Vistra (VST) 10-Q 5 Aug 20 2020 Q2 Quarterly report Financial data

Cover Page

Cover Page - shares	6 Months Ended
	Jun. 30, 2020	Jul. 31, 2020
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2020
Document Transition Report	false
Entity File Number	001-38086
Entity Registrant Name	Vistra 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		488,780,072
Entity Central Index Key	0001692819
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
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 Consolidated Statemen

Condensed Consolidated Statements of Income (Loss) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Income Statement [Abstract]
Operating revenues	$ 2,509	$ 2,832	$ 5,367	$ 5,755
Fuel, purchased power costs and delivery fees	(1,029)	(1,139)	(2,362)	(2,600)
Operating costs	(412)	(370)	(792)	(755)
Depreciation and amortization	(455)	(384)	(875)	(790)
Selling, general and administrative expenses	(236)	(210)	(488)	(392)
Impairment of long-lived assets	0	0	(84)	0
Operating income	377	729	766	1,218
Other income	5	13	12	39
Other deductions	(4)	(2)	(35)	(5)
Interest expense and related charges	(141)	(274)	(440)	(495)
Impacts of Tax Receivable Agreement	(6)	33	(14)	36
Equity in earnings of unconsolidated investments	1	3	4	10
Income before income taxes	232	502	293	803
Income tax expense	(68)	(148)	(84)	(225)
Net income	164	354	209	578
Net loss attributable to noncontrolling interest	2	2	13	3
Net income attributable to Vistra	$ 166	$ 356	$ 222	$ 581
Weighted average shares of common stock outstanding:
Weighted average shares of common stock outstanding - basic	488,680,442	499,778,235	488,312,503	499,213,522
Weighted average shares of common stock outstanding - diluted	490,468,735	507,500,383	490,709,932	507,248,920
Net income per weighted average share of common stock outstanding:
Net income per weighted average share of common stock outstanding - basic	$ 0.34	$ 0.71	$ 0.45	$ 1.16
Net income per weighted average share of common stock outstanding - diluted	$ 0.34	$ 0.70	$ 0.45	$ 1.15

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Comprehensive Income (Loss) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Statement of Comprehensive Income [Abstract]
Net income	$ 164	$ 354	$ 209	$ 578
Other comprehensive income, net of tax effects:
Effects related to pension and other retirement benefit obligations (net of tax benefit of $—, $—, $7 and $—)	1	0	(22)	1
Total other comprehensive income (loss)	1	0	(22)	1
Comprehensive income	165	354	187	579
Comprehensive loss attributable to noncontrolling interest	2	2	13	3
Comprehensive income attributable to Vistra	$ 167	$ 356	$ 200	$ 582

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Comprehensive Income (Loss) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Statement of Comprehensive Income [Abstract]
Effect related to pension and other retirement benefit obligations (tax)	$ 0	$ 0	$ 7	$ 0

Condensed Consolidated Statem_4

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Cash flows — operating activities:
Net income	$ 209	$ 578
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	1,022	886
Deferred income tax expense, net	73	217
Impairment of long-lived assets	84	0
Loss on disposal of investment in NELP	29	0
Unrealized net gain from mark-to-market valuations of commodities	(123)	(703)
Unrealized net loss from mark-to-market valuations of interest rate swaps	192	199
Asset retirement obligation accretion expense	23	27
Impacts of Tax Receivable Agreement	14	(36)
Stock-based compensation	30	24
Other, net	55	73
Changes in operating assets and liabilities:
Margin deposits, net	58	112
Accrued interest	(6)	6
Accrued taxes	(59)	(67)
Accrued employee incentive	(70)	(72)
Other operating assets and liabilities	(222)	(362)
Cash provided by operating activities	1,309	882
Cash flows — investing activities:
Capital expenditures, including nuclear fuel purchases and LTSA prepayments	(588)	(303)
Proceeds from sales of nuclear decommissioning trust fund securities	224	292
Investments in nuclear decommissioning trust fund securities	(234)	(302)
Proceeds from sales of environmental allowances	88	31
Purchases of environmental allowances	(173)	(138)
Other, net	30	21
Cash used in investing activities	(653)	(399)
Cash flows — financing activities:
Issuances of long-term debt	0	4,600
Repayments/repurchases of debt	(756)	(4,137)
Net borrowings under accounts receivable securitization program	0	91
Borrowings under Revolving Credit Facility	925	0
Repayments under Revolving Credit Facility	(725)	0
Stock repurchase	0	(457)
Dividends paid to stockholders	(132)	(120)
Debt tender offer and other financing fees	(10)	(146)
Other, net	0	(1)
Cash used in financing activities	(698)	(170)
Net change in cash, cash equivalents and restricted cash	(42)	313
Cash, cash equivalents and restricted cash — beginning balance	475	693
Cash, cash equivalents and restricted cash — ending balance	$ 433	$ 1,006

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 382	$ 300
Restricted cash	27	147
Trade accounts receivable — net	1,272	1,365
Inventories	541	469
Commodity and other derivative contractual assets	1,350	1,333
Margin deposits related to commodity contracts	161	202
Prepaid expense and other current assets	304	298
Total current assets	4,037	4,114
Restricted cash	24	28
Investments	1,552	1,537
Investment in unconsolidated subsidiary	0	124
Property, plant and equipment — net	13,881	13,914
Operating lease right-of-use assets	44	44
Goodwill	2,568	2,553
Identifiable intangible assets — net	2,532	2,748
Commodity and other derivative contractual assets	277	136
Accumulated deferred income taxes	994	1,066
Other noncurrent assets	398	352
Total assets	26,307	26,616
Current liabilities:
Short-term borrowings	550	350
Accounts receivable securitization program	450	450
Long-term debt due currently	337	277
Trade accounts payable	879	947
Commodity and other derivative contractual liabilities	1,546	1,529
Margin deposits related to commodity contracts	15	8
Accrued income taxes	10	1
Accrued taxes other than income	133	200
Accrued interest	144	151
Asset retirement obligations	138	141
Operating lease liabilities	11	14
Other current liabilities	418	506
Total current liabilities	4,631	4,574
Long-term debt, less amounts due currently	9,261	10,102
Operating lease liabilities	37	41
Commodity and other derivative contractual liabilities	599	396
Accumulated deferred income taxes	2	2
Tax Receivable Agreement obligation	468	455
Asset retirement obligation	2,314	2,097
Other noncurrent liabilities and deferred credits	951	989
Total liabilities	18,263	18,656
Commitments and Contingencies
Total equity:
Common stock (par value — $0.01; number of shares authorized — 1,800,000,000) (shares outstanding: June 30, 2020 — 488,772,572; December 31, 2019 — 487,698,111)	5	5
Treasury stock, at cost (shares: June 30, 2020 — 41,043,224; December 31, 2019 — 41,043,224)	(973)	(973)
Additional paid-in-capital	9,754	9,721
Retained deficit	(678)	(764)
Accumulated other comprehensive loss	(52)	(30)
Stockholders' equity	8,056	7,959
Noncontrolling interest in subsidiary	(12)	1
Total equity	8,044	7,960
Total liabilities and equity	$ 26,307	$ 26,616
Common stock, par or stated value per share	$ 0.01
Common stock, shares authorized	1,800,000,000
Common stock, shares, outstanding	488,772,572	487,698,111
Treasury stock, held in treasury	41,043,224	41,043,224

