhance the integrated value proposition through collateral and transaction efficiencies, particularly via Crius' retail portfolio. The Crius Transaction is being accounted for in accordance with ASC 805, Business Combinations (ASC 805), with identifiable assets acquired and liabilities assumed recorded at their estimated fair values on the Acquisition Date. Due to the limited time between the Acquisition Date and this filing, our purchase price allocation for the assets acquired and the liabilities assumed in the Merger has not been completed. The results of operations of Crius will be reported in our consolidated financial statements beginning as of the Acquisition Date. Vistra Energy funded the purchase price of approximately $400 million (including $380 million for outstanding trust units) using cash on hand and assumption of Crius' net debt of approximately $111 million . Our initial accounting for the purchase price allocation for the assets acquired and the liabilities assumed in the Crius Transaction and the supplemental pro forma financial results is currently underway and will be presented no later than the third quarter of 2019. Dynegy Merger Transaction On the Merger Date, Vistra Energy and Dynegy completed the transactions contemplated by the Merger Agreement. Pursuant to the Merger Agreement, Dynegy merged with and into Vistra Energy, with Vistra Energy continuing as the surviving corporation. The Merger was intended to qualify as a tax-free reorganization under the Internal Revenue Code, as amended, so that none of Vistra Energy, Dynegy or any of the Dynegy stockholders would recognize any gain or loss in the transaction, except that Dynegy stockholders could recognize a gain or loss with respect to cash received in lieu of fractional shares of Vistra Energy's common stock. Vistra Energy is the acquirer for both federal tax and accounting purposes. At the closing of the Merger, each issued and outstanding share of Dynegy common stock, par value $0.01 per share, other than shares owned by Vistra Energy or its subsidiaries, held in treasury by Dynegy or held by a subsidiary of Dynegy, was automatically converted into 0.652 shares of common stock, par value $0.01 per share, of Vistra Energy (the Exchange Ratio), except that cash was paid in lieu of fractional shares, which resulted in Vistra Energy issuing 94,409,573 shares of Vistra Energy common stock to the former Dynegy stockholders, as well as converting stock options, equity-based awards, tangible equity units and warrants. The total number of Vistra Energy shares outstanding at the close of the Merger was 522,932,453 shares. Dynegy stock options and equity-based awards outstanding immediately prior to the Merger Date were generally automatically converted upon completion of the Merger into stock options and equity-based awards, respectively, with respect to Vistra Energy's common stock, after giving effect to the Exchange Ratio. Dynegy Business Combination Accounting We believe the Merger has provided and continues to provide significant strategic benefits and opportunities to Vistra Energy, including increased scale and market diversification, rebalanced asset portfolio and improved earnings and cash flow. The Merger was accounted for in accordance with ASC 805, Business Combinations (ASC 805), with identifiable assets acquired and liabilities assumed recorded at their estimated fair values on the Merger Date. The combined results of operations are reported in our consolidated financial statements beginning as of the Merger Date. A summary of the techniques used to estimate the fair value of the identifiable assets and liabilities, as well as their classification within the fair value hierarchy (see Note 15 ), is listed below: • Working capital was valued using available market information (Level 2). • Acquired property, plant and equipment was valued using a combination of an income approach and a market approach. The income approach utilized a discounted cash flow analysis based upon a debt-free, free cash flow model (Level 3). • Acquired derivatives were valued using the methods described in Note 15 (Level 1, Level 2 or Level 3). • Contracts with terms that were not at current market prices were also valued using a discounted cash flow analysis (Level 3). The cash flows generated by the contracts were compared with their cash flows based on current market prices with the resulting difference discounted to present value and recorded as either an intangible asset or liability. • Long-term debt was valued using a market approach (Level 2). • AROs were recorded in accordance with ASC 410, Asset Retirement and Environmental Obligations (Level 3). The following table summarizes the consideration paid and the final allocation of the purchase price to the fair value amounts recognized for the assets acquired and liabilities assumed related to the Merger as of the Merger Date. Based on the opening price of Vistra Energy common stock on the Merger Date, the purchase price was approximately $2.3 billion . During the three months ended March 31, 2019, the purchase price allocation was completed. During the period from April 9, 2018 through March 31, 2019, we updated the initial purchase price allocation with final valuations by increasing property, plant and equipment by $173 million , decreasing intangible assets by $36 million , increasing goodwill by $175 million , decreasing accounts receivable, inventory, prepaid expenses and other current assets by $10 million , increasing accumulated deferred tax asset by $127 million , decreasing other noncurrent assets by $113 million , increasing trade accounts payable and other current liabilities by $89 million , increasing other noncurrent liabilities by $177 million , increasing asset retirement obligations, including amounts due currently, by $56 million , as well as other minor adjustments. The valuation revisions were a result of updated inputs used in determining the fair value of the acquired assets and liabilities. Dynegy shares outstanding as of April 9, 2018 (in millions) 144.8 Exchange Ratio 0.652 Vistra Energy shares issued for Dynegy shares outstanding (in millions) 94.4 Opening price of Vistra Energy common stock on April 9, 2018 $ 19.87 Purchase price for common stock $ 1,876 Fair value of equity component of tangible equity units $ 369 Fair value of outstanding stock compensation awards attributable to pre-combination service $ 26 Fair value of outstanding warrants $ 2 Total purchase price $ 2,273 Final Purchase Price Allocation Cash and cash equivalents $ 445 Trade accounts receivables, inventories, prepaid expenses and other current assets 853 Property, plant and equipment 10,535 Accumulated deferred income taxes 518 Identifiable intangible assets 351 Goodwill 175 Other noncurrent assets 419 Total assets acquired 13,296 Trade accounts payable and other current liabilities 733 Commodity and other derivative contractual assets and liabilities, net 422 Asset retirement obligations, including amounts due currently 475 Long-term debt, including amounts due currently 8,919 Other noncurrent liabilities 469 Total liabilities assumed 11,018 Identifiable net assets acquired 2,278 Noncontrolling interest in subsidiary 5 Total purchase price $ 2,273 Acquisition costs incurred in the Merger totaled less than $1 million and $50 million for the three months ended June 30, 2019 and 2018 , respectively, and less than $1 million and $52 million for the six months ended June 30, 2019 and 2018 , respectively. Unaudited Pro Forma Financial Information — The following unaudited pro forma financial information for the six months ended June 30, 2018 assumes that the Merger occurred on January 1, 2018. The unaudited pro forma financial information is provided for information purposes only and is not necessarily indicative of the results of operations that would have occurred had the Merger been completed on January 1, 2018, nor is the unaudited pro forma financial information indicative of future results of operations, which may differ materially from the pro forma financial information presented here. Six Months Revenues $ 4,789 Net loss $ (439 ) Net loss attributable to Vistra Energy $ (435 ) Net loss attributable to Vistra Energy per weighted average share of common stock outstanding — basic $ (0.83 ) Net loss attributable to Vistra Energy per weighted average share of common stock outstanding — diluted $ (0.83 ) The unaudited pro forma financial information presented above includes adjustments for incremental depreciation and amortization as a result of the fair value determination of the net assets acquired, interest expense on debt assumed in the Merger, effects of the Merger on tax expense (benefit), changes in the expected impacts of the tax receivable agreement due to the Merger, and other related adjustments.

Acquisition and Development of

Acquisition and Development of Generation Facilities (Notes)	6 Months Ended
	Jun. 30, 2019
Acquisition And Development Of Generation Facilities [Abstract]
Business Combination Disclosure [Text Block]	ACQUISITION AND DEVELOPMENT OF GENERATION FACILITIES Battery Energy Storage Projects We have completed the construction of our first battery energy storage system (ESS). In October 2018, we were awarded a $1 million grant from the TCEQ for our battery ESS at our Upton 2 solar facility. The grant is part of the Texas Emissions Reduction Plan. The 10 MW lithium-ion ESS captures excess solar energy produced during the day and releases the energy in late afternoon and early evening, when demand is highest. The Upton 2 battery ESS became operational in December 2018. In June 2019, East Bay Community Energy signed a ten-year contract to receive resource adequacy capacity from the planned development of a 20 MW battery ESS at our Oakland Power Plant site in California. The contract is now pending utility review and signature and will then be sent to the California Public Utilities Commission (CPUC) for approval. In June 2018, we announced that, subject to approval by the CPUC, we would enter into a 20 -year resource adequacy contract with Pacific Gas and Electric Company (PG&E) to develop a 300 MW battery ESS at our Moss Landing Power Plant site in California. PG&E filed its application with the CPUC in June 2018 and the CPUC approved the resource adequacy contract in November 2018. At June 30, 2019 , we had accumulated approximately $15 million in construction work-in-process for this ESS. We anticipate the Moss Landing battery ESS will commence commercial operations by the fourth quarter of 2020. PG&E filed for Chapter 11 bankruptcy protection in January 2019. If the terms of the resource adequacy contract are not honored by PG&E or the resource adequacy contract is rejected through the bankruptcy process, we could have future impairment losses. Upton 2 Solar Development In May 2017, we acquired the rights to develop, construct and operate a utility scale solar photovoltaic power generation facility in Upton County, Texas (Upton 2). As part of this project, we entered a turnkey engineering, procurement and construction agreement to construct the approximately 180 MW facility. During 2017 and 2018, we spent approximately $231 million related to this project primarily for progress payments under the engineering, procurement and construction agreement and the acquisition of the development rights. The facility began test operations in March 2018 and commercial operations began in June 2018.

Retirement of Generation Facili

Retirement of Generation Facilities (Notes)	6 Months Ended
	Jun. 30, 2019
Retirement of Generation Facilities [Abstract]
Retirement of generation facilities	RETIREMENT OF GENERATION FACILITIES In August 2018, we filed a notice of suspension of operation with PJM and other mandatory regulatory notifications related to the retirement of our 51 MW Northeastern Power Company waste coal facility in McAdoo, Pennsylvania (Northeastern Facility). We decided to retire the Northeastern Facility due to its uneconomic operations and financial outlook. Following the receipt of regulatory approvals, the Northeastern Facility was retired in October 2018. The decision to retire the Northeastern Facility did not result in a material impact to the financial statements, and the operational results of the Northeastern Facility are included in our Asset Closure segment. Two of our non-operated, jointly held power plants acquired in the Merger, for which our proportional generation capacity was 883 MW, were retired in May 2018. These units were retired as previously scheduled. No gain or loss was recorded in conjunction with the retirement of these units, and the operational results of these facilities are included in our Asset Closure segment. The following table details the units retired. Name Location Fuel Type Net Generation Capacity (MW) Ownership Interest Date Units Taken Offline Killen Manchester, Ohio Coal 204 33% May 31, 2018 Stuart Aberdeen, Ohio Coal 679 39% May 24, 2018 Total 883 In January and February 2018, we retired three power plants with a total installed nameplate generation capacity of 4,167 MW. We decided to retire these units because they were projected to be uneconomic based on then current market conditions and would have faced significant environmental costs associated with operating such units. In the case of the Sandow units, the decision also reflected the execution of a contract termination agreement pursuant to which the Company and Alcoa agreed to an early settlement of a long-standing power and mining agreement. Expected retirement expenses were accrued in the third and fourth quarter of 2017 and, as a result, no retirement expenses were recorded related to these facilities in the three and six months ended June 30, 2018 . The operational results of these facilities are included in our Asset Closure segment, which is engaged in the decommissioning and reclamation of retired plants and mines. The following table details the units retired. Name Location (all in the state of Texas) Fuel Type Installed Nameplate Generation Capacity (MW) Number of Units Date Units Taken Offline Monticello Titus County Lignite/Coal 1,880 3 January 4, 2018 Sandow Milam County Lignite 1,137 2 January 11, 2018 Big Brown Freestone County Lignite/Coal 1,150 2 February 12, 2018 Total 4,167 7

Revenue (Notes)

Revenue (Notes)	6 Months Ended
	Jun. 30, 2019
Revenue Recognition and Deferred Revenue [Abstract]
Revenue from Contract with Customer [Text Block]	REVENUE The following tables disaggregate our revenue by major source: Three Months Ended June 30, 2019 Retail ERCOT PJM NY/NE MISO CAISO/Eliminations Consolidated Revenue from contracts with customers: Retail energy charge in ERCOT $ 1,091 $ — $ — $ — $ — $ — $ 1,091 Retail energy charge in Northeast/Midwest 315 — — — — — 315 Wholesale generation revenue from ISO/RTO — 188 130 81 76 22 497 Capacity revenue — — 53 72 11 — 136 Revenue from other wholesale contracts — 52 87 6 41 4 190 Total revenue from contracts with customers 1,406 240 270 159 128 26 2,229 Other revenues: Intangible amortization (10 ) — — (1 ) (4 ) 1 (14 ) Hedging and other revenues (a) 25 404 81 61 26 20 617 Affiliate sales — 1,027 335 35 96 (1,493 ) — Total other revenues 15 1,431 416 95 118 (1,472 ) 603 Total revenues $ 1,421 $ 1,671 $ 686 $ 254 $ 246 $ (1,446 ) $ 2,832 ____________ (a) Includes $538 million of unrealized net gains from mark-to-market valuations of commodity positions. See Note 18 for unrealized net gains (losses) by segment. Three Months Ended June 30, 2018 Retail ERCOT PJM NY/NE MISO Asset Closure CAISO/Eliminations Consolidated Revenue from contracts with customers: Retail energy charge in ERCOT $ 1,111 $ — $ — $ — $ — $ — $ — $ 1,111 Retail energy charge in Northeast/Midwest 336 — — — — — — 336 Wholesale generation revenue from ISO/RTO — 208 367 118 180 15 13 901 Capacity revenue — — 119 82 29 10 11 251 Revenue from other wholesale contracts — 50 8 6 12 — 2 78 Total revenue from contracts with customers 1,447 258 494 206 221 25 26 2,677 Other revenues: Intangible amortization (15 ) — — (2 ) (6 ) — — (23 ) Hedging and other revenues (a) 22 229 (161 ) (29 ) (121 ) (25 ) 5 (80 ) Affiliate sales — 840 152 12 163 21 (1,188 ) — Total other revenues 7 1,069 (9 ) (19 ) 36 (4 ) (1,183 ) (103 ) Total revenues $ 1,454 $ 1,327 $ 485 $ 187 $ 257 $ 21 $ (1,157 ) $ 2,574 ____________ (a) Includes $203 million of unrealized net gains from mark-to-market valuations of commodity positions. See Note 18 for unrealized net gains (losses) by segment. Six Months Ended June 30, 2019 Retail ERCOT PJM NY/NE MISO CAISO/Eliminations Consolidated Revenue from contracts with customers: Retail energy charge in ERCOT $ 2,116 $ — $ — $ — $ — $ — $ 2,116 Retail energy charge in Northeast/Midwest 663 — — — — — 663 Wholesale generation revenue from ISO/RTO — 435 351 276 214 95 1,371 Capacity revenue — — 120 152 24 — 296 Revenue from other wholesale contracts — 97 159 12 57 6 331 Total revenue from contracts with customers 2,779 532 630 440 295 101 4,777 Other revenues: Intangible amortization (19 ) — — (3 ) (9 ) 2 (29 ) Hedging and other revenues (a) 46 562 171 113 54 61 1,007 Affiliate sales — 1,531 590 49 160 (2,330 ) — Total other revenues 27 2,093 761 159 205 (2,267 ) 978 Total revenues $ 2,806 $ 2,625 $ 1,391 $ 599 $ 500 $ (2,166 ) $ 5,755 ____________ (a) Includes $697 million of unrealized net gains from mark-to-market valuations of commodity positions. See Note 18 for unrealized net gains (losses) by segment. Six Months Ended June 30, 2018 Retail ERCOT PJM NY/NE MISO Asset Closure CAISO/Eliminations Consolidated Revenue from contracts with customers: Retail energy charge in ERCOT $ 2,059 $ — $ — $ — $ — $ — $ — $ 2,059 Retail energy charge in Northeast/Midwest 336 — — — — — — 336 Wholesale generation revenue from ISO/RTO — 383 367 118 180 51 13 1,112 Capacity revenue — — 119 82 29 10 11 251 Revenue from other wholesale contracts — 102 8 6 12 1 2 131 Total revenue from contracts with customers 2,395 485 494 206 221 62 26 3,889 Other revenues: Intangible amortization (27 ) (1 ) — (2 ) (6 ) — — (36 ) Hedging and other revenues (a) 58 (233 ) (161 ) (29 ) (121 ) (34 ) 5 (515 ) Affiliate sales — 543 152 12 163 21 (891 ) — Total other revenues 31 309 (9 ) (19 ) 36 (13 ) (886 ) (551 ) Total revenues $ 2,426 $ 794 $ 485 $ 187 $ 257 $ 49 $ (860 ) $ 3,338 ____________ (a) Includes $208 million of unrealized net losses from mark-to-market valuations of commodity positions. See Note 18 for unrealized net gains (losses) by segment. Performance Obligations As of June 30, 2019 , we have future performance obligations that are unsatisfied, or partially unsatisfied, relating to capacity auction volumes awarded through capacity auctions held by the ISO or RTO or through bilateral sales. Therefore, an obligation exists as of the date of the results of the respective ISO or RTO capacity auction or the contract execution date for bilateral customers. The transaction price is also set by the results of the capacity auction and/or executed contract. These obligations total $440 million , $770 million , $720 million , $423 million and $96 million that will be recognized in the balance of the year ended December 31, 2019 and the years ending December 31, 2020 , 2021 , 2022 and 2023 , respectively, and $65 million thereafter. Capacity revenues are recognized as capacity services are provided to the related ISOs or RTOs or bilateral counterparties. Accounts Receivable The following table presents trade accounts receivable (net of allowance for uncollectible accounts) relating to both contracts with customers and other activities: June 30, December 31, 2018 Trade accounts receivable from contracts with customers — net $ 977 $ 951 Other trade accounts receivable — net 124 136 Total trade accounts receivable — net $ 1,101 $ 1,087

Goodwill and Identifiable Intan

Goodwill and Identifiable Intangible Assets and Liabilities (Notes)	6 Months Ended
	Jun. 30, 2019
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill And Identifiable Intangible Assets	GOODWILL AND IDENTIFIABLE INTANGIBLE ASSETS AND LIABILITIES Goodwill The carrying value of goodwill totaled $2.082 billion and $2.068 billion at June 30, 2019 and December 31, 2018 , respectively. Of the total goodwill at June 30, 2019 , $175 million arose in connection with the Merger, and $122 million is recorded in our ERCOT Generation and Wholesale reporting unit and $53 million is recorded in our ERCOT Retail reporting unit. The remaining $1.907 billion arose in connection with our application of fresh start reporting at Emergence and was allocated entirely to our ERCOT Retail reporting unit. Of the goodwill recorded at Emergence, $1.686 billion is deductible for tax purposes over 15 years on a straight-line basis. Identifiable Intangible Assets and Liabilities Identifiable intangible assets are comprised of the following: June 30, 2019 December 31, 2018 Identifiable Intangible Asset Gross Carrying Amount Accumulated Amortization Net Gross Carrying Amount Accumulated Amortization Net Retail customer relationship $ 1,680 $ 987 $ 693 $ 1,680 $ 876 $ 804 Software and other technology-related assets 321 124 197 270 105 165 Retail and wholesale contracts 315 172 143 316 138 178 Contractual service agreements (a) 60 2 58 70 — 70 Other identifiable intangible assets (b) 118 74 44 42 15 27 Total identifiable intangible assets subject to amortization $ 2,494 $ 1,359 1,135 $ 2,378 $ 1,134 1,244 Retail trade names (not subject to amortization) 1,245 1,245 Mineral interests (not currently subject to amortization) 3 4 Total identifiable intangible assets $ 2,383 $ 2,493 __________ (a) At June 30, 2019 , amounts related to contractual service agreements that have become liabilities due to amortization of the economic impacts of the intangibles have been removed from both the gross carrying amount and accumulated amortization. (b) Includes mining development costs and environmental allowances and credits. Identifiable intangible liabilities are comprised of the following: Identifiable Intangible Liability June 30, December 31, 2018 Contractual service agreements $ 107 $ 136 Purchase and sale contracts 183 195 Environmental allowances 41 70 Total identifiable intangible liabilities $ 331 $ 401 Amortization expense related to finite-lived identifiable intangible assets and liabilities (including the classification in the condensed statements of consolidated income (loss)) consisted of: Identifiable Intangible Assets and Liabilities Condensed Statements of Consolidated Income (Loss) Line Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Retail customer relationship Depreciation and amortization $ 55 $ 77 $ 111 $ 150 Software and other technology-related assets Depreciation and amortization 15 19 29 30 Retail and wholesale contracts/purchase and sale contracts Operating revenues/fuel, purchased power costs and delivery fees 12 23 24 32 Other identifiable intangible assets Operating revenues/fuel, purchased power costs and delivery fees/depreciation and amortization 15 2 39 3 Total amortization expense (a) $ 97 $ 121 $ 203 $ 215 ____________ (a) Amounts recorded in depreciation and amortization totaled $72 million and $97 million for the three months ended June 30, 2019 and 2018 , respectively, and $141 million and $182 million for the six months ended June 30, 2019 and 2018 , respectively. Excludes contractual services agreements. Estimated Amortization of Identifiable Intangible Assets and Liabilities As of June 30, 2019 , the estimated aggregate amortization expense of identifiable intangible assets and liabilities for each of the next five fiscal years is as shown below. Year Estimated Amortization Expense 2019 $ 309 2020 $ 211 2021 $ 164 2022 $ 101 2023 $ 76

Income Taxes (Notes)

Income Taxes (Notes)	6 Months Ended
	Jun. 30, 2019
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES Income Tax Expense The calculation of our effective tax rate is as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Income (loss) before income taxes $ 502 $ 31 $ 803 $ (364 ) Income tax (expense) benefit $ (148 ) $ 74 $ (225 ) $ 163 Effective tax rate 29.5 % (238.7 )% 28.0 % 44.8 % For the three months ended June 30, 2019 , the effective tax rate of 29.5% related to our income tax expense was higher than the U.S. federal statutory rate of 21% due primarily to nondeductible impacts of the TRA and state income taxes, including the impact of a partial valuation allowance on the state of Illinois net operating loss. For the six months ended June 30, 2019 , the effective tax rate of 28.0% related to our income tax expense was higher than the U.S. federal statutory rate of 21% due primarily to nondeductible impacts of the TRA and state income taxes, including the impact of a partial valuation allowance on the state of Illinois net operating loss. For the three months ended June 30, 2018 , the effective tax rate of (238.7)% related to our income tax benefit was lower than the U.S. federal statutory rate of 21% due primarily to Vistra Energy's expanded state tax footprint requiring a one-time remeasurement of historical Vistra Energy deferred tax balances, partially offset by an increase in state tax expense. For the six months ended June 30, 2018 , the effective tax rate of 44.8% related to our income tax benefit was higher than the U.S. federal statutory rate of 21% due primarily to Vistra Energy's expanded state tax footprint requiring a one-time remeasurement of historical Vistra Energy deferred tax balances and an increase in state tax expense. Liability for Uncertain Tax Positions Vistra Energy and its subsidiaries file income tax returns in U.S. federal and state jurisdictions and are expected to be subject to examinations by the IRS and other taxing authorities. Vistra Energy is not currently under audit by the IRS for any period, although review of Dynegy tax years 2017 and 2018 continue to progress through the IRS's Compliance Assurance Process audit program. Uncertain tax positions totaling $39 million at both June 30, 2019 and December 31, 2018 arose in connection with the Merger.

Tax Receivable Agreement Obliga

Tax Receivable Agreement Obligation (Notes)	6 Months Ended
	Jun. 30, 2019
Income Tax Disclosure [Abstract]
Tax Receivables Agreement Obligation	TAX RECEIVABLE AGREEMENT OBLIGATION On the Effective Date, Vistra Energy entered into a tax receivable agreement (the TRA) with a transfer agent on behalf of certain former first lien creditors of TCEH. The TRA generally provides for the payment by us to holders of TRA Rights of 85% of the amount of cash savings, if any, in U.S. federal and state income tax that we realize in periods after Emergence as a result of (a) certain transactions consummated pursuant to the Plan of Reorganization (including the step-up in tax basis in our assets resulting from the PrefCo Preferred Stock Sale), (b) the tax basis of all assets acquired in connection with the acquisition of two CCGT natural gas-fueled generation facilities in April 2016 and (c) tax benefits related to imputed interest deemed to be paid by us as a result of payments under the TRA, plus interest accruing from the due date of the applicable tax return. Pursuant to the TRA, we issued the TRA Rights for the benefit of the first lien secured creditors of TCEH entitled to receive such TRA Rights under the Plan of Reorganization. Such TRA Rights are entitled to certain registration rights more fully described in the Registration Rights Agreement (see Note 17 ). During the three months ended June 30, 2019, we recorded a decrease to the carrying value of the TRA obligation totaling approximately $48 million as a result of the decrease in forecasted taxable income over the projected life of the TRA. During the three months ended March 31, 2019, we recorded a decrease to the carrying value of the TRA obligation totaling approximately $19 million as a result of adjustments to forecasted taxable income and higher net operating losses acquired in the Merger. During the three months ended June 30, 2018, we recorded an increase to the carrying value of the TRA obligation totaling approximately $46 million related to changes in the timing of estimated payments and new multistate tax impacts resulting from the Merger. The following table summarizes the changes to the TRA obligation, reported as other current liabilities and Tax Receivable Agreement obligation in our condensed consolidated balance sheets, for the six months ended June 30, 2019 and 2018 : Six Months Ended June 30, 2019 2018 TRA obligation at the beginning of the period $ 420 $ 357 Accretion expense 31 36 Changes in tax assumptions impacting timing of payments (67 ) 46 Impacts of Tax Receivable Agreement (36 ) 82 TRA obligation at the end of the period 384 439 Less amounts due currently — (25 ) Noncurrent TRA obligation at the end of the period $ 384 $ 414 As of June 30, 2019 , the estimated carrying value of the TRA obligation totaled $384 million , which represents the discounted amount of projected payments under the TRA. The projected payments are based on certain assumptions, including but not limited to (a) the federal corporate income tax rate of 21% , (b) estimates of our taxable income in the current and future years and (c) additional states that Vistra Energy now operates in, including the relevant tax rate and apportionment factor for each state. Our taxable income takes into consideration the current federal tax code, various relevant state tax laws and reflects our current estimates of future results of the business. These assumptions are subject to change, and those changes could have a material impact on the carrying value of the TRA obligation. As of June 30, 2019 , the aggregate amount of undiscounted federal and state payments under the TRA is estimated to be approximately $1.3 billion , with more than half of such amount expected to be attributable to the first 15 tax years following Emergence, and the final payment expected to be made approximately 40 years following Emergence (if the TRA is not terminated earlier pursuant to its terms). The carrying value of the obligation is being accreted to the amount of the gross expected obligation using the effective interest method. Changes in the amount of this obligation resulting from changes to either the timing or amount of TRA payments are recognized in the period of change and measured using the discount rate inherent in the initial fair value of the obligation.

Earnings Per Share (Notes)

Earnings Per Share (Notes)	6 Months Ended
	Jun. 30, 2019
Earnings Per Share [Abstract]
Earnings Per Share	EARNINGS PER SHARE Basic earnings per share available to common shareholders are based on the weighted average number of common shares outstanding during the period. Diluted earnings per share is calculated using the treasury stock method and includes the effect of all potential issuances of common shares under stock-based incentive compensation arrangements. Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Net income (loss) attributable to common stock — basic $ 356 $ 108 $ 581 $ (198 ) Weighted average shares of common stock outstanding — basic (a) 499,778,235 526,332,862 499,213,522 477,662,016 Net income (loss) per weighted average share of common stock outstanding — basic $ 0.71 $ 0.21 $ 1.16 $ (0.41 ) Dilutive securities: Stock-based incentive compensation plan and tangible equity units 7,722,148 7,453,962 8,035,398 — Weighted average shares of common stock outstanding — diluted 507,500,383 533,786,824 507,248,920 477,662,016 Net income (loss) per weighted average share of common stock outstanding — diluted $ 0.70 $ 0.20 $ 1.15 $ (0.41 ) ____________ (a) The minimum settlement amount of tangible equity units, or 15,207,600 shares in both the three and six months ended June 30, 2019 and 15,056,260 shares in both the three and six months ended June 30, 2018 , are considered to be outstanding and are included in the computation of basic net income per share (see Note 14 ). Stock-based incentive compensation plan awards excluded from the calculation of diluted earnings per share because the effect would have been antidilutive totaled 2,910,226 and 8,064,657 shares for the three months ended June 30, 2019 and 2018 , respectively, and 7,577,246 and 18,392,470 shares for the six months ended June 30, 2019 and 2018 , respectively.

Accounts Receivable Securitizat

Accounts Receivable Securitization Program (Notes)	6 Months Ended
	Jun. 30, 2019
Accounts Receivable Securitization Program [Abstract]
Accounts Receivable Securitization Program [Text Block]	ACCOUNTS RECEIVABLE SECURITIZATION PROGRAM TXU Energy Receivables Company LLC (RecCo), an indirect subsidiary of Vistra Energy, has an accounts receivable financing facility (Receivables Facility) provided by issuers of asset-backed commercial paper and commercial banks (Purchasers). At June 30, 2019, the Receivables Facility provided RecCo with the ability to borrow up to $450 million , pursuant to an amendment to the terms of the Receivables Facility in April 2019. The Receivables Facility was renewed in July 2019, extending its scheduled termination from August 2019 to July 2020, with the ability to borrow up to $600 million until the settlement date in November 2019, after which the amount available for RecCo to borrow will revert to $450 million . Under the Receivables Facility, TXU Energy and Dynegy Energy Services are obligated to sell or contribute, on an ongoing basis and without recourse, their accounts receivable to TXU Energy's special purpose subsidiary, RecCo, a consolidated, wholly owned, bankruptcy-remote, direct subsidiary of TXU Energy. RecCo, in turn, is subject to certain conditions, and may, from time to time, sell an undivided interest in all the receivables acquired from TXU Energy and Dynegy Energy Services to the Purchasers, and its assets and credit are not available to satisfy the debts and obligations of any person, including affiliates of RecCo. Amounts funded by the Purchasers to RecCo are reflected as short-term borrowings on the condensed consolidated balance sheets. Proceeds and repayments under the Receivables Facility are reflected as cash flows from financing activities in our condensed statements of consolidated cash flows. Receivables transferred to the Purchasers remain on Vistra Energy's balance sheet and Vistra Energy reflects a liability equal to the amount advanced by the Purchasers. The Company records interest expense on amounts advanced. TXU Energy continues to service, administer and collect the trade receivables on behalf of RecCo and the Purchasers, as applicable. As of June 30, 2019 , outstanding borrowings under the receivables facility totaled $430 million and were supported by $662 million of RecCo gross receivables. As of December 31, 2018 , outstanding borrowings under the receivables facility totaled $339 million .

Long-Term Debt (Notes)

Long-Term Debt (Notes)	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Long-Term Debt	LONG-TERM DEBT Amounts in the table below represent the categories of long-term debt obligations incurred by the Company. June 30, December 31, Vistra Operations Credit Facilities $ 3,798 $ 5,813 Vistra Operations Senior Secured Notes: 3.550% Senior Secured Notes, due July 15, 2024 1,200 — 4.300% Senior Secured Notes, due July 15, 2029 800 — Total Vistra Operations Senior Secured Notes 2,000 — Vistra Operations Senior Unsecured Notes: 5.500% Senior Notes, due September 1, 2026 1,000 1,000 5.625% Senior Notes, due February 15, 2027 1,300 — 5.000% Senior Notes, due July 31, 2027 1,300 — Total Vistra Operations Senior Unsecured Notes 3,600 1,000 Vistra Energy Senior Unsecured Notes: 7.375% Senior Notes, due November 1, 2022 306 1,707 5.875% Senior Notes, due June 1, 2023 500 500 7.625% Senior Notes, due November 1, 2024 475 1,147 8.034% Senior Notes, due February 2, 2024 — 25 8.000% Senior Notes, due January 15, 2025 81 81 8.125% Senior Notes, due January 30, 2026 166 166 Total Vistra Energy Senior Unsecured Notes 1,528 3,626 Other: 7.000% Amortizing Notes, due July 1, 2019 8 24 Forward Capacity Agreements 222 236 Equipment Financing Agreements 114 120 Mandatorily redeemable subsidiary preferred stock (a) 70 70 8.82% Building Financing due semiannually through February 11, 2022 (b) 18 21 Total other long-term debt 432 471 Unamortized debt premiums, discounts and issuance costs (c) (4 ) 155 Total long-term debt including amounts due currently 11,354 11,065 Less amounts due currently (161 ) (191 ) Total long-term debt less amounts due currently $ 11,193 $ 10,874 ____________ (a) Shares of mandatorily redeemable preferred stock in PrefCo. This subsidiary preferred stock is accounted for as a debt instrument under relevant accounting guidance. At any time after October 3, 2019, Vistra Energy may redeem all or any portion of the preferred stock for a price per share equal to the preferred liquidation amount. (b) Obligation related to a corporate office space finance lease. This obligation will be funded by amounts held in an escrow account that is reflected in other noncurrent assets in our condensed consolidated balance sheets. (c) Includes impact of recording debt assumed in the Merger at fair value. Vistra Operations Credit Facilities At June 30, 2019 , the Vistra Operations Credit Facilities consisted of up to $6.523 billion in senior secured, first lien revolving credit commitments and outstanding term loans, which consisted of revolving credit commitments of up to $2.725 billion , including a $2.35 billion letter of credit sub-facility (Revolving Credit Facility) and term loans of $1.897 billion (Term Loan B-1 Facility) and $1.901 billion (Term Loan B-3 Facility). In June 2019, Vistra Operations used the net proceeds from the Senior Secured Notes Offering described below to repay $889 million under the Term Loan B-1 Facility, the entire amount outstanding of $977 million under Term Loan B-2 Facility (and together with the Term Loan B-1 Facility and the Term Loan B-3 Facility, the Term Loan B Facility) and $134 million under the Term Loan B-3 Facility. We recorded an extinguishment loss of $4 million on the transactions in the three months ended June 30, 2019 . These amounts reflect amendments to the Vistra Operations Credit Facilities in March 2019 and May 2019 whereby we obtained $225 million of incremental Revolving Credit Facility commitments. The letter of credit sub-facility was also increased by $50 million . Fees and expenses related to the amendments to the Vistra Operations Credit Facilities totaled $2 million in the six months ended June 30, 2019 , which were capitalized as a noncurrent asset. These amounts also reflect an amendment to the Vistra Operations Credit Facilities in June 2018 whereby we incurred $2.050 billion of borrowings under the new Term Loan B-3 Facility and obtained $1.640 billion of incremental Revolving Credit Facility commitments. The letter of credit sub-facility was also increased by $1.585 billion . The maturity date of the Revolving Credit Facility was extended from August 4, 2021 to June 14, 2023. As discussed below, the proceeds from the Term Loan B-3 Facility were used to repay borrowings under the credit agreement that Vistra Energy assumed from Dynegy in connection with the Merger. Additionally, letter of credit term loans totaling $500 million (Term Loan C Facility) were repaid using $500 million of cash from collateral accounts used to backstop letters of credit. Fees and expenses related to the amendment to the Vistra Operations Credit Facilities totaled $42 million in the six months ended June 30, 2018 , of which $23 million was recorded as interest expense and other charges on the statements of consolidated income (loss), $9 million was capitalized as a reduction in the carrying amount of the debt and $10 million was capitalized as a noncurrent asset. The Vistra Operations Credit Facilities and related available capacity at June 30, 2019 are presented below. June 30, 2019 Vistra Operations Credit Facilities Maturity Date Facility Limit Cash Borrowings Available Capacity Revolving Credit Facility (a) June 14, 2023 $ 2,725 $ — $ 2,173 Term Loan B-1 Facility August 4, 2023 1,897 1,897 — Term Loan B-3 Facility December 31, 2025 1,901 1,901 — Total Vistra Operations Credit Facilities $ 6,523 $ 3,798 $ 2,173 ___________ (a) Facility to be used for general corporate purposes. Facility includes a $2.35 billion letter of credit sub-facility, of which $552 million of letters of credit were outstanding at June 30, 2019 and which reduce our available capacity. In February 2018 and June 2018, certain pricing terms for the Vistra Operations Credit Facilities were amended. We accounted for these transactions as modifications of debt. At June 30, 2019 , cash borrowings under the Revolving Credit Facility would bear interest based on applicable LIBOR rates, plus a fixed spread of 1.75% , and there were no outstanding borrowings. Letters of credit issued under the Revolving Credit Facility bear interest of 1.75% . Amounts borrowed under the Term Loan B-1 and B-3 Facilities bear interest based on applicable LIBOR rates plus fixed spreads of 2.00% and 2.00% , respectively. At June 30, 2019 , the weighted average interest rates before taking into consideration interest rate swaps on outstanding borrowings was 4.40% and 4.40% under the Term Loan B-1 and B-3 Facilities, respectively. The Vistra Operations Credit Facilities also provide for certain additional fees payable to the agents and lenders, including fronting fees with respect to outstanding letters of credit and availability fees payable with respect to any unused portion of the available Revolving Credit Facility. Obligations under the Vistra Operations Credit Facilities are secured by a lien covering substantially all of Vistra Operations' (and its subsidiaries') consolidated assets, rights and properties, subject to certain exceptions set forth in the Vistra Operations Credit Facilities, provided that the amount of loans outstanding under the Vistra Operations Credit Facilities that may be secured by a lien covering certain principal properties of the Company is expressly limited by the terms of the Vistra Operations Credit Facilities. The Vistra Operations Credit Facilities also permit certain hedging agreements to be secured on a pari-passu basis with the Vistra Operations Credit Facilities in the event those hedging agreements met certain criteria set forth in the Vistra Operations Credit Facilities. The Vistra Operations Credit Facilities provide for affirmative and negative covenants applicable to Vistra Operations (and its restricted subsidiaries), including affirmative covenants requiring it to provide financial and other information to the agents under the Vistra Operations Credit Facilities and to not change its lines of business, and negative covenants restricting Vistra Operations' (and its restricted subsidiaries') ability to incur additional indebtedness, make investments, dispose of assets, pay dividends, grant liens or take certain other actions, in each case, except as permitted in the Vistra Operations Credit Facilities. Vistra Operations' ability to borrow under the Vistra Operations Credit Facilities is subject to the satisfaction of certain customary conditions precedent set forth therein. The Vistra Operations Credit Facilities provide for certain customary events of default, including events of default resulting from non-payment of principal, interest or fees when due, material breaches of representations and warranties, material breaches of covenants in the Vistra Operations Credit Facilities or ancillary loan documents, cross-defaults under other agreements or instruments and the entry of material judgments against Vistra Operations. Solely with respect to the Revolving Credit Facility, and solely during a compliance period (which, in general, is applicable when the aggregate revolving borrowings and issued revolving letters of credit (in excess of $300 million ) exceed 30% of the revolving commitments), the agreement includes a covenant that requires the consolidated first lien net leverage ratio, which is based on the ratio of net first lien debt compared to an EBITDA calculation defined under the terms of the facilities, not to exceed 4.25 to 1.00. Although the period ended June 30, 2019 was not a compliance period, we would have been in compliance with this financial covenant if it was required to be tested at such date. Upon the existence of an event of default, the Vistra Operations Credit Facilities provide that all principal, interest and other amounts due thereunder will become immediately due and payable, either automatically or at the election of specified lenders. Interest Rate Swaps — Effective January 2017, we entered into $3.0 billion notional amount of interest rate swaps to hedge a portion of our exposure to our variable rate debt. The interest rate swaps expire in July 2023. In May 2018 and June 2018, we entered into $3.0 billion notional amount of interest rate swaps that become effective in July 2023 and expire in July 2026. In June 2018, we completed the novation of $1.959 billion notional amount of Vistra Energy (legacy Dynegy) interest rate swaps to Vistra Operations. In June 2019, we terminated $841 million notional amount of these interest rate swaps. At June 30, 2019 , $720 million notional amount of these interest rate swaps remained in effect with an expiration date of February 2024. The interest rate swaps that are currently effective and expire in July 2023 and February 2024 effectively fix the interest rates between 3.92% and 4.16% on $3.720 billion of our variable rate debt. The interest rate swaps that become effective in July 2023 and expire in July 2026 effectively fix the interest rates between 4.97% and 5.04% on $3.0 billion of our variable rate debt during the period. The interest rate swaps are secured by a first lien secured interest on a pari-passu basis with the Vistra Operations Credit Facilities. Alternate Letter of Credit Facilities Two alternate letter of credit facilities (each, an Alternative LOC Facility, and collectively, the Alternate LOC Facilities) with an aggregate facility limit of $500 million became effective in the six months ended June 30, 2019 . At June 30, 2019 , $500 million of letters of credit were outstanding under the Alternate LOC Facilities. Of the total facility limit, $250 million matures in December 2020 and $250 million matures in December 2021. Vistra Energy (legacy Dynegy) Credit Agreement On the Merger Date, Vistra Energy assumed the obligations under Dynegy's $3.563 billion credit agreement consisting of a $2.018 billion senior secured term loan facility due 2024 and a $1.545 billion senior secured revolving credit facility. As of the Merger Date, there were no cash borrowings and $656 million of letters of credit outstanding under the senior secured revolving credit facility. On April 23, 2018, $70 million of the senior secured revolving credit facility matured. In June 2018, the $2.018 billion senior secured term loan facility due 2024 was repaid using proceeds from the Term Loan B-3 Facility. In addition, all letters of credit outstanding under the senior secured revolving credit facility were replaced with letters of credit under the amended Vistra Operations Credit Facilities discussed above, and the revolving credit facility assumed from Dynegy in connection with the Merger was paid off in full and terminated. Vistra Operations Senior Secured Notes In June 2019, Vistra Operations issued and sold $2.0 billion aggregate principal amount of senior secured notes (Senior Secured Notes), consisting of $1.2 billion aggregate principal amount of 3.55% senior secured notes due 2024 (3.55% senior secured notes) at a price to the public of 99.807% of their face value and $800 million aggregate principal amount of 4.30% senior secured notes due 2029 (4.30% senior secured notes) at a price to the public of 99.784% of their face value in an offering to eligible purchasers under Rule 144A and Regulation S under the Securities Act (Senior Secured Notes Offering). The Senior Secured Notes were sold pursuant to a purchase agreement by and among Vistra Operations, certain direct and indirect subsidiaries of Vistra Operations and Citigroup Global Markets Inc., as representative of the several initial purchasers. Fees and expenses related to the offering totaled $20 million in the three months ended June 30, 2019 , which were capitalized as a reduction in the carrying amount of the debt. Net proceeds from the Senior Secured Notes Offering totaling $1.976 billion , together with cash on hand, were used to prepay certain amounts outstanding and accrued interest (together with fees and expenses) under the Vistra Operations Credit Facilities' Term Loan B Facility. Interest on the Senior Secured Notes is payable in cash semiannually in arrears on January 15 and July 15 beginning January 15, 2020. The Senior Secured Notes are and will be fully and unconditionally guaranteed by certain of Vistra Operations' current and future subsidiaries that also guarantee the Vistra Operations Credit Facilities. The Senior Secured Notes are secured by a first-priority security interest in the same collateral that is pledged for the benefit of the lenders under the Vistra Operations Credit Facilities, which consists of a substantial portion of the property, assets and rights owned by Vistra Operations and certain direct and indirect subsidiaries of Vistra Operations as subsidiary guarantors (collectively, the Guarantor Subsidiaries) as well as the stock of Vistra Operations held by Vistra Intermediate. The collateral securing the Senior Secured Notes will be released if Vistra Operations' senior, unsecured long-term debt securities obtain an investment grade rating from two out of the three rating agencies, subject to reversion if such rating agencies withdraw the investment grade rating of Vistra Operations' senior, unsecured long-term debt securities or downgrade such rating below investment grade. Vistra Operations Senior Unsecured Notes In June 2019, Vistra Operations issued and sold $1.3 billion aggregate principal amount of 5.00% senior unsecured notes due 2027 (5.00% senior notes) in an offering to eligible purchasers under Rule 144A and Regulation S under the Securities Act (the June 2019 Notes Offering). The 5.00% senior notes were sold pursuant to a purchase agreement by and among Vistra Operations, the Guarantor Subsidiaries and Goldman Sachs & Co. LLC, as representative of the several initial purchasers. Fees and expenses related to the offering totaled $13 million in the three months ended June 30, 2019 , which were capitalized as a reduction in the carrying amount of the debt. Net proceeds from the June 2019 Notes Offering totaling approximately $1.287 billion , together with cash on hand, were used to pay the purchase price and accrued interest (together with fees and expenses) required in connection with (i) the June 2019 Tender Offer described below and (ii) the redemption of approximately $306 million of our outstanding 7.375% senior unsecured notes due 2022 (7.375% senior notes) and approximately $87 million of our 7.625% senior unsecured notes due 2024 (7.625% senior notes) in July 2019. The 5.00% senior notes mature in July 2027, with interest payable in cash semiannually in arrears on January 31and July 31 beginning January 31, 2020. In February 2019, Vistra Operations issued and sold $1.3 billion aggregate principal amount of 5.625% senior unsecured notes due 2027 (5.625% senior notes) in an offering to eligible purchasers under Rule 144A and Regulation S under the Securities Act (the February 2019 Notes Offering). The 5.625% senior notes were sold pursuant to a purchase agreement by and among Vistra Operations, the Guarantor Subsidiaries and J.P. Morgan Securities LLC, as representative of the several initial purchasers. Fees and expenses related to the offering totaled $16 million in the three months ended March 31, 2019, which were capitalized as a reduction in the carrying amount of the debt. Net proceeds from the February 2019 Notes Offering totaling approximately $1.287 billion , together with cash on hand, were used to pay the purchase price and accrued interest (together with fees and expenses) required in connection with (i) the February 2019 Tender Offer described below, (ii) the redemption of approximately $35 million aggregate principal amount of our 7.375% senior notes and (iii) the redemption of approximately $25 million aggregate principal amount of our outstanding 8.034% senior unsecured notes due 2024 (8.034% senior notes). The 5.625% senior notes mature in February 2027, with interest payable in cash semiannually in arrears on February 15 and August 15 beginning August 15, 2019. In August 2018, Vistra Operations issued $1.0 billion principal amount of 5.500% senior unsecured notes due 2026 (5.500% senior notes, and together with the 5.00% senior notes and the 5.625% senior notes, the Vistra Operations Senior Unsecured Notes) in an offering to eligible purchasers under Rule 144A and Regulation S under the Securities Act (the 2018 Notes Offering). The 5.500% senior notes were sold pursuant to a purchase agreement by and among Vistra Operations, the Guarantor Subsidiaries and Citigroup Global Markets Inc., as representative of the several initial purchasers. Fees and expenses related to the offering totaled $12 million in the three months ended September 30, 2018, which were capitalized as a reduction in the carrying amount of the debt. Net proceeds from the 2018 Notes Offering totaling approximately $990 million , together with cash on hand and cash received from the funding of the Receivables Facility (see Note 10 ), were used to pay the purchase price and accrued interest (together with fees and expenses) required in connection with the 2018 Tender Offers described below. The 5.500% senior notes mature in September 2026, with interest payable in cash semiannually in arrears on March 1 and September 1 beginning March 1, 2019. The indentures governing the 5.00% senior notes, the 5.625% senior notes and the 5.500% senior notes (collectively, as each may be amended or supplemented from time to time, the Vistra Operations Senior Unsecured Indentures) provide for the full and unconditional guarantee by the Guarantor Subsidiaries of the punctual payment of the principal and interest on such notes. The Vistra Operations Senior Unsecured Indentures contain certain covenants and restrictions, including, among others, restrictions on the ability of the Issuer and its subsidiaries, as applicable, to create certain liens, merge or consolidate with another entity, and sell all or substantially all of their assets. Vistra Energy Senior Unsecured Notes Bond Repurchase Program — In November 2018, our board of directors (the Board) authorized a bond repurchase program under which up to $200 million principal amount of outstanding Vistra Energy Senior Unsecured Notes could be repurchased. Through June 30, 2019 , $119 million principal amount of Vistra Energy Senior Unsecured Notes had been repurchased. No repurchases were made in the three and six months ended June 30, 2019 . June 2019 Tender Offer — In June 2019, Vistra Energy used the net proceeds from the June 2019 Notes Offering to fund a cash tender offer (the June 2019 Tender Offer) to purchase for cash $845 million aggregate principal amount of certain notes assumed in the Merger, including $173 million of 7.375% senior notes and $672 million of 7.625% senior notes. We recorded an extinguishment gain of $7 million on the transactions in the three months ended June 30, 2019 . In July 2019, Vistra Energy accepted and settled an additional approximately $1 million aggregate principal amount of outstanding 7.625% senior notes that were tendered after the early tender date of the 2019 Tender Offer. February 2019 Tender Offer and Consent Solicitation — In February 2019, Vistra Energy used the net proceeds from the February 2019 Notes Offering to fund a cash tender offer (the February 2019 Tender Offer) to purchase for cash $1.193 billion aggregate principal amount of 7.375% senior notes assumed in the Merger. We recorded an extinguishment gain of $7 million on the transactions in the three months ended March 31, 2019. In connection with the February 2019 Tender Offer, Vistra Energy also commenced solicitation of consents from holders of the 7.375% senior notes. Vistra Energy received the requisite consents from the holders of the 7.375% senior notes and amended the indenture governing these senior notes to, among other things, eliminate substantially all of the restrictive covenants and certain events of default. August 2018 Tender Offers and Consent Solicitations — In August 2018, Vistra Energy used the net proceeds from the 2018 Notes Offering, proceeds from the Receivables Facility (see Note 10 ) and cash on hand to fund cash tender offers (the 2018 Tender Offers) to purchase for cash $1.542 billion aggregate principal amount of Vistra Energy Senior Unsecured Notes assumed in the Merger. We recorded an extinguishment loss of $27 million on the transactions in the three months ended September 30, 2018. Notes purchased consisted of the following: • $26 million of 7.625% senior notes; • $163 million of 8.034% senior notes; • $669 million of 8.000% senior unsecured notes due 2025 (8.000% senior notes), and • $684 million of 8.125% senior unsecured notes due 2026 (8.125% senior notes). In connection with the 2018 Tender Offers, Vistra Energy also commenced solicitations of consents from holders of the 7.375% senior notes, the 7.625% senior notes, the 8.034% senior notes, the 8.000% senior notes and the 8.125% senior notes to amend certain provisions of the applicable indentures governing each series of senior notes and the registration rights agreement with respect to the 8.125% senior notes. Vistra Energy received the requisite consents from the holders of the 8.034% senior notes, the 8.000% senior notes and the 8.125% senior notes (collectively, the Consent Senior Notes) and amended (a) the indentures governing each series of the applicable senior notes to, among other things, eliminate substantially all of the restrictive covenants and certain events of default and (b) the registration rights agreement with respect to the 8.125% senior notes to remove, among other things, the requirement that Vistra Energy commence an exchange offer to issue registered securities in exchange for the existing, nonregistered notes. Assumption of Senior Notes in Merger — On the Merger Date, Vistra Energy assumed $6.138 billion principal amount of Dynegy's senior unsecured notes. In May 2018, $850 million of outstanding 6.75% senior unsecured notes due 2019 were redeemed at a redemption price of 101.688% of the aggregate principal amount, plus accrued and unpaid interest up to but not including the date of redemption. Fees and expenses related to the redemption totaled $14 million in the three months ended June 30, 2018 and were recorded as interest expense and other charges on the condensed statements of consolidated income (loss). In June 2018, each of the Company's subsidiaries that guaranteed the Vistra Operations Credit Facilities (and did not already guarantee the senior notes) provided a guarantee on the senior notes that remained outstanding. The senior notes that remain outstanding after the closing of the Tender Offers are unsecured and unsubordinated obligations of Vistra Energy and are guaranteed by substantially all of its current and future wholly owned domestic subsidiaries that from time to time are a borrower or guarantor under the agreement governing the Vistra Operations Credit Facilities (Credit Facilities Agreement) (see Note 20 ). Except with respect to the Consent Senior Notes, the respective indentures of the senior notes of Vistra Energy (collectively, as each may be amended or supplemented from time to time, the Vistra Energy Senior Unsecured Indentures) limit, among other things, the ability of the Company or any of the guarantors to create liens upon any principal property to secure debt for borrowed money in excess of, among other limitations, 30% of total assets. The Vistra Energy Senior Unsecured Indentures also contain customary events of default which would permit the holders of the applicable series of senior notes to declare such notes to be immediately due and payable if not cured within applicable grace periods, including the failure to make timely principal or interest payments on such notes or (except with respect to the Consent Senior Notes) other indebtedness aggregating $100 million or more, and, except with respect to the Consent Senior Notes, the failure to satisfy covenants, and specified events of bankruptcy and insolvency. Amortizing Notes On the Merger Date, Vistra Energy assumed the obligations of Dynegy's senior unsecured amortizing note (Amortizing Notes) that matured on July 1, 2019. The Amortizing Notes were issued in connection with the issuance of the tangible equity units (TEUs) by Dynegy (see Note 14 ). Each installment payment per Amortizing Note was paid in cash and constituted a partial repayment of principal and a payment of interest, computed at an annual rate of 7.00%. Interest was calculated on the basis of a 360-day year consisting of twelve 30-day months. Payments were applied first to the interest due and payable and then to the reduction of the unpaid principal amount, allocated as set forth in the indenture (Amortizing Notes Indenture). On the maturity date, the Company paid all amounts due under the Amortizing Notes Indenture and the Amortizing Notes Indenture ceased to be of further force and effect. Forward Capacity Agreements On the Merger Date, the Company assumed the obligation of Dynegy's agreements under which a portion of the PJM capacity that cleared for Planning Years 2018-2019, 2019-2020 and 2020-2021 was sold to a financial institution (Forward Capacity Agreements). The buyer in this transaction will receive capacity payments from PJM during the Planning Years 2019-2020 and 2020-2021 in the amounts of $112 million and $110 million , respectively. We will continue to be subject to the performance obligations as well as any associated performance penalties and bonus payments for those planning years. As a result, this transaction is accounted for as long-term debt of $222 million with an implied interest rate of 3.36% . Equipment Financing Agreements On the Merger Date, the Company assumed Dynegy's Equipment Financing Agreements. Under certain of our contractual service agreements in which we receive maintenance and capital improvements for our gas-fueled generation fleet, we have obtained parts and equipment intended to increase the output, efficiency and availability of our generation units. We have financed these parts and equipment under agreements with maturities ranging from 2019 to 2026. The portion of future payments attributable to principal will be classified as cash outflows from financing activities, and the portion of future payments attributable to interest will be classified as cash outflows from operating activities in our condensed statements of consolidated cash flows. Maturities Long-term debt maturities (including mandatory amortization of the Term Loan B Facility) at June 30, 2019 are as follows: June 30, 2019 Remainder of 2019 $ 93 2020 144 2021 70 2022 321 2023 2,408 Thereafter 8,322 Unamortized premiums, discounts and debt issuance costs (4 ) Total long-term debt, including amounts due currently $ 11,354

Leases

Leases	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
Leases	LEASES Vistra has operating leases for real estate, rail cars, rental tanks and equipment. Our leases have remaining lease terms for 1 to 38 years . Our leases include options to renew up to 14 years . Certain leases also contain options to terminate the lease. Lease Cost The following table presents costs related to lease activities: Three Months Six Months Operating lease cost $ 3 $ 7 Finance lease: Finance lease right-of-use asset amortization 1 2 Interest on lease liabilities 1 1 Total finance lease cost 2 3 Variable lease cost (a) 6 12 Short-term lease cost 8 13 Sublease income (b) (2 ) (4 ) Net lease cost $ 17 $ 31 ____________ (a) Represents coal stockpile management services, common area maintenance services and rail car payments based on the number of rail cars used. (b) Represents sublease income related to real estate leases. Balance Sheet Information The following table presents lease related balance sheet information: June 30, 2019 Lease assets Operating lease right-of-use assets $ 34 Finance lease right-of-use assets (net of accumulated depreciation) 61 Total lease right-of-use assets 95 Current lease liabilities Operating lease liabilities 13 Finance lease liabilities 5 Total current lease liabilities 18 Noncurrent lease liabilities Operating lease liabilities 40 Finance lease liabilities 74 Total noncurrent lease liabilities 114 Total lease liabilities $ 132 Cash Flow and Other Information The following table presents lease related cash flow and other information: Six Months Cash paid for amounts included in the measurement of lease liabilities Operating cash flows from operating leases $ 7 Operating cash flow from finance leases 2 Finance cash flow from finance leases 1 Non-cash disclosure upon commencement of new lease Right-of-use assets obtained in exchange for new operating lease liabilities 72 Right-of-use assets obtained in exchange for new finance lease liabilities 15 Non-cash disclosure upon modification of existing lease Modification of operating lease right-of-use assets (36 ) Modification of finance lease right-of-use assets 50 Weighted Average Remaining Lease Term The following table presents weighted average remaining lease term information: June 30, 2019 Weighted average remaining lease term Operating lease 8 years Finance lease 18 years Weighted average discount rate Operating lease 6.04% Finance lease 6.07% Maturity of Lease Liabilities The following table presents maturity of lease liabilities: Operating lease Finance lease Total lease Remainder of 2019 $ 7 $ 4 $ 11 2020 14 9 23 2021 9 9 18 2022 7 9 16 2023 6 9 15 Thereafter 22 79 101 Total lease payments 65 119 184 Less: Interest (12 ) (40 ) (52 ) Present value of lease liabilities $ 53 $ 79 $ 132 As of June 30, 2019 , we have no material operating or finance leases that have not yet commenced.
Leases	LEASES Vistra has operating leases for real estate, rail cars, rental tanks and equipment. Our leases have remaining lease terms for 1 to 38 years . Our leases include options to renew up to 14 years . Certain leases also contain options to terminate the lease. Lease Cost The following table presents costs related to lease activities: Three Months Six Months Operating lease cost $ 3 $ 7 Finance lease: Finance lease right-of-use asset amortization 1 2 Interest on lease liabilities 1 1 Total finance lease cost 2 3 Variable lease cost (a) 6 12 Short-term lease cost 8 13 Sublease income (b) (2 ) (4 ) Net lease cost $ 17 $ 31 ____________ (a) Represents coal stockpile management services, common area maintenance services and rail car payments based on the number of rail cars used. (b) Represents sublease income related to real estate leases. Balance Sheet Information The following table presents lease related balance sheet information: June 30, 2019 Lease assets Operating lease right-of-use assets $ 34 Finance lease right-of-use assets (net of accumulated depreciation) 61 Total lease right-of-use assets 95 Current lease liabilities Operating lease liabilities 13 Finance lease liabilities 5 Total current lease liabilities 18 Noncurrent lease liabilities Operating lease liabilities 40 Finance lease liabilities 74 Total noncurrent lease liabilities 114 Total lease liabilities $ 132 Cash Flow and Other Information The following table presents lease related cash flow and other information: Six Months Cash paid for amounts included in the measurement of lease liabilities Operating cash flows from operating leases $ 7 Operating cash flow from finance leases 2 Finance cash flow from finance leases 1 Non-cash disclosure upon commencement of new lease Right-of-use assets obtained in exchange for new operating lease liabilities 72 Right-of-use assets obtained in exchange for new finance lease liabilities 15 Non-cash disclosure upon modification of existing lease Modification of operating lease right-of-use assets (36 ) Modification of finance lease right-of-use assets 50 Weighted Average Remaining Lease Term The following table presents weighted average remaining lease term information: June 30, 2019 Weighted average remaining lease term Operating lease 8 years Finance lease 18 years Weighted average discount rate Operating lease 6.04% Finance lease 6.07% Maturity of Lease Liabilities The following table presents maturity of lease liabilities: Operating lease Finance lease Total lease Remainder of 2019 $ 7 $ 4 $ 11 2020 14 9 23 2021 9 9 18 2022 7 9 16 2023 6 9 15 Thereafter 22 79 101 Total lease payments 65 119 184 Less: Interest (12 ) (40 ) (52 ) Present value of lease liabilities $ 53 $ 79 $ 132 As of June 30, 2019 , we have no material operating or finance leases that have not yet commenced.

Commitments and Contingencies (

Commitments and Contingencies (Notes)	6 Months Ended
	Jun. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES Guarantees We have entered into contracts, including the assumed Dynegy senior unsecured notes described above, that contain guarantees to unaffiliated parties that could require performance or payment under certain conditions. As of June 30, 2019 , there are no material outstanding claims related to our guarantee obligations, and we do not anticipate we will be required to make any material payments under these guarantees. Letters of Credit At June 30, 2019 , we had outstanding letters of credit totaling $1.052 billion as follows: • $896 million to support commodity risk management collateral requirements in the normal course of business, including over-the-counter and exchange-traded transactions and collateral postings with ISOs or RTOs; • $46 million to support executory contracts and insurance agreements; • $55 million to support our REP financial requirements with the PUCT, and • $55 million for other credit support requirements. Surety Bonds At June 30, 2019 , we had outstanding surety bonds totaling $27 million to support performance under various contracts and legal obligations in the normal course of business. Litigation Gas Index Pricing Litigation — We, through our subsidiaries, and other energy companies are named as defendants in several lawsuits claiming damages resulting from alleged price manipulation through false reporting of natural gas prices to various index publications, wash trading and churn trading from 2000-2002. The cases allege that the defendants engaged in an antitrust conspiracy to inflate natural gas prices in three states (Kansas, Missouri and Wisconsin) during the relevant time period and seek damages under the respective state antitrust statutes. The cases had been consolidated (along with other similar cases) in a multi-district litigation (MDL) proceeding in the U.S. District Court for Nevada, but in January 2019 the MDL judge issued an order remanding the consolidated cases back to their respective courts of origin. Along with the other defendants, we had previously reached settlement terms in the Kansas and Missouri class action cases, and plaintiffs in those cases filed a Notice of Settlement with the judge in the multi-district court proceeding. We remain as defendants in two putative class actions (Wisconsin) and one individual action (Kansas) on behalf of Farmland Industries, Inc. While we cannot predict the outcome of these legal proceedings, or estimate a range of costs, they could have a material impact on our results of operations, liquidity or financial condition. Advatech Dispute — In September 2016, Illinois Power Generating Company (Genco), terminated its Second Amended and Restated Newton Flue Gas Desulfurization System Engineering, Procurement, Construction and Commissioning Services Contract dated as of December 15, 2014 with Advatech, LLC (Advatech). Advatech issued Genco its final invoice in September 2016 totaling $81 million . Genco contested the invoice in October 2016 and believes the proper amount is less than $1 million . In October 2016, Advatech initiated the dispute resolution process under the contract and filed for arbitration in March 2017. The arbitration hearing occurred in October 2018, and the arbitration panel issued a final award in June 2019, including pre-award and post-award interest and fees totaling approximately $46 million , of which $42 million was recorded as a liability as part of our purchase price allocation of the Merger, $2 million was recorded as interest expense in our condensed statements of consolidated income (loss) and $2 million was recorded as selling, general and administrative expense in our condensed statements of consolidated income (loss). In June 2019, Genco moved to vacate the award in the U.S. District Court for the Southern District of Illinois, and Advatech moved to confirm the award in the U.S. District Court for the Northern District of Illinois. Wood River Rail Dispute — In November 2017, Dynegy Midwest Generation, LLC (DMG) received notification that BNSF Railway Company and Norfolk Southern Railway Company were initiating dispute resolution related to DMG's suspension of its Wood River Rail Transportation Agreement with the railroads. Settlement discussions required under the dispute resolution process have been unsuccessful. In March 2018, BNSF Railway Company and Norfolk Southern Railway Company filed a demand for arbitration. The arbitration hearing on the merits is scheduled for February 2020. We dispute the railroads' allegations and will defend our position vigorously. While we cannot predict the outcome of this legal proceeding, or estimate a range of costs, it could have a material impact on our results of operations, liquidity or financial condition. Greenhouse Gas Emissions In August 2015, the EPA finalized rules to address greenhouse gas emissions (GHG) from electricity generation units, referred to as the Clean Power Plan, including rules for existing facilities that would establish state-specific emissions rate goals to reduce nationwide CO 2 emissions. Various parties (including Luminant) filed petitions for review in the U.S. Court of Appeals for the District of Columbia Circuit (D.C. Circuit Court) and subsequently, in January 2016, a coalition of state, industry (including Luminant) and other parties filed applications with the U.S. Supreme Court (Supreme Court) asking that the Supreme Court stay the rule pending review by the D.C. Circuit Court. In February 2016, the Supreme Court stayed the rule. After oral argument in September 2016, the case was placed in abeyance and remains pending before the D.C. Circuit Court. In July 2019, petitioners filed a joint motion to dismiss in light of the EPA's new rule, the Affordable Clean Energy rule, that replaces the Clean Power Plan discussed below. That motion remains pending before the D.C. Circuit Court. In July 2019, the EPA finalized a rule to repeal the Clean Power Plan, with new regulations addressing GHG emissions from existing coal-fueled electric generation units, referred to as the Affordable Clean Energy (ACE) rule. The ACE rule develops emission guidelines that states must use when developing plans to regulate GHG emissions from existing coal-fueled electric generating units. States must submit their plans for regulating GHG emissions from existing facilities by July 2022. Environmental groups filed a petition for review of the ACE rule and the repeal of the Clean Power Plan in the D.C. Circuit Court. Additionally, in December 2018, the EPA issued proposed revisions to the emission standards for new, modified and reconstructed units. Vistra submitted comments on that proposed rulemaking. While we cannot predict the outcome of these rulemakings and related legal proceedings, or estimate a range of reasonably probable costs, the rules, if implemented, could have a material impact on our results of operations, liquidity or financial condition. Regional Haze — Reasonable Progress and Best Available Retrofit Technology (BART) for Texas In January 2016, the EPA issued a final rule approving in part and disapproving in part Texas's 2009 State Implementation Plan (SIP) as it relates to the reasonable progress component of the Regional Haze program and issuing a Federal Implementation Plan (FIP). The EPA's emission limits in the FIP assume additional control equipment for specific lignite/coal-fueled generation units across Texas, including new flue gas desulfurization systems (scrubbers) at seven electricity generation units (including Big Brown Units 1 and 2, Monticello Units 1 and 2 and Coleto Creek) and upgrades to existing scrubbers at seven generation units (including Martin Lake Units 1, 2 and 3, Monticello Unit 3 and Sandow Unit 4). In March 2016, various parties (including Luminant and the State of Texas) filed petitions for review in the U.S. Court of Appeals for the Fifth Circuit (Fifth Circuit Court) challenging the FIP's Texas requirements. In July 2016, the Fifth Circuit Court granted motions to stay the rule pending final review of the petitions for review. In March 2017, the Fifth Circuit Court granted a motion by the EPA to remand the rule back to the EPA for reconsideration. The stay of the rule (and the emission control requirements) remains in effect. The retirements of our Monticello, Big Brown and Sandow 4 plants should have a favorable impact on this rulemaking and litigation. While we cannot predict the outcome of the rulemaking and legal proceedings, or estimate a range of reasonably possible costs, the result could have a material impact on our results of operations, liquidity or financial condition. In September 2017, the EPA signed a final rule addressing BART for Texas electricity generation units, with the rule serving as a partial approval of Texas's 2009 SIP and a partial FIP. For SO 2 , the rule creates an intrastate Texas emission allowance trading program as a "BART alternative" that operates in a similar fashion to a CSAPR trading program. The program includes 39 generating units (including our Martin Lake, Big Brown, Monticello, Sandow 4, Coleto Creek, Stryker 2 and Graham 2 plants). The compliance obligations in the program started on January 1, 2019. We believe the retirements of our Monticello, Big Brown and Sandow 4 plants will enhance our ability to comply with this BART rule for SO 2 . For NO X , the rule adopts the CSAPR's ozone program as BART and for particulate matter, the rule approves Texas's SIP that determines that no electricity generation units are subject to BART for particulate matter. Various parties filed a petition challenging the rule in the Fifth Circuit Court as well as a petition for reconsideration filed with the EPA. Luminant intervened on behalf of the EPA in the Fifth Circuit Court action. In March 2018, the Fifth Circuit Court abated its proceedings until the EPA concludes the reconsideration process. In August 2018, the EPA issued a proposed rule affirming the prior BART final rule and seeking comments on that proposal, which were due in October 2018. While we cannot predict the outcome of the rulemaking and legal proceedings, we believe the rule, if ultimately implemented or upheld as issued, will not have a material impact on our results of operations, liquidity or financial condition. Affirmative Defenses During Malfunctions In May 2015, the EPA finalized a rule requiring 36 states, including Texas, Illinois and Ohio, to remove or replace either EPA-approved exemptions or affirmative defense provisions for excess emissions during upset events and unplanned maintenance and startup and shutdown events, referred to as the SIP Call. Various parties (including Luminant, the State of Texas and the State of Ohio) filed petitions for review of the EPA's final rule, and all of those petitions were consolidated in the D.C. Circuit Court. In April 2017, the D.C. Circuit Court ordered the case to be held in abeyance. In April 2019, the EPA Region 6 proposed a rule to withdraw the SIP Call with respect to the Texas affirmative defense provisions. We submitted comments on that proposed rulemaking. We cannot predict the timing or outcome of this proceeding, or estimate a range of reasonably possible costs, but implementation of the 2015 rule as finalized could have a material impact on our results of operations, liquidity or financial condition. Illinois Multi-Pollutant Standards (MPS) In 2007, our MISO coal-fueled generation facilities became subject to the Illinois multi-pollutant standard rule (MPS rule), which requires compliance with NO X , SO 2 and mercury emissions limits. We are in compliance with the MPS rule. In October 2017, the Illinois Environmental Protection Agency (IEPA) filed a proposed rule with the Illinois Pollution Control Board (IPCB) that would amend the MPS rule by replacing the two separate group-wide annual emission rate limits that currently apply to our eight downstate Illinois coal-fueled stations with tonnage limits for both SO 2 (annual) and NO X (annual and seasonal) that apply to the eight stations as a single group. In March 2019, we were asked to agree to even further reduced emission caps and in order to move the rule forward, committed to 2,000 MW of coal plant retirements following finalization of the rule. Under the proposal, allowable annual emissions of SO 2 would be 48% lower than the current rule and NO X emission would be 42% lower. All other federal and state air quality regulations, including health-based standards, would remain unchanged and in place. The proposed rule also would impose new requirements to ensure the continuous operation of existing selective catalytic reduction (SCR) control systems during the ozone season, require SCR-controlled units to meet an ozone season NO X emission rate limit, and set an additional, site-specific annual SO 2 limit for our Joppa Power Station. In June 2019, the IPCB voted to approve the rule and it now awaits review by the Joint Committee on Administrative Rules. We are supportive of the proposed rule as it would provide operational flexibility to our MISO fleet while also providing a number of regulatory and environmental benefits. We expect the rule to be finalized in 2019. SO 2 Designations for Texas In November 2016, the EPA finalized its nonattainment designations for counties surrounding our Big Brown, Monticello and Martin Lake generation plants. The final designations require Texas to develop nonattainment plans for these areas. In February 2017, the State of Texas and Luminant filed challenges to the nonattainment designations in the Fifth Circuit Court. Subsequently, in October 2017, the Fifth Circuit Court granted the EPA's motion to hold the case in abeyance considering the EPA's representation that it intended to revisit the nonattainment rule. In December 2017, the TCEQ submitted a petition for reconsideration to the EPA. In addition, with respect to Monticello and Big Brown, the retirement of those plants should favorably impact our legal challenge to the nonattainment designations in that the nonattainment designations for Freestone County and Titus County are based solely on the Sierra Club modeling, which we dispute, of SO 2 emissions from Monticello and Big Brown. Regardless, considering these retirements, the nonattainment designations for those counties are no longer supported. While we cannot predict the outcome of this matter, or estimate a range of reasonably possible costs, the result could have a material impact on our results of operations, liquidity or financial condition. Effluent Limitation Guidelines (ELGs) In November 2015, the EPA revised the ELGs for steam electricity generation facilities, which will impose more stringent standards (as individual permits are renewed) for wastewater streams, such as flue gas desulfurization (FGD), fly ash, bottom ash and flue gas mercury control wastewaters. Various parties filed petitions for review of the ELG rule, and the petitions were consolidated in the Fifth Circuit Court. In April 2017, the EPA granted petitions requesting reconsideration of the ELG final rule and administratively stayed the rule's compliance date deadlines. In August 2017, the EPA announced that its reconsideration of the 2015 ELG final rule would be limited to a review of the effluent limitations applicable to FGD and bottom ash wastewaters and the agency subsequently postponed the earliest compliance dates in the 2015 ELG Rule for the application of effluent limitations for FGD and bottom ash wastewaters from November 1, 2018 to November 1, 2020. Based on these administrative developments, the Fifth Circuit Court agreed to sever and hold in abeyance challenges to effluent limitations. The remainder of the case proceeded, and in April 2019 the Fifth Circuit Court vacated and remanded portions of the EPA's ELG rule pertaining to effluent limitations for legacy wastewater and leachate. The EPA has not yet proposed or finalized a rule reconsidering the FGD and bottom ash wastewater provisions of the 2015 ELG rule. Given the EPA's decision to reconsider the FGD and bottom ash wastewater provisions of the ELG rule, the rule postponing the ELG rule's earliest compliance dates for those provisions, the uncertainty stemming from the vacatur of the effluent limitations for legacy wastewater and leachate, and the intertwined relationship of the ELG rule with the Coal Combustion Residuals rule discussed below, which is also being reconsidered by the EPA, as well as pending legal challenges concerning both rules, substantial uncertainty exists regarding our projected capital expenditures for ELG compliance, including the timing of such expenditures. While we cannot predict the outcome of this matter, or estimate a range of costs, it could have a material impact on our results of operations, liquidity or financial condition. New Source Review and CAA Matters New Source Review — Since 1999, the EPA has engaged in a nationwide enforcement initiative to determine whether coal-fueled power plants failed to comply with the requirements of the New Source Review (NSR) and New Source Performance Standard provisions under the CAA when the plants implemented changes. The EPA's NSR initiative focuses on whether projects performed at power plants triggered various permitting requirements, including the need to install pollution control equipment. In August 2013, the U.S. Department of Justice (DOJ), acting as the attorneys for the EPA, filed a civil enforcement lawsuit against Luminant in federal district court in Dallas, alleging violations of the CAA, including its NSR standards, at our Big Brown and Martin Lake generation facilities. The lawsuit requests (i) 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 (ii) injunctive relief, including an order to apply for pre-construction permits which may require the installation of best available control technology at the affected units. In August 2015, the district court granted Luminant's motion to dismiss seven of the nine claims asserted by the EPA in the lawsuit. In January 2017, the EPA dismissed its two remaining claims with prejudice and the district court entered final judgment in Luminant's favor. In March 2017, the EPA and the Sierra Club appealed the final judgment to the Fifth Circuit Court. In October 2018, the Fifth Circuit Court affirmed in part, reversed in part, and remanded to the district court. The Fifth Circuit Court's decision held that the district court properly dismissed all of the civil penalties as time-barred. The Fifth Circuit Court further held that the grounds cited by the district court did not support dismissal of the injunctive relief claims at this early stage of the case and remanded the case back to the district court for further consideration. In November 2018, we filed a petition for rehearing en banc on two issues and the EPA has filed a response to that petition. In July 2019, the full Fifth Circuit Court granted our en banc petition and oral argument will be held in September 2019. We believe that we have complied with all requirements of the CAA and intend to continue to vigorously defend against the remaining allegations. An adverse outcome could require substantial capital expenditures that cannot be determined at this time or retirement of the remaining plant at issue, Martin Lake. The retirement of the Big Brown plant should have a favorable impact on this litigation. Zimmer NOVs — In December 2014, the EPA issued a notice of violation (NOV) alleging violation of opacity standards at the Zimmer facility. The EPA previously had issued NOVs to Zimmer in 2008 and 2010 alleging violations of the CAA, the Ohio State Implementation Plan and the station's air permits including standards applicable to opacity, sulfur dioxide, sulfuric acid mist and heat input. The NOVs remain unresolved. Edwards CAA Citizen Suit — In April 2013, environmental groups filed a CAA citizen suit in the U.S. District Court for the Central District of Illinois alleging violations of opacity and particulate matter limits at our MISO segment's Edwards facility. In August 2016, the district court granted the plaintiffs' motion for summary judgment on certain liability issues. In March 2019, the court denied the parties' motions for summary judgment on remedy issues. A bench trial on the remedy issues is scheduled for the end of September 2019. We dispute the allegations and will defend the case vigorously. Ultimate resolution of any of these CAA matters could have a material adverse impact on our future financial condition, results of operations, and cash flows. A resolution could result in increased capital expenditures for the installation of pollution control equipment, increased operations and maintenance expenses, and penalties, or could result in an order or a decision to retire these plants. While we cannot predict the outcome of these legal proceedings, or estimate a range of costs, they could have a material impact on our results of operations, liquidity or financial condition. Coal Combustion Residuals/Groundwater In July 2018, the EPA published a final rule, which became effective in August 2018, that amends certain provisions of the Coal Combustion Residuals (CCR) rule that the agency issued in 2015. Among other changes, the 2018 revisions extend closure deadlines to October 31, 2020, related to the aquifer location restriction and groundwater monitoring requirements. Also, on August 21, 2018, the D.C. Circuit Court issued a decision that vacates and remands certain provisions of the 2015 CCR rule, including an applicability exemption for legacy impoundments. The EPA is expected to undertake further revisions to its CCR regulations in response to the D.C. Circuit Court's ruling. In October 2018, the rule that extends certain closure deadlines to 2020 was challenged in the D.C. Circuit Court. In March 2019, the D.C. Circuit Court granted the EPA's request for remand without vacatur. The EPA is expected to issue proposed rules on these and other aspects of the CCR rule in the near term. While we cannot predict the impacts of these rule revisions (including whether and if so how the states in which we operate will utilize the authority delegated to the states through the revisions), or estimate a range of reasonably possible costs related to these revisions, the changes that result from these revisions could have a material impact on our results of operations, liquidity or financial condition. MISO Segment — In 2012, the Illinois Environmental Protection Agency (IEPA) issued violation notices alleging violations of groundwater standards onsite at our Baldwin and Vermilion facilities' CCR surface impoundments. In 2016, the IEPA approved our closure and post-closure care plans for the Baldwin old east, east, and west fly ash CCR surface impoundments. We are working towards implementation of those closure plans. At our retired Vermilion facility, which was not subject to the EPA's 2015 CCR rule until the aforementioned D.C. Circuit court decision in August 2018, we submitted proposed corrective action plans involving closure of two CCR surface impoundments ( i.e. , the old east and the north impoundments) to the IEPA in 2012, with revised plans submitted in 2014. In May 2017, in response to a request from the IEPA for additional information regarding the closure of these Vermilion surface impoundments, we agreed to perform additional groundwater sampling and closure options and riverbank stabilizing options. In May 2018, Prairie Rivers Network filed a citizen suit against our subsidiary Dynegy Midwest Generation, LLC (DMG), alleging violations of the Clean Water Act for alleged unauthorized discharges. In August 2018, we filed a motion to dismiss the lawsuit. In November 2018, the district court granted our motion to dismiss and judgment was entered in our favor. Plaintiffs have appealed the judgment to the U.S Court of Appeals for the Seventh Circuit. That appeal is now stayed. In April 2019, PRN also filed a complaint against DMG before the IPCB, alleging that groundwater flows allegedly associated with the ash impoundments at the Vermilion site have resulted in exceedances both of surface water standards and Illinois groundwater standards dating back to 1992. This matter is in very early stages and we dispute the allegations in the complaint. We dispute the allegations in both of these matters and will vigorously defend our position. In 2012, the IEPA issued violation notices alleging violations of groundwater standards at the Newton and Coffeen facilities' CCR surface impoundments. We are addressing these CCR surface impoundments in accordance with the federal CCR rule. In June 2018, the IEPA issued a violation notice for alleged seep discharges claimed to be coming from the surface impoundments at our retired Vermilion facility and that notice has since been referred to the Illinois Attorney General. In December 2018, the Sierra Club filed a complaint with the IPCB alleging the disposal and storage of coal ash at the Coffeen, Edwards and Joppa generation facilities are causing exceedances of the applicable groundwater standards. We dispute the allegations and will vigorously defend our position. In May 2019, coal ash disposal and storage legislation passed the Illinois legislature and is now awaiting signature by the Illinois Governor. The legislation addresses state requirements for the proper closure of coal ash ponds in the state of Illinois. The legislation tasks the IEPA and the IPCB to set up a series of guidelines, rules and permit requirements for closure of ash ponds. Assuming the legislation is signed, we expect the rulemaking process should take about 18 months to complete. Under the legislation, coal ash impoundment owners would be required to submit a closure alternative analysis to the IEPA for the selection of the best method for coal ash remediation at a particular site. The legislation does not mandate closure by removal at any site. With respect to near-term costs, the legislation requires that operators pay a one-time fee of $50,000 for each closed site and $75,000 for each open site. This one-time fee is paid six months after the effective date of the legislation. The legislation also requires annual permit fees. While we cannot predict the outcome of these proceedings, or estimate a range of costs, they could have a material impact on our results of operations, liquidity or financial condition. For all of the above matters, if remediation measures concerning groundwater are necessary at any of our coal-fueled facilities, we may incur significant costs that could have a material adverse effect on our financial condition, results of operations, and cash flows. At this time, in part because of the revisions to the CCR rule that the EPA published in July 2018 and the D.C. Circuit Court's vacatur and remand of certain provisions of the EPA's 2015 CCR rule and the Illinois coal ash legislation, we cannot reasonably estimate the costs, or range of costs, of groundwater remediation, if any, that ultimately may be required. Current CCR surface impoundment and landfill closure costs, as determined by our operations and environmental services teams, are reflected in our AROs. MISO 2015-2016 Planning Resource Auction In May 2015, three complaints were filed at FERC regarding the Zone 4 results for the 2015-2016 planning resource auction (PRA) conducted by MISO. Dynegy is a named party in one of the complaints. The complainants, Public Citizen, Inc., the Illinois Attorney General and Southwestern Electric Cooperative, Inc. (Complainants), challenged the results of the PRA as unjust and unreasonable, requested rate relief/refunds, and requested changes to the MISO planning resource auction structure going forward. Complainants also alleged that Dynegy may have engaged in economic or physical withholding in Zone 4 constituting market manipulation in the PRA. The Independent Market Monitor for MISO (MISO IMM), which was responsible for monitoring the PRA, determined that all offers were competitive and that no physical or economic withholding occurred. The MISO IMM also stated, in a filing responding to the complaints, that there is no basis for the remedies sought by the Complainants. We filed our answer to these complaints explaining that we complied fully with the terms of the MISO tariff in connection with the PRA and disputing the allegations. The Illinois Industrial Energy Consumers filed a related complaint at FERC against MISO in June 2015 requesting prospective changes to the MISO tariff. Dynegy also responded to this complaint with respect to Dynegy's conduct alleged in the complaint. In October 2015, FERC issued an order of nonpublic, formal investigation (the investigation) into whether market manipulation or other potential violations of FERC orders, rules and regulations occurred before or during the PRA. In December 2015, FERC issued an order on the complaints requiring a number of prospective changes to the MISO tariff provisions effective as of the 2016-2017 planning resource auction. The order did not address the arguments of the Complainants regarding the PRA and stated that those issues remained under consideration and would be addressed in a future order. In July 2019, FERC issued an order denying the remaining issues raised by the complaints and noted that the investigation into Dynegy was closed. FERC found that Dynegy's conduct did not constitute market manipulation and the results of the PRA were just and reasonable because the PRA was conducted in accordance with MISO's tariff. With the issuance of the order, this matter has been resolved in Dynegy's favor. The order remains subject to rehearing at FERC and appeal. Other Matters We are involved in various legal and administrative proceedings in the normal course of business, the ultimate resolutions of which, in the opinion of management, are not anticipated to have a material effect on our results of operations, liquidity or financial condition.