Business And Significant Accoun

Business And Significant Accounting Policies	6 Months Ended
	Jun. 30, 2020
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 and/or its subsidiaries, as apparent in the context. See Glossary for defined terms. Vistra is a holding company operating an integrated retail and electric power generation business primarily in markets throughout the U.S. Through our subsidiaries, we are engaged in competitive energy market activities including power generation, wholesale energy sales and purchases, commodity risk management and retail sales of electricity and natural gas to end users. Effective July 2, 2020, we changed our name from Vistra Energy Corp. to Vistra Corp. (Vistra) to distinguish from companies that are involved in exploring for, producing, refining, or transporting fossil fuels (many of which use "energy" in their names) and to better reflect our integrated business model, which combines a retail electricity and natural gas business focused on serving its customers with new and innovative products and services and an electric power generation business powering the communities we serve with safe, reliable power. Vistra 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 17 for further information concerning reportable business segments. Ambit Transaction On November 1, 2019, an indirect, wholly owned subsidiary of Vistra completed the acquisition of Ambit (Ambit Transaction). Because the Ambit Transaction closed on November 1, 2019, Vistra's condensed consolidated financial statements and the notes related thereto do not include the financial condition or the operating results of Ambit and its subsidiaries prior to November 1, 2019. See Note 2 for a summary of the Ambit Transaction. Crius Transaction On July 15, 2019, an indirect, wholly owned subsidiary of Vistra completed the acquisition of the equity interests of two wholly owned subsidiaries of Crius that indirectly owned the operating business of Crius (Crius Transaction). Because the Crius Transaction closed on July 15, 2019, Vistra's condensed consolidated financial statements and the notes related thereto do not include the financial condition or the operating results of Crius and its subsidiaries prior to July 15, 2019. See Note 2 for a summary of the Crius Transaction. COVID-19 Pandemic In March 2020, the World Health Organization categorized the novel coronavirus (COVID-19) as a pandemic, and the President of the United States (the President) declared the COVID-19 outbreak a national emergency. The U.S. government has deemed electricity generation, transmission and distribution as “critical infrastructure” providing essential services during this global emergency. As a provider of critical infrastructure, Vistra has an obligation to provide critically needed power to homes, businesses, hospitals and other customers. Vistra remains focused on protecting the health and well-being of its employees and the communities in which it operates while assuring the continuity of its business operations. The Company's condensed consolidated financial statements reflect estimates and assumptions made by management that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and reported amounts of revenue and expenses during the reporting periods presented. The Company considered the impact of COVID-19 on the assumptions and estimates used and determined that there have been no material adverse impacts on the Company's results of operations for the three or six months ended June 30, 2020. In response to the global pandemic related to COVID-19, the President signed into law the CARES Act on March 27, 2020. See Note 7 for a summary of certain anticipated tax-related impacts of the CARES Act to the Company. 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 2019 Form 10-K. The condensed consolidated financial information herein reflects all adjustments which are, in the opinion of management, necessary to fairly state the results for the interim periods presented. All such adjustments are of a normal nature. 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 2019 Form 10-K. The results of operations for an interim period may not give a true indication of results for a full year. All dollar amounts in the financial statements and tables in the notes are stated in millions of 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, judgments 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. Adoption of Accounting Standards In December 2019, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2019-12, Simplifying the Accounting for Income Taxes (Topic 740) . The ASU enhances and simplifies various aspects of the income tax accounting guidance including the elimination of certain exceptions related to the approach for intraperiod tax allocation, the methodology for calculating income taxes in an interim period and the recognition of deferred tax liabilities for outside basis differences. The new guidance also simplifies aspects of the accounting for franchise taxes and enacted changes in tax laws or rates and clarifies the accounting for transactions that result in a step-up in the tax basis of goodwill. We adopted all provisions of this ASU in the first quarter of 2020, and it did not have a material impact on our financial statements. In August 2018, the FASB issued ASU 2018-13, Changes to the Disclosure Requirements for Fair Value Measurement. 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 requires 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 adopted this ASU in the first quarter of 2020, and the updated disclosures are included in Note 14. 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 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 adopted this ASU in the first quarter of 2020, and it did not have a material impact on our financial statements. In June 2016, the FASB issued ASU 2016-13, Financial Instruments—Credit Losses . The ASU requires organizations to measure all expected credit losses for financial instruments held at the reporting date based on historical experience, current conditions and reasonable and supportable forecasts. We adopted this ASU in the first quarter of 2020, and it did not have a material impact on our financial statements. Changes in Accounting Standards In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting . The ASU provides optional expedients and exceptions for applying GAAP to contract modifications and hedging relationships, subject to meeting certain criteria, that reference LIBOR or another rate that is expected to be discontinued. The amendments in the ASU are effective for all entities as of March 12, 2020 through December 31, 2022. The adoption of this guidance did not have a material impact on our financial statements.

Acquisitions, Merger Transactio

Acquisitions, Merger Transaction and Business Combination Accounting (Notes)	6 Months Ended
	Jun. 30, 2020
Business Combinations [Abstract]
Acquisitions, Merger Transaction and Business Combination Accounting	ACQUISITIONS, MERGER TRANSACTION AND BUSINESS COMBINATION ACCOUNTING Ambit Transaction On November 1, 2019 (Ambit Acquisition Date), Volt Asset Company, Inc., an indirect, wholly owned subsidiary of Vistra, completed the Ambit Transaction. Ambit is an energy retailer selling both electricity and natural gas products to residential and small business customers in 17 states. Vistra funded the purchase price of $555 million (including cash acquired and net working capital) using cash on hand. All of Ambit's outstanding debt was repaid from the purchase price at closing and not assumed by Vistra. Crius Transaction On July 15, 2019 (Crius Acquisition Date), Vienna Acquisition B.C. Ltd., an indirect, wholly owned subsidiary of Vistra, 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. Vistra funded the purchase price of $400 million (including $382 million for outstanding trust units) using cash on hand. In addition, Vistra assumed $140 million of outstanding debt and acquired $26 million of cash at the closing of the Crius Transaction. Ambit and Crius Business Combination Accounting We believe the Ambit Transaction has (i) augmented Vistra's existing retail marketing capabilities with additional direct selling capability and a proprietary technology platform, (ii) reduced risk and aided expansion into higher margin channels by improving Vistra's match of its generation to load profile due to a high degree of overlap of Vistra's generation fleet with Ambit's approximately 11 TWh of annual load, primarily in ERCOT and PJM and (iii) enhanced the integrated value proposition through collateral and transaction efficiencies, particularly via Ambit's retail electric portfolio. We believe the Crius Transaction has (i) reduced risk and aided expansion into higher margin channels by improving Vistra's match of its generation to load profile due to a high degree of overlap of Vistra's generation fleet with Crius' approximately 10 TWh of annual electricity load, (ii) established a platform for growth by leveraging Vistra's existing retail marketing capabilities and Crius' experienced team and (iii) enhanced the integrated value proposition through collateral and transaction efficiencies, particularly via Crius' retail electric portfolio. Each of the Ambit Transaction and Crius Transaction, respectively, 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 Ambit Acquisition Date and Crius Acquisition Date, respectively. The combined results of operations are reported in our condensed consolidated financial statements beginning as of the respective Ambit Acquisition Date and Crius Acquisition 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 14), is listed below: • Working capital was valued using available market information (Level 2). • Acquired derivatives were valued using the methods described in Note 14 (Level 2 or Level 3). • Acquired retail customer relationship was valued based on discounted cash flow analysis of acquired customers and estimated attrition rates (Level 3). • Crius' long-term debt was valued using a market approach (Level 2). The following table summarizes the allocation of the purchase price to the fair value amounts recognized for the assets acquired and liabilities assumed related to the Ambit Transaction and Crius Transaction, respectively, as of the Ambit Acquisition Date and Crius Acquisition Date, respectively. The Ambit Transaction purchase price was $555 million (including cash acquired and net working capital), and the Crius Transaction purchase price was $400 million. The Ambit Transaction purchase price allocation is ongoing and is dependent upon final valuation determinations, which have not been completed. The Ambit Transaction preliminary values included below represent our current best estimates for identifiable intangible assets, goodwill and net working capital. The Ambit Transaction purchase price allocation is preliminary and each of the values included below may change materially based upon the receipt of more detailed information, additional analyses and completed valuations. The final purchase price allocation was completed in the second quarter of 2020 for the Crius Transaction and will be completed no later than the third quarter of 2020 for the Ambit Transaction. Ambit Transaction Preliminary Purchase Price Allocation and Crius Transaction Final Purchase Price Allocation Ambit Transaction Crius Transaction Updated Preliminary Purchase Price Allocation Measurement Period Adjustments recorded through Final Measurement Period Adjustments recorded through Cash and cash equivalents $ 49 $ — $ 26 $ — Net working capital 35 6 (9) (42) Accumulated deferred income taxes — — — (36) Identifiable intangible assets 230 (33) 317 23 Goodwill 243 29 243 38 Commodity and other derivative contractual assets 23 — 18 — Other noncurrent assets 13 — 17 (3) Total assets acquired 593 2 612 (20) Identifiable intangible liabilities — — 2 (34) Long-term debt, including amounts due currently — — 140 — Commodity and other derivative contractual liabilities 28 — 40 — Accumulated deferred income taxes — — 14 14 Other noncurrent liabilities and deferred credits 10 2 16 — Total liabilities assumed 38 2 212 (20) Identifiable net assets acquired $ 555 $ — $ 400 $ — Dynegy Merger Transaction On the Merger Date, Vistra and Dynegy completed the transactions contemplated by the Merger Agreement. Pursuant to the Merger Agreement, Dynegy merged with and into Vistra, with Vistra continuing as the surviving corporation. The Merger was intended to qualify as a tax-free reorganization under the IRC, so that none of Vistra, 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's common stock. Vistra is the acquirer for both federal tax and accounting purposes.

Development of Generation Facil

Development of Generation Facilities (Notes)	6 Months Ended
	Jun. 30, 2020
Acquisition And Development Of Generation Facilities [Abstract]
Development of Generation Facilities	DEVELOPMENT OF GENERATION FACILITIES Battery Energy Storage Projects Oakland — In June 2019, East Bay Community Energy (EBCE) 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. In April 2020, the project received necessary approvals from EBCE and from Pacific Gas and Electric Company (PG&E), and the contract was amended to increase the capacity of the planned development to a 36.25 MW battery ESS. In April 2020, the concurrent local area reliability service agreement to ensure grid reliability as part of the Oakland Clean Energy Initiative was signed and sent to the California Public Utilities Commission (CPUC) for approval. The battery ESS project is expected to enter commercial operations by January 2022. Moss Landing — In June 2018, we announced that, subject to approval by the CPUC, we would enter into a 20-year resource adequacy contract with PG&E to develop a 300 MW battery ESS at our Moss Landing Power Plant site in California (Moss Landing Phase I). 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, 2020, we had accumulated approximately $315 million in construction work-in-process for Moss Landing Phase I. Under the contract, PG&E will pay us a fixed monthly resource adequacy payment, while we will receive the energy revenues and incur the costs from dispatching and charging the ESS. We anticipate the Moss Landing Phase I will commence commercial operations in the fourth quarter of 2020. PG&E filed for Chapter 11 bankruptcy protection in January 2019. In November 2019, the bankruptcy court approved PG&E's motion requesting approval of the assumption of the resource adequacy contract subject to the CPUC approving the terms of an amendment to the resource adequacy contract, and the CPUC approved the terms of the amendment in January 2020. PG&E emerged from bankruptcy protection in July 2020. In May 2020, we announced that, subject to approval by the CPUC, we would enter into a 10-year resource adequacy contract with PG&E to develop an additional 100 MW battery ESS at our Moss Landing Power Plant site (Moss Landing Phase II). PG&E filed its application with the CPUC in May 2020, and a decision is expected to be received by the end of the third quarter of 2020. Assuming the receipt of CPUC approval, we anticipate Moss Landing Phase II will commence commercial operations in the third quarter of 2021.