Equity (Notes)

Equity (Notes)	6 Months Ended
	Jun. 30, 2019
Stockholders' Equity Note [Abstract]
Equity	EQUITY Share Repurchase Program In November 2018, we announced that the Board had authorized an incremental share repurchase program (Program) under which up to $1.250 billion of our outstanding stock may be purchased. In the three months ended June 30, 2019 , 8,558,712 shares of our common stock were repurchased for $212 million (including related fees and expenses) at an average price of $24.72 per share of common stock. In the six months ended June 30, 2019 , 18,100,329 shares of our common stock were repurchased for $448 million (including related fees and expenses) at an average price of $24.75 per share of common stock. On a cumulative basis, 30,173,420 shares of our common stock have been repurchased under the Program for $726 million (including related fees and expenses) at an average price of $24.05 per share of common stock. At June 30, 2019 , $524 million was available for additional repurchases under the Program, and we intend to implement the Program opportunistically from time to time in 2019 and 2020. Shares of the Company's common stock may be repurchased in open market transactions at prevailing market prices, in privately negotiated transactions, pursuant to plans complying with the Exchange Act, or by other means in accordance with federal securities laws. The actual timing, number and value of shares repurchased under the Program will be determined at our discretion and will depend on a number of factors, including the market price of our stock, general market and economic conditions, applicable legal requirements and compliance with the terms of our debt agreements and the Tax Matters Agreement. Dividends In November 2018, Vistra Energy announced the Board had adopted a dividend program pursuant to which Vistra Energy would initiate an annual dividend of approximately $0.50 per share expected to begin in the first quarter of 2019. Each dividend under the program will be subject to the declaration by the Board and, thus, may be subject to numerous factors in existence at the time of any such declaration including, but not limited to, prevailing market conditions, Vistra Energy's results of operations, financial condition and liquidity and Delaware law. In February 2019 and May 2019, the Board declared quarterly dividends of $0.125 per share that were paid in March 2019 and June 2019, respectively. In July 2019, the Board declared a quarterly dividend of $0.125 per share that will be paid in September 2019. Vistra Energy did not declare or pay any dividends during the six months ended June 30, 2018 . Dividend Restrictions The agreement governing the Credit Facilities Agreement generally restricts the ability of Vistra Operations to make distributions to any direct or indirect parent unless such distributions are expressly permitted thereunder. As of June 30, 2019 , Vistra Operations can distribute approximately $6.3 billion to Parent under the Credit Facilities Agreement without the consent of any party. The amount that can be distributed by Vistra Operations to Parent was partially reduced by distributions made by Vistra Operations to Parent of approximately $1.645 billion and $3.195 billion during the three and six months ended June 30, 2019 , respectively, and approximately $4.7 billion and $1.1 billion during the years ended December 31, 2018 and 2017, respectively. Additionally, Vistra Operations may make distributions to Parent in amounts sufficient for Parent to make any payments required under the TRA or the Tax Matters Agreement or, to the extent arising out of Parent's ownership or operation of Vistra Operations, to pay any taxes or general operating or corporate overhead expenses. As of June 30, 2019 , the maximum amount of restricted net assets of Vistra Operations that may not be distributed to Parent totaled approximately $1.9 billion . Under applicable Delaware General Corporate Law, we are prohibited from paying any distribution to the extent that such distribution exceeds the value of our "surplus," which is defined as the excess of our net assets above our capital (the aggregate par value of all outstanding shares of our stock). Warrants At the Merger Date, the Company entered into an agreement whereby holders of each outstanding warrant previously issued by Dynegy will be entitled to receive, upon exercise, the equity securities to which the holder would have been entitled to receive of Dynegy common stock converted into shares of Vistra Energy common stock at the Exchange Ratio. As of June 30, 2019 , nine million warrants expiring in 2024 with an exercise price of $35.00 (subject to adjustment from time to time) were outstanding, each of which can be redeemed for 0.652 share of Vistra Energy common stock. The warrants are recorded as equity in our condensed consolidated balance sheet. Tangible Equity Units (TEUs) At the Merger Date, the Company assumed the obligations of Dynegy's 4,600,000 7.00% TEUs, each with a stated amount of $100.00 and each comprised of (i) a prepaid stock purchase contract that delivered to the holder, on July 1, 2019, 4.0813 shares of Vistra Energy common stock per contract with cash paid in lieu of any fractional shares at a rate of $22.5954 per share and (ii) a senior amortizing note with an outstanding principal amount of $38 million at the Merger Date that paid an equal quarterly cash installment of $1.75 per amortizing note (see Note 11 ). In the aggregate, the annual quarterly cash installments were equivalent to a 7.00% cash payment per year with respect to each $100.00 stated amount of TEUs. The amortizing notes were accounted for as debt while the stock purchase contract was included in equity based on the fair value of the contract at the Merger Date (see Note 11 ). The entire class of TEUs were suspended from trading on the New York Stock Exchange on July 1, 2019 and removed from listing and registration on July 12, 2019. On July 1, 2019, approximately 18.8 million treasury shares of Vistra Energy common stock were issued in connection with the settlement of the TEUs. Equity The following table presents the changes to equity for the three months ended June 30, 2019 : Common Stock (a) Additional Paid-in Capital Retained Earnings (Deficit) Accumulated Other Comprehensive Income (Loss) Total Stockholders' Equity Noncontrolling Interest Total Equity Balance at March 31, 2019 $ 5 $ 9,105 $ (1,285 ) $ (21 ) $ 7,804 $ 2 $ 7,806 Treasury stock — (212 ) — — (212 ) — (212 ) Dividends declared on common stock — — (59 ) — (59 ) — (59 ) Effects of stock-based incentive compensation plans — 16 — — 16 — 16 Net income (loss) — — 356 — 356 (2 ) 354 Other — — (1 ) — (1 ) — (1 ) Balance at June 30, 2019 $ 5 $ 8,909 $ (989 ) $ (21 ) $ 7,904 $ — $ 7,904 The following table presents the changes to equity for the six months ended June 30, 2019 : Common Stock (a) Additional Paid-in Capital Retained Earnings (Deficit) Accumulated Other Comprehensive Income (Loss) Total Stockholders' Equity Noncontrolling Interest Total Equity Balance at December 31, 2018 $ 5 $ 9,329 $ (1,449 ) $ (22 ) $ 7,863 $ 4 $ 7,867 Treasury stock — (448 ) — — (448 ) — (448 ) Dividends declared on common stock — — (120 ) — (120 ) — (120 ) Effects of stock-based incentive compensation plans — 28 — — 28 — 28 Net income (loss) — — 581 — 581 (3 ) 578 Adoption of accounting standard (Note 1) — — (2 ) — (2 ) — (2 ) Change in unrecognized losses related to pension and OPEB plans — — — 1 1 — 1 Other — — 1 — 1 (1 ) — Balance at June 30, 2019 $ 5 $ 8,909 $ (989 ) $ (21 ) $ 7,904 $ — $ 7,904 ________________ (a) Authorized shares totaled 1,800,000,000 at June 30, 2019 . Outstanding shares totaled 476,166,856 and 493,215,309 at June 30, 2019 and December 31, 2018 , respectively. The following table presents the changes to equity for the three months ended June 30, 2018 : Common Stock (a) Additional Paid-in Capital Retained Earnings (Deficit) Accumulated Other Comprehensive Income (Loss) Total Stockholders' Equity Noncontrolling Interest Total Equity Balance at March 31, 2018 $ 4 $ 7,772 $ (1,700 ) $ (16 ) $ 6,060 $ — $ 6,060 Stock and stock compensation awards issued in connection with the Merger 1 1,891 — — 1,892 — 1,892 Treasury stock — (75 ) — — (75 ) — (75 ) Effects of stock-based incentive compensation plans — 56 — — 56 — 56 Tangible equity units acquired — 369 — — 369 — 369 Warrants acquired — 2 — — 2 — 2 Net income (loss) — — 108 — 108 — 108 Investment by noncontrolling interest — — — — — 7 7 Other — — 1 — 1 — 1 Balance at June 30, 2018 $ 5 $ 10,015 $ (1,591 ) $ (16 ) $ 8,413 $ 7 $ 8,420 The following table presents the changes to equity for the six months ended June 30, 2018 : Common Stock (a) Additional Paid-in Capital Retained Earnings (Deficit) Accumulated Other Comprehensive Income (Loss) Total Stockholders' Equity Noncontrolling Interest Total Equity Balance at December 31, 2017 $ 4 $ 7,765 $ (1,410 ) $ (17 ) $ 6,342 $ — $ 6,342 Stock and stock compensation awards issued in connection with the Merger 1 1,891 — — 1,892 — 1,892 Treasury stock — (75 ) — — (75 ) — (75 ) Effects of stock-based incentive compensation plans — 63 — — 63 — 63 Tangible equity units acquired — 369 — — 369 — 369 Warrants acquired — 2 — — 2 — 2 Net loss — — (198 ) — (198 ) — (198 ) Adoption of accounting standard — — 17 — 17 — 17 Change in unrecognized losses related to pension and OPEB plans — — — 1 1 — 1 Investment by noncontrolling interest — — — — — 7 7 Balance at June 30, 2018 $ 5 $ 10,015 $ (1,591 ) $ (16 ) $ 8,413 $ 7 $ 8,420 ________________ (a) Authorized shares totaled 1,800,000,000 at June 30, 2018 . Outstanding shares totaled 521,214,879 and 428,398,802 at June 30, 2018 and December 31, 2017 , respectively.

Fair Value Measurements (Notes)

Fair Value Measurements (Notes)	6 Months Ended
	Jun. 30, 2019
Fair Value Disclosures [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS 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. 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 and use valuation techniques to maximize the use of observable inputs and minimize the use of unobservable inputs. Our valuation policies and procedures were developed, maintained and validated by a centralized risk management group that reports to the Vistra Energy Chief Financial Officer. Fair value measurements of derivative assets and liabilities incorporate an adjustment for credit-related nonperformance risk. These nonperformance risk adjustments take into consideration master netting arrangements, 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 credit ratings and default rate factors in calculating these fair value measurement adjustments. 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. Our Level 1 assets and liabilities include CME or ICE (electronic commodity derivative exchanges) futures and options transacted through clearing brokers for which prices are actively quoted. We report the fair value of CME and ICE transactions without taking into consideration margin deposits, with the exception of certain margin amounts related to changes in fair value on certain CME transactions that, beginning in January 2017, are legally characterized as settlement of derivative contracts rather than collateral. • 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 such as interest rates and yield curves observable at commonly quoted intervals. We attempt to obtain multiple quotes from brokers that are active in the markets in which we participate and require at least one quote from two brokers to determine a pricing input as observable. 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. • 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. Significant unobservable inputs used to develop the valuation models include volatility curves, correlation curves, illiquid pricing delivery periods and locations and credit-related nonperformance risk assumptions. These inputs and valuation models are developed and maintained by employees trained and experienced in market operations and fair value measurements and validated by the Company's risk management group. 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. Assets and liabilities measured at fair value on a recurring basis consisted of the following at the respective balance sheet dates shown below: June 30, 2019 Level 1 Level 2 Level 3 (a) Reclassification (b) Total Assets: Commodity contracts $ 958 $ 300 $ 214 $ 70 $ 1,542 Nuclear decommissioning trust – 510 — — — 510 Nuclear decommissioning trust – — 502 — — 502 Sub-total $ 1,468 $ 802 $ 214 $ 70 2,554 Assets measured at net asset value (d): Nuclear decommissioning trust – 330 Total assets $ 2,884 Liabilities: Commodity contracts $ 1,063 $ 419 $ 210 $ 70 $ 1,762 Interest rate swaps — 156 — — 156 Total liabilities $ 1,063 $ 575 $ 210 $ 70 $ 1,918 December 31, 2018 Level 1 Level 2 Level 3 (a) Reclassification (b) Total Assets: Commodity contracts $ 456 $ 152 $ 153 $ 1 $ 762 Interest rate swaps — 77 — — 77 Nuclear decommissioning trust – 449 — — — 449 Nuclear decommissioning trust – — 443 — — 443 Sub-total $ 905 $ 672 $ 153 $ 1 1,731 Assets measured at net asset value (d): Nuclear decommissioning trust – 278 Total assets $ 2,009 Liabilities: Commodity contracts $ 557 $ 766 $ 288 $ 1 $ 1,612 Interest rate swaps — 34 — — 34 Total liabilities $ 557 $ 800 $ 288 $ 1 $ 1,646 ____________ (a) See table below for description of Level 3 assets and liabilities. (b) Fair values are determined on a contract basis, but certain contracts result in a current asset and a noncurrent liability, or vice versa, as presented in our condensed consolidated balance sheets. (c) The nuclear decommissioning trust investment is included in the investments line in our condensed consolidated balance sheets. See Note 19 . (d) The fair value amounts presented in this line are intended to permit reconciliation of the fair value hierarchy to the amounts presented in our condensed consolidated balance sheets. Certain investments measured at fair value using the net asset value per share (or its equivalent) have not been classified in the fair value hierarchy. Commodity contracts consist primarily of natural gas, electricity, coal and emissions agreements and include financial instruments entered into for economic hedging purposes as well as physical contracts that have not been designated as normal purchases or sales. Interest rate swaps are used to reduce exposure to interest rate changes by converting floating-rate interest to fixed rates. See Note 16 for further discussion regarding derivative instruments. Nuclear decommissioning trust assets represent securities held for the purpose of funding the future retirement and decommissioning of our nuclear generation facility. These investments include equity, debt and other fixed-income securities consistent with investment rules established by the NRC and the PUCT. The following tables present the fair value of the Level 3 assets and liabilities by major contract type and the significant unobservable inputs used in the valuations at June 30, 2019 and December 31, 2018 : June 30, 2019 Fair Value Contract Type (a) Assets Liabilities Total Valuation Technique Significant Unobservable Input Range (b) Electricity purchases and sales $ 72 $ (58 ) $ 14 Valuation Model Hourly price curve shape (c) $0 to $110/ MWh Illiquid delivery periods for hub power prices and heat rates (d) $20 to $120/ MWh Electricity and weather options 10 (102 ) (92 ) Option Pricing Model Gas to power correlation (e) 10% to 100% Power volatility (e) 5% to 435% Financial transmission rights 121 (16 ) 105 Market Approach (f) Illiquid price differences between settlement points (g) $(5) to $50/ MWh Other (h) 11 (34 ) (23 ) Total $ 214 $ (210 ) $ 4 December 31, 2018 Fair Value Contract Type (a) Assets Liabilities Total Valuation Technique Significant Unobservable Input Range (b) Electricity purchases and sales $ 22 $ (48 ) $ (26 ) Valuation Model Hourly price curve shape (c) $0 to $110/ MWh Illiquid delivery periods for ERCOT hub power prices and heat rates (d) $20 to $120/ MWh Electricity and weather options 31 (192 ) (161 ) Option Pricing Model Gas to power correlation (e) 15% to 95% Power volatility (e) 5% to 435% Financial transmission rights 85 (20 ) 65 Market Approach (f) Illiquid price differences between settlement points (g) $(10) to $50/ MWh Other (h) 15 (28 ) (13 ) Total $ 153 $ (288 ) $ (135 ) ____________ (a) Electricity purchase and sales contracts include power and heat rate positions in ERCOT, PJM, NYISO, ISO-NE and MISO regions. The forward purchase contracts (swaps and options) used to hedge electricity price differences between settlement points within are referred to as congestion revenue rights in ERCOT and financial transmission rights in PJM, NYISO, ISO-NE and MISO regions. Electricity options consist of physical electricity options and spread options. (b) The range of the inputs may be influenced by factors such as time of day, delivery period, season and location. (c) Primarily based on the historical range of forward average hourly ERCOT North Hub prices. (d) Primarily based on historical forward ERCOT and PJM power prices and ERCOT heat rate variability. (e) Based on historical forward correlation and volatility within ERCOT. (f) While we use the market approach, there is insufficient market data to consider the valuation liquid. (g) Primarily based on the auction price that reflects the difference in power prices at two locations. (h) Other includes contracts for natural gas, coal, coal option, power and gas swaption and emissions. There were no transfers between Level 1 and Level 2 of the fair value hierarchy for the three and six months ended June 30, 2019 and 2018 . See the table below for discussion of transfers between Level 2 and Level 3 for the three and six months ended June 30, 2019 and 2018 . The following table presents the changes in fair value of the Level 3 assets and liabilities for the three and six months ended June 30, 2019 and 2018 . Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Net liability balance at beginning of period $ (113 ) $ (224 ) $ (135 ) $ (53 ) Total unrealized valuation gains (losses) 87 (18 ) 125 (230 ) Purchases, issuances and settlements (a): Purchases 61 29 79 58 Issuances (10 ) (4 ) (17 ) (7 ) Settlements (20 ) 29 (42 ) 45 Transfers into Level 3 (b) 3 2 5 1 Transfers out of Level 3 (b) (4 ) 1 (11 ) 1 Net liabilities assumed in connection with the Merger — (37 ) — (37 ) Net change (c) 117 2 139 (169 ) Net liability balance at end of period $ 4 $ (222 ) $ 4 $ (222 ) Unrealized valuation gains (losses) relating to instruments held at end of period $ 92 $ (17 ) $ 110 $ (226 ) ____________ (a) Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received. (b) Includes transfers due to changes in the observability of significant inputs. All Level 3 transfers during the periods presented are in and out of Level 2. For six months ended June 30, 2019 , transfers out of Level 3 primarily consists of coal derivatives where forward pricing inputs have become observable. (c) Activity excludes change in fair value in the month positions settle. Substantially all changes in values of commodity contracts (excluding the net liabilities assumed in connection with the Merger) are reported as operating revenues in our condensed statements of consolidated income (loss).

Commodity and Other Derivative

Commodity and Other Derivative Contractual Assets and Liabilities (Notes)	6 Months Ended
	Jun. 30, 2019
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 and interest rate risk. See Note 15 for a discussion of the fair value of derivatives. Commodity Hedging and Trading Activity — We utilize natural gas and electricity derivatives to reduce exposure to changes in electricity prices primarily to hedge future revenues from electricity sales from our generation assets. We also utilize short-term electricity, natural gas, coal, and emissions derivative instruments for fuel hedging and other purposes. Counterparties to these transactions include energy companies, financial institutions, electric utilities, independent power producers, oil and gas producers, local distribution companies and energy marketing companies. Unrealized gains and losses arising from changes in the fair value of derivative instruments as well as realized gains and losses upon settlement of the instruments are reported in our condensed statements of consolidated income (loss) in operating revenues and fuel, purchased power costs and delivery fees. Interest Rate Swaps — Interest rate swap agreements are used to reduce exposure to interest rate changes by converting floating-rate interest rates to fixed rates, thereby hedging future interest costs and related cash flows. Unrealized gains and losses arising from changes in the fair value of the swaps as well as realized gains and losses upon settlement of the swaps are reported in our condensed statements of consolidated income (loss) in interest expense and related charges. Financial Statement Effects of Derivatives Substantially all derivative contractual assets and liabilities are accounted for under mark-to-market accounting consistent with accounting standards related to derivative instruments and hedging activities. The following tables provide detail of derivative contractual assets and liabilities as reported in our condensed consolidated balance sheets at June 30, 2019 and December 31, 2018 . Derivative asset and liability totals represent the net value of the contract, while the balance sheet totals represent the gross value of the contract. June 30, 2019 Derivative Assets Derivative Liabilities Commodity Contracts Interest Rate Swaps Commodity Contracts Interest Rate Swaps Total Current assets $ 1,403 $ — $ 15 $ — $ 1,418 Noncurrent assets 114 — 10 — 124 Current liabilities — — (1,508 ) (6 ) (1,514 ) Noncurrent liabilities (45 ) — (209 ) (150 ) (404 ) Net assets (liabilities) $ 1,472 $ — $ (1,692 ) $ (156 ) $ (376 ) December 31, 2018 Derivative Assets Derivative Liabilities Commodity Contracts Interest Rate Swaps Commodity Contracts Interest Rate Swaps Total Current assets $ 707 $ 22 $ 1 $ — $ 730 Noncurrent assets 54 55 — — 109 Current liabilities — — (1,374 ) (2 ) (1,376 ) Noncurrent liabilities — — (238 ) (32 ) (270 ) Net assets (liabilities) $ 761 $ 77 $ (1,611 ) $ (34 ) $ (807 ) At June 30, 2019 and December 31, 2018 , there were no derivative positions accounted for as cash flow or fair value hedges. The following table presents the pretax effect of derivative gains (losses) on net income, including realized and unrealized effects. 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. Derivative (condensed statements of consolidated income (loss) presentation) Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Commodity contracts (Operating revenues) $ 549 $ 69 $ 776 $ (376 ) Commodity contracts (Fuel, purchased power costs and delivery fees) (24 ) 13 3 12 Interest rate swaps (Interest expense and related charges) (108 ) 22 (183 ) 78 Net gain (loss) $ 417 $ 104 $ 596 $ (286 ) Balance Sheet Presentation of Derivatives We elect to report derivative assets and liabilities in our condensed consolidated balance sheets on a gross basis without taking into consideration netting arrangements we have with counterparties to those derivatives. We maintain standardized master netting agreements with certain counterparties that allow for the right to offset assets and liabilities and collateral 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. Generally, margin deposits that contractually offset these derivative instruments are reported separately in our condensed consolidated balance sheets, with the exception of certain margin amounts related to changes in fair value on CME transactions that are legally characterized as settlement of forward exposure rather than collateral. Margin deposits received from counterparties are primarily used for working capital or other general corporate purposes. The following tables reconcile our derivative assets and liabilities on a contract basis to net amounts after taking into consideration netting arrangements with counterparties and financial collateral: June 30, 2019 December 31, 2018 Derivative Assets and Liabilities Offsetting Instruments (a) Cash Collateral (Received) Pledged (b) Net Amounts Derivative Assets and Liabilities Offsetting Instruments (a) Cash Collateral (Received) Pledged (b) Net Amounts Derivative assets: Commodity contracts $ 1,472 $ (1,199 ) $ (6 ) $ 267 $ 761 $ (593 ) $ (1 ) $ 167 Interest rate swaps — — — — 77 (26 ) — 51 Total derivative assets 1,472 (1,199 ) (6 ) 267 838 (619 ) (1 ) 218 Derivative liabilities: Commodity contracts (1,692 ) 1,199 118 (375 ) (1,611 ) 593 109 (909 ) Interest rate swaps (156 ) — — (156 ) (34 ) 26 — (8 ) Total derivative liabilities (1,848 ) 1,199 118 (531 ) (1,645 ) 619 109 (917 ) Net amounts $ (376 ) $ — $ 112 $ (264 ) $ (807 ) $ — $ 108 $ (699 ) ____________ (a) Amounts presented exclude trade accounts receivable and payable related to settled financial instruments. (b) Represents cash amounts received or pledged pursuant to a master netting arrangement, including fair value-based margin requirements. Derivative Volumes The following table presents the gross notional amounts of derivative volumes at June 30, 2019 and December 31, 2018 : June 30, 2019 December 31, 2018 Derivative type Notional Volume Unit of Measure Natural gas (a) 6,867 7,011 Million MMBtu Electricity 394,990 317,572 GWh Financial Transmission Rights (b) 234,664 172,611 GWh Coal 35 45 Million U.S. tons Fuel oil 73 60 Million gallons Uranium 125 50 Thousand pounds Emissions 16 10 Million tons Interest rate swaps – floating/fixed (c) $ 6,720 $ 7,717 Million U.S. dollars ____________ (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 ISOs or RTOs. (c) Includes notional amounts of interest rate swaps with maturity dates through July 2026. See Note 11 for termination of interest rate swaps. Credit Risk-Related Contingent Features of Derivatives Our derivative contracts 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 or include cross-default contractual provisions that could result in the settlement of such contracts if there was a failure under other financing arrangements related to payment terms or other covenants. The following table presents the commodity derivative liabilities subject to credit risk-related contingent features that are not fully collateralized: June 30, December 31, Fair value of derivative contract liabilities (a) $ (631 ) $ (856 ) Offsetting fair value under netting arrangements (b) 223 218 Cash collateral and letters of credit 79 190 Liquidity exposure $ (329 ) $ (448 ) ____________ (a) Excludes fair value of contracts that contain contingent features that do not provide specific amounts to be posted if features are triggered, including provisions that generally provide the right to request additional collateral (material adverse change, performance assurance and other clauses). (b) Amounts include the offsetting fair value of in-the-money derivative contracts and net accounts receivable under master netting arrangements. Concentrations of Credit Risk Related to Derivatives We have concentrations of credit risk with the counterparties to our derivative contracts. At June 30, 2019 , total credit risk exposure to all counterparties related to derivative contracts totaled $1,675 million (including associated accounts receivable). The net exposure to those counterparties totaled $398 million at June 30, 2019 , after taking into effect netting arrangements, setoff provisions and collateral, with the largest net exposure to a single counterparty totaling $119 million . At June 30, 2019 , the credit risk exposure to the banking and financial sector represented 71% of the total credit risk exposure and 23% of the net exposure. Exposure to banking and financial sector counterparties is considered to be within an acceptable level of risk tolerance because all of this exposure is with counterparties with investment grade credit ratings. However, this concentration increases the risk that a default by any of these counterparties would have a material effect on our financial condition, results of operations and liquidity. The transactions with these counterparties contain certain provisions that would require the counterparties to post collateral in the event of a material downgrade in their credit rating. We maintain credit risk policies with regard to our counterparties to minimize overall credit risk. These policies authorize specific risk mitigation tools including, but not limited to, use of standardized master agreements that allow for netting of positive and negative exposures associated with a single counterparty. Credit enhancements such as parent guarantees, letters of credit, surety bonds, liens on assets and margin deposits are also utilized. Prospective material changes in the payment history or financial condition of a counterparty or downgrade of its credit quality result in the reassessment of the credit limit with that counterparty. The process can result in the subsequent reduction of the credit limit or a request for additional financial assurances. An event of default by one or more counterparties could subsequently result in termination-related settlement payments that reduce available liquidity if amounts are owed to the counterparties related to the derivative contracts or delays in receipts of expected settlements if the counterparties owe amounts to us.

Related Party Transactions (Not

Related Party Transactions (Notes)	6 Months Ended
	Jun. 30, 2019
Related Party Transactions [Abstract]
Related Party Transactions	RELATED PARTY TRANSACTIONS In connection with Emergence, we entered into agreements with certain of our affiliates and with parties who received shares of common stock and TRA Rights in exchange for their claims. Registration Rights Agreement Pursuant to the Plan of Reorganization, on the Effective Date, we entered into a Registration Rights Agreement (the Registration Rights Agreement) with certain selling stockholders providing for registration of the resale of the Vistra Energy common stock held by such selling stockholders. In December 2016, we filed a Form S-1 registration statement with the SEC to register for resale the shares of Vistra Energy common stock held by certain significant stockholders pursuant to the Registration Rights Agreement, which was declared effective by the SEC in May 2017. The registration statement was amended in March 2018. Pursuant to the Registration Rights Agreement, in June 2018, we filed a post-effective amendment to the Form S-1 registration statement on Form S-3, which was declared effective by the SEC in July 2018. Among other things, under the terms of the Registration Rights Agreement: • if we propose to file certain types of registration statements under the Securities Act with respect to an offering of equity securities, we will be required to use our reasonable best efforts to offer the other parties to the Registration Rights Agreement the opportunity to register all or part of their shares on the terms and conditions set forth in the Registration Rights Agreement; and • the selling stockholders received the right, subject to certain conditions and exceptions, to request that we file registration statements or amend or supplement registration statements, with the SEC for an underwritten offering of all or part of their respective shares of Vistra Energy common stock (a Demand Registration), and the Company is required to cause any such registration statement or amendment or supplement (a) to be filed with the SEC promptly and, in any event, on or before the date that is 45 days , in the case of a registration statement on Form S-1, or 30 days , in the case of a registration statement on Form S-3, after we receive the written request from the relevant selling stockholders to effectuate the Demand Registration and (b) to become effective as promptly as reasonably practicable and in any event no later than 120 days after it is initially filed. All expenses of registration under the Registration Rights Agreement, including the legal fees of one counsel retained by or on behalf of the selling stockholders, will be paid by us. Legal fee expenses paid or accrued by Vistra Energy on behalf of the selling stockholders totaled less than $1 million during both the three and six months ended June 30, 2019 and 2018 . Tax Receivable Agreement On the Effective Date, Vistra Energy entered into the TRA with a transfer agent on behalf of certain former first lien creditors of TCEH. See Note 8 for discussion of the TRA.

Segment Information (Notes)

Segment Information (Notes)	6 Months Ended
	Jun. 30, 2019
Segment Reporting [Abstract]
Segment Information	SEGMENT INFORMATION The operations of Vistra Energy are aligned into six reportable business segments: (i) Retail, (ii) ERCOT, (iii) PJM, (iv) NY/NE, (v) MISO and (vi) Asset Closure. Our chief operating decision maker reviews the results of these segments separately and allocates resources to the respective segments as part of our strategic operations. The Retail segment is engaged in retail sales of electricity and related services to residential, commercial and industrial customers. Substantially all of these activities are conducted by TXU Energy and Value Based Brands in Texas, Dynegy Energy Services in Massachusetts, Ohio, Illinois and Pennsylvania and Homefield Energy in Illinois. The ERCOT, PJM, NY/NE (comprising NYISO and ISO-NE) and MISO segments are engaged in electricity generation, wholesale energy sales and purchases, commodity risk management activities, fuel production and fuel logistics management, all largely within their respective RTO/ISO market. The PJM, NY/NE and MISO segments were established on the Merger Date to reflect markets served by businesses acquired in the Merger. The Asset Closure segment is engaged in the decommissioning and reclamation of retired plants and mines. Separately reporting the Asset Closure segment provides management with better information related to the performance and earnings power of Vistra Energy's ongoing operations and facilitates management's focus on minimizing the cost associated with decommissioning and reclamation of retired plants and mines. We have not allocated any unrealized gains or losses on commodity risk management activities to the Asset Closure segment for the generation plants that were retired in January, February and May 2018. Corporate and Other represents the remaining non-segment operations consisting primarily of (i) general corporate expenses, interest, taxes and other expenses related to our support functions that provide shared services to our operating segments and (ii) CAISO operations. Except as noted in Note 1, the accounting policies of the business segments are the same as those described in the summary of significant accounting policies in Note 1 . Our chief operating decision maker uses more than one measure to assess segment performance, including segment net income (loss), which is the measure most comparable to consolidated net income (loss) prepared based on U.S. GAAP. We account for intersegment sales and transfers as if the sales or transfers were to third parties, that is, at market prices. Certain shared services costs are allocated to the segments. Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Operating revenues (a) Retail $ 1,421 $ 1,454 $ 2,806 $ 2,426 ERCOT 1,671 1,327 2,625 794 PJM 686 485 1,391 485 NY/NE 254 187 599 187 MISO 246 257 500 257 Asset Closure — 21 — 49 Corporate and Other (b) 47 31 164 31 Eliminations (1,493 ) (1,188 ) (2,330 ) (891 ) Consolidated operating revenues $ 2,832 $ 2,574 $ 5,755 $ 3,338 Depreciation and amortization Retail $ (59 ) $ (80 ) $ (118 ) $ (157 ) ERCOT (128 ) (108 ) (259 ) (173 ) PJM (134 ) (125 ) (265 ) (125 ) NY/NE (39 ) (49 ) (104 ) (49 ) MISO (3 ) (3 ) (7 ) (3 ) Asset Closure — — — — Corporate and Other (b) (21 ) (23 ) (37 ) (35 ) Eliminations — (1 ) — — Consolidated depreciation and amortization $ (384 ) $ (389 ) $ (790 ) $ (542 ) Operating income (loss) Retail (c) $ (581 ) $ (303 ) $ (563 ) $ 455 ERCOT 1,047 680 1,335 (409 ) PJM 185 24 348 24 NY/NE 78 (7 ) 94 (7 ) MISO 35 31 46 31 Asset Closure (16 ) 1 (30 ) (22 ) Corporate and Other (b) (19 ) (196 ) (12 ) (237 ) Eliminations — 1 — 1 Consolidated operating income (loss) $ 729 $ 231 $ 1,218 $ (164 ) Net income (loss) Retail (c) $ (585 ) $ (288 ) $ (571 ) $ 483 ERCOT 1,056 679 1,356 (407 ) PJM 183 23 346 23 NY/NE 79 (5 ) 100 (5 ) MISO 35 31 46 31 Asset Closure (15 ) 2 (29 ) (20 ) Corporate and Other (b) (399 ) (337 ) (670 ) (306 ) Consolidated net income (loss) $ 354 $ 105 $ 578 $ (201 ) ____________ (a) The following unrealized net gains (losses) from mark-to-market valuations of commodity positions are included in operating revenues: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Retail $ 6 $ 1 $ 5 $ 13 ERCOT 1,050 668 1,287 (398 ) PJM 184 (10 ) 276 (10 ) NY/NE 31 (24 ) 32 (24 ) MISO 67 30 46 30 Corporate and Other (b) 3 1 19 1 Eliminations (1) (803 ) (463 ) (968 ) 180 Consolidated unrealized net gains (losses) from mark-to-market valuations of commodity positions included in operating revenues $ 538 $ 203 $ 697 $ (208 ) ____________ (1) Amounts offset in fuel, purchased power costs and delivery fees in the Retail segment, with no impact to consolidated results. (b) Other includes CAISO operations. Income tax expense is not reflected in net income of the segments but is reflected entirely in Corporate and Other net income. (c) For the three and six months ended June 30, 2019 , Retail operating loss and net loss is driven by unrealized losses from mark-to-market valuations of commodity positions included in fuel, purchased power costs and delivery fees. For the six months ended June 30, 2018 , Retail operating income and net income is driven by unrealized gains from mark-to-market valuations of commodity positions included in fuel, purchased power costs and delivery fees. June 30, December 31, 2018 Total assets Retail $ 8,249 $ 7,699 ERCOT 10,252 9,347 PJM 5,778 7,188 NY/NE 2,798 2,722 MISO 468 836 Asset Closure 253 254 Corporate and Other and Eliminations (1,278 ) (2,022 ) Consolidated total assets $ 26,520 $ 26,024