Retirement of Generation Facili

Retirement of Generation Facilities (Notes)	6 Months Ended
	Jun. 30, 2020
Retirement of Generation Facilities [Abstract]
Retirement of generation facilities	RETIREMENT OF GENERATION FACILITIES MISO — In September 2019, we announced the settlement of a lawsuit alleging violations of opacity and particulate matter limits at our Edwards facility in Bartonville, Illinois. As part of the settlement, which was approved by the U.S. District Court for the Central District of Illinois in November 2019, we will retire the Edwards facility by the end of 2022 (see Note 12). In August 2019, we announced the planned retirement of four power plants in Illinois with a total installed nameplate generation capacity of 2,068 MW. We retired these units due to changes in the Illinois multi-pollutant standard rule (MPS rule) that require us to retire approximately 2,000 MW of generation capacity (see Note 12). In light of the provisions of the Federal Power Act and the FERC regulations thereunder, the affected subsidiaries of Vistra identified the retired units by analyzing the economics of each of our Illinois plants and designating the least economic units for retirement. Expected plant retirement expenses of $47 million, driven by severance costs, were accrued in the three months ended September 30, 2019 and were included primarily in operating costs of our Asset Closure segment. In August 2019, we remeasured our pension and OPEB plans resulting in an increase to the benefit obligation liability of $21 million, pretax other comprehensive loss of $18 million and curtailment expense of $3 million recognized as other deductions in our condensed consolidated statements of operations. The following table details the units in Illinois totaling 2,653 MW that have been or will be retired. Operational results for retired plants are included in the Asset Closure segment, which is engaged in the decommissioning and reclamation of retired plants and mines. Name Location Fuel Type Net Generation Capacity (MW) Number of Units Dates Units Retired or Coffeen Coffeen, IL Coal 915 2 November 1, 2019 Duck Creek Canton, IL Coal 425 1 December 15, 2019 Havana Havana, IL Coal 434 1 November 1, 2019 Hennepin Hennepin, IL Coal 294 2 November 1, 2019 Edwards Bartonville, IL Coal 585 2 By the end of 2022 Total 2,653 8

Revenue (Notes)

Revenue (Notes)	6 Months Ended
	Jun. 30, 2020
Revenue Recognition and Deferred Revenue [Abstract]
Revenue	REVENUE The following tables disaggregate our revenue by major source: Three Months Ended June 30, 2020 Retail ERCOT PJM NY/NE MISO Asset CAISO/Eliminations Consolidated Revenue from contracts with customers: Retail energy charge in ERCOT $ 1,411 $ — $ — $ — $ — $ — $ — $ 1,411 Retail energy charge in Northeast/Midwest 540 — — — — — — 540 Wholesale generation revenue from ISO/RTO — 76 71 16 3 — 13 179 Capacity revenue from ISO/RTO — — 15 10 4 — — 29 Revenue from other wholesale contracts — 63 137 26 54 — 21 301 Total revenue from contracts with customers 1,951 139 223 52 61 — 34 2,460 Other revenues: Intangible amortization (5) — — — (7) — — (12) Hedging and other revenues (a) 10 62 (6) (10) (6) — 11 61 Affiliate sales — 664 195 89 73 — (1,021) — Total other revenues 5 726 189 79 60 — (1,010) 49 Total revenues $ 1,956 $ 865 $ 412 $ 131 $ 121 $ — $ (976) $ 2,509 ____________ (a) Includes $69 million of unrealized net losses from mark-to-market valuations of commodity positions. See Note 17 for unrealized net gains (losses) by segment. Three Months Ended June 30, 2019 Retail ERCOT PJM NY/NE MISO Asset 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 33 43 22 497 Capacity revenue from ISO/RTO — — 53 72 8 3 — 136 Revenue from other wholesale contracts — 52 87 6 40 1 4 190 Total revenue from contracts with customers 1,406 240 270 159 81 47 26 2,229 Other revenues: Intangible amortization (10) — — (1) (4) — 1 (14) Hedging and other revenues (a) 25 404 81 61 15 11 20 617 Affiliate sales — 1,027 335 35 96 — (1,493) — Total other revenues 15 1,431 416 95 107 11 (1,472) 603 Total revenues $ 1,421 $ 1,671 $ 686 $ 254 $ 188 $ 58 $ (1,446) $ 2,832 ____________ (a) Includes $538 million of unrealized net gains from mark-to-market valuations of commodity positions. See Note 17 for unrealized net gains (losses) by segment. Six Months Ended June 30, 2020 Retail ERCOT PJM NY/NE MISO Asset CAISO/Eliminations Consolidated Revenue from contracts with customers: Retail energy charge in ERCOT $ 2,665 $ — $ — $ — $ — $ — $ — $ 2,665 Retail energy charge in Northeast/Midwest 1,180 — — — — — — 1,180 Wholesale generation revenue from ISO/RTO — 174 148 58 17 — 46 443 Capacity revenue from ISO/RTO — — 30 35 9 — — 74 Revenue from other wholesale contracts — 113 288 38 103 — 25 567 Total revenue from contracts with customers 3,845 287 466 131 129 — 71 4,929 Other revenues: Intangible amortization (8) — — — (11) — — (19) Hedging and other revenues (a) 27 313 32 29 2 — 54 457 Affiliate sales — 1,131 562 257 143 — (2,093) — Total other revenues 19 1,444 594 286 134 — (2,039) 438 Total revenues $ 3,864 $ 1,731 $ 1,060 $ 417 $ 263 $ — $ (1,968) $ 5,367 ____________ (a) Includes $131 million of unrealized net gains from mark-to-market valuations of commodity positions. See Note 17 for unrealized net gains (losses) by segment. Six Months Ended June 30, 2019 Retail ERCOT PJM NY/NE MISO Asset 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 — 435 351 276 104 110 95 1,371 Capacity revenue from ISO/RTO — — 120 152 18 6 — 296 Revenue from other wholesale contracts — 97 159 12 55 2 6 331 Total revenue from contracts with customers 2,779 532 630 440 177 118 101 4,777 Other revenues: Intangible amortization (19) — — (3) (9) — 2 (29) Hedging and other revenues (a) 46 562 171 113 29 25 61 1,007 Affiliate sales — 1,531 590 49 160 — (2,330) — Total other revenues 27 2,093 761 159 180 25 (2,267) 978 Total revenues $ 2,806 $ 2,625 $ 1,391 $ 599 $ 357 $ 143 $ (2,166) $ 5,755 ____________ (a) Includes $697 million of unrealized net gains from mark-to-market valuations of commodity positions. See Note 17 for unrealized net gains (losses) by segment. Performance Obligations As of June 30, 2020, 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 contracts with customers. Therefore, an obligation exists as of the date of the results of the respective ISO or RTO capacity auction or the contract execution date. These obligations total $390 million, $826 million, $479 million, $121 million and $38 million that will be recognized, in the balance of the year ended December 31, 2020 and the years ending December 31, 2021, 2022, 2023 and 2024, respectively, and $18 million thereafter. Capacity revenues are recognized as capacity is made available to the related ISOs or RTOs or 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, 2019 Trade accounts receivable from contracts with customers — net $ 1,197 $ 1,246 Other trade accounts receivable — net 75 119 Total trade accounts receivable — net $ 1,272 $ 1,365

Goodwill and Identifiable Intan

Goodwill and Identifiable Intangible Assets and Liabilities (Notes)	6 Months Ended
	Jun. 30, 2020
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill And Identifiable Intangible Assets	GOODWILL AND IDENTIFIABLE INTANGIBLE ASSETS AND LIABILITIES Goodwill The following table provides information regarding our goodwill balance. There have been no impairments of goodwill. Balance at December 31, 2019 $ 2,553 Measurement period adjustments recorded in connection with the Ambit Transaction 29 Measurement period adjustments recorded in connection with the Crius Transaction (14) Balance at June 30, 2020 $ 2,568 At June 30, 2020, the goodwill balance of $2.568 billion consisted of the following: • $1.907 billion arose in connection with our application of fresh start reporting at Emergence and was allocated entirely to our 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. • $175 million arose in connection with the Merger, of which $122 million was allocated to our ERCOT Generation reporting unit and $53 million was allocated to our Retail reporting unit. None of the goodwill related to the Merger is deductible for tax purposes. • $243 million of goodwill arose in connection with the Crius Transaction and was allocated entirely to our Retail reporting unit. None of the goodwill related to the Crius Transaction is deductible for tax purposes. • $243 million of preliminary goodwill arose in connection with the Ambit Transaction and is allocated entirely to our Retail reporting unit pending completion of the purchase price allocation. The goodwill related to the Ambit Transaction 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, 2020 December 31, 2019 Identifiable Intangible Asset Gross Carrying Amount Accumulated Net Gross Carrying Amount Accumulated Net Retail customer relationship $ 2,087 $ 1,302 $ 785 $ 2,078 $ 1,151 $ 927 Software and other technology-related assets 364 151 213 341 125 216 Retail and wholesale contracts 272 195 77 315 182 133 Contractual service agreements (a) 55 2 53 59 5 54 Other identifiable intangible assets (b) 45 17 28 40 15 25 Total identifiable intangible assets subject to amortization $ 2,823 $ 1,667 1,156 $ 2,833 $ 1,478 1,355 Retail trade names (not subject to amortization) 1,374 1,391 Mineral interests (not currently subject to amortization) 2 2 Total identifiable intangible assets $ 2,532 $ 2,748 ____________ (a) At June 30, 2020, 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 (emissions allowances and renewable energy certificates). Identifiable intangible liabilities are comprised of the following: Identifiable Intangible Liability June 30, December 31, 2019 Contractual service agreements $ 127 $ 110 Purchase and sale of power and capacity 92 100 Fuel and transportation purchase contracts 75 76 Total identifiable intangible liabilities $ 294 $ 286 Expense related to finite-lived identifiable intangible assets and liabilities (including the classification in the condensed consolidated statements of operations) consisted of: Identifiable Intangible Assets and Liabilities Condensed Consolidated Statements of Operations Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 Retail customer relationship Depreciation and amortization $ 77 $ 55 $ 151 $ 111 Software and other technology-related assets Depreciation and amortization 21 15 38 29 Retail and wholesale contracts/purchase and sale/fuel and transportation contracts Operating revenues/fuel, purchased power costs and delivery fees 13 12 15 24 Other identifiable intangible assets Operating revenues/fuel, purchased power costs and delivery fees/depreciation and amortization 44 15 96 39 Total intangible asset expense (a) $ 155 $ 97 $ 300 $ 203 ____________ (a) Amounts recorded in depreciation and amortization totaled $99 million and $72 million for the three months ended June 30, 2020 and 2019, respectively, and $190 million and $141 million for the six months ended June 30, 2020 and 2019, respectively. Amounts exclude contractual services agreements. Amounts include all expenses associated with environmental allowances including expenses accrued to comply with emissions allowance programs and renewable portfolio standards which are presented in fuel, purchased power costs and delivery fees on our condensed consolidated statements of operations. Emissions allowance obligations are accrued as associated electricity is generated and renewable energy credit obligations are accrued as retail electricity delivery occurs. Estimated Amortization of Identifiable Intangible Assets and Liabilities As of June 30, 2020, 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 2020 $ 369 2021 $ 257 2022 $ 161 2023 $ 116 2024 $ 78

Income Taxes (Notes)

Income Taxes (Notes)	6 Months Ended
	Jun. 30, 2020
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, 2020 2019 2020 2019 Income before income taxes $ 232 $ 502 $ 293 $ 803 Income tax expense $ (68) $ (148) $ (84) $ (225) Effective tax rate 29.3 % 29.5 % 28.7 % 28.0 % For the three months ended June 30, 2020, the effective tax rate of 29.3% was higher that the U.S. federal statutory rate of 21% due primarily to nondeductible impacts of the TRA and state income taxes. For the six months ended June 30, 2020, the effective tax rate of 28.7% was higher than the U.S. federal statutory rate of 21% due primarily to nondeductible impacts of the TRA and state income taxes. For the three months ended June 30, 2019, the effective tax rate of 29.5% was higher that 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% 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. Coronavirus Aid, Relief, and Economic Security Act (CARES Act) In response to the global pandemic related to COVID-19, the President signed into law the CARES Act on March 27, 2020. The CARES Act provides numerous relief provisions for corporate taxpayers, including modification of the utilization limitations on net operating losses, favorable expansion of the deduction for business interest expense under IRC Section 163(j) (Section 163(j)), the ability to accelerate timing of refundable alternative minimum tax (AMT) credits and the temporary suspension of certain payment requirements for the employer portion of social security taxes. While Vistra is still evaluating the impact of certain tax-related benefits available under the CARES Act, we anticipate the acceleration of AMT refunds and the expansion of the Section 163(j) limitation from 30% to 50% of adjusted taxable income to have material impacts to Vistra. Specifically, we expect to receive approximately $64 million in 2020 relating to the acceleration of AMT refunds and an approximate $550 million increase in interest expense deduction over the 2019 and 2020 tax years under Section 163(j). We do not anticipate a material impact to the effective tax rate from these impacts. Vistra will continue to monitor legislative developments related to COVID-19. Liability for Uncertain Tax Positions Vistra 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 is not currently under audit by the IRS for any period, although review of Dynegy's final pre-acquisition tax year 2018 continues to progress through the IRS's Compliance Assurance Process audit program. Crius is currently under audit by the IRS for the tax years 2015, 2016 and 2017. Uncertain tax positions totaled $125 million and $126 million at June 30, 2020 and December 31, 2019, respectively. The final regulations under Section 163(j) were released in July 2020. While we are still evaluating the impact, we expect to adjust deferred tax assets and deferred tax liabilities in the third quarter of 2020 and do not expect the final regulation to materially impact our effective tax rate.

Tax Receivable Agreement Obliga

Tax Receivable Agreement Obligation (Notes)	6 Months Ended
	Jun. 30, 2020
Income Tax Disclosure [Abstract]
Tax Receivable Agreement Obligation	TAX RECEIVABLE AGREEMENT OBLIGATION On the Effective Date, Vistra 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 16). 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, 2020 and 2019: Six Months Ended June 30, 2020 2019 TRA obligation at the beginning of the period $ 455 $ 420 Accretion expense 34 31 Changes in tax assumptions impacting timing of payments (a) (20) (67) Impacts of Tax Receivable Agreement 14 (36) TRA obligation at the end of the period 469 384 Less amounts due currently (1) — TRA obligation at the end of the period (noncurrent) $ 468 $ 384 ____________ (a) During the three and six months ended June 30, 2020, we recorded decreases to the carrying value of the TRA obligation totaling $11 million and $20 million, respectively, as a result of adjustments to forecasted taxable income, including the impacts of the CARES Act changes to Section 163(j) percentage limitation amount. During the three and six months ended June 30, 2019, we recorded decreases to the carrying value of the TRA obligation totaling $48 million and $67 million, respectively, as a result of adjustments to forecasted taxable income and higher net operating losses acquired in the Merger. As of June 30, 2020, the estimated carrying value of the TRA obligation totaled $469 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 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, 2020, the aggregate amount of undiscounted federal and state payments under the TRA is estimated to be approximately $1.4 billion, with more than half of such amount expected to be paid during the next 15 years, and the final payment expected to be made around the year 2056 (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, 2020
Earnings Per Share [Abstract]
Earnings Per Share	EARNINGS PER SHARE Basic earnings per share available to common stockholders 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, 2020 2019 2020 2019 Net income attributable to common stock — basic $ 166 $ 356 $ 222 $ 581 Weighted average shares of common stock outstanding — basic (a) 488,680,442 499,778,235 488,312,503 499,213,522 Net income per weighted average share of common stock outstanding — basic $ 0.34 $ 0.71 $ 0.45 $ 1.16 Dilutive securities: Stock-based incentive compensation plan 1,788,293 7,722,148 2,397,429 8,035,398 Weighted average shares of common stock outstanding — diluted 490,468,735 507,500,383 490,709,932 507,248,920 Net income per weighted average share of common stock outstanding — diluted $ 0.34 $ 0.70 $ 0.45 $ 1.15 ____________ (a) For the three and six months ended June 30, 2019, the minimum settlement amount of tangible equity units, or 15,207,600 shares, are considered to be outstanding and are included in the computation of basic net income per share. Stock-based incentive compensation plan awards excluded from the calculation of diluted earnings per share because the effect would have been antidilutive totaled 13,978,168 and 2,910,226 for the three months ended June 30, 2020 and 2019, respectively, and 12,123,691 and 7,577,246 shares for the six months ended June 30, 2020 and 2019, respectively.

Accounts Receivable Securitizat

Accounts Receivable Securitization Program (Notes)	6 Months Ended
	Jun. 30, 2020
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, has an accounts receivable financing facility (Receivables Facility) provided by issuers of asset-backed commercial paper and commercial banks (Purchasers). The Receivables Facility was renewed in July 2020, extending the term of the Receivables Facility from July 2020 to July 2021, with the ability to borrow $550 million beginning with the settlement date in July 2020 until the settlement date in August 2020, $625 million from the settlement date in August 2020 until the settlement date in November 2020, $550 million from the settlement date in November 2020 until the settlement date in December 2020 and $450 million thereafter for the remaining term of the Receivables Facility. 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 consolidated statements of cash flows. Receivables transferred to the Purchasers remain on Vistra's balance sheet and Vistra 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, 2020, outstanding borrowings under the receivables facility totaled $450 million and were supported by $639 million of RecCo gross receivables. As of December 31, 2019, outstanding borrowings under the receivables facility totaled $450 million and were supported by $629 million of RecCo gross receivables.

Long-Term Debt (Notes)