Supplementary Financial Informa

Supplementary Financial Information (Notes)	6 Months Ended
	Jun. 30, 2019
Supplementary Financial Information [Abstract]
Supplementary Financial Information	SUPPLEMENTARY FINANCIAL INFORMATION Pension and OPEB Plans — Components of Net Benefit Cost For the three and six months ended June 30, 2019 and 2018 , net periodic benefit costs consisted of the following: Pension Benefits OPEB Benefits Three Months Ended June 30, Six Months Ended Three Months Ended June 30, Six Months Ended 2019 2018 2019 2018 2019 2018 2019 2018 Service cost $ 2 $ 4 $ 4 $ 5 $ — $ 1 $ — $ 1 Other costs — — — — 2 1 4 2 Net periodic benefit cost $ 2 $ 4 $ 4 $ 5 $ 2 $ 2 $ 4 $ 3 Interest Expense and Related Charges Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Interest paid/accrued $ 154 $ 166 $ 305 $ 216 Unrealized mark-to-market net (gains) losses on interest rate swaps 119 (25 ) 199 (86 ) Amortization of debt issuance costs, discounts and premiums — 3 (2 ) 4 Debt extinguishment gain (3 ) — (10 ) — Capitalized interest (3 ) (4 ) (7 ) (7 ) Other 7 6 10 10 Total interest expense and related charges $ 274 $ 146 $ 495 $ 137 The weighted average interest rate applicable to the Vistra Operations Credit Facilities, taking into account the interest rate swaps discussed in Note 11 , was 4.03% at June 30, 2019 . Other Income and Deductions Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Other income: Office space sublease rental income (a) $ — $ 2 $ — $ 4 Insurance settlement (b) 8 — 19 — Funds released from escrow to settle pre-petition claims of our predecessor — — 9 — Sale of land (b) — — — 1 Interest income 3 4 7 10 All other 2 1 4 3 Total other income $ 13 $ 7 $ 39 $ 18 Other deductions: All other 2 1 $ 5 $ 3 Total other deductions $ 2 $ 1 $ 5 $ 3 ____________ (a) Reported in Corporate and Other non-segment. Beginning January 1, 2019, our sublease rental income related to real estate leases is reported in selling, general and administrative expenses in the condensed statements of consolidated income (loss). (b) Reported in ERCOT segment. Restricted Cash June 30, December 31, 2018 Current Assets Amounts related to restructuring escrow accounts $ 42 $ 57 Total restricted cash $ 42 $ 57 Trade Accounts Receivable June 30, December 31, Wholesale and retail trade accounts receivable $ 1,118 $ 1,106 Allowance for uncollectible accounts (17 ) (19 ) Trade accounts receivable — net $ 1,101 $ 1,087 Gross trade accounts receivable at June 30, 2019 and December 31, 2018 included unbilled retail revenues of $375 million and $350 million , respectively. Allowance for Uncollectible Accounts Receivable Six Months Ended June 30, 2019 2018 Allowance for uncollectible accounts receivable at beginning of period $ 19 $ 14 Increase for bad debt expense 29 22 Decrease for account write-offs (31 ) (22 ) Allowance for uncollectible accounts receivable at end of period $ 17 $ 14 Inventories by Major Category June 30, December 31, Materials and supplies $ 290 $ 286 Fuel stock 172 115 Natural gas in storage 14 11 Total inventories $ 476 $ 412 Investments June 30, December 31, Nuclear plant decommissioning trust $ 1,342 $ 1,170 Assets related to employee benefit plans 31 31 Land 49 49 Total investments $ 1,422 $ 1,250 Investment in Unconsolidated Subsidiaries On the Merger Date, we assumed Dynegy's 50% interest in Northeast Energy, LP (NELP), a joint venture with NextEra Energy, Inc., which indirectly owns the Bellingham NEA facility and the Sayreville facility. At June 30, 2019 , our investment in NELP totaled $125 million . Our risk of loss related to our equity method investment is limited to our investment balance. Equity earnings related to our investment in NELP totaled $3 million and $4 million for the three months ended June 30, 2019 and 2018 , respectively, and $9 million and $4 million for the six months ended June 30, 2019 and 2018 , respectively, recorded in equity in earnings (loss) of unconsolidated investment in our condensed statements of consolidated net income (loss). We received distributions totaling $9 million and $6 million for the three months ended June 30, 2019 and 2018 , respectively, and $14 million and $6 million for the six months ended June 30, 2019 and 2018 , respectively. 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 Electric Delivery Company LLC's (Oncor) customers as a delivery fee surcharge over the life of the plant and deposited by Vistra Energy (and prior to the Effective Date, a subsidiary of 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 regulatory asset/liability (currently a regulatory liability reported in other noncurrent liabilities and deferred credits) that will ultimately be settled through changes in Oncor's delivery fees rates. If funds recovered from Oncor's customers held in the trust fund are determined to be inadequate to decommission the Comanche Peak nuclear generation plant, Oncor would be required to collect all additional amounts from its customers, with no obligation from Vistra Energy, provided that Vistra Energy complied with PUCT rules and regulations regarding decommissioning trusts. A summary of investments in the fund follows: June 30, 2019 Cost (a) Unrealized gain Unrealized loss Fair market value Debt securities (b) $ 481 $ 21 $ — $ 502 Equity securities (c) 272 568 — 840 Total $ 753 $ 589 $ — $ 1,342 December 31, 2018 Cost (a) Unrealized gain Unrealized loss Fair market value Debt securities (b) $ 444 $ 7 $ (8 ) $ 443 Equity securities (c) 280 448 (1 ) 727 Total $ 724 $ 455 $ (9 ) $ 1,170 ____________ (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 government and municipal bonds and investment grade corporate bonds. The debt securities had an average coupon rate of 3.44% and 3.69% at June 30, 2019 and December 31, 2018 , respectively, and an average maturity of nine years and eight years at June 30, 2019 and December 31, 2018 , respectively. (c) The investment objective for equity securities is to invest tax efficiently and to match the performance of the S&P 500 Index for U.S. equity investments and the MSCI EAFE Index for non-U.S. equity investments. Debt securities held at June 30, 2019 mature as follows: $186 million in one to five years, $134 million in five to 10 years and $182 million after 10 years. The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from such sales. Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Realized gains $ 7 $ 1 $ 10 $ 1 Realized losses $ (2 ) $ (1 ) $ (3 ) $ (3 ) Proceeds from sales of securities $ 214 $ 47 $ 292 $ 93 Investments in securities $ (219 ) $ (52 ) $ (302 ) $ (103 ) Property, Plant and Equipment June 30, December 31, Power generation and structures $ 15,066 $ 14,604 Land 640 642 Office and other equipment 163 182 Total 15,869 15,428 Less accumulated depreciation (1,923 ) (1,284 ) Net of accumulated depreciation 13,946 14,144 Nuclear fuel (net of accumulated amortization of $163 million and $189 million) 179 191 Construction work in progress 135 277 Property, plant and equipment — net $ 14,260 $ 14,612 Depreciation expenses totaled $312 million and $292 million for the three months ended June 30, 2019 and 2018 , respectively, and $647 million and $360 million for six months ended June 30, 2019 and 2018 , respectively. Asset Retirement and Mining Reclamation Obligations (ARO) These liabilities primarily relate to nuclear generation plant decommissioning, land reclamation related to lignite mining, removal of coal/lignite 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 delivery fees charged by Oncor. At June 30, 2019 , the carrying value of our ARO related to our nuclear generation plant decommissioning totaled $1.298 billion , which is lower than the fair value of the assets contained in the nuclear decommissioning trust. Since the costs to ultimately decommission that plant are recoverable through the regulatory rate making process as part of Oncor's delivery fees, a corresponding regulatory liability has been recorded to our condensed consolidated balance sheet of $44 million in other noncurrent liabilities and deferred credits. The following tables summarize the changes to these obligations, reported as asset retirement obligations (current and noncurrent liabilities) in our condensed consolidated balance sheets, for the six months ended June 30, 2019 and 2018 . Nuclear Plant Decommissioning Mining Land Reclamation Coal Ash and Other Total Liability at December 31, 2018 $ 1,276 $ 442 $ 655 $ 2,373 Additions: Accretion 22 11 16 49 Adjustment for change in estimates — (3 ) (3 ) (6 ) Adjustment for obligations assumed through acquisitions — — (3 ) (3 ) Reductions: Payments — (32 ) (16 ) (48 ) Liability at June 30, 2019 1,298 418 649 2,365 Less amounts due currently — (132 ) (100 ) (232 ) Noncurrent liability at June 30, 2019 $ 1,298 $ 286 $ 549 $ 2,133 Nuclear Plant Decommissioning Mining Land Reclamation Coal Ash and Other Total Liability at December 31, 2017 $ 1,233 $ 438 $ 265 $ 1,936 Additions: Accretion 21 11 12 44 Adjustment for change in estimates — 7 (43 ) (36 ) Obligations assumed in the Merger — 2 417 419 Reductions: Payments — (35 ) (6 ) (41 ) Liability at June 30, 2018 $ 1,254 $ 423 $ 645 $ 2,322 Other Noncurrent Liabilities and Deferred Credits The balance of other noncurrent liabilities and deferred credits consists of the following: June 30, December 31, Retirement and other employee benefits $ 273 $ 270 Finance lease liabilities 74 — Uncertain tax positions, including accrued interest 6 4 Other 111 66 Total other noncurrent liabilities and deferred credits $ 464 $ 340 Fair Value of Debt June 30, 2019 December 31, 2018 Long-term debt (see Note 11): Fair Value Hierarchy Carrying Amount Fair Value Carrying Amount Fair Value Long-term debt under the Vistra Operations Credit Facilities Level 2 $ 3,808 $ 3,796 $ 5,820 $ 5,599 Vistra Operations Senior Notes Level 2 5,535 5,787 987 963 Vistra Energy Senior Notes Level 2 1,603 1,592 3,819 3,765 7.000% Amortizing Notes Level 2 8 8 23 24 Forward Capacity Agreements Level 3 212 212 221 221 Equipment Financing Agreements Level 3 98 98 102 102 Mandatorily redeemable subsidiary preferred stock Level 2 70 70 70 70 Building Financing Level 2 20 19 23 21 We determine fair value in accordance with accounting standards as discussed in Note 15 . 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. Supplemental Cash Flow Information The following table reconciles cash, cash equivalents and restricted cash reported in our condensed statements of consolidated cash flows to the amounts reported in our condensed balance sheets at June 30, 2019 and December 31, 2018 : June 30, December 31, Cash and cash equivalents $ 964 $ 636 Restricted cash included in current assets 42 57 Total cash, cash equivalents and restricted cash $ 1,006 $ 693 The following table summarizes our supplemental cash flow information for the six months ended June 30, 2019 and 2018 : Six Months Ended June 30, 2019 2018 Cash payments related to: Interest paid $ 307 $ 344 Capitalized interest (7 ) (7 ) Interest paid (net of capitalized interest) $ 300 $ 337 Income taxes (a) $ 9 $ 58 Noncash investing and financing activities: Construction expenditures (b) $ 41 $ 13 Vistra Energy common stock issued in the Merger (Notes 2 and 14) $ — $ 2,245 ____________ (a) Income tax payments are net of tax refunds of $21 million and $5 million in the six months ended June 30, 2019 and 2018 , respectively (b) Represents end-of-period accruals for ongoing construction projects.

Supplemental Condensed Consolid

Supplemental Condensed Consolidating Financial Information Supplemental Condensed Consolidating Financial Information (Notes)	6 Months Ended
	Jun. 30, 2019
Supplemental Condensed Consolidating Financial Information [Abstract]
Supplemental Condensed Consolidating Financial Information [Text Block]	SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION Our senior unsecured notes are guaranteed by substantially all of our wholly owned subsidiaries. The following condensed consolidating financial statements present the financial information of (i) Vistra Energy Corp. (Parent), which is the ultimate parent company and issuer of the senior notes with effect as of the Merger Date, on a stand-alone, unconsolidated basis, (ii) the guarantor subsidiaries of Vistra Energy (Guarantor Subsidiaries), (iii) the non-guarantor subsidiaries of Vistra Energy (Non-Guarantor Subsidiaries) and (iv) the eliminations necessary to arrive at the information for Vistra Energy on a consolidated basis. The Guarantor Subsidiaries consist of the wholly-owned subsidiaries, which jointly, severally, fully and unconditionally, guarantee the payment obligations under the senior notes. See Note 11 for discussion of the senior notes. These statements should be read in conjunction with the unaudited condensed consolidated financial statements and notes thereto of Vistra Energy. The supplemental condensed consolidating financial information has been prepared pursuant to the rules and regulations for condensed financial information and does not include all disclosures included in annual financial statements. The inclusion of Vistra Energy's subsidiaries as either Guarantor Subsidiaries or Non-Guarantor Subsidiaries in the condensed consolidating financial information is determined as of the most recent balance sheet date presented. The Parent files a consolidated U.S. federal income tax return. All consolidated income tax expense or benefits and deferred tax assets and liabilities have been allocated to the respective subsidiary columns in accordance with the accounting rules that apply to separate financial statements of subsidiaries. Vistra Energy Corp. (Parent) received $3.195 billion in dividends from its consolidated subsidiaries in the six months ended June 30, 2019 . Condensed Statements of Consolidating Income (Loss) for the Three Months Ended June 30, 2019 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Operating revenues $ — $ 2,835 $ 53 $ (56 ) $ 2,832 Fuel, purchased power costs and delivery fees — (1,144 ) (19 ) 24 (1,139 ) Operating costs — (355 ) (15 ) — (370 ) Depreciation and amortization (1 ) (364 ) (19 ) — (384 ) Selling, general and administrative expenses (13 ) (216 ) (19 ) 38 (210 ) Operating income (loss) (14 ) 756 (19 ) 6 729 Other income 1 14 — (2 ) 13 Other deductions — (2 ) — — (2 ) Interest expense and related charges (29 ) (241 ) (6 ) 2 (274 ) Impacts of Tax Receivable Agreement 33 — — — 33 Equity in earnings of unconsolidated investment — 3 — — 3 Income (loss) before income taxes (9 ) 530 (25 ) 6 502 Income tax benefit (expense) 4 (160 ) 14 (6 ) (148 ) Equity in earnings (loss) of subsidiaries, net of tax 361 (9 ) — (352 ) — Net income (loss) 356 361 (11 ) (352 ) 354 Net loss attributable to noncontrolling interest — — 2 — 2 Net income (loss) attributable to Vistra Energy $ 356 $ 361 $ (9 ) $ (352 ) $ 356 Condensed Statements of Consolidating Income (Loss) for the Three Months Ended June 30, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Operating revenues $ — $ 2,508 $ 68 $ (2 ) $ 2,574 Fuel, purchased power costs and delivery fees — (1,166 ) (51 ) 1 (1,216 ) Operating costs — (370 ) (16 ) — (386 ) Depreciation and amortization — (371 ) (18 ) — (389 ) Selling, general and administrative expenses (192 ) (160 ) (2 ) 2 (352 ) Operating income (loss) (192 ) 441 (19 ) 1 231 Other income 3 5 — (1 ) 7 Other deductions — (1 ) — — (1 ) Interest expense and related charges (87 ) (58 ) (1 ) — (146 ) Impacts of Tax Receivable Agreement (64 ) — — — (64 ) Equity in earnings of unconsolidated investment — 4 — — 4 Income (loss) before income taxes (340 ) 391 (20 ) — 31 Income tax benefit (expense) 102 (34 ) 6 — 74 Equity in earnings (loss) of subsidiaries, net of tax 343 (14 ) — (329 ) — Net income (loss) 105 343 (14 ) (329 ) 105 Net loss attributable to noncontrolling interest — — 3 — 3 Net income (loss) attributable to Vistra Energy $ 105 $ 343 $ (11 ) $ (329 ) $ 108 Condensed Statements of Consolidating Income (Loss) for the Six Months Ended June 30, 2019 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Operating revenues $ — $ 5,761 $ 110 $ (116 ) $ 5,755 Fuel, purchased power costs and delivery fees — (2,612 ) (48 ) 60 (2,600 ) Operating costs — (726 ) (29 ) — (755 ) Depreciation and amortization (2 ) (746 ) (42 ) — (790 ) Selling, general and administrative expenses (31 ) (395 ) (38 ) 72 (392 ) Operating income (loss) (33 ) 1,282 (47 ) 16 1,218 Other income 15 31 1 (8 ) 39 Other deductions — (5 ) — — (5 ) Interest expense and related charges (72 ) (419 ) (12 ) 8 (495 ) Impacts of Tax Receivable Agreement 36 — — — 36 Equity in earnings of unconsolidated investment — 10 — — 10 Income (loss) before income taxes (54 ) 899 (58 ) 16 803 Income tax benefit (expense) 17 (249 ) 23 (16 ) (225 ) Equity in earnings (loss) of subsidiaries, net of tax 618 (32 ) — (586 ) — Net income (loss) 581 618 (35 ) (586 ) 578 Net loss attributable to noncontrolling interest — — 3 — 3 Net income (loss) attributable to Vistra Energy $ 581 $ 618 $ (32 ) $ (586 ) $ 581 Condensed Statements of Consolidating Income (Loss) for the Six Months Ended June 30, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Operating revenues $ — $ 3,272 $ 68 $ (2 ) $ 3,338 Fuel, purchased power costs and delivery fees — (1,816 ) (51 ) 1 (1,866 ) Operating costs — (564 ) (16 ) — (580 ) Depreciation and amortization — (524 ) (18 ) — (542 ) Selling, general and administrative expenses (226 ) (288 ) (2 ) 2 (514 ) Operating income (loss) (226 ) 80 (19 ) 1 (164 ) Other income 6 12 1 (1 ) 18 Other deductions — (3 ) — — (3 ) Interest expense and related charges (87 ) (49 ) (1 ) — (137 ) Impacts of Tax Receivable Agreement (82 ) — — — (82 ) — 4 — — 4 Income (loss) before income taxes (389 ) 44 (19 ) — (364 ) Income tax benefit (expense) 117 41 5 — 163 Equity in earnings (loss) of subsidiaries, net of tax 71 (14 ) — (57 ) — Net income (loss) (201 ) 71 (14 ) (57 ) (201 ) Net loss attributable to noncontrolling interest — — 3 — 3 Net income (loss) attributable to Vistra Energy $ (201 ) $ 71 $ (11 ) $ (57 ) $ (198 ) Condensed Statements of Consolidating Comprehensive Income (Loss) for the Three Months Ended June 30, 2019 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Net income (loss) $ 356 $ 361 $ (11 ) $ (352 ) $ 354 Other comprehensive income (loss), net of tax effects: Effect related to pension and other retirement benefit obligations — — — — — Total other comprehensive income — — — — — Comprehensive income (loss) 356 361 (11 ) (352 ) 354 Comprehensive loss attributable to noncontrolling interest — — 2 — 2 Comprehensive income (loss) attributable to Vistra Energy $ 356 $ 361 $ (9 ) $ (352 ) $ 356 Condensed Statements of Consolidating Comprehensive Income (Loss) for the Three Months Ended June 30, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Net income (loss) $ 105 $ 343 $ (14 ) $ (329 ) $ 105 Other comprehensive income (loss), net of tax effects: Effect related to pension and other retirement benefit obligations — — — — — Total other comprehensive income — — — — — Comprehensive income (loss) $ 105 $ 343 $ (14 ) $ (329 ) $ 105 Comprehensive loss attributable to noncontrolling interest — — 3 — 3 Comprehensive income (loss) attributable to Vistra Energy $ 105 $ 343 $ (11 ) $ (329 ) $ 108 Condensed Statements of Consolidating Comprehensive Income (Loss) for the Six Months Ended June 30, 2019 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Net income (loss) $ 581 $ 618 $ (35 ) $ (586 ) $ 578 Other comprehensive income (loss), net of tax effects: Effect related to pension and other retirement benefit obligations 1 — — — 1 Total other comprehensive income 1 — — — 1 Comprehensive income (loss) 582 618 (35 ) (586 ) 579 Comprehensive loss attributable to noncontrolling interest — — 3 — 3 Comprehensive income (loss) attributable to Vistra Energy $ 582 $ 618 $ (32 ) $ (586 ) $ 582 Condensed Statements of Consolidating Comprehensive Income (Loss) for the Six Months Ended June 30, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Net income (loss) $ (201 ) $ 71 $ (14 ) $ (57 ) $ (201 ) Other comprehensive income (loss), net of tax effects: Effect related to pension and other retirement benefit obligations 1 — — — 1 Total other comprehensive income 1 — — — 1 Comprehensive income (loss) $ (200 ) $ 71 $ (14 ) $ (57 ) $ (200 ) Comprehensive loss attributable to noncontrolling interest — — 3 — 3 Comprehensive income (loss) attributable to Vistra Energy $ (200 ) $ 71 $ (11 ) $ (57 ) $ (197 ) Condensed Statements of Consolidating Cash Flows for the Six Months Ended June 30, 2019 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Cash flows — operating activities: Cash provided by (used in) operating activities $ (127 ) $ 1,111 $ (102 ) $ — $ 882 Cash flows — financing activities: Issuances of long-term debt — 4,600 — — 4,600 Repayments/repurchases of debt (2,114 ) (2,023 ) — — (4,137 ) Net borrowings under accounts receivable securitization program — — 91 91 Cash dividends paid (120 ) (3,195 ) — 3,195 (120 ) Stock repurchase (457 ) — — — (457 ) Debt tender offer and other financing fees (92 ) (54 ) — — (146 ) Other, net (1 ) — — — (1 ) Cash provided by (used in) financing activities (2,784 ) (672 ) 91 3,195 (170 ) Cash flows — investing activities: Capital expenditures, including LTSA prepayments (1 ) (246 ) — — (247 ) Nuclear fuel purchases — (20 ) — — (20 ) Development and growth expenditures — (36 ) — — (36 ) Proceeds from sales of nuclear decommissioning trust fund securities — 292 — — 292 Investments in nuclear decommissioning trust fund securities — (302 ) — — (302 ) Proceeds from sale of environmental allowances — 31 — — 31 Purchases of environmental allowances — (138 ) — — (138 ) Dividend received from subsidiaries 3,195 — (3,195 ) — Other, net — 21 — — 21 Cash provided by (used in) investing activities 3,194 (398 ) — (3,195 ) (399 ) Net change in cash, cash equivalents and restricted cash 283 41 (11 ) — 313 Cash, cash equivalents and restricted cash — beginning balance 228 453 12 — 693 Cash, cash equivalents and restricted cash — ending balance $ 511 $ 494 $ 1 $ — $ 1,006 Condensed Statements of Consolidating Cash Flows for the Six Months Ended June 30, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Cash flows — operating activities: Cash provided by (used in) operating activities $ (280 ) $ (109 ) $ 360 $ — $ (29 ) Cash flows — financing activities: Repayments/repurchases of debt (840 ) (498 ) — — (1,338 ) Stock repurchase (63 ) — — — (63 ) Debt financing fees (29 ) (17 ) — — (46 ) Other, net — 4 — — 4 Cash provided by (used in) financing activities (932 ) (511 ) — — (1,443 ) Cash flows — investing activities: Capital expenditures (4 ) (147 ) (2 ) — (153 ) Nuclear fuel purchases — (28 ) — — (28 ) Development and growth expenditures — (21 ) — — (21 ) Cash acquired in the Merger 418 27 — — 445 Proceeds from sales of nuclear decommissioning trust fund securities — 93 — — 93 Investments in nuclear decommissioning trust fund securities — (103 ) — — (103 ) Proceeds from sale of environmental allowances — — — — — Purchases of environmental allowances — (1 ) — — (1 ) Other, net (4 ) 359 (345 ) — 10 Cash provided by (used in) investing activities 410 179 (347 ) — 242 Net change in cash, cash equivalents and restricted cash (802 ) (441 ) 13 — (1,230 ) Cash, cash equivalents and restricted cash — beginning balance 1,183 863 — — 2,046 Cash, cash equivalents and restricted cash — ending balance $ 381 $ 422 $ 13 $ — $ 816 Condensed Consolidating Balance Sheet as of June 30, 2019 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ 469 $ 494 $ 1 $ — $ 964 Restricted cash 42 — — — 42 Advances to affiliates — 40 1 (41 ) — Trade accounts receivable — net 11 640 650 (200 ) 1,101 Accounts receivable — affiliates 2 770 242 (1,014 ) — Notes due from affiliates — 102 — (102 ) — Income taxes receivable — — — — — Inventories — 453 23 — 476 Commodity and other derivative contractual assets — 1,418 — — 1,418 Margin deposits related to commodity contracts — 253 — — 253 Prepaid expense and other current assets 130 140 15 — 285 Total current assets 654 4,310 932 (1,357 ) 4,539 Investments — 1,390 32 — 1,422 Investment in unconsolidated subsidiary — 127 — — 127 Investment in affiliated companies 8,925 123 — (9,048 ) — Property, plant and equipment — net 4 13,713 543 — 14,260 Operating lease right-of-use assets — 34 — — 34 Goodwill — 2,082 — — 2,082 Identifiable intangible assets — net 36 2,344 3 — 2,383 Commodity and other derivative contractual assets — 124 — — 124 Accumulated deferred income taxes 810 415 — (81 ) 1,144 Other noncurrent assets 131 267 7 — 405 Total assets $ 10,560 $ 24,929 $ 1,517 $ (10,486 ) $ 26,520 LIABILITIES AND EQUITY Current liabilities: Accounts receivable securitization program $ — $ — $ 430 $ — $ 430 Advances from affiliates — 1 40 (41 ) — Long-term debt due currently 8 148 5 — 161 Trade accounts payable — 761 211 (190 ) 782 Accounts payable — affiliates 556 143 315 (1,014 ) — Notes due to affiliates — — 101 (101 ) — Commodity and other derivative contractual liabilities — 1,514 — — 1,514 Margin deposits related to commodity contracts — 8 — — 8 Accrued taxes 12 — — — 12 Accrued taxes other than income — 114 1 — 115 Accrued interest 21 65 7 (11 ) 82 Asset retirement obligations — 232 — — 232 Operating lease liabilities — 12 1 — 13 Other current liabilities 53 253 2 — 308 Total current liabilities 650 3,251 1,113 (1,357 ) 3,657 Condensed Consolidating Balance Sheet as of June 30, 2019 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Long-term debt, less amounts due currently 1,602 9,560 31 — 11,193 Operating lease liabilities — 38 2 — 40 Commodity and other derivative contractual liabilities — 404 — — 404 Accumulated deferred income taxes — — 91 (81 ) 10 Tax Receivable Agreement obligation 384 — — — 384 Asset retirement obligations — 2,119 14 — 2,133 Identifiable intangible liabilities — net — 207 124 — 331 Other noncurrent liabilities and deferred credits 20 425 19 — 464 Total liabilities 2,656 16,004 1,394 (1,438 ) 18,616 Total stockholders' equity 7,904 8,925 123 (9,048 ) 7,904 Noncontrolling interest in subsidiary — — — — — Total liabilities and equity $ 10,560 $ 24,929 $ 1,517 $ (10,486 ) $ 26,520 Condensed Consolidating Balance Sheet as of December 31, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ 171 $ 453 $ 12 $ — $ 636 Restricted cash 57 — — — 57 Advances to affiliates 11 11 — (22 ) — Trade accounts receivable — net 4 729 464 (110 ) 1,087 Accounts receivable - affiliates — 245 — (245 ) — Notes due from affiliates — 101 — (101 ) — Income taxes receivable — 1 — (1 ) — Inventories — 391 21 — 412 Commodity and other derivative contractual assets — 730 — — 730 Margin deposits related to commodity contracts — 361 — — 361 Prepaid expense and other current assets 2 134 16 — 152 Total current assets 245 3,156 513 (479 ) 3,435 Investments — 1,218 32 — 1,250 Investments in unconsolidated subsidiary — 131 — — 131 Investment in affiliated companies 11,186 263 — (11,449 ) — Property, plant and equipment — net 15 14,017 580 — 14,612 Goodwill — 2,068 — — 2,068 Identifiable intangible assets — net 10 2,480 3 — 2,493 Commodity and other derivative contractual assets — 109 — — 109 Accumulated deferred income taxes 809 599 — (72 ) 1,336 Other noncurrent assets 255 330 5 — 590 Total assets $ 12,520 $ 24,371 $ 1,133 $ (12,000 ) $ 26,024 Condensed Consolidating Balance Sheet as of December 31, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated LIABILITIES AND EQUITY Current liabilities: Accounts receivable securitization program $ — $ — $ 339 $ — $ 339 Advances from affiliates — — 22 (22 ) — Long-term debt due currently 23 163 5 — 191 Trade accounts payable 2 928 121 (106 ) 945 Accounts payable - affiliates 236 — 9 (245 ) — Notes due to affiliates — — 101 (101 ) — Commodity and other derivative contractual liabilities — 1,376 — — 1,376 Margin deposits related to commodity contracts — 4 — — 4 Accrued income taxes 11 — — (1 ) 10 Accrued taxes other than income — 181 1 — 182 Accrued interest 48 29 4 (4 ) 77 Asset retirement obligations — 156 — — 156 Other current liabilities 74 267 4 — 345 Total current liabilities 394 3,104 606 (479 ) 3,625 Long-term debt, less amounts due currently 3,819 7,027 28 — 10,874 Commodity and other derivative contractual liabilities — 270 — — 270 Accumulated deferred income taxes — — 82 (72 ) 10 Tax Receivable Agreement obligation 420 — — — 420 Asset retirement obligations — 2,203 14 — 2,217 Identifiable intangible liabilities — net — 278 123 — 401 Other noncurrent liabilities and deferred credits 20 303 17 — 340 Total liabilities 4,653 13,185 870 (551 ) 18,157 Total stockholders' equity 7,867 11,186 259 (11,449 ) 7,863 Noncontrolling interest in subsidiary — — 4 — 4 Total liabilities and equity $ 12,520 $ 24,371 $ 1,133 $ (12,000 ) $ 26,024

Business And Significant Acco_2

Business And Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The condensed consolidated financial statements have been prepared in accordance with U.S. GAAP and on the same basis as the audited financial statements included in our annual report on Form 10-K for the year ended December 31, 2018. Adjustments (consisting of normal recurring accruals) necessary for a fair presentation of the results of operations and financial position have been included therein. All intercompany items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with U.S. GAAP have been omitted pursuant to the rules and regulations of the SEC. Because the condensed consolidated interim financial statements do not include all of the information and footnotes required by U.S. GAAP, they should be read in conjunction with the audited financial statements and related notes contained in our annual report on Form 10-K for the year ended December 31, 2018. The results of operations for an interim period may not give a true indication of results for a full year. All dollar amounts in the financial statements and tables in the notes are stated in millions of U.S. dollars unless otherwise indicated.
Use of Estimates	Use of Estimates Preparation of financial statements requires estimates and assumptions about future events that affect the reporting of assets and liabilities at the balance sheet dates and the reported amounts of revenue and expense, including fair value measurements, estimates of expected obligations, judgment related to the potential timing of events and other estimates. 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.
Lessee, Leases [Policy Text Block]	Leases At the inception of a contract we determine if it is or contains a lease, which involves the contract conveying the right to control the use of explicitly or implicitly identified property, plant, or equipment for a period of time in exchange for consideration. Right-of-use (ROU) assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. ROU assets and lease liabilities are recognized at the commencement date of the underlying lease based on the present value of lease payments over the lease term. We use our secured incremental borrowing rate based on the information available at the lease commencement date to determine the present value of lease payments. Operating leases are included in operating lease ROU assets, operating lease liabilities (current) and operating lease liabilities (noncurrent) on our condensed consolidated balance sheet. Finance leases are included in property, plant and equipment, other current liabilities and other noncurrent liabilities and deferred credits on our condensed consolidated balance sheet. Lease term includes options to extend or terminate the lease when it is reasonably certain that we will exercise the option. We have elected the practical expedient which permits us to not reassess under the new standard our prior conclusion about lease classification and initial direct costs. We have also elected the practical expedient to not separate lease and non-lease components for a majority of the lease asset classes. We have also elected the hindsight practical expedient to determine the lease term. Leases with an initial lease term of 12 months or less are not recorded on the balance sheet; we recognize lease expense for these leases on a straight-line basis over the lease term. We also present lessor sublease income on a net basis against the related lessee lease expense.

Business And Significant Acco_3

Business And Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2019
Accounting Policies [Abstract]
Schedule of new accounting pronouncements and changes in accounting principles	As of January 1, 2019, the cumulative effect of the changes made to our condensed consolidated balance sheet for the adoption of the new lease standard was as follows: December 31, 2018 Adoption of New Lease Standard January 1, 2019 Impact on condensed consolidated balance sheet: Assets Property, plant and equipment — net $ 14,612 $ 15 $ 14,627 Operating lease right-of-use assets — 70 70 Prepaid expense and other current assets 152 (2 ) 150 Accumulated deferred income taxes 1,336 1 1,337 Liabilities Other current liabilities 345 (1 ) 344 Operating lease liabilities — 109 109 Identifiable intangible liabilities 401 (36 ) 365 Other noncurrent liabilities and deferred credits 340 14 354 Equity Retained deficit (1,449 ) (2 ) (1,451 )

Acquisition of Crius, Dynegy _2

Acquisition of Crius, Dynegy Merger Transaction and Business Combination Accounting (Tables)	6 Months Ended
	Jun. 30, 2019
Business Combinations [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	The following table summarizes the consideration paid and the final allocation of the purchase price to the fair value amounts recognized for the assets acquired and liabilities assumed related to the Merger as of the Merger Date. Based on the opening price of Vistra Energy common stock on the Merger Date, the purchase price was approximately $2.3 billion . During the three months ended March 31, 2019, the purchase price allocation was completed. During the period from April 9, 2018 through March 31, 2019, we updated the initial purchase price allocation with final valuations by increasing property, plant and equipment by $173 million , decreasing intangible assets by $36 million , increasing goodwill by $175 million , decreasing accounts receivable, inventory, prepaid expenses and other current assets by $10 million , increasing accumulated deferred tax asset by $127 million , decreasing other noncurrent assets by $113 million , increasing trade accounts payable and other current liabilities by $89 million , increasing other noncurrent liabilities by $177 million , increasing asset retirement obligations, including amounts due currently, by $56 million , as well as other minor adjustments. The valuation revisions were a result of updated inputs used in determining the fair value of the acquired assets and liabilities. Dynegy shares outstanding as of April 9, 2018 (in millions) 144.8 Exchange Ratio 0.652 Vistra Energy shares issued for Dynegy shares outstanding (in millions) 94.4 Opening price of Vistra Energy common stock on April 9, 2018 $ 19.87 Purchase price for common stock $ 1,876 Fair value of equity component of tangible equity units $ 369 Fair value of outstanding stock compensation awards attributable to pre-combination service $ 26 Fair value of outstanding warrants $ 2 Total purchase price $ 2,273 Final Purchase Price Allocation Cash and cash equivalents $ 445 Trade accounts receivables, inventories, prepaid expenses and other current assets 853 Property, plant and equipment 10,535 Accumulated deferred income taxes 518 Identifiable intangible assets 351 Goodwill 175 Other noncurrent assets 419 Total assets acquired 13,296 Trade accounts payable and other current liabilities 733 Commodity and other derivative contractual assets and liabilities, net 422 Asset retirement obligations, including amounts due currently 475 Long-term debt, including amounts due currently 8,919 Other noncurrent liabilities 469 Total liabilities assumed 11,018 Identifiable net assets acquired 2,278 Noncontrolling interest in subsidiary 5 Total purchase price $ 2,273
Unaudited Pro Forma Financial Information [Table Text Block]	Unaudited Pro Forma Financial Information — The following unaudited pro forma financial information for the six months ended June 30, 2018 assumes that the Merger occurred on January 1, 2018. The unaudited pro forma financial information is provided for information purposes only and is not necessarily indicative of the results of operations that would have occurred had the Merger been completed on January 1, 2018, nor is the unaudited pro forma financial information indicative of future results of operations, which may differ materially from the pro forma financial information presented here. Six Months Revenues $ 4,789 Net loss $ (439 ) Net loss attributable to Vistra Energy $ (435 ) Net loss attributable to Vistra Energy per weighted average share of common stock outstanding — basic $ (0.83 ) Net loss attributable to Vistra Energy per weighted average share of common stock outstanding — diluted $ (0.83 )

Retirement of Generation Faci_2

Retirement of Generation Facilities (Tables)	6 Months Ended
	Jun. 30, 2019
Retirement of Generation Facilities [Abstract]
Retirements of generation capacity	Two of our non-operated, jointly held power plants acquired in the Merger, for which our proportional generation capacity was 883 MW, were retired in May 2018. These units were retired as previously scheduled. No gain or loss was recorded in conjunction with the retirement of these units, and the operational results of these facilities are included in our Asset Closure segment. The following table details the units retired. Name Location Fuel Type Net Generation Capacity (MW) Ownership Interest Date Units Taken Offline Killen Manchester, Ohio Coal 204 33% May 31, 2018 Stuart Aberdeen, Ohio Coal 679 39% May 24, 2018 Total 883 In January and February 2018, we retired three power plants with a total installed nameplate generation capacity of 4,167 MW. We decided to retire these units because they were projected to be uneconomic based on then current market conditions and would have faced significant environmental costs associated with operating such units. In the case of the Sandow units, the decision also reflected the execution of a contract termination agreement pursuant to which the Company and Alcoa agreed to an early settlement of a long-standing power and mining agreement. Expected retirement expenses were accrued in the third and fourth quarter of 2017 and, as a result, no retirement expenses were recorded related to these facilities in the three and six months ended June 30, 2018 . The operational results of these facilities are included in our Asset Closure segment, which is engaged in the decommissioning and reclamation of retired plants and mines. The following table details the units retired. Name Location (all in the state of Texas) Fuel Type Installed Nameplate Generation Capacity (MW) Number of Units Date Units Taken Offline Monticello Titus County Lignite/Coal 1,880 3 January 4, 2018 Sandow Milam County Lignite 1,137 2 January 11, 2018 Big Brown Freestone County Lignite/Coal 1,150 2 February 12, 2018 Total 4,167 7

Revenue (Tables)

Revenue (Tables)	6 Months Ended
	Jun. 30, 2019
Revenue Recognition and Deferred Revenue [Abstract]
Disaggregation of revenue	Three Months Ended June 30, 2019 Retail ERCOT PJM NY/NE MISO CAISO/Eliminations Consolidated Revenue from contracts with customers: Retail energy charge in ERCOT $ 1,091 $ — $ — $ — $ — $ — $ 1,091 Retail energy charge in Northeast/Midwest 315 — — — — — 315 Wholesale generation revenue from ISO/RTO — 188 130 81 76 22 497 Capacity revenue — — 53 72 11 — 136 Revenue from other wholesale contracts — 52 87 6 41 4 190 Total revenue from contracts with customers 1,406 240 270 159 128 26 2,229 Other revenues: Intangible amortization (10 ) — — (1 ) (4 ) 1 (14 ) Hedging and other revenues (a) 25 404 81 61 26 20 617 Affiliate sales — 1,027 335 35 96 (1,493 ) — Total other revenues 15 1,431 416 95 118 (1,472 ) 603 Total revenues $ 1,421 $ 1,671 $ 686 $ 254 $ 246 $ (1,446 ) $ 2,832 ____________ (a) Includes $538 million of unrealized net gains from mark-to-market valuations of commodity positions. See Note 18 for unrealized net gains (losses) by segment. Three Months Ended June 30, 2018 Retail ERCOT PJM NY/NE MISO Asset Closure CAISO/Eliminations Consolidated Revenue from contracts with customers: Retail energy charge in ERCOT $ 1,111 $ — $ — $ — $ — $ — $ — $ 1,111 Retail energy charge in Northeast/Midwest 336 — — — — — — 336 Wholesale generation revenue from ISO/RTO — 208 367 118 180 15 13 901 Capacity revenue — — 119 82 29 10 11 251 Revenue from other wholesale contracts — 50 8 6 12 — 2 78 Total revenue from contracts with customers 1,447 258 494 206 221 25 26 2,677 Other revenues: Intangible amortization (15 ) — — (2 ) (6 ) — — (23 ) Hedging and other revenues (a) 22 229 (161 ) (29 ) (121 ) (25 ) 5 (80 ) Affiliate sales — 840 152 12 163 21 (1,188 ) — Total other revenues 7 1,069 (9 ) (19 ) 36 (4 ) (1,183 ) (103 ) Total revenues $ 1,454 $ 1,327 $ 485 $ 187 $ 257 $ 21 $ (1,157 ) $ 2,574 ____________ (a) Includes $203 million of unrealized net gains from mark-to-market valuations of commodity positions. See Note 18 for unrealized net gains (losses) by segment. Six Months Ended June 30, 2019 Retail ERCOT PJM NY/NE MISO CAISO/Eliminations Consolidated Revenue from contracts with customers: Retail energy charge in ERCOT $ 2,116 $ — $ — $ — $ — $ — $ 2,116 Retail energy charge in Northeast/Midwest 663 — — — — — 663 Wholesale generation revenue from ISO/RTO — 435 351 276 214 95 1,371 Capacity revenue — — 120 152 24 — 296 Revenue from other wholesale contracts — 97 159 12 57 6 331 Total revenue from contracts with customers 2,779 532 630 440 295 101 4,777 Other revenues: Intangible amortization (19 ) — — (3 ) (9 ) 2 (29 ) Hedging and other revenues (a) 46 562 171 113 54 61 1,007 Affiliate sales — 1,531 590 49 160 (2,330 ) — Total other revenues 27 2,093 761 159 205 (2,267 ) 978 Total revenues $ 2,806 $ 2,625 $ 1,391 $ 599 $ 500 $ (2,166 ) $ 5,755 ____________ (a) Includes $697 million of unrealized net gains from mark-to-market valuations of commodity positions. See Note 18 for unrealized net gains (losses) by segment. Six Months Ended June 30, 2018 Retail ERCOT PJM NY/NE MISO Asset Closure CAISO/Eliminations Consolidated Revenue from contracts with customers: Retail energy charge in ERCOT $ 2,059 $ — $ — $ — $ — $ — $ — $ 2,059 Retail energy charge in Northeast/Midwest 336 — — — — — — 336 Wholesale generation revenue from ISO/RTO — 383 367 118 180 51 13 1,112 Capacity revenue — — 119 82 29 10 11 251 Revenue from other wholesale contracts — 102 8 6 12 1 2 131 Total revenue from contracts with customers 2,395 485 494 206 221 62 26 3,889 Other revenues: Intangible amortization (27 ) (1 ) — (2 ) (6 ) — — (36 ) Hedging and other revenues (a) 58 (233 ) (161 ) (29 ) (121 ) (34 ) 5 (515 ) Affiliate sales — 543 152 12 163 21 (891 ) — Total other revenues 31 309 (9 ) (19 ) 36 (13 ) (886 ) (551 ) Total revenues $ 2,426 $ 794 $ 485 $ 187 $ 257 $ 49 $ (860 ) $ 3,338 ____________ (a) Includes $208 million of unrealized net losses from mark-to-market valuations of commodity positions. See Note 18 for unrealized net gains (losses) by segment.
Accounts receivable, contracts with customers	Accounts Receivable The following table presents trade accounts receivable (net of allowance for uncollectible accounts) relating to both contracts with customers and other activities: June 30, December 31, 2018 Trade accounts receivable from contracts with customers — net $ 977 $ 951 Other trade accounts receivable — net 124 136 Total trade accounts receivable — net $ 1,101 $ 1,087

Goodwill and Identifiable Int_2

Goodwill and Identifiable Intangible Assets and Liabilities (Tables)	6 Months Ended
	Jun. 30, 2019
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of identifiable intangible assets reported in the balance sheet	Identifiable intangible assets are comprised of the following: June 30, 2019 December 31, 2018 Identifiable Intangible Asset Gross Carrying Amount Accumulated Amortization Net Gross Carrying Amount Accumulated Amortization Net Retail customer relationship $ 1,680 $ 987 $ 693 $ 1,680 $ 876 $ 804 Software and other technology-related assets 321 124 197 270 105 165 Retail and wholesale contracts 315 172 143 316 138 178 Contractual service agreements (a) 60 2 58 70 — 70 Other identifiable intangible assets (b) 118 74 44 42 15 27 Total identifiable intangible assets subject to amortization $ 2,494 $ 1,359 1,135 $ 2,378 $ 1,134 1,244 Retail trade names (not subject to amortization) 1,245 1,245 Mineral interests (not currently subject to amortization) 3 4 Total identifiable intangible assets $ 2,383 $ 2,493 __________ (a) At June 30, 2019 , amounts related to contractual service agreements that have become liabilities due to amortization of the economic impacts of the intangibles have been removed from both the gross carrying amount and accumulated amortization. (b) Includes mining development costs and environmental allowances and credits. Identifiable intangible liabilities are comprised of the following: Identifiable Intangible Liability June 30, December 31, 2018 Contractual service agreements $ 107 $ 136 Purchase and sale contracts 183 195 Environmental allowances 41 70 Total identifiable intangible liabilities $ 331 $ 401
Schedule of amortization expense related to intangible assets (including income statement line item)	Amortization expense related to finite-lived identifiable intangible assets and liabilities (including the classification in the condensed statements of consolidated income (loss)) consisted of: Identifiable Intangible Assets and Liabilities Condensed Statements of Consolidated Income (Loss) Line Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Retail customer relationship Depreciation and amortization $ 55 $ 77 $ 111 $ 150 Software and other technology-related assets Depreciation and amortization 15 19 29 30 Retail and wholesale contracts/purchase and sale contracts Operating revenues/fuel, purchased power costs and delivery fees 12 23 24 32 Other identifiable intangible assets Operating revenues/fuel, purchased power costs and delivery fees/depreciation and amortization 15 2 39 3 Total amortization expense (a) $ 97 $ 121 $ 203 $ 215 ____________ (a) Amounts recorded in depreciation and amortization totaled $72 million and $97 million for the three months ended June 30, 2019 and 2018 , respectively, and $141 million and $182 million for the six months ended June 30, 2019 and 2018
Schedule of estimated amortization expense of identifiable intangible assets	As of June 30, 2019 , the estimated aggregate amortization expense of identifiable intangible assets and liabilities for each of the next five fiscal years is as shown below. Year Estimated Amortization Expense 2019 $ 309 2020 $ 211 2021 $ 164 2022 $ 101 2023 $ 76