Long-Term Debt (Notes)	6 Months Ended
	Jun. 30, 2020
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 $ 2,586 $ 2,700 Vistra Operations Senior Secured Notes: 3.550% Senior Secured Notes, due July 15, 2024 1,500 1,500 3.700% Senior Secured Notes, due January 30, 2027 800 800 4.300% Senior Secured Notes, due July 15, 2029 800 800 Total Vistra Operations Senior Secured Notes 3,100 3,100 Vistra Operations Senior Unsecured Notes: 5.500% Senior Unsecured Notes, due September 1, 2026 1,000 1,000 5.625% Senior Unsecured Notes, due February 15, 2027 1,300 1,300 5.000% Senior Unsecured Notes, due July 31, 2027 1,300 1,300 Total Vistra Operations Senior Unsecured Notes 3,600 3,600 Vistra Senior Unsecured Notes: 5.875% Senior Unsecured Notes, due June 1, 2023 — 500 8.000% Senior Unsecured Notes, due January 15, 2025 — 81 8.125% Senior Unsecured Notes, due January 30, 2026 (a) 166 166 Total Vistra Senior Unsecured Notes 166 747 Other: Forward Capacity Agreements 101 161 Equipment Financing Agreements 91 99 8.82% Building Financing due semiannually through February 11, 2022 (b) 13 15 Other 4 12 Total other long-term debt 209 287 Unamortized debt premiums, discounts and issuance costs (c) (63) (55) Total long-term debt including amounts due currently 9,598 10,379 Less amounts due currently (337) (277) Total long-term debt less amounts due currently $ 9,261 $ 10,102 ____________ (a) Vistra redeemed all of its outstanding 8.125% senior unsecured notes due 2026 in July 2020. (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, 2020, the Vistra Operations Credit Facilities consisted of up to $5.311 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 $2.586 billion (Term Loan B-3 Facility). In March 2020, Vistra Operations repurchased $100 million principal amount of Term Loan B-3 Facility borrowings at a weighted average price of $93.875 and cancelled them. We recorded an extinguishment gain of $6 million on the transaction in the six months ended June 30, 2020. During the six months ended June 30, 2020, we borrowed $925 million and repaid $725 million under the Revolving Credit Facility, with proceeds from the borrowings used for general corporate purposes. In June 2019, Vistra Operations used the net proceeds from the June 2019 Senior Secured Notes Offerings (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. In March 2019 and May 2019 the Vistra Operations Credit Facilities were amended 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 for the six months ended June 30, 2019, which were capitalized as a noncurrent asset. The Vistra Operations Credit Facilities and related available capacity at June 30, 2020 are presented below. June 30, 2020 Vistra Operations Credit Facilities Maturity Date Facility Cash Available Revolving Credit Facility (a) June 14, 2023 $ 2,725 $ 550 $ 1,287 Term Loan B-3 Facility December 31, 2025 2,586 2,586 — Total Vistra Operations Credit Facilities $ 5,311 $ 3,136 $ 1,287 ___________ (a) Facility to be used for general corporate purposes. Facility includes a $2.35 billion letter of credit sub-facility, of which $888 million of letters of credit were outstanding at June 30, 2020 and which reduce our available capacity. Cash borrowings under the Revolving Credit Facility are reported in short-term borrowings in our condensed consolidated balance sheets. At June 30, 2020, cash borrowings under the Revolving Credit Facility bear interest based on applicable LIBOR rates, plus a fixed spread of 1.75%, and there were $550 million outstanding borrowings. Letters of credit issued under the Revolving Credit Facility bear interest of 1.75%. Amounts borrowed under the Term Loan B-3 Facility bears interest based on applicable LIBOR rates plus fixed spreads of 1.75%. At June 30, 2020, the weighted average interest rates before taking into consideration interest rate swaps on outstanding borrowings was 1.93% including both the Revolving Credit Facility and the Term Loan B-3 Facility. 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 Vistra Operations Credit Facilities, not to exceed 4.25 to 1.00. As of June 30, 2020, we were in compliance with this financial covenant. 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 — Vistra employs interest rate swaps to hedge our exposure to variable rate debt. As of June 30, 2020, Vistra has entered into the following series of interest rate swap transactions. Notional Amount Expiration Date Rate Range Swapped to fixed $3,000 July 2023 3.67 % - 3.91% Swapped to variable $700 July 2023 3.20 % - 3.23% Swapped to fixed $720 February 2024 3.71 % - 3.72% Swapped to variable $720 February 2024 3.20 % - 3.20% Swapped to fixed (a) $3,000 July 2026 4.72 % - 4.79% Swapped to variable (a) $700 July 2026 3.28 % - 3.33% ____________ (a) Effective from July 2023 through July 2026. During 2019, Vistra entered into $2.120 billion of new interest rate swaps, pursuant to which Vistra will pay a variable rate and receive a fixed rate. The terms of these new swaps were matched against the terms of certain existing swaps, effectively offsetting the hedge of the existing swaps and fixing the out-of-the-money position of such swaps. These matched swaps will settle over time, in accordance with the original contractual terms. The remaining existing swaps continue to hedge our exposure on $2.3 billion of debt through July 2026. 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 year ended December 31, 2019. At June 30, 2020, $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 Operations Senior Secured Notes In the six months ended June 30, 2019, Vistra Operations issued and sold $2.0 billion aggregate principal amount of senior secured notes (June 2019 Senior Secured Notes) in offerings to eligible purchasers under Rule 144A and Regulation S under the Securities Act (June 2019 Senior Secured Notes Offerings) consisting of the following: Senior Secured Notes Maturity Year Interest Terms June 2019 3.550% Senior Secured Notes 2024 January 15 and July 15 $ 1,200 4.300% Senior Secured Notes 2029 January 15 and July 15 800 Total senior secured notes $ 2,000 Net proceeds $ 1,976 Debt issuance and other fees (b) $ 20 ___________ (a) The June 2019 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. Net proceeds, 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 Facility's Term Loan B Facility. (b) Capitalized as a reduction in the carrying amount of the debt. The indenture (as may be amended or supplemented from time to time, the Vistra Operations Senior Secured Indenture) governing the June 2019 Senior Secured Notes and the 3.700% senior secured notes due 2027 (collectively, the Senior Secured Notes) provides for the full and unconditional guarantee 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. The Vistra Operations Senior Secured Indenture contains certain covenants and restrictions, including, among others, restrictions on the ability of Vistra Operations 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 Operations Senior Unsecured Notes In the six months ended June 30, 2019, Vistra Operations issued and sold $2.6 billion aggregate principal amount of senior unsecured notes in offerings (the February 2019 Senior Unsecured Notes Offering and the June 2019 Senior Unsecured Notes Offering) to eligible purchasers under Rule 144A and Regulation S under the Securities Act consisting of the following: Senior Unsecured Notes Maturity Year Interest Terms February 2019 Senior Unsecured Notes Offering (a) June 2019 5.625% Senior Unsecured Notes 2027 February 15 and August 15 1,300 — 5.000% Senior Unsecured Notes 2027 January 31 and July 31 — 1,300 Total $ 1,300 $ 1,300 Net Proceeds $ 1,287 $ 1,287 Debt issuance and other fees (c) $ 16 $ 13 ___________ (a) The 5.625% senior unsecured notes due 2027 (the February 2019 Senior Unsecured 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. Net proceeds, 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 (defined below) and (ii) the redemption of approximately $35 million aggregate principal amount of our 7.375% senior unsecured notes due 2022 (7.375% senior notes) and approximately $25 million aggregate principal amount of our outstanding 8.034% senior unsecured notes due 2024 (8.034% senior notes). (b) The 5.000% senior unsecured notes due 2027 (the June 2019 Senior Unsecured 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. Net proceeds, 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 (defined below) and (ii) the redemption of approximately $306 million of our outstanding 7.375% senior notes and approximately $87 million of our 7.625% senior unsecured notes due 2024 (7.625% senior notes) in July 2019. We recorded an extinguishment gain of $2 million on the redemptions in the six months ended June 30, 2019. (c) Capitalized as a reduction in the carrying amount of the debt. The indentures governing the June 2019 Senior Unsecured Notes, the February 2019 Senior Unsecured Notes and the 5.500% senior unsecured notes due 2026 (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 Vistra Operations and its subsidiaries, as applicable, to create certain liens, merge or consolidate with another entity, and sell all or substantially all of their assets. Debt 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 Senior Unsecured Notes could be repurchased. In July 2019, the Board authorized up to $1.0 billion to repay or repurchase any outstanding debt of the Company (or its subsidiaries), with that authority superseding the remaining availability under the $200 million bond repurchase program. Through April 2020, $684 million amount of debt had been repurchased under the $1.0 billion July 2019 authorization, including the repurchase of $100 million principal amount of Term Loan B-3 Facility borrowings discussed above and the redemption of $81 million aggregate principal amount outstanding of 8.000% senior unsecured notes due 2025 (8.000% senior notes) discussed below. In April 2020, the Board authorized up to $1.0 billion to repay or repurchase additional outstanding debt, with this new authority superseding and replacing the $316 million of availability under the previously authorized $1.0 billion debt repurchase program. Through July 31, 2020, approximately $666 million had been repurchased under the $1.0 billion April 2020 authorization, consisting of the redemption of the Vistra 5.875% senior unsecured notes due 2023 (5.875% senior notes) and the redemption of the Vistra 8.125% senior unsecured notes due 2026 (8.125% senior notes), each as described below. Vistr a Seni or Unsecured Notes July 2020 Redemption — In July 2020, Vistra redeemed the entire $166 million aggregate principal amount of 8.125% senior notes, at a redemption price equal to 104.063% of the aggregate principal amount thereof, plus accrued and unpaid interest to, but excluding, the date of redemption (July 2020 Redemption). Following the July 2020 Redemption, Vistra had no outstanding senior notes at the Parent level. June 2020 Redemption — In June 2020, Vistra redeemed the entire $500 million aggregate principal amount outstanding of 5.875% senior notes at a redemption price equal to 100.979% of the aggregate principal amount thereof, plus accrued and unpaid interest to, but excluding, the date of redemption (the June 2020 Redemption). We recorded an extinguishment gain of $3 million on the transaction in the six months ended June 30, 2020. January 2020 Redemption — In January 2020, Vistra redeemed the entire $81 million aggregate principal amount outstanding of 8.000% senior notes at a redemption price equal to 104.0% of the aggregate principal amount thereof, plus accrued and unpaid interest to, but excluding, the date of redemption (January 2020 Redemption, and together with the June 2020 Redemption and the July 2020 Redemption, the Redemptions). We recorded an extinguishment gain of $2 million on the transaction in the six months ended June 30, 2020. June 2019 Tender Offer — In June 2019, Vistra used the net proceeds from the June 2019 Senior Unsecured Notes Offering to fund a cash tender offer (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 six months ended June 30, 2019. In July 2019, Vistra 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 June 2019 Tender Offer. February 2019 Tender Offer and Consent Solicitation — In February 2019, Vistra used the net proceeds from the February 2019 Senior Unsecured Notes Offering to fund a cash tender offer (February 2019 Tender Offer, and together with the June 2019 Tender Offer, the Tender Offers) 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 six months ended June 30, 2019. In connection with the February 2019 Tender Offer, Vistra also commenced a solicitation of consents from holders of the 7.375% senior notes. Vistra 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. As of June 30, 2020, as a result of the Tender Offers and Redemptions of the Vistra senior unsecured notes, only the 8.125% senior notes remained outstanding. The 8.125% senior notes were redeemed in July 2020. Other Long-Term Debt 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 2020-2021 in the amount of $101 million. 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 with an implied interest rate of 2.29%. 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 financed these parts and equipment under agreements with maturities ranging from 2020 to 2026. Letter of Credit Obligations Assumed in Ambit Transaction — At June 30, 2020, approximately $3 million of letters of credit were outstanding under legacy Ambit agreements, all of which are collateralized with cash and recorded as restricted cash in the condensed consolidated balance sheets. Maturities Long-term debt maturities at June 30, 2020 are as follows: June 30, 2020 Remainder of 2020 $ 263 2021 96 2022 44 2023 40 2024 1,540 Thereafter 7,678 Unamortized premiums, discounts and debt issuance costs (63) Total long-term debt, including amounts due currently $ 9,598

Commitments and Contingencies (

Commitments and Contingencies (Notes)	6 Months Ended
	Jun. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES Guarantees We have entered into contracts that contain guarantees to unaffiliated parties that could require performance or payment under certain conditions. As of June 30, 2020, 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 in the near term. Letters of Credit At June 30, 2020, we had outstanding letters of credit totaling $1.391 billion as follows: • $1.117 billion 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; • $108 million to support battery and solar development projects; • $45 million to support executory contracts and insurance agreements; • $59 million to support our REP financial requirements with the PUCT, and • $62 million for other credit support requirements. Surety Bonds At June 30, 2020, we had outstanding surety bonds totaling $71 million to support performance under various contracts and legal obligations in the normal course of business. Litigation and Regulatory Proceedings Our material legal proceedings and regulatory proceedings affecting our business are described below. We believe that we have valid defenses to the legal proceedings described below and intend to defend them vigorously. We also intend to participate in the regulatory processes described below. We record reserves for estimated losses related to these matters when information available indicates that a loss is probable and the amount of the loss, or range of loss, can be reasonably estimated. As applicable, we have established an adequate reserve for the matters discussed below. In addition, legal costs are expensed as incurred. Management has assessed each of the following legal matters based on current information and made a judgment concerning its potential outcome, considering the nature of the claim, the amount and nature of damages sought, and the probability of success. Unless specified below, we are unable to predict the outcome of these matters or reasonably estimate the scope or amount of any associated costs and potential liabilities, but they could have a material impact on our results of operations, liquidity, or financial condition. As additional information becomes available, we adjust our assessment and estimates of such contingencies accordingly. Because litigation and rulemaking proceedings are subject to inherent uncertainties and unfavorable rulings or developments, it is possible that the ultimate resolution of these matters could be at amounts that are different from our currently recorded reserves and that such differences could be material. Gas Index Pricing Litigation — We, through our subsidiaries, and other 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 plaintiffs in these cases allege that the defendants engaged in an antitrust conspiracy to inflate natural gas prices during the relevant time period and seek damages under the respective state antitrust statutes. We remain as defendants in two consolidated putative class actions (Wisconsin) and one individual action (Kansas) both pending in federal court in those states. 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 (BNSF) and Norfolk Southern Railway Company (NS) filed a demand for arbitration and an arbitration hearing is currently scheduled for March 2021. Coffeen and Duck Creek Rail Disputes — In April 2020, IPH, LLC (IPH) received notification that BNSF and NS were initiating dispute resolution related to IPH's suspension of its Coffeen Rail Transportation Agreement with the railroads, and Illinois Power Resources Generating, LLC (IPRG), received notification that BNSF was initiating dispute resolution related to IPRG's suspension of its Duck Creek Rail Transportation Agreement with BNSF. In November 2019, IPH and IPRG sent suspension notices to the railroads asserting that the MPS rule requirement to retire at least 2,000 megawatts of generation (see discussion below) was a change-in-law under the agreement that rendered continued operation of the plants no longer economically feasible. In addition, IPH and IPRG asserted that the MPS rule's retirement requirement also qualified as a force majeure event under the agreements excusing performance. ME2C Patent Dispute — In July 2019, Midwest Energy Emissions Corporation and MES Inc. (collectively, the plaintiffs) filed a patent infringement complaint in federal court in Delaware against numerous parties, including Vistra and some of its subsidiaries (collectively, the Vistra defendants), and its amended complaint in July 2020. The amended complaint alleges that the Vistra defendants infringed five patents owned by the plaintiffs by using specific processes for mercury control at certain coal-fueled plants. The amended complaint seeks injunctive relief and unspecified damages. In July 2020, the plaintiffs and the Vistra defendants entered into an agreement resolving all the claims alleged against the Vistra defendants in the complaint. The court signed its stipulation and order of dismissal in July 2020, dismissing the Vistra defendants from the lawsuit. Greenhouse Gas Emissions In August 2015, the EPA finalized rules to address greenhouse gas (GHG) emissions 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 filed petitions for review in the U.S. Court of Appeals for the District of Columbia Circuit (D.C. Circuit Court). In July 2019, petitioners filed a joint motion to dismiss in light of the EPA's new rule that replaces the Clean Power Plan, the Affordable Clean Energy rule, discussed below. In September 2019, the D.C. Circuit Court granted petitioners' motion to dismiss and dismissed all of the petitions challenging the Clean Power Plan as moot. 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. States where we operate coal plants (Texas, Illinois and Ohio) have begun the development of their state plans to comply with the rule. Environmental groups and certain states filed petitions 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 in March 2019. Regional Haze — Reasonable Progress and Best Available Retrofit Technology (BART) for Texas 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 established 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. The retirements of our Monticello, Big Brown and Sandow 4 plants have enhanced our ability to comply with this BART rule for SO 2 . For NO X , the rule adopted the CSAPR's ozone program as BART and for particulate matter, the rule approved 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 pending conclusion of the EPA's reconsideration process. In June 2020, the EPA signed a final rule affirming the prior BART final rule but also includes additional revisions that were proposed in November 2019. As finalized, we expect that we will be able to comply with the rule. 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 in June 2019. In February 2020, the EPA issued the final rule withdrawing the Texas SIP Call. In April 2020, a group of environmental petitioners, including the Sierra Club, filed a petition in the D.C. Circuit Court challenging the EPA's action. Illinois Multi-Pollutant Standards (MPS) In August 2019, changes proposed by the Illinois Pollution Control Board to the MPS rule, which places NOx, SO 2 and mercury emissions limits on our coal plants located in MISO went into effect. Under the revised MPS rule, our allowable SO 2 and NO X emissions from the MISO fleet are 48% and 42% lower, respectively, than prior to the rule changes. The revised MPS rule requires the continuous operation of existing selective catalytic reduction (SCR) control systems during the ozone season, requires 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. Additionally, in 2019, the Company retired its Havana, Hennepin, Coffeen and Duck Creek plants in order to comply with the MPS rule's requirement to retire at least 2,000 MW of our generation in MISO. See Note 4 for information regarding the retirement of these four plants. SO2 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 August 2019, the EPA issued a proposed Error Correction Rule for all three areas, which, if finalized, would revise its previous nonattainment designations and each area at issue would be designated unclassifiable. In September 2019, we submitted comments in support of the proposed Error Correction Rule. 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 rule and administratively stayed the rule's compliance date deadlines. In August 2017, the EPA announced that its reconsideration of the ELG 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 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. In November 2019, the EPA issued a proposal that would extend the compliance deadline for FGD wastewater to no later than December 31, 2025 and maintains the December 31, 2023 compliance date for bottom ash transport water. The proposal also creates new sub-categories of facilities with more flexible FGD compliance options, including a retirement exemption to 2028 and a low utilization boiler exemption. The proposed rule also modified some of the FGD final effluent limitations. We filed comments on the proposal in January 2020. 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. CAA Matters 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. In January 2020, the U.S. Department of Justice filed a complaint and proposed consent decree agreed to by Dynegy Zimmer, LLC in the U.S. District Court for the Southern District of Ohio that would resolve claims alleged in the 2008, 2010 and 2014 NOVs. The District Court approved that consent decree in May 2020. The consent decree does not have a material impact on our results of operations, liquidity or financial condition. Coal Combustion Residuals (CCR)/Groundwater In July 2018, the EPA published a final rule, which became effective in August 2018, that amends certain provisions of the 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, in August 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. In December 2019, the EPA issued a proposed rule containing a revised closure deadline for unlined CCR impoundments and new procedures for seeking extensions of that revised closure deadline. We filed comments on the proposal in January 2020. In July 2020, the EPA finalized the December 2019 proposal with a final deadline of April 11, 2021 to initiate closure of unlined CCR impoundments. The final rule allows a generation plant to seek the EPA's approval to retire by either 2023 or 2028 (depending on the size of the impoundment at issue) as a means of compliance. We may decide to avail ourselves of this compliance mechanism for some of our facilities. MISO — 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. These violation notices remain unresolved; however, 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, and we submitted revised plans 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 in federal court in Illinois against 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 and briefing on that appeal is now underway. 