Income Taxes (Tables)

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2019
Income Tax Disclosure [Abstract]
Calculation of effective income tax rate	The calculation of our effective tax rate is as follows: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Income (loss) before income taxes $ 502 $ 31 $ 803 $ (364 ) Income tax (expense) benefit $ (148 ) $ 74 $ (225 ) $ 163 Effective tax rate 29.5 % (238.7 )% 28.0 % 44.8 %

Tax Receivable Agreement Obli_2

Tax Receivable Agreement Obligation (Tables)	6 Months Ended
	Jun. 30, 2019
Income Tax Disclosure [Abstract]
Tax receivable agreement obligation	The following table summarizes the changes to the TRA obligation, reported as other current liabilities and Tax Receivable Agreement obligation in our condensed consolidated balance sheets, for the six months ended June 30, 2019 and 2018 : Six Months Ended June 30, 2019 2018 TRA obligation at the beginning of the period $ 420 $ 357 Accretion expense 31 36 Changes in tax assumptions impacting timing of payments (67 ) 46 Impacts of Tax Receivable Agreement (36 ) 82 TRA obligation at the end of the period 384 439 Less amounts due currently — (25 ) Noncurrent TRA obligation at the end of the period $ 384 $ 414

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2019
Earnings Per Share [Abstract]
Schedule of earnings per share, basic and diluted	Basic earnings per share available to common shareholders are based on the weighted average number of common shares outstanding during the period. Diluted earnings per share is calculated using the treasury stock method and includes the effect of all potential issuances of common shares under stock-based incentive compensation arrangements. Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Net income (loss) attributable to common stock — basic $ 356 $ 108 $ 581 $ (198 ) Weighted average shares of common stock outstanding — basic (a) 499,778,235 526,332,862 499,213,522 477,662,016 Net income (loss) per weighted average share of common stock outstanding — basic $ 0.71 $ 0.21 $ 1.16 $ (0.41 ) Dilutive securities: Stock-based incentive compensation plan and tangible equity units 7,722,148 7,453,962 8,035,398 — Weighted average shares of common stock outstanding — diluted 507,500,383 533,786,824 507,248,920 477,662,016 Net income (loss) per weighted average share of common stock outstanding — diluted $ 0.70 $ 0.20 $ 1.15 $ (0.41 ) ____________ (a) The minimum settlement amount of tangible equity units, or 15,207,600 shares in both the three and six months ended June 30, 2019 and 15,056,260 shares in both the three and six months ended June 30, 2018

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2019
Debt Disclosure [Abstract]
Schedule of long-term debt instruments	Amounts in the table below represent the categories of long-term debt obligations incurred by the Company. June 30, December 31, Vistra Operations Credit Facilities $ 3,798 $ 5,813 Vistra Operations Senior Secured Notes: 3.550% Senior Secured Notes, due July 15, 2024 1,200 — 4.300% Senior Secured Notes, due July 15, 2029 800 — Total Vistra Operations Senior Secured Notes 2,000 — Vistra Operations Senior Unsecured Notes: 5.500% Senior Notes, due September 1, 2026 1,000 1,000 5.625% Senior Notes, due February 15, 2027 1,300 — 5.000% Senior Notes, due July 31, 2027 1,300 — Total Vistra Operations Senior Unsecured Notes 3,600 1,000 Vistra Energy Senior Unsecured Notes: 7.375% Senior Notes, due November 1, 2022 306 1,707 5.875% Senior Notes, due June 1, 2023 500 500 7.625% Senior Notes, due November 1, 2024 475 1,147 8.034% Senior Notes, due February 2, 2024 — 25 8.000% Senior Notes, due January 15, 2025 81 81 8.125% Senior Notes, due January 30, 2026 166 166 Total Vistra Energy Senior Unsecured Notes 1,528 3,626 Other: 7.000% Amortizing Notes, due July 1, 2019 8 24 Forward Capacity Agreements 222 236 Equipment Financing Agreements 114 120 Mandatorily redeemable subsidiary preferred stock (a) 70 70 8.82% Building Financing due semiannually through February 11, 2022 (b) 18 21 Total other long-term debt 432 471 Unamortized debt premiums, discounts and issuance costs (c) (4 ) 155 Total long-term debt including amounts due currently 11,354 11,065 Less amounts due currently (161 ) (191 ) Total long-term debt less amounts due currently $ 11,193 $ 10,874 ____________ (a) Shares of mandatorily redeemable preferred stock in PrefCo. This subsidiary preferred stock is accounted for as a debt instrument under relevant accounting guidance. At any time after October 3, 2019, Vistra Energy may redeem all or any portion of the preferred stock for a price per share equal to the preferred liquidation amount. (b) Obligation related to a corporate office space finance lease. This obligation will be funded by amounts held in an escrow account that is reflected in other noncurrent assets in our condensed consolidated balance sheets. (c)
Schedule of line of credit facilities	The Vistra Operations Credit Facilities and related available capacity at June 30, 2019 are presented below. June 30, 2019 Vistra Operations Credit Facilities Maturity Date Facility Limit Cash Borrowings Available Capacity Revolving Credit Facility (a) June 14, 2023 $ 2,725 $ — $ 2,173 Term Loan B-1 Facility August 4, 2023 1,897 1,897 — Term Loan B-3 Facility December 31, 2025 1,901 1,901 — Total Vistra Operations Credit Facilities $ 6,523 $ 3,798 $ 2,173 ___________ (a) Facility to be used for general corporate purposes. Facility includes a $2.35 billion letter of credit sub-facility, of which $552 million of letters of credit were outstanding at June 30, 2019 and which reduce our available capacity.
Schedule of maturities of long-term debt	Long-term debt maturities (including mandatory amortization of the Term Loan B Facility) at June 30, 2019 are as follows: June 30, 2019 Remainder of 2019 $ 93 2020 144 2021 70 2022 321 2023 2,408 Thereafter 8,322 Unamortized premiums, discounts and debt issuance costs (4 ) Total long-term debt, including amounts due currently $ 11,354

Leases (Tables)

Leases (Tables)	6 Months Ended
	Jun. 30, 2019
Leases [Abstract]
Schedule of Lease Cost and Supplemental Cash Flow Information	The following table presents lease related cash flow and other information: Six Months Cash paid for amounts included in the measurement of lease liabilities Operating cash flows from operating leases $ 7 Operating cash flow from finance leases 2 Finance cash flow from finance leases 1 Non-cash disclosure upon commencement of new lease Right-of-use assets obtained in exchange for new operating lease liabilities 72 Right-of-use assets obtained in exchange for new finance lease liabilities 15 Non-cash disclosure upon modification of existing lease Modification of operating lease right-of-use assets (36 ) Modification of finance lease right-of-use assets 50 The following table presents costs related to lease activities: Three Months Six Months Operating lease cost $ 3 $ 7 Finance lease: Finance lease right-of-use asset amortization 1 2 Interest on lease liabilities 1 1 Total finance lease cost 2 3 Variable lease cost (a) 6 12 Short-term lease cost 8 13 Sublease income (b) (2 ) (4 ) Net lease cost $ 17 $ 31 ____________ (a) Represents coal stockpile management services, common area maintenance services and rail car payments based on the number of rail cars used. (b) Represents sublease income related to real estate leases.
Schedule of Lease Balance Sheet Information	The following table presents lease related balance sheet information: June 30, 2019 Lease assets Operating lease right-of-use assets $ 34 Finance lease right-of-use assets (net of accumulated depreciation) 61 Total lease right-of-use assets 95 Current lease liabilities Operating lease liabilities 13 Finance lease liabilities 5 Total current lease liabilities 18 Noncurrent lease liabilities Operating lease liabilities 40 Finance lease liabilities 74 Total noncurrent lease liabilities 114 Total lease liabilities $ 132
Schedule of Weighted Average Remaining Lease Terms and Discount Rates	The following table presents weighted average remaining lease term information: June 30, 2019 Weighted average remaining lease term Operating lease 8 years Finance lease 18 years Weighted average discount rate Operating lease 6.04% Finance lease 6.07%
Schedule of Maturity of Operating Lease Liabilities	The following table presents maturity of lease liabilities: Operating lease Finance lease Total lease Remainder of 2019 $ 7 $ 4 $ 11 2020 14 9 23 2021 9 9 18 2022 7 9 16 2023 6 9 15 Thereafter 22 79 101 Total lease payments 65 119 184 Less: Interest (12 ) (40 ) (52 ) Present value of lease liabilities $ 53 $ 79 $ 132
Schedule of Maturity of Finance Lease Liabilities	The following table presents maturity of lease liabilities: Operating lease Finance lease Total lease Remainder of 2019 $ 7 $ 4 $ 11 2020 14 9 23 2021 9 9 18 2022 7 9 16 2023 6 9 15 Thereafter 22 79 101 Total lease payments 65 119 184 Less: Interest (12 ) (40 ) (52 ) Present value of lease liabilities $ 53 $ 79 $ 132

Equity (Tables)

Equity (Tables)	6 Months Ended
	Jun. 30, 2019
Stockholders' Equity Note [Abstract]
Schedule of stockholders equity	Equity The following table presents the changes to equity for the three months ended June 30, 2019 : Common Stock (a) Additional Paid-in Capital Retained Earnings (Deficit) Accumulated Other Comprehensive Income (Loss) Total Stockholders' Equity Noncontrolling Interest Total Equity Balance at March 31, 2019 $ 5 $ 9,105 $ (1,285 ) $ (21 ) $ 7,804 $ 2 $ 7,806 Treasury stock — (212 ) — — (212 ) — (212 ) Dividends declared on common stock — — (59 ) — (59 ) — (59 ) Effects of stock-based incentive compensation plans — 16 — — 16 — 16 Net income (loss) — — 356 — 356 (2 ) 354 Other — — (1 ) — (1 ) — (1 ) Balance at June 30, 2019 $ 5 $ 8,909 $ (989 ) $ (21 ) $ 7,904 $ — $ 7,904 The following table presents the changes to equity for the six months ended June 30, 2019 : Common Stock (a) Additional Paid-in Capital Retained Earnings (Deficit) Accumulated Other Comprehensive Income (Loss) Total Stockholders' Equity Noncontrolling Interest Total Equity Balance at December 31, 2018 $ 5 $ 9,329 $ (1,449 ) $ (22 ) $ 7,863 $ 4 $ 7,867 Treasury stock — (448 ) — — (448 ) — (448 ) Dividends declared on common stock — — (120 ) — (120 ) — (120 ) Effects of stock-based incentive compensation plans — 28 — — 28 — 28 Net income (loss) — — 581 — 581 (3 ) 578 Adoption of accounting standard (Note 1) — — (2 ) — (2 ) — (2 ) Change in unrecognized losses related to pension and OPEB plans — — — 1 1 — 1 Other — — 1 — 1 (1 ) — Balance at June 30, 2019 $ 5 $ 8,909 $ (989 ) $ (21 ) $ 7,904 $ — $ 7,904 ________________ (a) Authorized shares totaled 1,800,000,000 at June 30, 2019 . Outstanding shares totaled 476,166,856 and 493,215,309 at June 30, 2019 and December 31, 2018 , respectively. The following table presents the changes to equity for the three months ended June 30, 2018 : Common Stock (a) Additional Paid-in Capital Retained Earnings (Deficit) Accumulated Other Comprehensive Income (Loss) Total Stockholders' Equity Noncontrolling Interest Total Equity Balance at March 31, 2018 $ 4 $ 7,772 $ (1,700 ) $ (16 ) $ 6,060 $ — $ 6,060 Stock and stock compensation awards issued in connection with the Merger 1 1,891 — — 1,892 — 1,892 Treasury stock — (75 ) — — (75 ) — (75 ) Effects of stock-based incentive compensation plans — 56 — — 56 — 56 Tangible equity units acquired — 369 — — 369 — 369 Warrants acquired — 2 — — 2 — 2 Net income (loss) — — 108 — 108 — 108 Investment by noncontrolling interest — — — — — 7 7 Other — — 1 — 1 — 1 Balance at June 30, 2018 $ 5 $ 10,015 $ (1,591 ) $ (16 ) $ 8,413 $ 7 $ 8,420 The following table presents the changes to equity for the six months ended June 30, 2018 : Common Stock (a) Additional Paid-in Capital Retained Earnings (Deficit) Accumulated Other Comprehensive Income (Loss) Total Stockholders' Equity Noncontrolling Interest Total Equity Balance at December 31, 2017 $ 4 $ 7,765 $ (1,410 ) $ (17 ) $ 6,342 $ — $ 6,342 Stock and stock compensation awards issued in connection with the Merger 1 1,891 — — 1,892 — 1,892 Treasury stock — (75 ) — — (75 ) — (75 ) Effects of stock-based incentive compensation plans — 63 — — 63 — 63 Tangible equity units acquired — 369 — — 369 — 369 Warrants acquired — 2 — — 2 — 2 Net loss — — (198 ) — (198 ) — (198 ) Adoption of accounting standard — — 17 — 17 — 17 Change in unrecognized losses related to pension and OPEB plans — — — 1 1 — 1 Investment by noncontrolling interest — — — — — 7 7 Balance at June 30, 2018 $ 5 $ 10,015 $ (1,591 ) $ (16 ) $ 8,413 $ 7 $ 8,420 ________________ (a) Authorized shares totaled 1,800,000,000 at June 30, 2018 . Outstanding shares totaled 521,214,879 and 428,398,802 at June 30, 2018 and December 31, 2017 , respectively.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2019
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 at the respective balance sheet dates shown below: June 30, 2019 Level 1 Level 2 Level 3 (a) Reclassification (b) Total Assets: Commodity contracts $ 958 $ 300 $ 214 $ 70 $ 1,542 Nuclear decommissioning trust – 510 — — — 510 Nuclear decommissioning trust – — 502 — — 502 Sub-total $ 1,468 $ 802 $ 214 $ 70 2,554 Assets measured at net asset value (d): Nuclear decommissioning trust – 330 Total assets $ 2,884 Liabilities: Commodity contracts $ 1,063 $ 419 $ 210 $ 70 $ 1,762 Interest rate swaps — 156 — — 156 Total liabilities $ 1,063 $ 575 $ 210 $ 70 $ 1,918 December 31, 2018 Level 1 Level 2 Level 3 (a) Reclassification (b) Total Assets: Commodity contracts $ 456 $ 152 $ 153 $ 1 $ 762 Interest rate swaps — 77 — — 77 Nuclear decommissioning trust – 449 — — — 449 Nuclear decommissioning trust – — 443 — — 443 Sub-total $ 905 $ 672 $ 153 $ 1 1,731 Assets measured at net asset value (d): Nuclear decommissioning trust – 278 Total assets $ 2,009 Liabilities: Commodity contracts $ 557 $ 766 $ 288 $ 1 $ 1,612 Interest rate swaps — 34 — — 34 Total liabilities $ 557 $ 800 $ 288 $ 1 $ 1,646 ____________ (a) See table below for description of Level 3 assets and liabilities. (b) Fair values are determined on a contract basis, but certain contracts result in a current asset and a noncurrent liability, or vice versa, as presented in our condensed consolidated balance sheets. (c) The nuclear decommissioning trust investment is included in the investments line in our condensed consolidated balance sheets. See Note 19 . (d) The fair value amounts presented in this line are intended to permit reconciliation of the fair value hierarchy to the amounts presented in our condensed consolidated balance sheets. Certain investments measured at fair value using the net asset value per share (or its equivalent) have not been classified in the fair value hierarchy.
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 June 30, 2019 and December 31, 2018 : June 30, 2019 Fair Value Contract Type (a) Assets Liabilities Total Valuation Technique Significant Unobservable Input Range (b) Electricity purchases and sales $ 72 $ (58 ) $ 14 Valuation Model Hourly price curve shape (c) $0 to $110/ MWh Illiquid delivery periods for hub power prices and heat rates (d) $20 to $120/ MWh Electricity and weather options 10 (102 ) (92 ) Option Pricing Model Gas to power correlation (e) 10% to 100% Power volatility (e) 5% to 435% Financial transmission rights 121 (16 ) 105 Market Approach (f) Illiquid price differences between settlement points (g) $(5) to $50/ MWh Other (h) 11 (34 ) (23 ) Total $ 214 $ (210 ) $ 4 December 31, 2018 Fair Value Contract Type (a) Assets Liabilities Total Valuation Technique Significant Unobservable Input Range (b) Electricity purchases and sales $ 22 $ (48 ) $ (26 ) Valuation Model Hourly price curve shape (c) $0 to $110/ MWh Illiquid delivery periods for ERCOT hub power prices and heat rates (d) $20 to $120/ MWh Electricity and weather options 31 (192 ) (161 ) Option Pricing Model Gas to power correlation (e) 15% to 95% Power volatility (e) 5% to 435% Financial transmission rights 85 (20 ) 65 Market Approach (f) Illiquid price differences between settlement points (g) $(10) to $50/ MWh Other (h) 15 (28 ) (13 ) Total $ 153 $ (288 ) $ (135 ) ____________ (a) Electricity purchase and sales contracts include power and heat rate positions in ERCOT, PJM, NYISO, ISO-NE and MISO regions. The forward purchase contracts (swaps and options) used to hedge electricity price differences between settlement points within are referred to as congestion revenue rights in ERCOT and financial transmission rights in PJM, NYISO, ISO-NE and MISO regions. Electricity options consist of physical electricity options and spread options. (b) The range of the inputs may be influenced by factors such as time of day, delivery period, season and location. (c) Primarily based on the historical range of forward average hourly ERCOT North Hub prices. (d) Primarily based on historical forward ERCOT and PJM power prices and ERCOT heat rate variability. (e) Based on historical forward correlation and volatility within ERCOT. (f) While we use the market approach, there is insufficient market data to consider the valuation liquid. (g) Primarily based on the auction price that reflects the difference in power prices at two locations. (h) Other includes contracts for natural gas, coal, coal option, power and gas swaption and emissions.
Schedule of changes in fair value of the Level 3 assets and liabilities	The following table presents the changes in fair value of the Level 3 assets and liabilities for the three and six months ended June 30, 2019 and 2018 . Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Net liability balance at beginning of period $ (113 ) $ (224 ) $ (135 ) $ (53 ) Total unrealized valuation gains (losses) 87 (18 ) 125 (230 ) Purchases, issuances and settlements (a): Purchases 61 29 79 58 Issuances (10 ) (4 ) (17 ) (7 ) Settlements (20 ) 29 (42 ) 45 Transfers into Level 3 (b) 3 2 5 1 Transfers out of Level 3 (b) (4 ) 1 (11 ) 1 Net liabilities assumed in connection with the Merger — (37 ) — (37 ) Net change (c) 117 2 139 (169 ) Net liability balance at end of period $ 4 $ (222 ) $ 4 $ (222 ) Unrealized valuation gains (losses) relating to instruments held at end of period $ 92 $ (17 ) $ 110 $ (226 ) ____________ (a) Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received. (b) Includes transfers due to changes in the observability of significant inputs. All Level 3 transfers during the periods presented are in and out of Level 2. For six months ended June 30, 2019 , transfers out of Level 3 primarily consists of coal derivatives where forward pricing inputs have become observable. (c) Activity excludes change in fair value in the month positions settle. Substantially all changes in values of commodity contracts (excluding the net liabilities assumed in connection with the Merger) are reported as operating revenues in our condensed statements of consolidated income (loss).

Commodity and Other Derivativ_2

Commodity and Other Derivative Contractual Assets and Liabilities (Tables)	6 Months Ended
	Jun. 30, 2019
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 are accounted for under mark-to-market accounting consistent with accounting standards related to derivative instruments and hedging activities. The following tables provide detail of derivative contractual assets and liabilities as reported in our condensed consolidated balance sheets at June 30, 2019 and December 31, 2018 . Derivative asset and liability totals represent the net value of the contract, while the balance sheet totals represent the gross value of the contract. June 30, 2019 Derivative Assets Derivative Liabilities Commodity Contracts Interest Rate Swaps Commodity Contracts Interest Rate Swaps Total Current assets $ 1,403 $ — $ 15 $ — $ 1,418 Noncurrent assets 114 — 10 — 124 Current liabilities — — (1,508 ) (6 ) (1,514 ) Noncurrent liabilities (45 ) — (209 ) (150 ) (404 ) Net assets (liabilities) $ 1,472 $ — $ (1,692 ) $ (156 ) $ (376 ) December 31, 2018 Derivative Assets Derivative Liabilities Commodity Contracts Interest Rate Swaps Commodity Contracts Interest Rate Swaps Total Current assets $ 707 $ 22 $ 1 $ — $ 730 Noncurrent assets 54 55 — — 109 Current liabilities — — (1,374 ) (2 ) (1,376 ) Noncurrent liabilities — — (238 ) (32 ) (270 ) Net assets (liabilities) $ 761 $ 77 $ (1,611 ) $ (34 ) $ (807 )
Schedule of pretax effect on net income of derivatives not under hedge accounting, including realized and unrealized effects	The following table presents the pretax effect of derivative gains (losses) on net income, including realized and unrealized effects. 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. Derivative (condensed statements of consolidated income (loss) presentation) Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Commodity contracts (Operating revenues) $ 549 $ 69 $ 776 $ (376 ) Commodity contracts (Fuel, purchased power costs and delivery fees) (24 ) 13 3 12 Interest rate swaps (Interest expense and related charges) (108 ) 22 (183 ) 78 Net gain (loss) $ 417 $ 104 $ 596 $ (286 )
Offsetting assets and liabilities	The following tables reconcile our derivative assets and liabilities on a contract basis to net amounts after taking into consideration netting arrangements with counterparties and financial collateral: June 30, 2019 December 31, 2018 Derivative Assets and Liabilities Offsetting Instruments (a) Cash Collateral (Received) Pledged (b) Net Amounts Derivative Assets and Liabilities Offsetting Instruments (a) Cash Collateral (Received) Pledged (b) Net Amounts Derivative assets: Commodity contracts $ 1,472 $ (1,199 ) $ (6 ) $ 267 $ 761 $ (593 ) $ (1 ) $ 167 Interest rate swaps — — — — 77 (26 ) — 51 Total derivative assets 1,472 (1,199 ) (6 ) 267 838 (619 ) (1 ) 218 Derivative liabilities: Commodity contracts (1,692 ) 1,199 118 (375 ) (1,611 ) 593 109 (909 ) Interest rate swaps (156 ) — — (156 ) (34 ) 26 — (8 ) Total derivative liabilities (1,848 ) 1,199 118 (531 ) (1,645 ) 619 109 (917 ) Net amounts $ (376 ) $ — $ 112 $ (264 ) $ (807 ) $ — $ 108 $ (699 ) ____________ (a) Amounts presented exclude trade accounts receivable and payable related to settled financial instruments. (b) Represents cash amounts received or pledged pursuant to a master netting arrangement, including fair value-based margin requirements.
Schedule of gross notional amounts of derivative volumes	The following table presents the gross notional amounts of derivative volumes at June 30, 2019 and December 31, 2018 : June 30, 2019 December 31, 2018 Derivative type Notional Volume Unit of Measure Natural gas (a) 6,867 7,011 Million MMBtu Electricity 394,990 317,572 GWh Financial Transmission Rights (b) 234,664 172,611 GWh Coal 35 45 Million U.S. tons Fuel oil 73 60 Million gallons Uranium 125 50 Thousand pounds Emissions 16 10 Million tons Interest rate swaps – floating/fixed (c) $ 6,720 $ 7,717 Million U.S. dollars ____________ (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 ISOs or RTOs. (c)
Credit risk-related contingent features of derivatives	The following table presents the commodity derivative liabilities subject to credit risk-related contingent features that are not fully collateralized: June 30, December 31, Fair value of derivative contract liabilities (a) $ (631 ) $ (856 ) Offsetting fair value under netting arrangements (b) 223 218 Cash collateral and letters of credit 79 190 Liquidity exposure $ (329 ) $ (448 ) ____________ (a) Excludes fair value of contracts that contain contingent features that do not provide specific amounts to be posted if features are triggered, including provisions that generally provide the right to request additional collateral (material adverse change, performance assurance and other clauses). (b) Amounts include the offsetting fair value of in-the-money derivative contracts and net accounts receivable under master netting arrangements.

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2019
Segment Reporting [Abstract]
Schedule of segment reporting information, by segment	ts. Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Operating revenues (a) Retail $ 1,421 $ 1,454 $ 2,806 $ 2,426 ERCOT 1,671 1,327 2,625 794 PJM 686 485 1,391 485 NY/NE 254 187 599 187 MISO 246 257 500 257 Asset Closure — 21 — 49 Corporate and Other (b) 47 31 164 31 Eliminations (1,493 ) (1,188 ) (2,330 ) (891 ) Consolidated operating revenues $ 2,832 $ 2,574 $ 5,755 $ 3,338 Depreciation and amortization Retail $ (59 ) $ (80 ) $ (118 ) $ (157 ) ERCOT (128 ) (108 ) (259 ) (173 ) PJM (134 ) (125 ) (265 ) (125 ) NY/NE (39 ) (49 ) (104 ) (49 ) MISO (3 ) (3 ) (7 ) (3 ) Asset Closure — — — — Corporate and Other (b) (21 ) (23 ) (37 ) (35 ) Eliminations — (1 ) — — Consolidated depreciation and amortization $ (384 ) $ (389 ) $ (790 ) $ (542 ) Operating income (loss) Retail (c) $ (581 ) $ (303 ) $ (563 ) $ 455 ERCOT 1,047 680 1,335 (409 ) PJM 185 24 348 24 NY/NE 78 (7 ) 94 (7 ) MISO 35 31 46 31 Asset Closure (16 ) 1 (30 ) (22 ) Corporate and Other (b) (19 ) (196 ) (12 ) (237 ) Eliminations — 1 — 1 Consolidated operating income (loss) $ 729 $ 231 $ 1,218 $ (164 ) Net income (loss) Retail (c) $ (585 ) $ (288 ) $ (571 ) $ 483 ERCOT 1,056 679 1,356 (407 ) PJM 183 23 346 23 NY/NE 79 (5 ) 100 (5 ) MISO 35 31 46 31 Asset Closure (15 ) 2 (29 ) (20 ) Corporate and Other (b) (399 ) (337 ) (670 ) (306 ) Consolidated net income (loss) $ 354 $ 105 $ 578 $ (201 ) ____________ (a) The following unrealized net gains (losses) from mark-to-market valuations of commodity positions are included in operating revenues: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Retail $ 6 $ 1 $ 5 $ 13 ERCOT 1,050 668 1,287 (398 ) PJM 184 (10 ) 276 (10 ) NY/NE 31 (24 ) 32 (24 ) MISO 67 30 46 30 Corporate and Other (b) 3 1 19 1 Eliminations (1) (803 ) (463 ) (968 ) 180 Consolidated unrealized net gains (losses) from mark-to-market valuations of commodity positions included in operating revenues $ 538 $ 203 $ 697 $ (208 ) ____________ (1) Amounts offset in fuel, purchased power costs and delivery fees in the Retail segment, with no impact to consolidated results. (b) Other includes CAISO operations. Income tax expense is not reflected in net income of the segments but is reflected entirely in Corporate and Other net income. (c) For the three and six months ended June 30, 2019 , Retail operating loss and net loss is driven by unrealized losses from mark-to-market valuations of commodity positions included in fuel, purchased power costs and delivery fees. For the six months ended June 30, 2018 , Retail operating income and net income is driven by unrealized gains from mark-to-market valuations of commodity positions included in fuel, purchased power costs and delivery fees. June 30, December 31, 2018 Total assets Retail $ 8,249 $ 7,699 ERCOT 10,252 9,347 PJM 5,778 7,188 NY/NE 2,798 2,722 MISO 468 836 Asset Closure 253 254 Corporate and Other and Eliminations (1,278 ) (2,022 ) Consolidated total assets $ 26,520 $ 26,024

Supplementary Financial Infor_2

Supplementary Financial Information (Tables)	6 Months Ended
	Jun. 30, 2019
Supplementary Financial Information [Abstract]
Schedule of components of net benefit cost	For the three and six months ended June 30, 2019 and 2018 , net periodic benefit costs consisted of the following: Pension Benefits OPEB Benefits Three Months Ended June 30, Six Months Ended Three Months Ended June 30, Six Months Ended 2019 2018 2019 2018 2019 2018 2019 2018 Service cost $ 2 $ 4 $ 4 $ 5 $ — $ 1 $ — $ 1 Other costs — — — — 2 1 4 2 Net periodic benefit cost $ 2 $ 4 $ 4 $ 5 $ 2 $ 2 $ 4 $ 3
Schedule of interest expense and related charges	Interest Expense and Related Charges Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Interest paid/accrued $ 154 $ 166 $ 305 $ 216 Unrealized mark-to-market net (gains) losses on interest rate swaps 119 (25 ) 199 (86 ) Amortization of debt issuance costs, discounts and premiums — 3 (2 ) 4 Debt extinguishment gain (3 ) — (10 ) — Capitalized interest (3 ) (4 ) (7 ) (7 ) Other 7 6 10 10 Total interest expense and related charges $ 274 $ 146 $ 495 $ 137
Schedule of other income and deductions	Other Income and Deductions Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Other income: Office space sublease rental income (a) $ — $ 2 $ — $ 4 Insurance settlement (b) 8 — 19 — Funds released from escrow to settle pre-petition claims of our predecessor — — 9 — Sale of land (b) — — — 1 Interest income 3 4 7 10 All other 2 1 4 3 Total other income $ 13 $ 7 $ 39 $ 18 Other deductions: All other 2 1 $ 5 $ 3 Total other deductions $ 2 $ 1 $ 5 $ 3 ____________ (a) Reported in Corporate and Other non-segment. Beginning January 1, 2019, our sublease rental income related to real estate leases is reported in selling, general and administrative expenses in the condensed statements of consolidated income (loss). (b) Reported in ERCOT segment.
Schedule of restricted cash	Restricted Cash June 30, December 31, 2018 Current Assets Amounts related to restructuring escrow accounts $ 42 $ 57 Total restricted cash $ 42 $ 57
Schedule of accounts, notes, loans and financing receivable	Allowance for Uncollectible Accounts Receivable Six Months Ended June 30, 2019 2018 Allowance for uncollectible accounts receivable at beginning of period $ 19 $ 14 Increase for bad debt expense 29 22 Decrease for account write-offs (31 ) (22 ) Allowance for uncollectible accounts receivable at end of period $ 17 $ 14 Trade Accounts Receivable June 30, December 31, Wholesale and retail trade accounts receivable $ 1,118 $ 1,106 Allowance for uncollectible accounts (17 ) (19 ) Trade accounts receivable — net $ 1,101 $ 1,087
Schedule of inventories by major category	Inventories by Major Category June 30, December 31, Materials and supplies $ 290 $ 286 Fuel stock 172 115 Natural gas in storage 14 11 Total inventories $ 476 $ 412
Summary of other investments	Investments June 30, December 31, Nuclear plant decommissioning trust $ 1,342 $ 1,170 Assets related to employee benefit plans 31 31 Land 49 49 Total investments $ 1,422 $ 1,250
Summary of investments in the fund	June 30, 2019 Cost (a) Unrealized gain Unrealized loss Fair market value Debt securities (b) $ 481 $ 21 $ — $ 502 Equity securities (c) 272 568 — 840 Total $ 753 $ 589 $ — $ 1,342 December 31, 2018 Cost (a) Unrealized gain Unrealized loss Fair market value Debt securities (b) $ 444 $ 7 $ (8 ) $ 443 Equity securities (c) 280 448 (1 ) 727 Total $ 724 $ 455 $ (9 ) $ 1,170 ____________ (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 government and municipal bonds and investment grade corporate bonds. The debt securities had an average coupon rate of 3.44% and 3.69% at June 30, 2019 and December 31, 2018 , respectively, and an average maturity of nine years and eight years at June 30, 2019 and December 31, 2018 , respectively. (c) The investment objective for equity securities is to invest tax efficiently and to match the performance of the S&P 500 Index for U.S. equity investments and the MSCI EAFE Index for non-U.S. equity investments.
Summary of proceeds from sales of available-for-sale securities and the related realized gains and losses from such sales	The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from such sales. Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 Realized gains $ 7 $ 1 $ 10 $ 1 Realized losses $ (2 ) $ (1 ) $ (3 ) $ (3 ) Proceeds from sales of securities $ 214 $ 47 $ 292 $ 93 Investments in securities $ (219 ) $ (52 ) $ (302 ) $ (103 )
Schedule of Property, Plant and Equipment	Property, Plant and Equipment June 30, December 31, Power generation and structures $ 15,066 $ 14,604 Land 640 642 Office and other equipment 163 182 Total 15,869 15,428 Less accumulated depreciation (1,923 ) (1,284 ) Net of accumulated depreciation 13,946 14,144 Nuclear fuel (net of accumulated amortization of $163 million and $189 million) 179 191 Construction work in progress 135 277 Property, plant and equipment — net $ 14,260 $ 14,612 Depreciation expenses totaled $312 million and $292 million for the three months ended June 30, 2019 and 2018 , respectively, and $647 million and $360 million for six months ended June 30, 2019 and 2018 , respectively.
Schedule of asset retirement and mining reclamation obligations	The following tables summarize the changes to these obligations, reported as asset retirement obligations (current and noncurrent liabilities) in our condensed consolidated balance sheets, for the six months ended June 30, 2019 and 2018 . Nuclear Plant Decommissioning Mining Land Reclamation Coal Ash and Other Total Liability at December 31, 2018 $ 1,276 $ 442 $ 655 $ 2,373 Additions: Accretion 22 11 16 49 Adjustment for change in estimates — (3 ) (3 ) (6 ) Adjustment for obligations assumed through acquisitions — — (3 ) (3 ) Reductions: Payments — (32 ) (16 ) (48 ) Liability at June 30, 2019 1,298 418 649 2,365 Less amounts due currently — (132 ) (100 ) (232 ) Noncurrent liability at June 30, 2019 $ 1,298 $ 286 $ 549 $ 2,133 Nuclear Plant Decommissioning Mining Land Reclamation Coal Ash and Other Total Liability at December 31, 2017 $ 1,233 $ 438 $ 265 $ 1,936 Additions: Accretion 21 11 12 44 Adjustment for change in estimates — 7 (43 ) (36 ) Obligations assumed in the Merger — 2 417 419 Reductions: Payments — (35 ) (6 ) (41 ) Liability at June 30, 2018 $ 1,254 $ 423 $ 645 $ 2,322
Schedule of other noncurrent liabilities and deferred credits	Other Noncurrent Liabilities and Deferred Credits The balance of other noncurrent liabilities and deferred credits consists of the following: June 30, December 31, Retirement and other employee benefits $ 273 $ 270 Finance lease liabilities 74 — Uncertain tax positions, including accrued interest 6 4 Other 111 66 Total other noncurrent liabilities and deferred credits $ 464 $ 340
Schedule of fair value of debt	Fair Value of Debt June 30, 2019 December 31, 2018 Long-term debt (see Note 11): Fair Value Hierarchy Carrying Amount Fair Value Carrying Amount Fair Value Long-term debt under the Vistra Operations Credit Facilities Level 2 $ 3,808 $ 3,796 $ 5,820 $ 5,599 Vistra Operations Senior Notes Level 2 5,535 5,787 987 963 Vistra Energy Senior Notes Level 2 1,603 1,592 3,819 3,765 7.000% Amortizing Notes Level 2 8 8 23 24 Forward Capacity Agreements Level 3 212 212 221 221 Equipment Financing Agreements Level 3 98 98 102 102 Mandatorily redeemable subsidiary preferred stock Level 2 70 70 70 70 Building Financing Level 2 20 19 23 21
Schedule of cash, cash equivalents and restricted cash	The following table reconciles cash, cash equivalents and restricted cash reported in our condensed statements of consolidated cash flows to the amounts reported in our condensed balance sheets at June 30, 2019 and December 31, 2018 : June 30, December 31, Cash and cash equivalents $ 964 $ 636 Restricted cash included in current assets 42 57 Total cash, cash equivalents and restricted cash $ 1,006 $ 693
Schedule of supplemental cash flow information	The following table summarizes our supplemental cash flow information for the six months ended June 30, 2019 and 2018 : Six Months Ended June 30, 2019 2018 Cash payments related to: Interest paid $ 307 $ 344 Capitalized interest (7 ) (7 ) Interest paid (net of capitalized interest) $ 300 $ 337 Income taxes (a) $ 9 $ 58 Noncash investing and financing activities: Construction expenditures (b) $ 41 $ 13 Vistra Energy common stock issued in the Merger (Notes 2 and 14) $ — $ 2,245 ____________ (a) Income tax payments are net of tax refunds of $21 million and $5 million in the six months ended June 30, 2019 and 2018 , respectively (b) Represents end-of-period accruals for ongoing construction projects.