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 the very early stages. 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. In July 2019, coal ash disposal and storage legislation in Illinois was enacted. The legislation addresses state requirements for the proper closure of coal ash ponds in the state of Illinois. The law tasks the IEPA and the IPCB to set up a series of guidelines, rules and permit requirements for closure of ash ponds. In March 2020, IEPA issued its proposed rule and we expect the rulemaking process should be completed by early 2021. Under the proposed rule, 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 proposed rule does not mandate closure by removal at any site. Public hearings for the proposed rule have been scheduled for August 2020 and September 2020. We will provide testimony during the hearing process. For all of the above matters, if certain corrective action measures, including groundwater treatment or removal of ash, are required 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. Until the revisions to the EPA's CCR rule and the Illinois coal ash rulemaking are finalized and we undertake further site specific evaluations required by each program we will not know the full range of costs of groundwater remediation, if any, that ultimately may be required under those rules. However, the currently anticipated CCR surface impoundment and landfill closure costs, as contained in our AROs, reflect the costs of closure methods that our operations and environmental services teams believe are appropriate and protective of the environment for each location. 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 request for rehearing was denied by FERC in March 2020. The order was appealed by Public Citizen, Inc. to the D.C. Circuit Court in May 2020, and Vistra, Dynegy and Illinois Power Marketing Company intervened in the case in June 2020. The appeal remains pending. 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, 2020
Stockholders' Equity Note [Abstract]
Equity	EQUITY Share Repurchase Program In June 2018, we announced that the Board had authorized a share repurchase program under which up to $500 million of our outstanding common stock may be purchased, and this authorized amount was fully utilized in 2018. In November 2018, we announced that the Board had authorized an incremental share repurchase program under which up to $1.250 billion of our outstanding stock may be purchased, resulting in an aggregate $1.750 billion share repurchase program (Share Repurchase Program). No repurchases were made under the Share Repurchase Program in the three and six months ended June 30, 2020. In the three months ended June 30, 2019, 8,558,712 shares of our common stock were repurchased under the Share Repurchase Program for approximately $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 under the Share Repurchase Program for approximately $448 million (including related fees and expenses) at an average price of $24.75 per share of common stock. On a cumulative basis, 59,817,182 shares of our common stock have been repurchased under the Share Repurchase Program for approximately $1.418 billion (including related fees and expenses) at an average price of $23.72 per share of common stock. As of June 30, 2020, approximately $332 million was available for additional repurchases under the Share Repurchase Program. 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 or otherwise will be determined at our discretion and will depend on a number of factors, including our capital allocation priorities, 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 announced the Board adopted a dividend program which we initiated in the first quarter of 2019. Each dividend under the program will be subject to 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's results of operations, financial condition and liquidity, Delaware law and any contractual limitations. In February 2019, May 2019, July 2019 and October 2019, the Board declared quarterly dividends of $0.125 per share that were paid in March 2019, June 2019, September 2019 and December 2019, respectively. In February 2020 and April 2020, the Board declared quarterly dividends of $0.135 per share that were paid in March 2020 and June 2020, respectively. In July 2020, the Board declared a quarterly dividend of $0.135 per share that will be paid in September 2020. Dividend Restrictions 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, 2020, Vistra Operations can distribute approximately $6.1 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 $740 million and $850 million during the three and six months ended June 30, 2020, respectively, and approximately $3.9 billion, $4.7 billion and $1.1 billion during the years ended December 31, 2019, 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, 2020, the maximum amount of restricted net assets of Vistra Operations that may not be distributed to Parent totaled approximately $1.5 billion. In addition to the restrictions under the Credit Facilities Agreement, under applicable Delaware law, we are only permitted to make distributions either out of "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), or out of net profits for the fiscal year in which the distribution is declared or the prior fiscal year. Warrants At the Merger Date, the Company entered into an agreement whereby the holder of each outstanding warrant previously issued by Dynegy would be entitled to receive, upon paying an exercise price of $35.00 (subject to adjustment from time to time), the number of shares of Vistra common stock that such holder would have been entitled to receive if it had held one share of Dynegy common stock at the closing of the Merger, or 0.652 shares of Vistra common stock. Accordingly, upon exercise, a warrant holder would effectively pay $53.68 (subject to adjustment of the exercise price from time to time) per share of Vistra common stock received. As of June 30, 2020, approximately nine million warrants expiring in 2024 were outstanding. The warrants are immaterial and reflected as equity in our condensed consolidated balance sheets. Equity The following table presents the changes to equity for the three months ended June 30, 2020: Common Treasury Stock Additional Paid-in Capital Retained Earnings (Deficit) Accumulated Other Comprehensive Income (Loss) Total Stockholders' Equity Noncontrolling Interest Total Equity Balance at March 31, 2020 $ 5 $ (973) $ 9,737 $ (780) $ (53) $ 7,936 $ (10) $ 7,926 Dividends declared on common stock — — — (66) — (66) — (66) Effects of stock-based incentive compensation plans — — 16 — — 16 — 16 Net income (loss) — — — 166 — 166 (2) 164 Change in accumulated other comprehensive income (loss) — — — — 1 1 — 1 Other — — 1 2 — 3 — 3 Balance at June 30, 2020 $ 5 $ (973) $ 9,754 $ (678) $ (52) $ 8,056 $ (12) $ 8,044 The following table presents the changes to equity for the six months ended June 30, 2020: Common Treasury Stock Additional Paid-in Capital Retained Earnings (Deficit) Accumulated Other Comprehensive Income (Loss) Total Stockholders' Equity Noncontrolling Interest Total Equity Balance at December 31, 2019 $ 5 $ (973) $ 9,721 $ (764) $ (30) $ 7,959 $ 1 $ 7,960 Dividends declared on common stock — — — (132) — (132) — (132) Effects of stock-based incentive compensation plans — — 30 — — 30 — 30 Net income (loss) — — — 222 — 222 (13) 209 Adoption of accounting standard — — — (4) — (4) — (4) Change in accumulated other comprehensive income (loss) — — — — (22) (22) — (22) Other — — 3 — — 3 — 3 Balance at June 30, 2020 $ 5 $ (973) $ 9,754 $ (678) $ (52) $ 8,056 $ (12) $ 8,044 ________________ (a) Authorized shares totaled 1,800,000,000 at June 30, 2020. Outstanding common shares totaled 488,772,572 and 487,698,111 at June 30, 2020 and December 31, 2019, respectively. Treasury shares totaled 41,043,224 at both June 30, 2020 and December 31, 2019. The following table presents the changes to equity for the three months ended June 30, 2019: Common Treasury Stock 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 $ (1,014) $ 10,119 $ (1,285) $ (21) $ 7,804 $ 2 $ 7,806 Stock repurchase — (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 $ (1,226) $ 10,135 $ (989) $ (21) $ 7,904 $ — $ 7,904 The following table presents the changes to equity for the six months ended June 30, 2019: Common Treasury Stock 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 $ (778) $ 10,107 $ (1,449) $ (22) $ 7,863 $ 4 $ 7,867 Stock repurchase — (448) — — — (448) — (448) Dividends declared on common stock — — — (120) — (120) — (120) Effects of stock-based incentive compensation plans — — 28 — — 28 — 28 Net income — — — 581 — 581 (3) 578 Adoption of accounting standard — — — (2) — (2) — (2) Change in accumulated other comprehensive income (loss) — — — — 1 1 — 1 Other — — — 1 — 1 (1) — Balance at June 30, 2019 $ 5 $ (1,226) $ 10,135 $ (989) $ (21) $ 7,904 $ — $ 7,904 ________________ (a) Authorized shares totaled 1,800,000,000 at June 30, 2019. Outstanding common shares totaled 476,166,856 and 493,215,309 at June 30, 2019 and December 31, 2018, respectively. Treasury shares totaled 51,323,829 and 32,815,783 at June 30, 2019 and December 31, 2018, respectively.