Supplemental Condensed Consol_2

Supplemental Condensed Consolidating Financial Information (Tables)	6 Months Ended
	Jun. 30, 2019
Supplemental Condensed Consolidating Financial Information [Abstract]
Condensed Statements of Consolidating Income (Loss)	Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Operating revenues $ — $ 2,835 $ 53 $ (56 ) $ 2,832 Fuel, purchased power costs and delivery fees — (1,144 ) (19 ) 24 (1,139 ) Operating costs — (355 ) (15 ) — (370 ) Depreciation and amortization (1 ) (364 ) (19 ) — (384 ) Selling, general and administrative expenses (13 ) (216 ) (19 ) 38 (210 ) Operating income (loss) (14 ) 756 (19 ) 6 729 Other income 1 14 — (2 ) 13 Other deductions — (2 ) — — (2 ) Interest expense and related charges (29 ) (241 ) (6 ) 2 (274 ) Impacts of Tax Receivable Agreement 33 — — — 33 Equity in earnings of unconsolidated investment — 3 — — 3 Income (loss) before income taxes (9 ) 530 (25 ) 6 502 Income tax benefit (expense) 4 (160 ) 14 (6 ) (148 ) Equity in earnings (loss) of subsidiaries, net of tax 361 (9 ) — (352 ) — Net income (loss) 356 361 (11 ) (352 ) 354 Net loss attributable to noncontrolling interest — — 2 — 2 Net income (loss) attributable to Vistra Energy $ 356 $ 361 $ (9 ) $ (352 ) $ 356 Condensed Statements of Consolidating Income (Loss) for the Three Months Ended June 30, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Operating revenues $ — $ 2,508 $ 68 $ (2 ) $ 2,574 Fuel, purchased power costs and delivery fees — (1,166 ) (51 ) 1 (1,216 ) Operating costs — (370 ) (16 ) — (386 ) Depreciation and amortization — (371 ) (18 ) — (389 ) Selling, general and administrative expenses (192 ) (160 ) (2 ) 2 (352 ) Operating income (loss) (192 ) 441 (19 ) 1 231 Other income 3 5 — (1 ) 7 Other deductions — (1 ) — — (1 ) Interest expense and related charges (87 ) (58 ) (1 ) — (146 ) Impacts of Tax Receivable Agreement (64 ) — — — (64 ) Equity in earnings of unconsolidated investment — 4 — — 4 Income (loss) before income taxes (340 ) 391 (20 ) — 31 Income tax benefit (expense) 102 (34 ) 6 — 74 Equity in earnings (loss) of subsidiaries, net of tax 343 (14 ) — (329 ) — Net income (loss) 105 343 (14 ) (329 ) 105 Net loss attributable to noncontrolling interest — — 3 — 3 Net income (loss) attributable to Vistra Energy $ 105 $ 343 $ (11 ) $ (329 ) $ 108 Condensed Statements of Consolidating Income (Loss) for the Six Months Ended June 30, 2019 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Operating revenues $ — $ 5,761 $ 110 $ (116 ) $ 5,755 Fuel, purchased power costs and delivery fees — (2,612 ) (48 ) 60 (2,600 ) Operating costs — (726 ) (29 ) — (755 ) Depreciation and amortization (2 ) (746 ) (42 ) — (790 ) Selling, general and administrative expenses (31 ) (395 ) (38 ) 72 (392 ) Operating income (loss) (33 ) 1,282 (47 ) 16 1,218 Other income 15 31 1 (8 ) 39 Other deductions — (5 ) — — (5 ) Interest expense and related charges (72 ) (419 ) (12 ) 8 (495 ) Impacts of Tax Receivable Agreement 36 — — — 36 Equity in earnings of unconsolidated investment — 10 — — 10 Income (loss) before income taxes (54 ) 899 (58 ) 16 803 Income tax benefit (expense) 17 (249 ) 23 (16 ) (225 ) Equity in earnings (loss) of subsidiaries, net of tax 618 (32 ) — (586 ) — Net income (loss) 581 618 (35 ) (586 ) 578 Net loss attributable to noncontrolling interest — — 3 — 3 Net income (loss) attributable to Vistra Energy $ 581 $ 618 $ (32 ) $ (586 ) $ 581 Condensed Statements of Consolidating Income (Loss) for the Six Months Ended June 30, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Operating revenues $ — $ 3,272 $ 68 $ (2 ) $ 3,338 Fuel, purchased power costs and delivery fees — (1,816 ) (51 ) 1 (1,866 ) Operating costs — (564 ) (16 ) — (580 ) Depreciation and amortization — (524 ) (18 ) — (542 ) Selling, general and administrative expenses (226 ) (288 ) (2 ) 2 (514 ) Operating income (loss) (226 ) 80 (19 ) 1 (164 ) Other income 6 12 1 (1 ) 18 Other deductions — (3 ) — — (3 ) Interest expense and related charges (87 ) (49 ) (1 ) — (137 ) Impacts of Tax Receivable Agreement (82 ) — — — (82 ) — 4 — — 4 Income (loss) before income taxes (389 ) 44 (19 ) — (364 ) Income tax benefit (expense) 117 41 5 — 163 Equity in earnings (loss) of subsidiaries, net of tax 71 (14 ) — (57 ) — Net income (loss) (201 ) 71 (14 ) (57 ) (201 ) Net loss attributable to noncontrolling interest — — 3 — 3 Net income (loss) attributable to Vistra Energy $ (201 ) $ 71 $ (11 ) $ (57 ) $ (198 )
Condensed Statements of Consolidating Other Comprehensive Income (Loss)	Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Net income (loss) $ 356 $ 361 $ (11 ) $ (352 ) $ 354 Other comprehensive income (loss), net of tax effects: Effect related to pension and other retirement benefit obligations — — — — — Total other comprehensive income — — — — — Comprehensive income (loss) 356 361 (11 ) (352 ) 354 Comprehensive loss attributable to noncontrolling interest — — 2 — 2 Comprehensive income (loss) attributable to Vistra Energy $ 356 $ 361 $ (9 ) $ (352 ) $ 356 Condensed Statements of Consolidating Comprehensive Income (Loss) for the Three Months Ended June 30, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Net income (loss) $ 105 $ 343 $ (14 ) $ (329 ) $ 105 Other comprehensive income (loss), net of tax effects: Effect related to pension and other retirement benefit obligations — — — — — Total other comprehensive income — — — — — Comprehensive income (loss) $ 105 $ 343 $ (14 ) $ (329 ) $ 105 Comprehensive loss attributable to noncontrolling interest — — 3 — 3 Comprehensive income (loss) attributable to Vistra Energy $ 105 $ 343 $ (11 ) $ (329 ) $ 108 Condensed Statements of Consolidating Comprehensive Income (Loss) for the Six Months Ended June 30, 2019 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Net income (loss) $ 581 $ 618 $ (35 ) $ (586 ) $ 578 Other comprehensive income (loss), net of tax effects: Effect related to pension and other retirement benefit obligations 1 — — — 1 Total other comprehensive income 1 — — — 1 Comprehensive income (loss) 582 618 (35 ) (586 ) 579 Comprehensive loss attributable to noncontrolling interest — — 3 — 3 Comprehensive income (loss) attributable to Vistra Energy $ 582 $ 618 $ (32 ) $ (586 ) $ 582 Condensed Statements of Consolidating Comprehensive Income (Loss) for the Six Months Ended June 30, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Net income (loss) $ (201 ) $ 71 $ (14 ) $ (57 ) $ (201 ) Other comprehensive income (loss), net of tax effects: Effect related to pension and other retirement benefit obligations 1 — — — 1 Total other comprehensive income 1 — — — 1 Comprehensive income (loss) $ (200 ) $ 71 $ (14 ) $ (57 ) $ (200 ) Comprehensive loss attributable to noncontrolling interest — — 3 — 3 Comprehensive income (loss) attributable to Vistra Energy $ (200 ) $ 71 $ (11 ) $ (57 ) $ (197 )
Condensed Statements of Consolidating Cash Flows	Condensed Statements of Consolidating Cash Flows for the Six Months Ended June 30, 2019 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Cash flows — operating activities: Cash provided by (used in) operating activities $ (127 ) $ 1,111 $ (102 ) $ — $ 882 Cash flows — financing activities: Issuances of long-term debt — 4,600 — — 4,600 Repayments/repurchases of debt (2,114 ) (2,023 ) — — (4,137 ) Net borrowings under accounts receivable securitization program — — 91 91 Cash dividends paid (120 ) (3,195 ) — 3,195 (120 ) Stock repurchase (457 ) — — — (457 ) Debt tender offer and other financing fees (92 ) (54 ) — — (146 ) Other, net (1 ) — — — (1 ) Cash provided by (used in) financing activities (2,784 ) (672 ) 91 3,195 (170 ) Cash flows — investing activities: Capital expenditures, including LTSA prepayments (1 ) (246 ) — — (247 ) Nuclear fuel purchases — (20 ) — — (20 ) Development and growth expenditures — (36 ) — — (36 ) Proceeds from sales of nuclear decommissioning trust fund securities — 292 — — 292 Investments in nuclear decommissioning trust fund securities — (302 ) — — (302 ) Proceeds from sale of environmental allowances — 31 — — 31 Purchases of environmental allowances — (138 ) — — (138 ) Dividend received from subsidiaries 3,195 — (3,195 ) — Other, net — 21 — — 21 Cash provided by (used in) investing activities 3,194 (398 ) — (3,195 ) (399 ) Net change in cash, cash equivalents and restricted cash 283 41 (11 ) — 313 Cash, cash equivalents and restricted cash — beginning balance 228 453 12 — 693 Cash, cash equivalents and restricted cash — ending balance $ 511 $ 494 $ 1 $ — $ 1,006 Condensed Statements of Consolidating Cash Flows for the Six Months Ended June 30, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Cash flows — operating activities: Cash provided by (used in) operating activities $ (280 ) $ (109 ) $ 360 $ — $ (29 ) Cash flows — financing activities: Repayments/repurchases of debt (840 ) (498 ) — — (1,338 ) Stock repurchase (63 ) — — — (63 ) Debt financing fees (29 ) (17 ) — — (46 ) Other, net — 4 — — 4 Cash provided by (used in) financing activities (932 ) (511 ) — — (1,443 ) Cash flows — investing activities: Capital expenditures (4 ) (147 ) (2 ) — (153 ) Nuclear fuel purchases — (28 ) — — (28 ) Development and growth expenditures — (21 ) — — (21 ) Cash acquired in the Merger 418 27 — — 445 Proceeds from sales of nuclear decommissioning trust fund securities — 93 — — 93 Investments in nuclear decommissioning trust fund securities — (103 ) — — (103 ) Proceeds from sale of environmental allowances — — — — — Purchases of environmental allowances — (1 ) — — (1 ) Other, net (4 ) 359 (345 ) — 10 Cash provided by (used in) investing activities 410 179 (347 ) — 242 Net change in cash, cash equivalents and restricted cash (802 ) (441 ) 13 — (1,230 ) Cash, cash equivalents and restricted cash — beginning balance 1,183 863 — — 2,046 Cash, cash equivalents and restricted cash — ending balance $ 381 $ 422 $ 13 $ — $ 816
Condensed Consolidating Balance Sheets	Condensed Consolidating Balance Sheet as of June 30, 2019 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ 469 $ 494 $ 1 $ — $ 964 Restricted cash 42 — — — 42 Advances to affiliates — 40 1 (41 ) — Trade accounts receivable — net 11 640 650 (200 ) 1,101 Accounts receivable — affiliates 2 770 242 (1,014 ) — Notes due from affiliates — 102 — (102 ) — Income taxes receivable — — — — — Inventories — 453 23 — 476 Commodity and other derivative contractual assets — 1,418 — — 1,418 Margin deposits related to commodity contracts — 253 — — 253 Prepaid expense and other current assets 130 140 15 — 285 Total current assets 654 4,310 932 (1,357 ) 4,539 Investments — 1,390 32 — 1,422 Investment in unconsolidated subsidiary — 127 — — 127 Investment in affiliated companies 8,925 123 — (9,048 ) — Property, plant and equipment — net 4 13,713 543 — 14,260 Operating lease right-of-use assets — 34 — — 34 Goodwill — 2,082 — — 2,082 Identifiable intangible assets — net 36 2,344 3 — 2,383 Commodity and other derivative contractual assets — 124 — — 124 Accumulated deferred income taxes 810 415 — (81 ) 1,144 Other noncurrent assets 131 267 7 — 405 Total assets $ 10,560 $ 24,929 $ 1,517 $ (10,486 ) $ 26,520 LIABILITIES AND EQUITY Current liabilities: Accounts receivable securitization program $ — $ — $ 430 $ — $ 430 Advances from affiliates — 1 40 (41 ) — Long-term debt due currently 8 148 5 — 161 Trade accounts payable — 761 211 (190 ) 782 Accounts payable — affiliates 556 143 315 (1,014 ) — Notes due to affiliates — — 101 (101 ) — Commodity and other derivative contractual liabilities — 1,514 — — 1,514 Margin deposits related to commodity contracts — 8 — — 8 Accrued taxes 12 — — — 12 Accrued taxes other than income — 114 1 — 115 Accrued interest 21 65 7 (11 ) 82 Asset retirement obligations — 232 — — 232 Operating lease liabilities — 12 1 — 13 Other current liabilities 53 253 2 — 308 Total current liabilities 650 3,251 1,113 (1,357 ) 3,657 Condensed Consolidating Balance Sheet as of June 30, 2019 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Long-term debt, less amounts due currently 1,602 9,560 31 — 11,193 Operating lease liabilities — 38 2 — 40 Commodity and other derivative contractual liabilities — 404 — — 404 Accumulated deferred income taxes — — 91 (81 ) 10 Tax Receivable Agreement obligation 384 — — — 384 Asset retirement obligations — 2,119 14 — 2,133 Identifiable intangible liabilities — net — 207 124 — 331 Other noncurrent liabilities and deferred credits 20 425 19 — 464 Total liabilities 2,656 16,004 1,394 (1,438 ) 18,616 Total stockholders' equity 7,904 8,925 123 (9,048 ) 7,904 Noncontrolling interest in subsidiary — — — — — Total liabilities and equity $ 10,560 $ 24,929 $ 1,517 $ (10,486 ) $ 26,520 Condensed Consolidating Balance Sheet as of December 31, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ 171 $ 453 $ 12 $ — $ 636 Restricted cash 57 — — — 57 Advances to affiliates 11 11 — (22 ) — Trade accounts receivable — net 4 729 464 (110 ) 1,087 Accounts receivable - affiliates — 245 — (245 ) — Notes due from affiliates — 101 — (101 ) — Income taxes receivable — 1 — (1 ) — Inventories — 391 21 — 412 Commodity and other derivative contractual assets — 730 — — 730 Margin deposits related to commodity contracts — 361 — — 361 Prepaid expense and other current assets 2 134 16 — 152 Total current assets 245 3,156 513 (479 ) 3,435 Investments — 1,218 32 — 1,250 Investments in unconsolidated subsidiary — 131 — — 131 Investment in affiliated companies 11,186 263 — (11,449 ) — Property, plant and equipment — net 15 14,017 580 — 14,612 Goodwill — 2,068 — — 2,068 Identifiable intangible assets — net 10 2,480 3 — 2,493 Commodity and other derivative contractual assets — 109 — — 109 Accumulated deferred income taxes 809 599 — (72 ) 1,336 Other noncurrent assets 255 330 5 — 590 Total assets $ 12,520 $ 24,371 $ 1,133 $ (12,000 ) $ 26,024 Condensed Consolidating Balance Sheet as of December 31, 2018 (Millions of Dollars) Parent (Issuer) Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated LIABILITIES AND EQUITY Current liabilities: Accounts receivable securitization program $ — $ — $ 339 $ — $ 339 Advances from affiliates — — 22 (22 ) — Long-term debt due currently 23 163 5 — 191 Trade accounts payable 2 928 121 (106 ) 945 Accounts payable - affiliates 236 — 9 (245 ) — Notes due to affiliates — — 101 (101 ) — Commodity and other derivative contractual liabilities — 1,376 — — 1,376 Margin deposits related to commodity contracts — 4 — — 4 Accrued income taxes 11 — — (1 ) 10 Accrued taxes other than income — 181 1 — 182 Accrued interest 48 29 4 (4 ) 77 Asset retirement obligations — 156 — — 156 Other current liabilities 74 267 4 — 345 Total current liabilities 394 3,104 606 (479 ) 3,625 Long-term debt, less amounts due currently 3,819 7,027 28 — 10,874 Commodity and other derivative contractual liabilities — 270 — — 270 Accumulated deferred income taxes — — 82 (72 ) 10 Tax Receivable Agreement obligation 420 — — — 420 Asset retirement obligations — 2,203 14 — 2,217 Identifiable intangible liabilities — net — 278 123 — 401 Other noncurrent liabilities and deferred credits 20 303 17 — 340 Total liabilities 4,653 13,185 870 (551 ) 18,157 Total stockholders' equity 7,867 11,186 259 (11,449 ) 7,863 Noncontrolling interest in subsidiary — — 4 — 4 Total liabilities and equity $ 12,520 $ 24,371 $ 1,133 $ (12,000 ) $ 26,024

Business And Significant Acco_4

Business And Significant Accounting Policies (Narrative) (Details)	6 Months Ended
	Jun. 30, 2019Reportable_segment
Business and Significant Accounting Policies
Number of reportable segments (in reportable segments)	6

Business And Significant Acco_5

Business And Significant Accounting Policies (Adoption of New Accounting Standards) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Jan. 01, 2019	Dec. 31, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease right-of-use asset	$ 95
Lease liability	132
Assets [Abstract]
Property, plant and equipment — net	14,260	$ 14,627	$ 14,612
Operating lease right-of-use assets	34	70	0
Prepaid expense and other current assets	285	150	152
Accumulated deferred income taxes	1,144	1,337	1,336
Liabilities [Abstract]
Other current liabilities	308	344	345
Operating lease liabilities	53	109
Identifiable intangible liabilities - net	331	365	401
Other noncurrent liabilities and deferred credits		354
Equity
Retained deficit	$ (989)	(1,451)	(1,449)
Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Lease right-of-use asset		85
Lease liability		123
Assets [Abstract]
Property, plant and equipment — net		15
Operating lease right-of-use assets		70
Prepaid expense and other current assets		(2)
Accumulated deferred income taxes		1
Liabilities [Abstract]
Other current liabilities		(1)
Operating lease liabilities		109
Identifiable intangible liabilities - net		(36)
Other noncurrent liabilities and deferred credits		14
Equity
Retained deficit		$ (2)
Previously Reported [Member]
Assets [Abstract]
Property, plant and equipment — net			14,612
Operating lease right-of-use assets			0
Prepaid expense and other current assets			152
Accumulated deferred income taxes			1,336
Liabilities [Abstract]
Other current liabilities			345
Operating lease liabilities			0
Identifiable intangible liabilities - net			401
Other noncurrent liabilities and deferred credits			340
Equity
Retained deficit			$ (1,449)

Acquisition of Crius, Dynegy _3

Acquisition of Crius, Dynegy Merger Transaction and Business Combination Accounting (Acquisition of Crius) (Details) $ in Millions	Jul. 15, 2019USD ($)	Apr. 09, 2018USD ($)	Jul. 31, 2019TW
Business Combination, Consideration Transferred		$ 2,273
Subsequent Event [Member]
Electricity Load, Annualized Basis | TW			11.6
Business Combination, Consideration Transferred	$ 400
Business Combination, Consideration Transferred to Acquire Outstanding Trust Units	380
Business Combination, Consideration Transferred, Liabilities Incurred	$ 111

Acquisition of Crius, Dynegy _4

Acquisition of Crius, Dynegy Merger Transaction and Business Combination Accounting (Dynegy Merger Transaction) (Details) - $ / shares	Apr. 09, 2018	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017
Common stock, par or stated value per share		$ 0.01
Merger agreement, common stock conversion ratio	0.652
Stock issued during period, shares, new issues	94,409,573
Common stock, shares outstanding	522,932,453	476,166,856	493,215,309	521,214,879	428,398,802
Vistra Energy Corp. [Member]
Common stock, par or stated value per share	$ 0.01
Dynegy Inc. [Member]
Common stock, par or stated value per share	$ 0.01
Common stock, shares outstanding	144,800,000

Acquisition of Crius, Dynegy _5

Acquisition of Crius, Dynegy Merger Transaction and Business Combination Accounting (Dynegy Business Combination Narrative) (Details) - USD ($) $ in Millions	Apr. 09, 2018	Jun. 30, 2018	Jun. 30, 2018	Mar. 31, 2019
Business Combinations [Abstract]
Business Combination, Consideration Transferred	$ 2,273
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Property, Plant, and Equipment				$ 173
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Intangibles				(36)
Goodwill, Period Increase (Decrease)				175
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Accounts Receivable, Inventory, Prepaid Expenses and Other Current Assets				(10)
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Accumulated Deferred Income Taxes				127
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Other Noncurrent Assets				(113)
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Trade Accounts Payable and Other Current Liabilities				89
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Other Noncurrent Liabilities				177
Business Combination, Provisional Information, Initial Accounting Incomplete, Adjustment, Assets Retirement Obligations, Including Amounts Due Currently				$ 56
Business Combination, Acquisition Related Costs		$ 50	$ 52

Acquisition of Crius, Dynegy _6

Acquisition of Crius, Dynegy Merger Transaction and Business Combination Accounting (Final Purchase Price Allocation) (Details) - USD ($) $ / shares in Units, $ in Millions	Apr. 09, 2018	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017
Common stock, shares outstanding	522,932,453	476,166,856	493,215,309	521,214,879	428,398,802
Merger agreement, common stock conversion ratio	0.652
Business Acquisition, Share Price	$ 19.87
Business Combination, Consideration Paid For Acquiree Outstanding Common Stock	$ 1,876
Business Combination, Fair Value Of Tangible Equity Units	369
Business Combination, Fair Value Of Outstanding Compensation Awards Attributable To Pre-Combination Service	26
Business Combination, Fair Value Of Outstanding Warrants	2
Final Purchase Price Allocation [Abstract]
Cash and cash equivalents	445
Trade accounts receivables, inventories, prepaid expenses and other current assets	853
Property, plant and equipment	10,535
Accumulated deferred income taxes	518
Identifiable intangible assets	351
Goodwill	175	$ 2,082	$ 2,068
Other noncurrent assets	419
Total assets acquired	13,296
Trade accounts payable and other current liabilities	733
Commodity and other derivative contractual assets and liabilities, net	422
Asset retirement obligations, including amounts due currently	475
Long-term debt, including amounts due currently	8,919
Other noncurrent liabilities	469
Total liabilities assumed	11,018
Identifiable net assets acquired	2,278
Noncontrolling interest in subsidiary	5
Total purchase price	2,273
Business Combination, Consideration Transferred	$ 2,273
Dynegy Inc. [Member]
Common stock, shares outstanding	144,800,000
Vistra Energy Corp. [Member]
Business Combination, Acquirer Common Shares Issued In Exchange For Acquireee Common Shares Outstanding	94,400,000

Acquisition of Crius, Dynegy _7

Acquisition of Crius, Dynegy Merger Transaction and Business Combination Accounting (Unaudited Pro Form Financial Information) (Details) $ / shares in Units, $ in Millions	6 Months Ended
	Jun. 30, 2018USD ($)$ / shares
Business Combinations [Abstract]
Revenue	$ 4,789
Net loss	(439)
Net loss attributable to Vistra Energy	$ (435)
Net loss attributable to Vistra Energy per weighted average share of common stock outstanding — basic | $ / shares	$ (0.83)
Net loss attributable to Vistra Energy per weighted average share of common stock outstanding — diluted | $ / shares	$ (0.83)

Acquisition and Development o_2

Acquisition and Development of Generation Facilities (Battery Energy Storage Projects) (Details) $ in Millions	1 Months Ended	3 Months Ended
	Jun. 30, 2018	Dec. 31, 2018USD ($)	Jun. 30, 2019USD ($)Megawatt-hour
Construction in Progress, Gross | $		$ 277	$ 135
Vistra Energy Corp. [Member] | Upton County 2 Solar Facility (Battery Storage Project) [Member]
Texas Emissions Reduction Plan, Grant Awarded | $		$ 1
Electricity Generation Facility Capacity | Megawatt-hour			10
Vistra Energy Corp. [Member] | Oakland Power Plant (Battery Storage Project) [Member]
Electricity Generation Facility Capacity | Megawatt-hour			20
Vistra Energy Corp. [Member] | Moss Landing Power Plant (Battery Storage Project) [Member]
Electricity Generation Facility Capacity | Megawatt-hour			300
Construction in Progress, Gross | $			$ 15
Proposed Contract, Duration, Number Of Years	20 years

Acquisition and Development o_3

Acquisition and Development of Generation Facilities (Upton Solar Development) (Details) $ in Millions	6 Months Ended		20 Months Ended
	Jun. 30, 2019USD ($)Megawatt-hour	Jun. 30, 2018USD ($)	Dec. 31, 2018USD ($)
Development and growth expenditures | $	$ (36)	$ (21)	$ (231)
Luminant Generation Company LLC [Member] | Upton County 2 Solar Facility [Member]
Electricity Generation Facility Capacity | Megawatt-hour	180

Retirement of Generation Faci_3

Retirement of Generation Facilities (Retirement of Generation Facilities) (Details)	Aug. 31, 2018Megawatt-hour	May 31, 2018power_plantMegawatt-hour	Feb. 28, 2018power_plantMegawatt-hour
Northeastern Power Cogeneration Facility [Member]
Electricity generation facility capacity retired	51
Killen Station [Member]
Electricity generation facility capacity retired		204
Jointly Owned Utility Plant, Proportionate Ownership Share		33.00%
J.M. Stuart Station [Member]
Electricity generation facility capacity retired		679
Jointly Owned Utility Plant, Proportionate Ownership Share		39.00%
Killen and J.M. Stuart Stations [Member]
Electricity generation facility capacity retired		883
Number Of Electric Generation Plants Retired | power_plant		2
Monticello Steam Electric Station [Member]
Electricity generation facility capacity retired			1,880
Number of electric generation units retired			3
Sandow Steam Electric Station Units 4 and 5 [Member]
Electricity generation facility capacity retired			1,137
Number of electric generation units retired			2
Big Brown Steam Electric Station [Member]
Electricity generation facility capacity retired			1,150
Number of electric generation units retired			2
Monticello, Sandow and Big Brown Steam Electric Stations [Member]
Electricity generation facility capacity retired			4,167
Number Of Electric Generation Plants Retired | power_plant			3
Number of electric generation units retired			7

Revenue (Revenue Disaggregated

Revenue (Revenue Disaggregated By Major Source) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Disaggregation of Revenue [Line Items]
Unrealized Gain (Loss) on Derivatives	$ (119)	$ 25	$ (199)	$ 86
Revenue from Contract with Customer, Excluding Assessed Tax	2,229	2,677	4,777	3,889
Revenues	2,832	2,574	5,755	3,338
Energy Charge In EROCT [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,091	1,111	2,116	2,059
Energy Charge In Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	315	336	663	336
Wholesale Generation Revenue From ISO [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	497	901	1,371	1,112
Capacity Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	136	251	296	251
Revenue From Other Wholesale Contracts [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	190	78	331	131
Intangible Amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	(14)	(23)	(29)	(36)
Hedging And Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	617	(80)	1,007	(515)
Affiliate Sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	0	0	0	0
Total Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	603	(103)	978	(551)
Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	26	26	101	26
Revenues	(1,446)	(1,157)	(2,166)	(860)
Intersegment Eliminations [Member] | Energy Charge In EROCT [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Intersegment Eliminations [Member] | Energy Charge In Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Intersegment Eliminations [Member] | Wholesale Generation Revenue From ISO [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	22	13	95	13
Intersegment Eliminations [Member] | Capacity Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	11	0	11
Intersegment Eliminations [Member] | Revenue From Other Wholesale Contracts [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	4	2	6	2
Intersegment Eliminations [Member] | Intangible Amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	1	0	2	0
Intersegment Eliminations [Member] | Hedging And Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	20	5	61	5
Intersegment Eliminations [Member] | Affiliate Sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	(1,493)	(1,188)	(2,330)	(891)
Intersegment Eliminations [Member] | Total Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	(1,472)	(1,183)	(2,267)	(886)
Retail Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,406	1,447	2,779	2,395
Revenues	1,421	1,454	2,806	2,426
Retail Segment [Member] | Energy Charge In EROCT [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,091	1,111	2,116	2,059
Retail Segment [Member] | Energy Charge In Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	315	336	663	336
Retail Segment [Member] | Wholesale Generation Revenue From ISO [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Retail Segment [Member] | Capacity Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Retail Segment [Member] | Revenue From Other Wholesale Contracts [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Retail Segment [Member] | Intangible Amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	(10)	(15)	(19)	(27)
Retail Segment [Member] | Hedging And Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	25	22	46	58
Retail Segment [Member] | Affiliate Sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	0	0	0	0
Retail Segment [Member] | Total Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	15	7	27	31
ERCOT Segment
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	240	258	532	485
Revenues	1,671	1,327	2,625	794
ERCOT Segment | Energy Charge In EROCT [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
ERCOT Segment | Energy Charge In Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
ERCOT Segment | Wholesale Generation Revenue From ISO [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	188	208	435	383
ERCOT Segment | Capacity Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
ERCOT Segment | Revenue From Other Wholesale Contracts [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	52	50	97	102
ERCOT Segment | Intangible Amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	0	0	0	(1)
ERCOT Segment | Hedging And Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	404	229	562	(233)
ERCOT Segment | Affiliate Sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	1,027	840	1,531	543
ERCOT Segment | Total Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	1,431	1,069	2,093	309
PJM Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	270	494	630	494
Revenues	686	485	1,391	485
PJM Segment [Member] | Energy Charge In EROCT [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
PJM Segment [Member] | Energy Charge In Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
PJM Segment [Member] | Wholesale Generation Revenue From ISO [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	130	367	351	367
PJM Segment [Member] | Capacity Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	53	119	120	119
PJM Segment [Member] | Revenue From Other Wholesale Contracts [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	87	8	159	8
PJM Segment [Member] | Intangible Amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	0	0	0	0
PJM Segment [Member] | Hedging And Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	81	(161)	171	(161)
PJM Segment [Member] | Affiliate Sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	335	152	590	152
PJM Segment [Member] | Total Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	416	(9)	761	(9)
NY/NE Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	159	206	440	206
Revenues	254	187	599	187
NY/NE Segment [Member] | Energy Charge In EROCT [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
NY/NE Segment [Member] | Energy Charge In Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
NY/NE Segment [Member] | Wholesale Generation Revenue From ISO [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	81	118	276	118
NY/NE Segment [Member] | Capacity Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	72	82	152	82
NY/NE Segment [Member] | Revenue From Other Wholesale Contracts [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	6	6	12	6
NY/NE Segment [Member] | Intangible Amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	(1)	(2)	(3)	(2)
NY/NE Segment [Member] | Hedging And Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	61	(29)	113	(29)
NY/NE Segment [Member] | Affiliate Sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	35	12	49	12
NY/NE Segment [Member] | Total Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	95	(19)	159	(19)
MISO Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	128	221	295	221
Revenues	246	257	500	257
MISO Segment [Member] | Energy Charge In EROCT [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
MISO Segment [Member] | Energy Charge In Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
MISO Segment [Member] | Wholesale Generation Revenue From ISO [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	76	180	214	180
MISO Segment [Member] | Capacity Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	11	29	24	29
MISO Segment [Member] | Revenue From Other Wholesale Contracts [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	41	12	57	12
MISO Segment [Member] | Intangible Amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	(4)	(6)	(9)	(6)
MISO Segment [Member] | Hedging And Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	26	(121)	54	(121)
MISO Segment [Member] | Affiliate Sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	96	163	160	163
MISO Segment [Member] | Total Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	118	36	205	36
Asset Closure Segment [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		25		62
Revenues	0	21	0	49
Asset Closure Segment [Member] | Energy Charge In EROCT [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0		0
Asset Closure Segment [Member] | Energy Charge In Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0		0
Asset Closure Segment [Member] | Wholesale Generation Revenue From ISO [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		15		51
Asset Closure Segment [Member] | Capacity Revenue [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		10		10
Asset Closure Segment [Member] | Revenue From Other Wholesale Contracts [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax		0		1
Asset Closure Segment [Member] | Intangible Amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues		0		0
Asset Closure Segment [Member] | Hedging And Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues		(25)		(34)
Asset Closure Segment [Member] | Affiliate Sales [Member]
Disaggregation of Revenue [Line Items]
Revenues		21		21
Asset Closure Segment [Member] | Total Other Revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues		(4)		(13)
Operating revenues [Member]
Disaggregation of Revenue [Line Items]
Unrealized Gain (Loss) on Derivatives	538	203	697	(208)
Operating revenues [Member] | Intersegment Eliminations [Member]
Disaggregation of Revenue [Line Items]
Unrealized Gain (Loss) on Derivatives	(803)	(463)	(968)	180
Operating revenues [Member] | Retail Segment [Member]
Disaggregation of Revenue [Line Items]
Unrealized Gain (Loss) on Derivatives	6	1	5	13
Operating revenues [Member] | ERCOT Segment
Disaggregation of Revenue [Line Items]
Unrealized Gain (Loss) on Derivatives	1,050	668	1,287	(398)
Operating revenues [Member] | PJM Segment [Member]
Disaggregation of Revenue [Line Items]
Unrealized Gain (Loss) on Derivatives	184	(10)	276	(10)
Operating revenues [Member] | NY/NE Segment [Member]
Disaggregation of Revenue [Line Items]
Unrealized Gain (Loss) on Derivatives	31	(24)	32	(24)
Operating revenues [Member] | MISO Segment [Member]
Disaggregation of Revenue [Line Items]
Unrealized Gain (Loss) on Derivatives	$ 67	$ 30	$ 46	$ 30

Revenue (Performance Obligation

Revenue (Performance Obligations) (Details) $ in Millions	Jun. 30, 2019USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 440
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 770
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 720
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 423
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	3 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 96
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	4 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 65
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Period	5 years

Revenue (Accounts Receivable) (

Revenue (Accounts Receivable) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Trade accounts receivable — net	$ 1,101	$ 1,087
Trade Accounts Receivable From Contracts With Customers [Member]
Trade accounts receivable — net	977	951
Other Trade Accounts Receivables [Member]
Trade accounts receivable — net	$ 124	$ 136

Goodwill and Identifiable Int_3

Goodwill and Identifiable Intangible Assets and Liabilities (Goodwill) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Dec. 31, 2018	Apr. 09, 2018
Goodwill [Line Items]
Goodwill	$ 2,082	$ 2,068	$ 175
ERCOT Retail Reporting Unit [Member]
Goodwill [Line Items]
Goodwill	1,907
Goodwill, expected tax deductible amount	$ 1,686
Business acquisition, goodwill, expected tax deductible term	15 years
Dynegy Merger [Member]
Goodwill [Line Items]
Goodwill	$ 175
Dynegy Merger [Member] | ERCOT Generation and Wholesale Reporting Unit [Member]
Goodwill [Line Items]
Goodwill	122
Dynegy Merger [Member] | ERCOT Retail Reporting Unit [Member]
Goodwill [Line Items]
Goodwill	$ 53

Goodwill and Identifiable Int_4

Goodwill and Identifiable Intangible Assets and Liabilities (Identifiable Intangible Assets and Liabilities Reported in the Balance Sheet) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount	$ 2,494	$ 2,378
Accumulated amortization	1,359	1,134
Total identifiable intangible assets subject to amortization, net	1,135	1,244
Total identifiable intangible assets	2,383	2,493
Identifiable intangible liabilities, Net	331	401
Retail trade names (not subject to amortization) [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount, unamortized intangibles	1,245	1,245
Mineral interests (not currently subject to amortization) [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount, unamortized intangibles	3	4
Retail customer relationship [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount	1,680	1,680
Accumulated amortization	987	876
Total identifiable intangible assets subject to amortization, net	693	804
Software and other technology-related assets [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount	321	270
Accumulated amortization	124	105
Total identifiable intangible assets subject to amortization, net	197	165
Retail and wholesale contracts [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount	315	316
Accumulated amortization	172	138
Total identifiable intangible assets subject to amortization, net	143	178
Contractual service agreements [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount	60	70
Accumulated amortization	2	0
Total identifiable intangible assets subject to amortization, net	58	70
Identifiable intangible liabilities, Net	107	136
Other identifiable intangible assets [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount	118	42
Accumulated amortization	74	15
Total identifiable intangible assets subject to amortization, net	44	27
Purchase and sale contracts [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Identifiable intangible liabilities, Net	183	195
Environmental allowances [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Identifiable intangible liabilities, Net	$ 41	$ 70

Goodwill and Identifiable Int_5

Goodwill and Identifiable Intangible Assets and Liabilities (Amortization Expense Related to Identifiable Intangible Assets and Liabilities) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Finite-Lived Intangible Assets and Liabilities [Line Items]
Amortization of intangible assets and liabilities	$ 97	$ 121	$ 203	$ 215
Depreciation and amortization [Member]
Finite-Lived Intangible Assets and Liabilities [Line Items]
Amortization of intangible assets and liabilities	72	97	141	182
Retail customer relationship [Member] | Depreciation and amortization [Member]
Finite-Lived Intangible Assets and Liabilities [Line Items]
Amortization of intangible assets and liabilities	55	77	111	150
Software and other technology-related assets [Member] | Depreciation and amortization [Member]
Finite-Lived Intangible Assets and Liabilities [Line Items]
Amortization of intangible assets and liabilities	15	19	29	30
Retail and wholesale contracts/purchase and sale contracts [Member] | Operating revenues, fuel, purchased power costs and delivery fees [Member]
Finite-Lived Intangible Assets and Liabilities [Line Items]
Amortization of intangible assets and liabilities	12	23	24	32
Other identifiable intangible assets [Member] | Operating revenues, fuel, purchased power costs and delivery fees, depreciation and amortization [Member]
Finite-Lived Intangible Assets and Liabilities [Line Items]
Amortization of intangible assets and liabilities	$ 15	$ 2	$ 39	$ 3

Goodwill and Identifiable Int_6

Goodwill and Identifiable Intangible Assets and Liabilities (Estimated Amortization of Identifiable Intangible Assets and Liabilities) (Details) $ in Millions	Jun. 30, 2019USD ($)
Goodwill and Intangible Assets Disclosure [Abstract]
2019	$ 309
2020	211
2021	164
2022	101
2023	$ 76

Income Taxes (Calculation of Ef

Income Taxes (Calculation of Effective Tax Rate) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Effective Income Tax Rate Reconciliation, Amount [Abstract]
Income (loss) before income taxes	$ 502	$ 31	$ 803	$ (364)
Income tax (expense) benefit	$ (148)	$ 74	$ (225)	$ 163
Effective tax rate	29.50%	(238.70%)	28.00%	44.80%
Effective tax rate at federal statutory rate	21.00%	21.00%	21.00%	21.00%
Unrecognized Tax Benefits	$ 39		$ 39		$ 39

Tax Receivable Agreement Obli_3

Tax Receivable Agreement Obligation (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Income Tax Disclosure [Abstract]
Percent of cash tax savings due Tax Receivable Agreement rights holders				85.00%
Effective tax rate at federal statutory rate	21.00%		21.00%	21.00%	21.00%
Estimated undiscounted future payments under Tax Receivable Agreement				$ 1,300
Changes in tax assumptions impacting timing of payments	$ (48)	$ (19)	$ 46	$ (67)	$ 46

Tax Receivable Agreement Obli_4

Tax Receivable Agreement Obligation (Summary of Tax Receivable Agreement Obligation) (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Income Tax Disclosure [Abstract]
TRA obligation at the beginning of the period		$ 420		$ 420	$ 357
Accretion expense				31	36
Changes in tax assumptions impacting timing of payments	$ (48)	$ (19)	$ 46	(67)	46
Impacts of Tax Receivable Agreement	(33)		64	(36)	82
TRA obligation at the end of the period	384		439	384	439
Less amounts due currently	0		(25)	0	(25)
Noncurrent TRA obligation at the end of the period	$ 384		$ 414	$ 384	$ 414	$ 420

Earnings Per Share (Earnings Pe

Earnings Per Share (Earnings Per Share) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Earnings Per Share [Abstract]
Net income (loss) attributable to Vistra Energy	$ 356	$ 108	$ 581	$ (198)
Weighted average shares of common stock outstanding - basic	499,778,235	526,332,862	499,213,522	477,662,016
Net income (loss) per weighted average share of common stock outstanding - basic	$ 0.71	$ 0.21	$ 1.16	$ (0.41)
Dilutive securities - stock-based incentive compensation plan and tangible equity units	7,722,148	7,453,962	8,035,398	0
Weighted average shares of common stock outstanding - diluted	507,500,383	533,786,824	507,248,920	477,662,016
Net income (loss) per weighted average share of common stock outstanding - diluted	$ 0.70	$ 0.20	$ 1.15	$ (0.41)
Prepaid stock purchase contract, minimum number of common shares issued if tangible equity units settled	15,207,600	15,056,260	15,207,600	15,056,260
Antidilutive securities excluded from computation of earnings per share	2,910,226	8,064,657	7,577,246	18,392,470

Accounts Receivable Securitiz_2

Accounts Receivable Securitization Program (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Nov. 30, 2019	Jul. 31, 2019	Dec. 31, 2018
Short-term Debt [Line Items]
Accretion expense	$ 31	$ 36
Accounts receivable securitization program	430				$ 339
Accounts receivable securitization program, gross trade accounts receivable held by special purpose subsidiary	$ 662
Subsequent Event [Member]
Short-term Debt [Line Items]
Accounts receivable securitization program, maximum borrowing capacity			$ 450	$ 600

Long-Term Debt (Long-Term Debt)

Long-Term Debt (Long-Term Debt) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Feb. 28, 2019	Dec. 31, 2018	Aug. 31, 2018	Apr. 09, 2018
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	$ 11,354
Total other long-term debt	432		$ 471
Unamortized debt premiums, discounts and issuance costs	(4)		155
Less amounts due currently	161		191
Total long-term debt less amounts due currently	11,193		10,874
Line of Credit | Vistra Operations Credit Facility [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	3,798		5,813
Vistra Operations Senior Secured Notes [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	$ 2,000		0
Vistra Operations Senior Secured Notes [Member] | 3.550% Senior Secured Notes Due 2024 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	3.55%
Long-term debt, including amounts due currently	$ 1,200		0
Vistra Operations Senior Secured Notes [Member] | 4.300% Senior Secured Notes Due 2029 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	4.30%
Long-term debt, including amounts due currently	$ 800		0
Vistra Operations Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	$ 3,600		1,000
Vistra Operations Senior Unsecured Notes [Member] | 5.50% Senior Notes Due 2026 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	5.50%			5.50%
Long-term debt, including amounts due currently	$ 1,000		1,000
Vistra Operations Senior Unsecured Notes [Member] | 5.625% Senior Notes Due 2027 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	5.625%	5.625%
Long-term debt, including amounts due currently	$ 1,300		0
Vistra Operations Senior Unsecured Notes [Member] | 5.000% Senior Notes due 2027 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	5.00%
Long-term debt, including amounts due currently	$ 1,300		0
Vistra Energy Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	$ 1,528		3,626
Vistra Energy Senior Unsecured Notes [Member] | 7.375% Senior Notes Due 2022 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	7.375%
Long-term debt, including amounts due currently	$ 306		1,707
Vistra Energy Senior Unsecured Notes [Member] | 5.875% Senior Notes Due 2023 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	5.875%
Long-term debt, including amounts due currently	$ 500		500
Vistra Energy Senior Unsecured Notes [Member] | 7.625% Senior Notes Due 2024 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	7.625%
Long-term debt, including amounts due currently	$ 475		1,147
Vistra Energy Senior Unsecured Notes [Member] | 8.034% Senior Notes Due 2024 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	8.034%	8.034%		8.034%
Long-term debt, including amounts due currently	$ 0		25
Vistra Energy Senior Unsecured Notes [Member] | 8.000% Senior Notes Due 2025 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	8.00%			8.00%
Long-term debt, including amounts due currently	$ 81		81
Vistra Energy Senior Unsecured Notes [Member] | 8.125% Senior Notes Due 2026 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	8.125%			8.125%
Long-term debt, including amounts due currently	$ 166		166
Amortizing Notes Due 2019 (Tangible Equity Units) [Member] | 7% Amortization note due 2019 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	7.00%				7.00%
Long-term debt, including amounts due currently	$ 8		24
Total long-term debt less amounts due currently					$ 38
Secured Debt [Member] | Forward Capacity Agreement [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	222		236
Unsecured Debt [Member] | Equipment Financing Agreement [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	114		120
Mandatorily Redeemable Preferred Stock [Member] | PrefCo Mandatorily Redeemable Preferred Stock [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	$ 70		70
Construction Loans [Member] | Building Financing 8.82% due semiannually through February 11, 2022 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	8.82%
Long-term debt, including amounts due currently	$ 18		21
Long-term debt, including amounts due currently [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	$ 11,354		$ 11,065

Long-Term Debt (Vistra Operatio

Long-Term Debt (Vistra Operations Credit Facilities) (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Line of Credit Facility [Line Items]
Repayment of long-term debt					$ 4,137	$ 1,338
Gain (loss) on extinguishment of debt			$ 3	$ 0	10	0
Vistra Operations Company LLC | Line of Credit
Line of Credit Facility [Line Items]
Line of credit facility, maximum borrowing capacity	$ 6,523		6,523		6,523
Line of credit facility, borrowings outstanding	(3,798)		(3,798)		(3,798)
Line of credit facility, remaining borrowing capacity	2,173		2,173		2,173
Gain (loss) on extinguishment of debt	(4)
Debt fees and expenses					2	42
Debt fees and expenses, recorded as interest expense						23
Debt fees and expenses, capitalized as reduction of debt						9
Debt fees and expenses, capitalized as noncurrent asset						10
Vistra Operations Company LLC | Line of Credit | Senior Secured Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum borrowing capacity	2,725		2,725		2,725
Line of credit facility, borrowings outstanding	0		0		0
Line of credit facility, remaining borrowing capacity	2,173		2,173		$ 2,173
Line of credit facility, increase (decrease), net	225	$ 1,640
Debt instrument, basis spread on variable rate					1.75%
Debt covenant, outstanding borrowings to outstanding commitments threshold, amount of letters of credit excluded	$ 300		$ 300		$ 300
Debt covenant, outstanding borrowings to outstanding commitments threshold, percent	30.00%		30.00%		30.00%
Vistra Operations Company LLC | Line of Credit | Senior Secured Revolving Credit Facility [Member] | Maximum
Line of Credit Facility [Line Items]
Debt covenant, net first lien debt to EBITDA threshold	4.25		4.25		4.25
Vistra Operations Company LLC | Line of Credit | Senior Secured Revolving Credit Facility Letter Of Credit Sub-Facility [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum borrowing capacity	$ 2,350		$ 2,350		$ 2,350
Debt instrument, interest rate, stated percentage	1.75%		1.75%		1.75%
Line of credit facility, increase (decrease), net	$ 50	1,585
Line of credit facility, letters of credit outstanding	552		$ 552		$ 552
Vistra Operations Company LLC | Line of Credit | Senior Secured Term Loan C Facility [Member]
Line of Credit Facility [Line Items]
Line of credit facility, increase (decrease), net		(500)
Vistra Operations Company LLC | Line of Credit | Senior Secured Term Loan B-1 Facility [Member] [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum borrowing capacity	1,897		1,897		1,897
Line of credit facility, borrowings outstanding	(1,897)		(1,897)		(1,897)
Line of credit facility, remaining borrowing capacity	0		$ 0		$ 0
Repayment of long-term debt	$ 889
Debt instrument, basis spread on variable rate					2.00%
Line of credit facility, interest rate at period end	4.40%		4.40%		4.40%
Vistra Operations Company LLC | Line of Credit | Senior Secured Term Loan B-2 Facility [Member] [Member]
Line of Credit Facility [Line Items]
Repayment of long-term debt	$ 977
Vistra Operations Company LLC | Line of Credit | Senior Secured Term Loan B-3 Facility [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum borrowing capacity	1,901		$ 1,901		$ 1,901
Line of credit facility, borrowings outstanding	(1,901)		(1,901)		(1,901)
Line of credit facility, remaining borrowing capacity	0		$ 0		$ 0
Repayment of long-term debt	$ 134
Line of credit facility, increase (decrease), net		2,050
Debt instrument, basis spread on variable rate					2.00%
Line of credit facility, interest rate at period end	4.40%		4.40%		4.40%
Cash Released from Collateral Accounts [Member] | Vistra Operations Company LLC
Line of Credit Facility [Line Items]
Cash Collateral for Borrowed Securities		$ 500		$ 500		$ 500

Long-Term Debt (Interest Rate S

Long-Term Debt (Interest Rate Swaps) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Apr. 09, 2018
Long-term debt, amount of variable interest debt hedged	$ 3,720
Interest Rate Swap, Effective Through July 2023 [Member] [Member]
Derivative, notional amount	3,000
Interest Rate Swap, Effective From July 2023 To July 2026 [Member]
Derivative, notional amount	3,000
Interest Rate Swaps, Effective Through February 2024 [Member]
Derivative, notional amount	720	$ 1,959
Derivative, notional amount, terminated	$ 841
Minimum | Interest Rate Swap, Effective From July 2023 To July 2026 [Member]
Effective interest rate, debt fixed based on derivative contracts	4.97%
Minimum | Interest Rate Swaps, Effective Through July 2023 and Legacy Swaps Effective Through 2024 [Member]
Effective interest rate, debt fixed based on derivative contracts	3.92%
Maximum | Interest Rate Swap, Effective From July 2023 To July 2026 [Member]
Effective interest rate, debt fixed based on derivative contracts	5.04%
Maximum | Interest Rate Swaps, Effective Through July 2023 and Legacy Swaps Effective Through 2024 [Member]
Effective interest rate, debt fixed based on derivative contracts	4.16%

Long-Term Debt (Vistra Operat_2

Long-Term Debt (Vistra Operations Senior Secured Notes) (Details) - Vistra Operations Senior Secured Notes [Member] $ in Millions	1 Months Ended
	Jun. 30, 2019USD ($)
Proceeds from issuance of debt	$ 2,000
Debt fees and expenses, capitalized as reduction of debt	20
Proceeds from issuance of senior long-term debt	1,976
3.550% Senior Secured Notes Due 2024 [Member]
Proceeds from issuance of debt	$ 1,200
Debt instrument, interest rate, stated percentage	3.55%
Issuance of debt, price to public, percentage of face value	99.807%
4.300% Senior Secured Notes Due 2029 [Member]
Proceeds from issuance of debt	$ 800
Debt instrument, interest rate, stated percentage	4.30%
Issuance of debt, price to public, percentage of face value	99.784%

Long-Term Debt (Vistra Operat_3

Long-Term Debt (Vistra Operations Senior Unsecured Notes) (Details) - USD ($) $ in Millions	1 Months Ended
	Jul. 31, 2019	Jun. 30, 2019	Feb. 28, 2019	Aug. 31, 2018
Vistra Operations Senior Unsecured Notes [Member] | 5.000% Senior Notes due 2027 [Member]
Proceeds from issuance of debt		$ 1,300
Debt instrument, interest rate, stated percentage		5.00%
Debt fees and expenses, capitalized as reduction of debt		$ 13
Proceeds from issuance of senior long-term debt		$ 1,287
Vistra Operations Senior Unsecured Notes [Member] | 5.625% Senior Notes Due 2027 [Member]
Proceeds from issuance of debt			$ 1,300
Debt instrument, interest rate, stated percentage		5.625%	5.625%
Debt fees and expenses, capitalized as reduction of debt			$ 16
Proceeds from issuance of senior long-term debt			1,287
Vistra Operations Senior Unsecured Notes [Member] | 5.50% Senior Notes Due 2026 [Member]
Proceeds from issuance of debt				$ 1,000
Debt instrument, interest rate, stated percentage		5.50%		5.50%
Debt fees and expenses, capitalized as reduction of debt				$ 12
Proceeds from issuance of senior long-term debt				$ 990
Vistra Energy Senior Unsecured Notes [Member] | 7.375% Senior Notes Due 2022 [Member]
Debt instrument, interest rate, stated percentage		7.375%
Repayments of long-term debt			$ 35
Vistra Energy Senior Unsecured Notes [Member] | 7.625% Senior Notes Due 2024 [Member]
Debt instrument, interest rate, stated percentage		7.625%
Vistra Energy Senior Unsecured Notes [Member] | 8.034% Senior Notes Due 2024 [Member]
Debt instrument, interest rate, stated percentage		8.034%	8.034%	8.034%
Repayments of long-term debt			$ 25
Subsequent Event [Member] | Vistra Energy Senior Unsecured Notes [Member] | 7.375% Senior Notes Due 2022 [Member]
Repayments of long-term debt	$ 306
Subsequent Event [Member] | Vistra Energy Senior Unsecured Notes [Member] | 7.625% Senior Notes Due 2024 [Member]
Repayments of long-term debt	$ 87

Long-Term Debt (Vistra Energy S

Long-Term Debt (Vistra Energy Senior Unsecured Notes) (Details) - USD ($)	1 Months Ended					3 Months Ended		6 Months Ended		18 Months Ended
	Jul. 31, 2019	Jun. 30, 2019	Feb. 28, 2019	Aug. 31, 2018	May 31, 2018	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Apr. 09, 2018
Repayment of long-term debt								$ 4,137,000,000	$ 1,338,000,000
Gain (loss) on extinguishment of debt						$ 3,000,000	$ 0	10,000,000	$ 0
Vistra Energy Senior Unsecured Notes [Member]
Repayment of long-term debt		$ 845,000,000		$ 1,542,000,000
Long-term debt											$ 6,138,000,000
Gain (loss) on extinguishment of debt		$ 7,000,000		27,000,000				$ 7,000,000
Debt instrument, debt covenant, borrowed money, maximum percent of total assets		30.00%				30.00%		30.00%		30.00%
Customary event of default, minimum aggregate amount threshold		$ 100,000,000				$ 100,000,000		$ 100,000,000		$ 100,000,000
Vistra Energy Senior Unsecured Notes [Member] | Bond Repurchase Program [Member]
Bond Repurchase Program, authorized amount		200,000,000				$ 200,000,000		200,000,000		200,000,000
Repayment of long-term debt								$ 0		$ 119,000,000
Vistra Energy Senior Unsecured Notes [Member] | 7.375% Senior Notes Due 2022 [Member]
Repayment of long-term debt		$ 173,000,000	$ 1,193,000,000
Debt instrument, interest rate, stated percentage		7.375%				7.375%		7.375%		7.375%
Vistra Energy Senior Unsecured Notes [Member] | 7.625% Senior Notes Due 2024 [Member]
Repayment of long-term debt		$ 672,000,000		26,000,000
Debt instrument, interest rate, stated percentage		7.625%				7.625%		7.625%		7.625%
Vistra Energy Senior Unsecured Notes [Member] | 8.034% Senior Notes Due 2024 [Member]
Repayment of long-term debt				$ 163,000,000
Debt instrument, interest rate, stated percentage		8.034%	8.034%	8.034%		8.034%		8.034%		8.034%
Vistra Energy Senior Unsecured Notes [Member] | 8.000% Senior Notes Due 2025 [Member]
Repayment of long-term debt				$ 669,000,000
Debt instrument, interest rate, stated percentage		8.00%		8.00%		8.00%		8.00%		8.00%
Vistra Energy Senior Unsecured Notes [Member] | 8.125% Senior Notes Due 2026 [Member]
Repayment of long-term debt				$ 684,000,000
Debt instrument, interest rate, stated percentage		8.125%		8.125%		8.125%		8.125%		8.125%
Vistra Energy Senior Unsecured Notes [Member] | 6.75% Senior Notes Due 2019 [Member]
Repayment of long-term debt					$ 850,000,000
Debt instrument, interest rate, stated percentage		6.75%			6.75%	6.75%		6.75%		6.75%
Debt instrument, redemption price, percentage					101.688%
Debt fees and expenses, recorded as interest expense					$ 14,000,000
Subsequent Event [Member] | Vistra Energy Senior Unsecured Notes [Member] | 7.625% Senior Notes Due 2024 [Member]
Repayment of long-term debt	$ 1,000,000

Long-Term Debt (Other Long-Term

Long-Term Debt (Other Long-Term Debt) (Details) - USD ($) $ in Millions	1 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Apr. 30, 2018	Dec. 31, 2018	Apr. 09, 2018
Long-term debt, including amounts due currently	$ 11,354
Amortizing Notes Due 2019 (Tangible Equity Units) [Member] | 7% Amortization note due 2019 [Member]
Long-term debt, including amounts due currently	8			$ 24
Secured Debt [Member] | Forward Capacity Agreement [Member]
Long-term debt, including amounts due currently	$ 222			$ 236
Debt instrument, interest rate, effective percentage	3.36%
Secured Debt [Member] | Forward Capacity Agreement [Member] | PJM Capacity Sold For Planning Years 2019-2020 [Member]
Long-term debt, including amounts due currently	$ 112
Secured Debt [Member] | Forward Capacity Agreement [Member] | PJM Capacity Sold For Planning Years 2020-2021 [Member]
Long-term debt, including amounts due currently	110
Vistra Operations Company LLC | Letter of Credit [Member] | Alternate Letter of Credit Facilities [Member]
Letter of Credit Facility, maximum borrowing capacity	500
Letters of Credit, amount outstanding	500
Vistra Operations Company LLC | Letter of Credit [Member] | Alternate Letter Of Credit Facility Maturing In December 2020 [Member]
Letter of Credit Facility, maximum borrowing capacity	250
Vistra Operations Company LLC | Letter of Credit [Member] | Alternate Letter Of Credit Facility Maturing In December 2021 [Member]
Letter of Credit Facility, maximum borrowing capacity	250
Vistra Operations Company LLC | Line of Credit
Line of credit facility, maximum borrowing capacity	6,523
Line of credit facility, borrowings outstanding	(3,798)
Vistra Operations Company LLC | Line of Credit | Senior Secured Revolving Credit Facility [Member]
Line of credit facility, increase (decrease), net	225	$ 1,640
Line of credit facility, maximum borrowing capacity	2,725
Line of credit facility, borrowings outstanding	$ 0
Dynegy Inc. [Member]
Long-term debt					$ 3,563
Dynegy Inc. [Member] | Borrowings [Member] | Senior Secured Revolving Credit Facility [Member]
Line of credit facility, borrowings outstanding					0
Dynegy Inc. [Member] | Line of Credit | Senior Secured Revolving Credit Facility [Member]
Line of credit facility, letters of credit outstanding					656
Dynegy Inc. [Member] | Senior Secured Term Loan [Member]
Long-term debt					2,018
Repayments of debt		$ 2,018
Dynegy Inc. [Member] | Revolving Credit Facility [Member]
Line of credit facility, maximum borrowing capacity					$ 1,545
Dynegy Inc. [Member] | Line of Credit | Senior Secured Revolving Credit Facility [Member]
Repayments of lines of credit			$ 70

Long-Term Debt (Maturities) (De

Long-Term Debt (Maturities) (Details) $ in Millions	Jun. 30, 2019USD ($)
Maturities [Abstract]
Remainder of 2019	$ 93
2020	144
2021	70
2022	321
2023	2,408
Thereafter	8,322
Unamortized premiums, discounts and debt issuance costs	(4)
Long-term debt, including amounts due currently	$ 11,354

Leases - Narrative (Details)

Leases - Narrative (Details)	6 Months Ended
	Jun. 30, 2019USD ($)
Lessee, Lease, Description [Line Items]
Renewal term	14 years
Leases not yet commenced	$ 0
Minimum
Lessee, Lease, Description [Line Items]
Remaining lease term	1 year
Maximum
Lessee, Lease, Description [Line Items]
Remaining lease term	38 years

Leases - Lease Cost (Details)

Leases - Lease Cost (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019
Leases [Abstract]
Operating lease cost	$ 3	$ 7
Finance lease:
Finance lease right-of-use asset amortization	1	2
Interest on lease liabilities	1	1
Total finance lease cost	2	3
Variable lease cost	6	12
Short-term lease cost	8	13
Sublease income	(2)	(4)
Net lease cost	$ 17	$ 31

Leases - Balance Sheet Informat

Leases - Balance Sheet Information Disclosure (Details) - USD ($) $ in Millions	Jun. 30, 2019	Jan. 01, 2019	Dec. 31, 2018
Lease assets
Operating lease right-of-use assets	$ 34	$ 70	$ 0
Finance lease right-of-use assets (net of accumulated depreciation)	61
Total lease right-of-use assets	95
Current lease liabilities
Operating lease liabilities	13		0
Finance lease liabilities	5
Total current lease liabilities	18
Noncurrent lease liabilities
Operating lease liabilities	40		0
Finance lease liabilities	74		$ 0
Total noncurrent lease liabilities	114
Total lease liabilities	$ 132

Leases - Cash Flow Information

Leases - Cash Flow Information Disclosure (Details) $ in Millions	6 Months Ended
	Jun. 30, 2019USD ($)
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$ 7
Operating cash flow from finance leases	2
Finance cash flow from finance leases	1
Non-cash disclosure upon commencement of new lease
Right-of-use assets obtained in exchange for new operating lease liabilities	72
Right-of-use assets obtained in exchange for new finance lease liabilities	15
Non-cash disclosure upon modification of existing lease
Modification of operating lease right-of-use assets	(36)
Modification of finance lease right-of-use assets	$ 50

Leases - Lease Term and Discoun

Leases - Lease Term and Discount Rate (Details)	Jun. 30, 2019
Weighted average remaining lease term
Operating lease	8 years
Finance lease	18 years
Weighted average discount rate
Operating lease (as a percent)	6.04%
Finance lease (as a percent)	6.07%

Leases - Maturity of Lease Liab

Leases - Maturity of Lease Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 2019	Jan. 01, 2019
Operating lease
Remainder of 2019	$ 7
2020	14
2021	9
2022	7
2023	6
Thereafter	22
Total lease payments	65
Less: Interest	(12)
Present value of lease liabilities	53	$ 109
Finance lease
Remainder of 2019	4
2020	9
2021	9
2022	9
2023	9
Thereafter	79
Total lease payments	119
Less: Interest	(40)
Present value of lease liabilities	79
Total lease
Remainder of 2019	11
2020	23
2021	18
2022	16
2023	15
Thereafter	101
Total lease payments	184
Less: Interest	(52)
Present value of lease liabilities	$ 132

Commitments And Contingencies_2

Commitments And Contingencies (Narrative) (Details)	6 Months Ended
	Jun. 30, 2019USD ($)Megawatt-hourgenerating_unit
Gas Index Pricing Litigation [Member]
Commitments and Contingencies [Line Items]
Numbers of states in which entity operates	3
Advatech Dispute [Member]
Commitments and Contingencies [Line Items]
Loss contingency, estimate of possible loss	$ 81,000,000
Loss contingency, contested invoice amount	1,000,000
Loss Contingency, Damages Awarded, Value	46,000,000
Advatech Dispute [Member] | Liability [Member]
Commitments and Contingencies [Line Items]
Loss Contingency, Damages Awarded, Value	42,000,000
Advatech Dispute [Member] | Interest expense [Member]
Commitments and Contingencies [Line Items]
Loss Contingency, Damages Awarded, Value	2,000,000
Advatech Dispute [Member] | Selling, General and Administrative Expenses [Member]
Commitments and Contingencies [Line Items]
Loss Contingency, Damages Awarded, Value	2,000,000
Pending Litigation [Member] | EPA Versus Luminant and Big Brown Power Company (Big Brown and Martin Lake Generation Facilities) [Member] | Minimum
Commitments and Contingencies [Line Items]
Loss contingency, damages sought, value per day	32,500
Pending Litigation [Member] | EPA Versus Luminant and Big Brown Power Company (Big Brown and Martin Lake Generation Facilities) [Member] | Maximum
Commitments and Contingencies [Line Items]
Loss contingency, damages sought, value per day	$ 37,500
Pending Litigation [Member] | MISO 2015-2016 Planning Resource Auction [Member]
Commitments and Contingencies [Line Items]
Loss contingency, pending claims, number	3
United States Environmental Protection Agency [Member]
Commitments and Contingencies [Line Items]
Clear Air Act, Regional Haze Program, Reasonable Progress Program, number of units in Texas subject to new scrubbers | generating_unit	7
Clean Air Act, Regional Haze Program, Reasonable Progress Program, number of units In Texas subject to upgrades to existing scrubbers | generating_unit	7
Clean Air Act, Regional Haze Program, Best Available Retrofit Technology Alternative, Sulfur Dioxide Emissions, number of units in Texas subject to rule, total	39
Startup, Shutdown and Malfunction Events, Number Of States Impacted By Final Rule	36
Illinois Environmental Protection Agency [Member]
Commitments and Contingencies [Line Items]
Illinois Multi-Pollutant Standards, Downstate Coal-Fueled Stations With Emission Tonnage Limits, Number	8
Illinois Multi-Pollutant Standards, Additional Reduction In Emissions, MW | Megawatt-hour	2,000
Illinois Multi-Pollutant Standards, Proposed Rule Reduction In Allowable Annual Emissions of Sulfur Dioxide	48.00%
Illinois Multi-Pollutant Standards, Proposed Rule Reduction In Allowable Annual Emissions Of Nitrogen-Oxide	42.00%
Coal Combustion Residuals, Coal Ash Disposal And Storage Legislation, One-Time Fee For Each Closed Site	$ 50,000
Coal Combustion Residuals, Coal Ash Disposal And Storage Legislation, One Time Fee For Each Open Site	$ 75,000
Vermillion Facility Old East And North Sites [Member]
Commitments and Contingencies [Line Items]
Site contingency, number of sites with regulatory violations	2
Vistra Operations Company LLC | Financial standby letter of credit [Member]
Commitments and Contingencies [Line Items]
Letters of Credit, amount outstanding	$ 1,052,000,000
Vistra Operations Company LLC | Financial standby letter of credit [Member] | Support risk management and trading margin requirements, including over the counter hedging transactions and collateral postings with independent system operators and regional transmission organizations [Member]
Commitments and Contingencies [Line Items]
Letters of Credit, amount outstanding	896,000,000
Vistra Operations Company LLC | Financial standby letter of credit [Member] | Support executory contracts and insurance agreements [Member]
Commitments and Contingencies [Line Items]
Letters of Credit, amount outstanding	46,000,000
Vistra Operations Company LLC | Financial standby letter of credit [Member] | Support retail electric provider's financial requirements with the Public Utility Commission of Texas [Member]
Commitments and Contingencies [Line Items]
Letters of Credit, amount outstanding	55,000,000
Vistra Operations Company LLC | Financial standby letter of credit [Member] | Miscellaneous credit support requirements [Member]
Commitments and Contingencies [Line Items]
Letters of Credit, amount outstanding	55,000,000
Vistra Operations Company LLC | Surety bond [Member]
Commitments and Contingencies [Line Items]
Surety bonds outstanding	$ 27,000,000
Dynegy Inc. [Member] | Pending Litigation [Member] | MISO 2015-2016 Planning Resource Auction [Member]
Commitments and Contingencies [Line Items]
Loss contingency, pending claims, number	1

Equity (Narrative) (Details)

Equity (Narrative) (Details)	Apr. 09, 2018USD ($)equity_unitshares	Jul. 31, 2019USD ($)$ / sharesshares	Nov. 30, 2018$ / shares	Jun. 30, 2019USD ($)$ / sharesshares	Mar. 31, 2019$ / shares	Jun. 30, 2018USD ($)shares	Jun. 30, 2019USD ($)$ / sharesshares	Jun. 30, 2018USD ($)shares	Dec. 31, 2018USD ($)shares	Dec. 31, 2017USD ($)shares	Jun. 30, 2019USD ($)$ / sharesshares	Jul. 01, 2019shares
Share Repurchase Program
Treasury stock				$ 212,000,000		$ 75,000,000	$ 448,000,000	$ 75,000,000
Dividends and Dividend Restrictions
Common stock, dividends per share, authorized | $ / shares			$ 0.50
Common stock, dividends, per share, cash paid | $ / shares				$ 0.125	$ 0.125
Dividends paid							(120,000,000)
Amount of restricted net assets for consolidated and unconsolidated subsidiaries				$ 1,900,000,000			$ 1,900,000,000				$ 1,900,000,000
Warrants
Class of Warrant or Right, outstanding | shares				9,000,000,000,000			9,000,000,000,000				9,000,000,000,000
Class of Warrant or Right, exercise price of warrants or rights | $ / shares				$ 35			$ 35				$ 35
Class of Warrant or Right, number of securities called by each warrant or right | shares				0.652			0.652				0.652
Tangible Equity Units [Abstract]
Tangible Equity Units, number of units issued | shares	4,600,000
Tangible Equity Units, unit price | equity_unit	100
Long-term debt, less amounts due currently				$ 11,193,000,000			$ 11,193,000,000		$ 10,874,000,000		$ 11,193,000,000
Shares of Common Stock Authorized and Outstanding
Common stock, shares authorized | shares				1,800,000,000		1,800,000,000	1,800,000,000	1,800,000,000			1,800,000,000
Common stock, shares outstanding | shares	522,932,453			476,166,856		521,214,879	476,166,856	521,214,879	493,215,309	428,398,802	476,166,856
Amortizing Notes Due 2019 (Tangible Equity Units) [Member]
Tangible Equity Units [Abstract]
Debt instrument, periodic payment	$ 1.75
Amortizing Notes Due 2019 (Tangible Equity Units) [Member] | 7% Amortization note due 2019 [Member]
Tangible Equity Units [Abstract]
Debt instrument, interest rate, stated percentage	7.00%			7.00%			7.00%				7.00%
Long-term debt, less amounts due currently	$ 38,000,000
Vistra Operations Company LLC | Vistra Energy Corp. [Member]
Dividends and Dividend Restrictions
Maximum allowable distribution to Parent Company by consolidated subsidiary without consent				$ 6,300,000,000			$ 6,300,000,000				$ 6,300,000,000
Dividends paid				1,645,000,000			3,195,000,000		$ 4,700,000,000	$ 1,100,000,000
Share Repurchase Program Approved By Board Of Directors In November 2018 [Member]
Share Repurchase Program
Stock Repurchase Program, authorized amount				$ 1,250,000,000			$ 1,250,000,000				$ 1,250,000,000
Treasury Stock, shares, acquired | shares				8,558,712			18,100,329				30,173,420
Treasury stock				$ 212,000,000			$ 448,000,000				$ 726,000,000
Treasury stock acquired, average cost per share | $ / shares				$ 24.72			$ 24.75				$ 24.05
Stock Repurchase Program, remaining authorized repurchase amount				$ 524,000,000			$ 524,000,000				$ 524,000,000
Subsequent Event [Member]
Dividends and Dividend Restrictions
Common stock, dividends, per share, declared | $ / shares		$ 0.125
Tangible Equity Units [Abstract]
Prepaid stock purchase contract, number of common shares per Tangible Equity Unit | shares												4.0813
Prepaid stock purchase contract, settlement rate per Tangible Equity Unit		$ 22.5954
Prepaid stock purchase contract, number of common shares issued upon settlement | shares		18,800,000

Equity (Changes to Equity) (Det

Equity (Changes to Equity) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		18 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Mar. 31, 2018	Dec. 31, 2017
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' Equity Attributable to Parent	$ 7,904		$ 7,904		$ 7,904		$ 7,863
Stockholders' Equity Attributable to Noncontrolling Interest	0		0		0		4
Beginning balance	7,806	$ 6,060	7,867	$ 6,342	6,342
Stock Issued During Period, Value, Acquisitions		1,892		1,892
Treasury stock	(212)	(75)	(448)	(75)
Dividends paid to stockholders	(59)		(120)	0
Effects of stock-based incentive compensation plans	16	56	28	63
Effects related to pension and other retirement benefit obligations (net of tax benefit of $— in all periods)	0	0	1	1
Adjustments To Additional Paid In Capital Tangible Equity Units Assumed		369		369
Adjustments To Additional Paid In Capital Warrants Acquired		2		2
Net income (loss)	356	108	581	(198)
Net loss attributable to noncontrolling interest	2	3	3	3
Net income (loss)		108
Adoption of accounting standard			(2)	17
Change in unrecognized losses related to pension and OPEB plans			1	1
Investment by noncontrolling interest		7		7
Other	(1)	1	0
Ending balance	7,904	8,420	7,904	8,420	7,904
Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' Equity Attributable to Parent	5	5	5	5	5	$ 5	5	$ 4	$ 4
Stock Issued During Period, Value, Acquisitions		1		1
Other	0	0	0
Additional Paid-in Capital [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' Equity Attributable to Parent	8,909	10,015	8,909	10,015	8,909	9,105	9,329	7,772	7,765
Stock Issued During Period, Value, Acquisitions		1,891		1,891
Treasury stock	(212)	(75)	(448)	(75)
Effects of stock-based incentive compensation plans	16	56	28	63
Adjustments To Additional Paid In Capital Tangible Equity Units Assumed		369		369
Adjustments To Additional Paid In Capital Warrants Acquired		2		2
Other	0	0	0
Retained Earnings [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' Equity Attributable to Parent	(989)	(1,591)	(989)	(1,591)	(989)	(1,285)	(1,449)	(1,700)	(1,410)
Dividends paid to stockholders	59		120
Net income (loss)	356	108	581	(198)
Adoption of accounting standard			(2)	17
Other	(1)	1	1
Accumulated Other Comprehensive Income (Loss) [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' Equity Attributable to Parent	(21)	(16)	(21)	(16)	(21)	(21)	(22)	(16)	(17)
Adoption of accounting standard			0	0
Change in unrecognized losses related to pension and OPEB plans			1	1
Other	0	0	0
Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' Equity Attributable to Parent	7,904	8,413	7,904	8,413	7,904	7,804	7,863	6,060	6,342
Stock Issued During Period, Value, Acquisitions		1,892		1,892
Treasury stock	(212)	(75)	(448)	(75)
Dividends paid to stockholders	59		120
Effects of stock-based incentive compensation plans	16	56	28	63
Adjustments To Additional Paid In Capital Tangible Equity Units Assumed		369		369
Adjustments To Additional Paid In Capital Warrants Acquired		2		2
Net income (loss)	356	108	581	(198)
Adoption of accounting standard			(2)	17
Change in unrecognized losses related to pension and OPEB plans			1	1
Investment by noncontrolling interest		0		0
Other	(1)	1	1
Noncontrolling Interest [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' Equity Attributable to Noncontrolling Interest	0	7	0	7	0	$ 2	$ 4	$ 0	$ 0
Net income (loss)				0
Net loss attributable to noncontrolling interest	(2)	0	(3)
Investment by noncontrolling interest		7		$ 7
Other	0	$ 0	(1)
Share Repurchase Program Approved By Board Of Directors In November 2018 [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Treasury stock	$ (212)		$ (448)		$ (726)

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule of Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Assets:
Nuclear decommissioning trust	$ 1,342	$ 1,170
Equity Securities [Member]
Assets:
Nuclear decommissioning trust	840	727
Debt Securities [Member]
Assets:
Nuclear decommissioning trust	502	443
Fair Value, Recurring [Member]
Assets:
Sub-total	70	1
Liabilities:
Total liabilities	70	1
Fair Value, Recurring [Member] | Equity Securities [Member]
Assets:
Assets measured at net asset value	330	278
Fair Value, Recurring [Member] | Commodity contracts [Member]
Assets:
Derivative Assets	70	1
Liabilities:
Derivative Liabilities	70	1
Fair Value, Recurring [Member] | Total [Member]
Assets:
Sub-total	2,554	1,731
Total assets	2,884	2,009
Liabilities:
Total liabilities	1,918	1,646
Fair Value, Recurring [Member] | Total [Member] | Equity Securities [Member]
Assets:
Nuclear decommissioning trust	510	449
Fair Value, Recurring [Member] | Total [Member] | Debt Securities [Member]
Assets:
Nuclear decommissioning trust	502	443
Fair Value, Recurring [Member] | Total [Member] | Commodity contracts [Member]
Assets:
Derivative Assets	1,542	762
Liabilities:
Derivative Liabilities	1,762	1,612
Fair Value, Recurring [Member] | Total [Member] | Interest rate swap [Member]
Assets:
Derivative Assets		77
Liabilities:
Derivative Liabilities	156	34
Level 1 [Member] | Fair Value, Recurring [Member]
Assets:
Sub-total	1,468	905
Liabilities:
Total liabilities	1,063	557
Level 1 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member]
Assets:
Nuclear decommissioning trust	510	449
Level 1 [Member] | Fair Value, Recurring [Member] | Commodity contracts [Member]
Assets:
Derivative Assets	958	456
Liabilities:
Derivative Liabilities	1,063	557
Level 2 [Member] | Fair Value, Recurring [Member]
Assets:
Sub-total	802	672
Liabilities:
Total liabilities	575	800
Level 2 [Member] | Fair Value, Recurring [Member] | Debt Securities [Member]
Assets:
Nuclear decommissioning trust	502	443
Level 2 [Member] | Fair Value, Recurring [Member] | Commodity contracts [Member]
Assets:
Derivative Assets	300	152
Liabilities:
Derivative Liabilities	419	766
Level 2 [Member] | Fair Value, Recurring [Member] | Interest rate swap [Member]
Assets:
Derivative Assets		77
Liabilities:
Derivative Liabilities	156	34
Level 3 [Member]
Assets:
Sub-total	214	153
Liabilities:
Total liabilities	210	288
Level 3 [Member] | Fair Value, Recurring [Member]
Assets:
Sub-total	214	153
Liabilities:
Total liabilities	210	288
Level 3 [Member] | Fair Value, Recurring [Member] | Commodity contracts [Member]
Assets:
Derivative Assets	214	153
Liabilities:
Derivative Liabilities	$ 210	$ 288

Fair Value Measurements (Sche_2

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) - Level 3 [Member] - USD ($)	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	$ 214,000,000		$ 153,000,000
Liabilities	(210,000,000)		(288,000,000)
Derivative Assets (Liabilities), at Fair Value, Net	4,000,000		(135,000,000)
Electricity purchases and sales [Member] | Valuation Model [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	72,000,000		22,000,000
Liabilities	(58,000,000)		(48,000,000)
Derivative Assets (Liabilities), at Fair Value, Net	14,000,000		(26,000,000)
Electricity And Weather Options [Member] | Option Pricing Model Valuation Technique [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	10,000,000		31,000,000
Liabilities	(102,000,000)		(192,000,000)
Derivative Assets (Liabilities), at Fair Value, Net	(92,000,000)		(161,000,000)
Financial Transmission Rights [Member] | Market Approach [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	121,000,000		85,000,000
Liabilities	(16,000,000)		(20,000,000)
Derivative Assets (Liabilities), at Fair Value, Net	105,000,000		65,000,000
Other [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	11,000,000		15,000,000
Liabilities	(34,000,000)		(28,000,000)
Derivative Assets (Liabilities), at Fair Value, Net	(23,000,000)		$ (13,000,000)
Minimum | Electricity purchases and sales [Member] | Valuation Model [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Hourly price curve shape (in usd per MWh)	0	$ 0
Fair Value Inputs Illiquid Delivery Periods For ERCOT Hub Power Prices And Heat Rates	$ 20	$ 20
Minimum | Electricity And Weather Options [Member] | Option Pricing Model Valuation Technique [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Gas to power correlation	10.00%	15.00%
Fair Value Inputs, Power volatility	5.00%	5.00%
Minimum | Financial Transmission Rights [Member] | Market Approach [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Illiquid price differences between settlement points	$ (5)	$ (10)
Maximum | Electricity purchases and sales [Member] | Valuation Model [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Hourly price curve shape (in usd per MWh)	110	110
Fair Value Inputs Illiquid Delivery Periods For ERCOT Hub Power Prices And Heat Rates	$ 120	$ 120
Maximum | Electricity And Weather Options [Member] | Option Pricing Model Valuation Technique [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Gas to power correlation	100.00%	95.00%
Fair Value Inputs, Power volatility	435.00%	435.00%
Maximum | Financial Transmission Rights [Member] | Market Approach [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Illiquid price differences between settlement points	$ 50	$ 50

Fair Value Measurements (Sche_3

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] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net liability balance at beginning of period	$ (113)	$ (224)	$ (135)	$ (53)
Total unrealized valuation gains (losses)	87	(18)	125	(230)
Purchases, issuances and settlements
Purchases	61	29	79	58
Issuances	(10)	(4)	(17)	(7)
Settlements	(20)	29	(42)	45
Transfers into Level 3	3	2	5	1
Transfers out of Level 3	(4)	1	(11)	1
Net liabilities assumed in connection with the Merger	0	37	0	37
Net change	117	2	139	(169)
Net liability balance at end of period	4	(222)	4	(222)
Unrealized valuation gains (losses) relating to instruments held at end of period	$ 92	$ (17)	$ 110	$ (226)

Commodity and Other Derivativ_3

Commodity and Other Derivative Contractual Assets and Liabilities (Financial Statement Effects of Derivatives) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 1,472	$ 838
Derivative liabilities, Fair Value, Gross Liability	(1,848)	(1,645)
Derivative, Fair Value, Net	(376)	(807)
Current assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets And Liability, Fair Value, Gross Assets	1,418	730
Noncurrent assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets And Liability, Fair Value, Gross Assets	124	109
Current liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets And Liability, Fair Value, Gross Liability	(1,514)	(1,376)
Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets And Liability, Fair Value, Gross Liability	(404)	(270)
Commodity contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1,472	761
Derivative liabilities, Fair Value, Gross Liability	(1,692)	(1,611)
Derivative asset, Fair Value, Net	1,472	761
Derivative liabilities, Fair Value, Net	(1,692)	(1,611)
Commodity contracts [Member] | Current assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1,403	707
Derivative liabilities, Fair Value, Gross Asset	15	1
Commodity contracts [Member] | Noncurrent assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	114	54
Derivative liabilities, Fair Value, Gross Asset	10	0
Commodity contracts [Member] | Current liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Liability	0	0
Derivative liabilities, Fair Value, Gross Liability	(1,508)	(1,374)
Commodity contracts [Member] | Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Liability	(45)	0
Derivative liabilities, Fair Value, Gross Liability	(209)	(238)
Interest rate swap [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	77
Derivative liabilities, Fair Value, Gross Liability	(156)	(34)
Derivative asset, Fair Value, Net	0	77
Derivative liabilities, Fair Value, Net	(156)	(34)
Interest rate swap [Member] | Current assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	22
Derivative liabilities, Fair Value, Gross Asset	0	0
Interest rate swap [Member] | Noncurrent assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	55
Derivative liabilities, Fair Value, Gross Asset	0	0
Interest rate swap [Member] | Current liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Liability	0	0
Derivative liabilities, Fair Value, Gross Liability	(6)	(2)
Interest rate swap [Member] | Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Liability	0	0
Derivative liabilities, Fair Value, Gross Liability	$ (150)	$ (32)

Commodity and Other Derivativ_4

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	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss)	$ 417	$ 104	$ 596	$ (286)
Operating revenues [Member] | Commodity contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss)	549	69	776	(376)
Fuel, purchased power costs and delivery fees [Member] | Commodity contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss)	(24)	13	3	12
Interest expense [Member] | Interest rate swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss)	$ (108)	$ 22	$ (183)	$ 78

Commodity and Other Derivativ_5

Commodity and Other Derivative Contractual Assets and Liabilities (Derivative Assets and Liabilities From Balance Sheet to Net Amounts After Consideration Netting Arrangements with Counterparties and Financial Collateral) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Derivative assets: Amounts Presented in Balance Sheet	$ 1,472	$ 838
Derivative assets: Offsetting Financial Instruments	(1,199)	(619)
Derivative assets: Financial Collateral (Received) Pledged	(6)	(1)
Derivative assets: Net Amounts	267	218
Derivative liabilities: Amounts Presented in Balance Sheet	(1,848)	(1,645)
Derivative liabilities: Offsetting Financial Instruments	1,199	619
Derivative liabilities: Financial Collateral (Received) Pledged	118	109
Derivative liabilities: Net Amounts	(531)	(917)
Derivative, Fair Value, Net	(376)	(807)
Derivative (Assets) Liability, Fair Value of Collateral, Net	112	108
Derivative Assets (Liability), Fair Value, Amount Offset Against Collateral	(264)	(699)
Commodity contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative assets: Amounts Presented in Balance Sheet	1,472	761
Derivative assets: Offsetting Financial Instruments	(1,199)	(593)
Derivative assets: Financial Collateral (Received) Pledged	(6)	(1)
Derivative assets: Net Amounts	267	167
Derivative liabilities: Amounts Presented in Balance Sheet	(1,692)	(1,611)
Derivative liabilities: Offsetting Financial Instruments	1,199	593
Derivative liabilities: Financial Collateral (Received) Pledged	118	109
Derivative liabilities: Net Amounts	(375)	(909)
Interest rate swap [Member]
Derivatives, Fair Value [Line Items]
Derivative assets: Amounts Presented in Balance Sheet	0	77
Derivative assets: Offsetting Financial Instruments	0	(26)
Derivative assets: Financial Collateral (Received) Pledged	0	0
Derivative assets: Net Amounts	0	51
Derivative liabilities: Amounts Presented in Balance Sheet	(156)	(34)
Derivative liabilities: Offsetting Financial Instruments	0	26
Derivative liabilities: Financial Collateral (Received) Pledged	0	0
Derivative liabilities: Net Amounts	$ (156)	$ (8)

Commodity and Other Derivativ_6

Commodity and Other Derivative Contractual Assets and Liabilities (Derivative Volumes) (Details) lb in Thousands, gal in Millions, T in Millions, MMBTU in Millions, $ in Millions	Jun. 30, 2019USD ($)TgallbMMBTUGWh	Dec. 31, 2018USD ($)TgallbMMBTUGWh
Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | MMBTU	6,867	7,011
Electricity (in GWh) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | GWh	394,990	317,572
Financial Transmission Rights [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | GWh	234,664	172,611
Coal (in tons) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | T	35	45
Fuel oil (in gallons) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | gal	73	60
Uranium (in pounds) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | lb	125	50
Emissions [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | T	16	10
Interest rate swaps - Floating/fixed [Member]
Derivatives, Fair Value [Line Items]
Derivative, notional amount | $	$ 6,720	$ 7,717

Commodity and Other Derivativ_7

Commodity and Other Derivative Contractual Assets and Liabilities (Credit Risk-Related Contingent Features of Derivatives) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Credit Derivatives [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ (631)	$ (856)
Credit risk derivative with contingent feature [Member]
Credit Derivatives [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	223	218
Collateral Already Posted, Aggregate Fair Value	79	190
Cross-default credit derivative [Member]
Credit Derivatives [Line Items]
Assets Needed for Immediate Settlement, Aggregate Fair Value	$ (329)	$ (448)

Commodity and Other Derivativ_8

Commodity and Other Derivative Contractual Assets and Liabilities (Concentrations of Credit Risk Related to Derivatives) (Details) - Credit Risk Contract [Member] $ in Millions	6 Months Ended
	Jun. 30, 2019USD ($)
Derivative [Line Items]
Total credit risk exposure to all counterparties related to derivative contracts	$ 1,675
Net exposure to those counterparties after taking into effect master netting arrangements, setoff provisions and collateral	398
Largest net exposure to single counterparty	$ 119
Credit risk exposure to Banking and financial sector percentage	71.00%
Net exposure to banking and financial sector percentage	23.00%

Related Party Transactions (Nar

Related Party Transactions (Narrrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Maximum
Related Party Transaction [Line Items]
Registration Rights Agreement, Demand Registration, Number Of Days To File S-1 Registration Statement			45 days
Registration Rights Agreement, Demand Registration, Number Of Days To File S-3 Registration Statement			30 days
Registration Rights Agreement, Demand Registration, Number Of Days Between Initial Registration And Effective Date			120 days
Legal Expenses Paid On Behalf of Selling Stockholders [Member]
Related Party Transaction [Line Items]
Legal fees	$ 0	$ 0	$ 0	$ 0

Segment Information (Segment In

Segment Information (Segment Information) (Details) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2019USD ($)Reportable_segment	Jun. 30, 2018USD ($)	Dec. 31, 2018USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments (in reportable segments) | Reportable_segment			6
Operating revenues	$ 2,832	$ 2,574	$ 5,755	$ 3,338
Depreciation and amortization	(384)	(389)	(790)	(542)
Operating income (loss)	729	231	1,218	(164)
Unrealized mark-to-market net gains (losses) on Commodity Positions	(119)	25	(199)	86
Net income (loss)	354	105	578	(201)
Total assets	26,520		26,520		$ 26,024
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	47	31	164	31
Depreciation and amortization	(21)	(23)	(37)	(35)
Operating income (loss)	(19)	(196)	(12)	(237)
Unrealized mark-to-market net gains (losses) on Commodity Positions	3	1	19	1
Net income (loss)	(399)	(337)	(670)	(306)
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Operating revenues	(1,446)	(1,157)	(2,166)	(860)
Depreciation and amortization	0	(1)	0	0
Operating income (loss)	0	1	0	1
Total assets	(1,278)		(1,278)		(2,022)
Retail Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,421	1,454	2,806	2,426
Depreciation and amortization	(59)	(80)	(118)	(157)
Operating income (loss)	(581)	(303)	(563)	455
Net income (loss)	(585)	(288)	(571)	483
Total assets	8,249		8,249		7,699
ERCOT Segment
Segment Reporting Information [Line Items]
Operating revenues	1,671	1,327	2,625	794
Depreciation and amortization	(128)	(108)	(259)	(173)
Operating income (loss)	1,047	680	1,335	(409)
Net income (loss)	1,056	679	1,356	(407)
Total assets	10,252		10,252		9,347
PJM Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	686	485	1,391	485
Depreciation and amortization	(134)	(125)	(265)	(125)
Operating income (loss)	185	24	348	24
Net income (loss)	183	23	346	23
Total assets	5,778		5,778		7,188
NY/NE Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	254	187	599	187
Depreciation and amortization	(39)	(49)	(104)	(49)
Operating income (loss)	78	(7)	94	(7)
Net income (loss)	79	(5)	100	(5)
Total assets	2,798		2,798		2,722
MISO Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	246	257	500	257
Depreciation and amortization	(3)	(3)	(7)	(3)
Operating income (loss)	35	31	46	31
Net income (loss)	35	31	46	31
Total assets	468		468		836
Asset Closure Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	21	0	49
Depreciation and amortization	0	0	0	0
Operating income (loss)	(16)	1	(30)	(22)
Net income (loss)	(15)	2	(29)	(20)
Total assets	253		253		$ 254
Operating revenues [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on Commodity Positions	538	203	697	(208)
Operating revenues [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on Commodity Positions	(803)	(463)	(968)	180
Operating revenues [Member] | Retail Segment [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on Commodity Positions	6	1	5	13
Operating revenues [Member] | ERCOT Segment
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on Commodity Positions	1,050	668	1,287	(398)
Operating revenues [Member] | PJM Segment [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on Commodity Positions	184	(10)	276	(10)
Operating revenues [Member] | NY/NE Segment [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on Commodity Positions	31	(24)	32	(24)
Operating revenues [Member] | MISO Segment [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on Commodity Positions	67	30	46	30
Affiliate Sales [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Affiliate Sales [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Operating revenues	(1,493)	(1,188)	(2,330)	(891)
Affiliate Sales [Member] | Retail Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	0	0	0
Affiliate Sales [Member] | ERCOT Segment
Segment Reporting Information [Line Items]
Operating revenues	1,027	840	1,531	543
Affiliate Sales [Member] | PJM Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	335	152	590	152
Affiliate Sales [Member] | NY/NE Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	35	12	49	12
Affiliate Sales [Member] | MISO Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	$ 96	163	$ 160	163
Affiliate Sales [Member] | Asset Closure Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues		$ 21		$ 21

Supplementary Financial Infor_3

Supplementary Financial Information (Components of Net Benefit Cost) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 2	$ 4	$ 4	$ 5
Other costs	0	0	0	0
Net periodic benefit cost	2	4	4	5
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	0	1	0	1
Other costs	2	1	4	2
Net periodic benefit cost	$ 2	$ 2	$ 4	$ 3

Supplementary Financial Infor_4

Supplementary Financial Information (Interest Expense and Related Charges) (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Interest Expense and Related Charges [Line Items]
Interest paid/accrued		$ 154	$ 166	$ 305	$ 216
Unrealized mark-to-market net (gains) losses on interest rate swaps		119	(25)	199	(86)
Amortization of debt issuance costs, discounts and premiums		0	3	(2)	4
Debt extinguishment gain		(3)	0	(10)	0
Capitalized interest		(3)	(4)	(7)	(7)
Other		7	6	10	10
Total interest expense and related charges		$ 274	$ 146	$ 495	$ 137
Vistra Operations Company LLC | Line of Credit
Interest Expense and Related Charges [Line Items]
Debt extinguishment gain	$ 4
Debt Instrument, Interest Rate During Period				4.03%

Supplementary Financial Infor_5

Supplementary Financial Information (Other Income and Deductions) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Other income:
Insurance settlement	$ 8	$ 0	$ 19	$ 0
Funds Released from Escrow to Settle Pre-petition Claims of Our Predecessor	0	0	9	0
Interest income	3	4	7	10
All other	2	1	4	3
Total other income	13	7	39	18
Other deductions:
All other	2	1	5	3
Total other deductions	2	1	5	3
Corporate and Other Nonsegment
Other income:
Office space sublease rental income	0	2	0	4
ERCOT Segment
Other income:
Sale of land	$ 0	$ 0	$ 0	$ 1

Supplementary Financial Infor_6

Supplementary Financial Information (Restricted Cash) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Restricted cash included in current assets	$ 42	$ 57
Amounts related to restructuring escrow accounts [Member]
Restricted cash included in current assets	$ 42	$ 57

Supplementary Financial Infor_7

Supplementary Financial Information (Trade Accounts Receivable and Allowance for Doubtful Accounts) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Dec. 31, 2018
Supplementary Financial Information [Abstract]
Wholesale and retail trade accounts receivable			$ 1,118	$ 1,106
Allowance for uncollectible accounts	$ (19)	$ (14)	(17)	(19)
Trade accounts receivable — net			1,101	1,087
Unbilled Receivables, Current			$ 375	$ 350
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowance for uncollectible accounts receivable at beginning of period	19	14
Increase for bad debt expense	29	22
Decrease for account write-offs	(31)	(22)
Allowance for uncollectible accounts receivable at end of period	$ 17	$ 14

Supplementary Financial Infor_8

Supplementary Financial Information (Inventories by Major Category and Other Investments) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Inventories by Major Category
Materials and supplies	$ 290	$ 286
Fuel stock	172	115
Natural gas in storage	14	11
Total inventories	476	412
Investments
Nuclear plant decommissioning trust	1,342	1,170
Assets related to employee benefit plans	31	31
Land	49	49
Total investments	$ 1,422	$ 1,250

Supplementary Financial Infor_9

Supplementary Financial Information (Investments) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Investment in unconsolidated subsidiary	$ 127		$ 127		$ 131
Equity in earnings of unconsolidated subsidiary	3	$ 4	9	$ 4
Proceeds from Equity Method Investment, Distribution, Return of Capital	9	$ 6	14	$ 6
Northeast Energy, LP [Member]
Investment in unconsolidated subsidiary	$ 125		$ 125

Supplementary Financial Info_10

Supplementary Financial Information (Nuclear Decommissioning Trust) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018
Schedule of Schedule of Decommissioning Fund Investments [Line Items]
Cost	$ 753		$ 753		$ 724
Unrealized gain	589		589		455
Unrealized loss	0		0		(9)
Fair market value	1,342		1,342		1,170
Realized gains	7	$ 1	10	$ 1
Realized losses	(2)	(1)	(3)	(3)
Proceeds from sales of securities	214	47	292	93
Investments in securities	(219)	$ (52)	(302)	$ (103)
Debt Securities [Member]
Schedule of Schedule of Decommissioning Fund Investments [Line Items]
Cost	481		481		444
Unrealized gain	21		21		7
Unrealized loss	0		0		(8)
Fair market value	$ 502		$ 502		$ 443
Debt, Weighted Average Interest Rate	3.44%		3.44%		3.69%
Decommissioning Fund Investments Debt Securities Average Maturities			9 years		8 years
Decommissioning Fund Investments, debt maturities, one through five years, fair value	$ 186		$ 186
Decommissioning Fund Investments, debt maturities, five through ten years, fair value	134		134
Decommissioning Fund Investments, debt maturities, after ten years, fair value	182		182
Equity Securities [Member]
Schedule of Schedule of Decommissioning Fund Investments [Line Items]
Cost	272		272		$ 280
Unrealized gain	568		568		448
Unrealized loss	0		0		(1)
Fair market value	$ 840		$ 840		$ 727

Supplementary Financial Info_11

Supplementary Financial Information (Property, Plant and Equipment) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Jan. 01, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 15,869		$ 15,869			$ 15,428
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	1,923		1,923			1,284
Property, Plant And Equipment Net Of Accumulated Depreciation, Excluding Construction Work In Progress	13,946		13,946			14,144
Nuclear Fuel, Net of Amortization	179		179			191
Construction in Progress, Gross	135		135			277
Property, plant and equipment — net	14,260		14,260		$ 14,627	14,612
Depreciation	312	$ 292	647	$ 360
Electric Generation Equipment
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	15,066		15,066			14,604
Land
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	640		640			642
Office Equipment
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 163		$ 163			$ 182

Supplementary Financial Info_12

Supplementary Financial Information (Asset Retirement and Mining Reclamation Obligations) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance, Liability	$ 2,373	$ 1,936
Additions:
Accretion	49	44
Adjustment for change in estimate	(6)	(36)
Obligations assumed in the Merger	(3)	419
Reductions:
Payments	(48)	(41)
Ending balance, Liability	2,373	1,936	$ 2,365	$ 2,373	$ 2,322
Less amounts due currently			(232)	(156)
Noncurrent liability at end of period	2,133
Nuclear Plant Decommissioning [Member]
Asset Retirement Obligations [Line Items]
Regulatory Liabilities			(44)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance, Liability	1,276	1,233
Additions:
Accretion	22	21
Adjustment for change in estimate	0	0
Obligations assumed in the Merger	0	0
Reductions:
Payments	0	0
Ending balance, Liability	1,276	1,233	1,298	1,276	1,254
Less amounts due currently			0
Noncurrent liability at end of period	1,298
Mining Land Reclamation [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance, Liability	442	438
Additions:
Accretion	11	11
Adjustment for change in estimate	(3)	7
Obligations assumed in the Merger	0	2
Reductions:
Payments	(32)	(35)
Ending balance, Liability	442	438	418	442	423
Less amounts due currently			(132)
Noncurrent liability at end of period	286
Other Asset Retirement Obligations [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance, Liability	655	265
Additions:
Accretion	16	12
Adjustment for change in estimate	(3)	(43)
Obligations assumed in the Merger	(3)	417
Reductions:
Payments	(16)	(6)
Ending balance, Liability	655	$ 265	649	$ 655	$ 645
Less amounts due currently			$ (100)
Noncurrent liability at end of period	$ 549

Supplementary Financial Info_13

Supplementary Financial Information (Other Noncurrent Liabilities and Deferred Credits) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Supplementary Financial Information [Abstract]
Retirement and other employee benefits	$ 273	$ 270
Finance lease liabilities	74	0
Uncertain tax positions, including accrued interest	6	4
Other	111	66
Total other noncurrent liabilities and deferred credits	$ 464	$ 340

Supplementary Financial Info_14

Supplementary Financial Information (Fair Value of Debt) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Vistra Operations Credit Facility [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	$ 3,808	$ 5,820
Vistra Operations Senior Unsecured Notes [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	5,535	987
Vistra Energy Senior Unsecured Notes [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	1,603	3,819
Amortizing Notes Due 2019 (Tangible Equity Units) [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	8	23
Secured Debt [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	212	221
Unsecured Debt [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	98	102
Mandatorily Redeemable Preferred Stock [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	70	70
Construction Loans [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	20	23
Fair Value, Inputs, Level 2 [Member] | Vistra Operations Credit Facility [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	3,796	5,599
Fair Value, Inputs, Level 2 [Member] | Vistra Operations Senior Unsecured Notes [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	5,787	963
Fair Value, Inputs, Level 2 [Member] | Vistra Energy Senior Unsecured Notes [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	1,592	3,765
Fair Value, Inputs, Level 2 [Member] | Amortizing Notes Due 2019 (Tangible Equity Units) [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	8	24
Fair Value, Inputs, Level 2 [Member] | Mandatorily Redeemable Preferred Stock [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	70	70
Fair Value, Inputs, Level 2 [Member] | Construction Loans [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	19	21
Level 3 [Member] | Secured Debt [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	212	221
Level 3 [Member] | Unsecured Debt [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	$ 98	$ 102

Supplementary Financial Info_15

Supplementary Financial Information (Supplemental Cash Flow Information) (Details) - USD ($) shares in Millions, $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018	Dec. 31, 2017
Supplementary Financial Information [Abstract]
Cash and cash equivalents	$ 964		$ 636
Restricted cash included in current assets	42		57
Total cash, cash equivalents and restricted cash	1,006	$ 816	$ 693	$ 2,046
Cash payments related to:
Interest paid	307	344
Capitalized interest	(7)	(7)
Interest paid (net of capitalized interest)	300	337
Income taxes	9	58
Noncash investing and financing activities:
Construction expenditures	$ 41	$ 13
Vistra Energy common stock issued in the Merger	0	2,245

Supplemental Condensed Consol_3

Supplemental Condensed Consolidating Financial Information (Condensed Consolidating Statements of Income (Loss)) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Condensed Financial Statements, Captions [Line Items]
Operating revenues	$ 2,832	$ 2,574	$ 5,755	$ 3,338
Fuel, purchased power costs and delivery fees	(1,139)	(1,216)	(2,600)	(1,866)
Operating costs	(370)	(386)	(755)	(580)
Depreciation and amortization	(384)	(389)	(790)	(542)
Selling, general and administrative expenses	(210)	(352)	(392)	(514)
Operating income (loss)	729	231	1,218	(164)
Other income	13	7	39	18
Other deductions	(2)	(1)	(5)	(3)
Interest expense and related charges	(274)	(146)	(495)	(137)
Impacts of Tax Receivable Agreement	33	(64)	36	(82)
Equity in earnings of unconsolidated investments	3	4	10	4
Income (loss) before income taxes	502	31	803	(364)
Income tax (expense) benefit	(148)	74	(225)	163
Equity in earnings (loss) of subsidiaries, net of tax	0	0	0	0
Net income (loss)	354	105	578	(201)
Net (income) loss attributable to noncontrolling interest	2	3	3	3
Net income (loss) attributable to Vistra Energy	356	108	581	(198)
Reportable Legal Entities [Member] | Parent Company [Member]
Condensed Financial Statements, Captions [Line Items]
Operating revenues	0	0	0	0
Fuel, purchased power costs and delivery fees	0	0	0	0
Operating costs	0	0	0	0
Depreciation and amortization	(1)	0	(2)	0
Selling, general and administrative expenses	(13)	(192)	(31)	(226)
Operating income (loss)	(14)	(192)	(33)	(226)
Other income	1	3	15	6
Other deductions	0	0	0	0
Interest expense and related charges	(29)	(87)	(72)	(87)
Impacts of Tax Receivable Agreement	33	(64)	36	(82)
Equity in earnings of unconsolidated investments	0	0	0	0
Income (loss) before income taxes	(9)	(340)	(54)	(389)
Income tax (expense) benefit	4	102	17	117
Equity in earnings (loss) of subsidiaries, net of tax	361	343	618	71
Net income (loss)	356	105	581	(201)
Net (income) loss attributable to noncontrolling interest	0	0	0	0
Net income (loss) attributable to Vistra Energy	356	105	581	(201)
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Operating revenues	2,835	2,508	5,761	3,272
Fuel, purchased power costs and delivery fees	(1,144)	(1,166)	(2,612)	(1,816)
Operating costs	(355)	(370)	(726)	(564)
Depreciation and amortization	(364)	(371)	(746)	(524)
Selling, general and administrative expenses	(216)	(160)	(395)	(288)
Operating income (loss)	756	441	1,282	80
Other income	14	5	31	12
Other deductions	(2)	(1)	(5)	(3)
Interest expense and related charges	(241)	(58)	(419)	(49)
Impacts of Tax Receivable Agreement	0	0	0	0
Equity in earnings of unconsolidated investments	3	4	10	4
Income (loss) before income taxes	530	391	899	44
Income tax (expense) benefit	(160)	(34)	(249)	41
Equity in earnings (loss) of subsidiaries, net of tax	(9)	(14)	(32)	(14)
Net income (loss)	361	343	618	71
Net (income) loss attributable to noncontrolling interest	0	0	0	0
Net income (loss) attributable to Vistra Energy	361	343	618	71
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Operating revenues	53	68	110	68
Fuel, purchased power costs and delivery fees	(19)	(51)	(48)	(51)
Operating costs	(15)	(16)	(29)	(16)
Depreciation and amortization	(19)	(18)	(42)	(18)
Selling, general and administrative expenses	(19)	(2)	(38)	(2)
Operating income (loss)	(19)	(19)	(47)	(19)
Other income	0	0	1	1
Other deductions	0	0	0	0
Interest expense and related charges	(6)	(1)	(12)	(1)
Impacts of Tax Receivable Agreement	0	0	0	0
Equity in earnings of unconsolidated investments	0	0	0	0
Income (loss) before income taxes	(25)	(20)	(58)	(19)
Income tax (expense) benefit	14	6	23	5
Equity in earnings (loss) of subsidiaries, net of tax	0	0	0	0
Net income (loss)	(11)	(14)	(35)	(14)
Net (income) loss attributable to noncontrolling interest	2	3	3	3
Net income (loss) attributable to Vistra Energy	(9)	(11)	(32)	(11)
Consolidation, Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Operating revenues	(56)	(2)	(116)	(2)
Fuel, purchased power costs and delivery fees	24	1	60	1
Operating costs	0	0	0	0
Depreciation and amortization	0	0	0	0
Selling, general and administrative expenses	38	2	72	2
Operating income (loss)	6	1	16	1
Other income	(2)	(1)	(8)	(1)
Other deductions	0	0	0	0
Interest expense and related charges	2	0	8	0
Impacts of Tax Receivable Agreement	0	0	0	0
Equity in earnings of unconsolidated investments	0	0	0	0
Income (loss) before income taxes	6	0	16	0
Income tax (expense) benefit	(6)	0	(16)	0
Equity in earnings (loss) of subsidiaries, net of tax	(352)	(329)	(586)	(57)
Net income (loss)	(352)	(329)	(586)	(57)
Net (income) loss attributable to noncontrolling interest	0	0	0	0
Net income (loss) attributable to Vistra Energy	$ (352)	$ (329)	$ (586)	$ (57)

Supplemental Condensed Consol_4

Supplemental Condensed Consolidating Financial Information (Condensed Statements of Consolidating Comprehensive Income (Loss)) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	$ 354	$ 105	$ 578	$ (201)
Effects related to pension and other retirement benefit obligations (net of tax benefit of $— in all periods)	0	0	1	1
Total other comprehensive income	0	0	1	1
Comprehensive income (loss)	354	105	579	(200)
Comprehensive (income) loss attributable to noncontrolling interest	2	3	3	3
Comprehensive income (loss) attributable to Vistra Energy	356	108	582	(197)
Reportable Legal Entities [Member] | Parent Company [Member]
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	356	105	581	(201)
Effects related to pension and other retirement benefit obligations (net of tax benefit of $— in all periods)	0	0	1	1
Total other comprehensive income	0	0	1	1
Comprehensive income (loss)	356	105	582	(200)
Comprehensive (income) loss attributable to noncontrolling interest	0	0	0	0
Comprehensive income (loss) attributable to Vistra Energy	356	105	582	(200)
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	361	343	618	71
Effects related to pension and other retirement benefit obligations (net of tax benefit of $— in all periods)	0	0	0	0
Total other comprehensive income	0	0	0	0
Comprehensive income (loss)	361	343	618	71
Comprehensive (income) loss attributable to noncontrolling interest	0	0	0	0
Comprehensive income (loss) attributable to Vistra Energy	361	343	618	71
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	(11)	(14)	(35)	(14)
Effects related to pension and other retirement benefit obligations (net of tax benefit of $— in all periods)	0	0	0	0
Total other comprehensive income	0	0	0	0
Comprehensive income (loss)	(11)	(14)	(35)	(14)
Comprehensive (income) loss attributable to noncontrolling interest	2	3	3	3
Comprehensive income (loss) attributable to Vistra Energy	(9)	(11)	(32)	(11)
Consolidation, Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	(352)	(329)	(586)	(57)
Effects related to pension and other retirement benefit obligations (net of tax benefit of $— in all periods)	0	0	0	0
Total other comprehensive income	0	0	0	0
Comprehensive income (loss)	(352)	(329)	(586)	(57)
Comprehensive (income) loss attributable to noncontrolling interest	0	0	0	0
Comprehensive income (loss) attributable to Vistra Energy	$ (352)	$ (329)	$ (586)	$ (57)

Supplemental Condensed Consol_5

Supplemental Condensed Consolidating Financial Information (Condensed Statements of Consolidating Cash Flows) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended	18 Months Ended	20 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2018	Jun. 30, 2019	Dec. 31, 2018
Condensed Financial Statements, Captions [Line Items]
Net Cash Provided by (Used in) Operating Activities			$ 882	$ (29)
Cash flows — financing activities:
Issuances of long-term debt			4,600	0
Repayments/repurchases of debt			(4,137)	(1,338)
Net borrowings under accounts receivable securitization program			91	0
Dividends paid			(120)
Payments for Repurchase of Common Stock			(457)	(63)
Debt tender offer and other financing fees			(146)	(46)
Other, net			(1)	4
Cash used in financing activities			(170)	(1,443)
Cash flows — investing activities:
Capital expenditures, including LTSA prepayments			(247)	(153)
Nuclear fuel purchases			(20)	(28)
Development and growth expenditures			(36)	(21)			$ (231)
Cash acquired in the Merger			0	445
Proceeds from sales of nuclear decommissioning trust fund securities	$ 214	$ 47	292	93
Investments in nuclear decommissioning trust fund securities	(219)	(52)	(302)	(103)
Proceeds from sale of environmental allowances			31	0
Purchases of environmental allowances			(138)	(1)
Proceeds from Dividends Received			0
Other, net			21	10
Cash (used in) provided by investing activities			(399)	242
Net change in cash, cash equivalents and restricted cash			313	(1,230)
Cash, cash equivalents and restricted cash — beginning balance			693	2,046	$ 2,046	$ 2,046
Cash, cash equivalents and restricted cash — ending balance	1,006	816	1,006	816	693	1,006	693
Reportable Legal Entities [Member] | Parent Company [Member]
Condensed Financial Statements, Captions [Line Items]
Net Cash Provided by (Used in) Operating Activities			(127)	(280)
Cash flows — financing activities:
Issuances of long-term debt			0
Repayments/repurchases of debt			(2,114)	(840)
Net borrowings under accounts receivable securitization program			0
Dividends paid			(120)
Payments for Repurchase of Common Stock			(457)	(63)
Debt tender offer and other financing fees			(92)	(29)
Other, net			(1)	0
Cash used in financing activities			(2,784)	(932)
Cash flows — investing activities:
Capital expenditures, including LTSA prepayments			(1)	(4)
Nuclear fuel purchases			0	0
Development and growth expenditures			0	0
Cash acquired in the Merger				418
Proceeds from sales of nuclear decommissioning trust fund securities			0	0
Investments in nuclear decommissioning trust fund securities			0	0
Proceeds from sale of environmental allowances			0	0
Purchases of environmental allowances			0	0
Proceeds from Dividends Received			3,195
Other, net			0	(4)
Cash (used in) provided by investing activities			3,194	410
Net change in cash, cash equivalents and restricted cash			283	(802)
Cash, cash equivalents and restricted cash — beginning balance			228	1,183	1,183	1,183
Cash, cash equivalents and restricted cash — ending balance	511	381	511	381	228	511	228
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net Cash Provided by (Used in) Operating Activities			1,111	(109)
Cash flows — financing activities:
Issuances of long-term debt			4,600
Repayments/repurchases of debt			(2,023)	(498)
Net borrowings under accounts receivable securitization program			0
Dividends paid			(3,195)
Payments for Repurchase of Common Stock			0	0
Debt tender offer and other financing fees			(54)	(17)
Other, net			0	4
Cash used in financing activities			(672)	(511)
Cash flows — investing activities:
Capital expenditures, including LTSA prepayments			(246)	(147)
Nuclear fuel purchases			(20)	(28)
Development and growth expenditures			(36)	(21)
Cash acquired in the Merger				27
Proceeds from sales of nuclear decommissioning trust fund securities			292	93
Investments in nuclear decommissioning trust fund securities			(302)	(103)
Proceeds from sale of environmental allowances			31	0
Purchases of environmental allowances			(138)	(1)
Proceeds from Dividends Received			0
Other, net			21	359
Cash (used in) provided by investing activities			(398)	179
Net change in cash, cash equivalents and restricted cash			41	(441)
Cash, cash equivalents and restricted cash — beginning balance			453	863	863	863
Cash, cash equivalents and restricted cash — ending balance	494	422	494	422	453	494	453
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net Cash Provided by (Used in) Operating Activities			(102)	360
Cash flows — financing activities:
Issuances of long-term debt			0
Repayments/repurchases of debt			0	0
Net borrowings under accounts receivable securitization program			91
Dividends paid			0
Payments for Repurchase of Common Stock			0	0
Debt tender offer and other financing fees			0	0
Other, net			0	0
Cash used in financing activities			91	0
Cash flows — investing activities:
Capital expenditures, including LTSA prepayments			0	(2)
Nuclear fuel purchases			0	0
Development and growth expenditures			0	0
Cash acquired in the Merger				0
Proceeds from sales of nuclear decommissioning trust fund securities			0	0
Investments in nuclear decommissioning trust fund securities			0	0
Proceeds from sale of environmental allowances			0	0
Purchases of environmental allowances			0	0
Proceeds from Dividends Received
Other, net			0	(345)
Cash (used in) provided by investing activities			0	(347)
Net change in cash, cash equivalents and restricted cash			(11)	13
Cash, cash equivalents and restricted cash — beginning balance			12	0	0	0
Cash, cash equivalents and restricted cash — ending balance	1	13	1	13	12	1	12
Consolidation, Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Net Cash Provided by (Used in) Operating Activities			0	0
Cash flows — financing activities:
Issuances of long-term debt			0
Repayments/repurchases of debt			0	0
Net borrowings under accounts receivable securitization program
Dividends paid			3,195
Payments for Repurchase of Common Stock			0	0
Debt tender offer and other financing fees			0	0
Other, net			0	0
Cash used in financing activities			3,195	0
Cash flows — investing activities:
Capital expenditures, including LTSA prepayments			0	0
Nuclear fuel purchases			0	0
Development and growth expenditures			0	0
Cash acquired in the Merger				0
Proceeds from sales of nuclear decommissioning trust fund securities			0	0
Investments in nuclear decommissioning trust fund securities			0	0
Proceeds from sale of environmental allowances			0	0
Purchases of environmental allowances			0	0
Proceeds from Dividends Received			(3,195)
Other, net			0	0
Cash (used in) provided by investing activities			(3,195)	0
Net change in cash, cash equivalents and restricted cash			0	0
Cash, cash equivalents and restricted cash — beginning balance			0	0	0	0
Cash, cash equivalents and restricted cash — ending balance	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0

Supplemental Condensed Consol_6

Supplemental Condensed Consolidating Financial Information (Condensed Consolidating Balance Sheets) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Jan. 01, 2019	Dec. 31, 2018	Jun. 30, 2018	Apr. 09, 2018
Current assets:
Cash and cash equivalents	$ 964		$ 636
Restricted cash	42		57
Advances to affiliates	0		0
Trade accounts receivable — net	1,101		1,087
Accounts receivable — affiliates	0		0
Notes due from affiliates	0		0
Income taxes receivable	0		0
Inventories	476		412
Commodity and other derivative contractual assets	1,418		730
Margin deposits related to commodity contracts	253		361
Prepaid expense and other current assets	285	$ 150	152
Total current assets	4,539		3,435
Investments	1,422		1,250
Investment in unconsolidated subsidiary	127		131
Investment in affiliated companies	0		0
Property, plant and equipment — net	14,260	14,627	14,612
Operating lease right-of-use assets	34	70	0
Goodwill	2,082		2,068		$ 175
Identifiable intangible assets — net	2,383		2,493
Commodity and other derivative contractual assets	124		109
Accumulated deferred income taxes	1,144	1,337	1,336
Other noncurrent assets	405		590
Total assets	26,520		26,024
Current liabilities:
Accounts receivable securitization program	430		339
Advances from affiliates	0		0
Long-term debt due currently	161		191
Trade accounts payable	782		945
Accounts payable — affiliates	0		0
Notes due to affiliates	0		0
Commodity and other derivative contractual liabilities	1,514		1,376
Margin deposits related to commodity contracts	8		4
Accrued income taxes	12		10
Accrued taxes other than income	115		182
Accrued interest	82		77
Asset retirement obligations	232		156
Operating lease liabilities	13		0
Other current liabilities	308	344	345
Total current liabilities	3,657		3,625
Long-term debt, less amounts due currently	11,193		10,874
Operating lease liabilities	40		0
Commodity and other derivative contractual liabilities	404		270
Deferred Tax Liabilities, Net, Noncurrent	10		10
Tax Receivable Agreement obligation	384		420	$ 414
Asset retirement obligation	2,133		2,217
Identifiable intangible liabilities - net	331	$ 365	401
Other noncurrent liabilities and deferred credits	464		340
Total liabilities	18,616		18,157
Total stockholders' equity	7,904		7,863
Noncontrolling interest in subsidiary	0		4
Total liabilities and equity	26,520		26,024
Reportable Legal Entities [Member] | Parent Company [Member]
Current assets:
Cash and cash equivalents	469		171
Restricted cash	42		57
Advances to affiliates	0		11
Trade accounts receivable — net	11		4
Accounts receivable — affiliates	2		0
Notes due from affiliates	0		0
Income taxes receivable	0		0
Inventories	0		0
Commodity and other derivative contractual assets	0		0
Margin deposits related to commodity contracts	0		0
Prepaid expense and other current assets	130		2
Total current assets	654		245
Investments	0		0
Investment in unconsolidated subsidiary	0		0
Investment in affiliated companies	8,925		11,186
Property, plant and equipment — net	4		15
Operating lease right-of-use assets	0
Goodwill	0		0
Identifiable intangible assets — net	36		10
Commodity and other derivative contractual assets	0		0
Accumulated deferred income taxes	810		809
Other noncurrent assets	131		255
Total assets	10,560		12,520
Current liabilities:
Accounts receivable securitization program	0		0
Advances from affiliates	0		0
Long-term debt due currently	8		23
Trade accounts payable	0		2
Accounts payable — affiliates	556		236
Notes due to affiliates	0		0
Commodity and other derivative contractual liabilities	0		0
Margin deposits related to commodity contracts	0		0
Accrued income taxes	12		11
Accrued taxes other than income	0		0
Accrued interest	21		48
Asset retirement obligations	0		0
Operating lease liabilities	0
Other current liabilities	53		74
Total current liabilities	650		394
Long-term debt, less amounts due currently	1,602		3,819
Operating lease liabilities	0
Commodity and other derivative contractual liabilities	0		0
Deferred Tax Liabilities, Net, Noncurrent	0		0
Tax Receivable Agreement obligation	384		420
Asset retirement obligation	0		0
Identifiable intangible liabilities - net	0		0
Other noncurrent liabilities and deferred credits	20		20
Total liabilities	2,656		4,653
Total stockholders' equity	7,904		7,867
Noncontrolling interest in subsidiary	0		0
Total liabilities and equity	10,560		12,520
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]
Current assets:
Cash and cash equivalents	494		453
Restricted cash	0		0
Advances to affiliates	40		11
Trade accounts receivable — net	640		729
Accounts receivable — affiliates	770		245
Notes due from affiliates	102		101
Income taxes receivable	0		1
Inventories	453		391
Commodity and other derivative contractual assets	1,418		730
Margin deposits related to commodity contracts	253		361
Prepaid expense and other current assets	140		134
Total current assets	4,310		3,156
Investments	1,390		1,218
Investment in unconsolidated subsidiary	127		131
Investment in affiliated companies	123		263
Property, plant and equipment — net	13,713		14,017
Operating lease right-of-use assets	34
Goodwill	2,082		2,068
Identifiable intangible assets — net	2,344		2,480
Commodity and other derivative contractual assets	124		109
Accumulated deferred income taxes	415		599
Other noncurrent assets	267		330
Total assets	24,929		24,371
Current liabilities:
Accounts receivable securitization program	0		0
Advances from affiliates	1		0
Long-term debt due currently	148		163
Trade accounts payable	761		928
Accounts payable — affiliates	143		0
Notes due to affiliates	0		0
Commodity and other derivative contractual liabilities	1,514		1,376
Margin deposits related to commodity contracts	8		4
Accrued income taxes	0		0
Accrued taxes other than income	114		181
Accrued interest	65		29
Asset retirement obligations	232		156
Operating lease liabilities	12
Other current liabilities	253		267
Total current liabilities	3,251		3,104
Long-term debt, less amounts due currently	9,560		7,027
Operating lease liabilities	38
Commodity and other derivative contractual liabilities	404		270
Deferred Tax Liabilities, Net, Noncurrent	0		0
Tax Receivable Agreement obligation	0		0
Asset retirement obligation	2,119		2,203
Identifiable intangible liabilities - net	207		278
Other noncurrent liabilities and deferred credits	425		303
Total liabilities	16,004		13,185
Total stockholders' equity	8,925		11,186
Noncontrolling interest in subsidiary	0		0
Total liabilities and equity	24,929		24,371
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]
Current assets:
Cash and cash equivalents	1		12
Restricted cash	0		0
Advances to affiliates	1		0
Trade accounts receivable — net	650		464
Accounts receivable — affiliates	242		0
Notes due from affiliates	0		0
Income taxes receivable	0		0
Inventories	23		21
Commodity and other derivative contractual assets	0		0
Margin deposits related to commodity contracts	0		0
Prepaid expense and other current assets	15		16
Total current assets	932		513
Investments	32		32
Investment in unconsolidated subsidiary	0		0
Investment in affiliated companies	0		0
Property, plant and equipment — net	543		580
Operating lease right-of-use assets	0
Goodwill	0		0
Identifiable intangible assets — net	3		3
Commodity and other derivative contractual assets	0		0
Accumulated deferred income taxes	0		0
Other noncurrent assets	7		5
Total assets	1,517		1,133
Current liabilities:
Accounts receivable securitization program	430		339
Advances from affiliates	40		22
Long-term debt due currently	5		5
Trade accounts payable	211		121
Accounts payable — affiliates	315		9
Notes due to affiliates	101		101
Commodity and other derivative contractual liabilities	0		0
Margin deposits related to commodity contracts	0		0
Accrued income taxes	0		0
Accrued taxes other than income	1		1
Accrued interest	7		4
Asset retirement obligations	0		0
Operating lease liabilities	1
Other current liabilities	2		4
Total current liabilities	1,113		606
Long-term debt, less amounts due currently	31		28
Operating lease liabilities	2
Commodity and other derivative contractual liabilities	0		0
Deferred Tax Liabilities, Net, Noncurrent	91		82
Tax Receivable Agreement obligation	0		0
Asset retirement obligation	14		14
Identifiable intangible liabilities - net	124		123
Other noncurrent liabilities and deferred credits	19		17
Total liabilities	1,394		870
Total stockholders' equity	123		259
Noncontrolling interest in subsidiary	0		4
Total liabilities and equity	1,517		1,133
Consolidation, Eliminations [Member]
Current assets:
Cash and cash equivalents	0		0
Restricted cash	0		0
Advances to affiliates	(41)		(22)
Trade accounts receivable — net	(200)		(110)
Accounts receivable — affiliates	(1,014)		(245)
Notes due from affiliates	(102)		(101)
Income taxes receivable	0		(1)
Inventories	0		0
Commodity and other derivative contractual assets	0		0
Margin deposits related to commodity contracts	0		0
Prepaid expense and other current assets	0		0
Total current assets	(1,357)		(479)
Investments	0		0
Investment in unconsolidated subsidiary	0		0
Investment in affiliated companies	(9,048)		(11,449)
Property, plant and equipment — net	0		0
Operating lease right-of-use assets	0
Goodwill	0		0
Identifiable intangible assets — net	0		0
Commodity and other derivative contractual assets	0		0
Accumulated deferred income taxes	(81)		(72)
Other noncurrent assets	0		0
Total assets	(10,486)		(12,000)
Current liabilities:
Accounts receivable securitization program	0		0
Advances from affiliates	(41)		(22)
Long-term debt due currently	0		0
Trade accounts payable	(190)		(106)
Accounts payable — affiliates	(1,014)		(245)
Notes due to affiliates	(101)		(101)
Commodity and other derivative contractual liabilities	0		0
Margin deposits related to commodity contracts	0		0
Accrued income taxes	0		(1)
Accrued taxes other than income	0		0
Accrued interest	(11)		(4)
Asset retirement obligations	0		0
Operating lease liabilities	0
Other current liabilities	0		0
Total current liabilities	(1,357)		(479)
Long-term debt, less amounts due currently	0		0
Operating lease liabilities	0
Commodity and other derivative contractual liabilities	0		0
Deferred Tax Liabilities, Net, Noncurrent	(81)		(72)
Tax Receivable Agreement obligation	0		0
Asset retirement obligation	0		0
Identifiable intangible liabilities - net	0		0
Other noncurrent liabilities and deferred credits	0		0
Total liabilities	(1,438)		(551)
Total stockholders' equity	(9,048)		(11,449)
Noncontrolling interest in subsidiary	0		0
Total liabilities and equity	$ (10,486)		$ (12,000)