Fair Value Measurements (Notes)

Fair Value Measurements (Notes)	6 Months Ended
	Jun. 30, 2020
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 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 15 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, 2020 December 31, 2019 Level Level Level Reclass Total Level Level Level Reclass Total Assets: Commodity contracts $ 1,033 $ 158 $ 314 $ 36 $ 1,541 $ 1,047 $ 172 $ 239 $ 11 $ 1,469 Interest rate swaps — 86 — — 86 — — — — — Nuclear decommissioning trust – equity securities (c) 523 — — 523 564 — — 564 Nuclear decommissioning trust – debt securities (c) — 588 — 588 — 521 — 521 Sub-total $ 1,556 $ 832 $ 314 $ 36 2,738 $ 1,611 $ 693 $ 239 $ 11 2,554 Assets measured at net asset value (d): Nuclear decommissioning trust – equity securities (c) 355 366 Total assets $ 3,093 $ 2,920 Liabilities: Commodity contracts $ 970 $ 484 $ 200 $ 36 $ 1,690 $ 985 $ 439 $ 313 $ 11 $ 1,748 Interest rate swaps — 455 — — 455 — 177 — — 177 Total liabilities $ 970 $ 939 $ 200 $ 36 $ 2,145 $ 985 $ 616 $ 313 $ 11 $ 1,925 ___________ (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 18. (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 15 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, 2020 and December 31, 2019: June 30, 2020 Fair Value Contract Type (a) Assets Liabilities Total Valuation Technique Significant Unobservable Input Range (b) Average (b) Electricity purchases and sales $ 149 $ (32) $ 117 Valuation Model Hourly price curve shape (c) $ — to $105 $53 MWh Illiquid delivery periods for ERCOT hub power prices and heat rates (d) $ 20 to $120 $73 MWh Options 74 (121) (47) Option Pricing Model Gas to power correlation (e) 25 % to 100% 63% Power and gas volatility (e) 5 % to 675% 341% Financial transmission rights 76 (13) 63 Market Approach (f) Illiquid price differences between settlement points (g) $ (5) to $50 $22 MWh Other (h) 15 (34) (19) Total $ 314 $ (200) $ 114 December 31, 2019 Fair Value Contract Type (a) Assets Liabilities Total Valuation Technique Significant Unobservable Input Range (b) Average (b) Electricity purchases and sales $ 64 $ (53) $ 11 Valuation Model Hourly price curve shape (c) $ — to $115 $58 MWh Illiquid delivery periods for ERCOT hub power prices and heat rates (d) $ 20 to $120 $70 MWh Options 38 (188) (150) Option Pricing Model Gas to power correlation (e) 10 % to 100% 55% Power and gas volatility (e) 5 % to 440% 223% Financial transmission rights 120 (26) 94 Market Approach (f) Illiquid price differences between settlement points (g) $ (10) to $40 $15 MWh Other (h) 17 (46) (29) Total $ 239 $ (313) $ (74) ____________ (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 are referred to as congestion revenue rights in ERCOT and financial transmission rights in PJM, NYISO, ISO-NE and MISO regions. Options consist of physical electricity options, spread options, swaptions and natural gas options. (b) The range of the inputs may be influenced by factors such as time of day, delivery period, season and location. The average represents the arithmetic average of the inputs and is not weighted by the related fair value or notional amount. (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) Primarily based on the 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 historical price differences between settlement points within ERCOT hubs and load zones. (h) Other includes contracts for natural gas, coal and emissions. See the table below for discussion of transfers between Level 2 and Level 3 for the three and six months ended June 30, 2020 and 2019. 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, 2020 and 2019. Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 Net asset (liability) balance at beginning of period $ 28 $ (113) $ (74) $ (135) Total unrealized valuation gains 104 87 98 125 Purchases, issuances and settlements (a): Purchases 34 61 89 79 Issuances (3) (10) (6) (17) Settlements (34) (20) (47) (42) Transfers into Level 3 (b) (2) 3 (1) 5 Transfers out of Level 3 (b) (13) (4) 55 (11) Net change (c) 86 117 188 139 Net asset balance at end of period $ 114 $ 4 $ 114 $ 4 Unrealized valuation gains relating to instruments held at end of period $ 123 $ 92 $ 137 $ 110 ____________ (a) Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received and purchases of Financial Transmission Rights. (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 the three months ended June 30, 2020, transfers out of Level 3 primarily consist of power derivatives where forward pricing inputs have become observable. For the six months ended June 30, 2020, transfers out of Level 3 primarily consist of gas, power and 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 consolidated statements of operations.

Commodity and Other Derivative

Commodity and Other Derivative Contractual Assets and Liabilities (Notes)	6 Months Ended
	Jun. 30, 2020
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 14 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 and to hedge future purchased power costs for our retail operations. 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 consolidated statements of operations 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 consolidated statements of operations 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, 2020 and December 31, 2019. 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, 2020 Derivative Assets Derivative Liabilities Commodity Contracts Interest Rate Swaps Commodity Contracts Interest Rate Swaps Total Current assets $ 1,313 $ 19 $ 18 $ — $ 1,350 Noncurrent assets 208 67 2 — 277 Current liabilities (3) — (1,473) (70) (1,546) Noncurrent liabilities (13) — (201) (385) (599) Net assets (liabilities) $ 1,505 $ 86 $ (1,654) $ (455) $ (518) December 31, 2019 Derivative Assets Derivative Liabilities Commodity Contracts Interest Rate Swaps Commodity Contracts Interest Rate Swaps Total Current assets $ 1,323 $ — $ 10 $ — $ 1,333 Noncurrent assets 136 — — — 136 Current liabilities (1) — (1,510) (18) (1,529) Noncurrent liabilities — — (237) (159) (396) Net assets (liabilities) $ 1,458 $ — $ (1,737) $ (177) $ (456) At June 30, 2020 and December 31, 2019, 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 consolidated statements of operations presentation) Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 Commodity contracts (Operating revenues) $ 6 $ 549 $ 263 $ 776 Commodity contracts (Fuel, purchased power costs and delivery fees) 48 (24) (58) 3 Interest rate swaps (Interest expense and related charges) (29) (108) (207) (183) Net gain (loss) $ 25 $ 417 $ (2) $ 596 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, 2020 December 31, 2019 Derivative Assets Offsetting Instruments (a) Cash Collateral (Received) Pledged (b) Net Amounts Derivative Assets Offsetting Instruments (a) Cash Collateral (Received) Pledged (b) Net Amounts Derivative assets: Commodity contracts $ 1,505 $ (1,171) $ (8) $ 326 $ 1,458 $ (1,113) $ — $ 345 Interest rate swaps 86 (86) — — — — — — Total derivative assets 1,591 (1,257) (8) 326 1,458 (1,113) — 345 Derivative liabilities: Commodity contracts (1,654) 1,171 30 (453) (1,737) 1,113 40 (584) Interest rate swaps (455) 86 — (369) (177) — — (177) Total derivative liabilities (2,109) 1,257 30 (822) (1,914) 1,113 40 (761) Net amounts $ (518) $ — $ 22 $ (496) $ (456) $ — $ 40 $ (416) ____________ (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, and to a lesser extent, initial margin requirements. Derivative Volumes The following table presents the gross notional amounts of derivative volumes at June 30, 2020 and December 31, 2019: June 30, 2020 December 31, 2019 Derivative type Notional Volume Unit of Measure Natural gas (a) 5,395 6,160 Million MMBtu Electricity 436,983 428,367 GWh Financial transmission rights (b) 212,461 199,648 GWh Coal 17 22 Million U.S. tons Fuel oil 165 33 Million gallons Emissions 37 20 Million tons Renewable energy certificates 12 11 Million certificates Interest rate swaps – variable/fixed (c) $ 6,720 $ 6,720 Million U.S. dollars Interest rate swaps – fixed/variable (c) $ 2,120 $ 2,120 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 regions. (c) Includes notional amounts of interest rate swaps with maturity dates through July 2026. 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) $ (930) $ (692) Offsetting fair value under netting arrangements (b) 303 167 Cash collateral and letters of credit 91 67 Liquidity exposure $ (536) $ (458) ____________ (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, 2020, total credit risk exposure to all counterparties related to derivative contracts totaled $1.712 billion (including associated accounts receivable). The net exposure to those counterparties totaled $378 million at June 30, 2020, after taking into effect netting arrangements, setoff provisions and collateral, with the largest net exposure to a single counterparty totaling $80 million. At June 30, 2020, the credit risk exposure to the banking and financial sector represented 79% of the total credit risk exposure and 47% 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, 2020
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 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 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 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 (as defined in the Registration Rights Agreement) 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 on behalf of the selling stockholders totaled less than $1 million during both the three and six months ended June 30, 2020 and 2019. Tax Receivable Agreement On the Effective Date, Vistra 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, 2020
Segment Reporting [Abstract]
Segment Information	SEGMENT INFORMATION The operations of Vistra 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 (CODM) reviews the results of these segments separately and allocates resources to the respective segments as part of our strategic operations. A measure of assets is not applicable, as segment assets are not regularly reviewed by the CODM for evaluating performance or allocating resources. Operational results for four facilities retired in late 2019 were recast from the MISO segment to the Asset Closure segment (see Note 4). The Retail segment is engaged in retail sales of electricity and natural gas to residential, commercial and industrial customers. Substantially all of these activities are conducted by TXU Energy, Ambit, Value Based Brands, Dynegy Energy Services, Homefield Energy, TriEagle Energy, Public Power and U.S. Gas & Electric across 19 states in the U.S. 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 ISO/RTO market. The Asset Closure segment is engaged in the decommissioning and reclamation of retired plants and mines (see Note 4). Separately reporting the Asset Closure segment provides management with better information related to the performance and earnings power of Vistra'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 the commodity risk management activities to the Asset Closure segment for the generation plants that were retired in 2018 and 2019. 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. 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 Retail ERCOT PJM NY/NE MISO Asset Closure Corporate and Other (b) Eliminations Consolidated Operating revenues (a): June 30, 2020 $ 1,956 $ 865 $ 412 $ 131 $ 121 $ — $ 46 $ (1,022) $ 2,509 June 30, 2019 1,421 1,671 686 254 188 58 47 (1,493) 2,832 Depreciation and amortization: June 30, 2020 $ (82) $ (130) $ (165) $ (48) $ (9) $ — $ (21) $ — $ (455) June 30, 2019 (59) (128) (134) (39) (3) — (21) — (384) Operating income (loss): June 30, 2020 $ 232 $ 296 $ (66) $ (18) $ (32) $ (14) $ (21) $ — $ 377 June 30, 2019 (581) 1,047 185 78 46 (27) (19) — 729 Net income (loss): June 30, 2020 $ 229 $ 299 $ (66) $ (18) $ (32) $ (14) $ (234) $ — $ 164 June 30, 2019 (585) 1,056 183 79 46 (26) (399) — 354 Six months ended Retail ERCOT PJM NY/NE MISO Asset Closure Corporate and Other (b) Eliminations Consolidated Operating revenues (a): June 30, 2020 $ 3,864 $ 1,731 $ 1,060 $ 417 $ 263 $ — $ 127 $ (2,095) $ 5,367 June 30, 2019 2,806 2,625 1,391 599 357 143 164 (2,330) 5,755 Depreciation and amortization: June 30, 2020 $ (162) $ (253) $ (303) $ (97) $ (20) $ — $ (40) $ — $ (875) June 30, 2019 (118) (259) (265) (104) (7) — (37) — (790) Operating income (loss): June 30, 2020 $ 329 $ 552 $ 68 $ 10 $ (114) $ (30) $ (49) $ — $ 766 June 30, 2019 (563) 1,335 348 94 67 (51) (12) — 1,218 Net income (loss): June 30, 2020 $ 323 $ 557 $ 53 $ (3) $ (111) $ (31) $ (579) $ — $ 209 June 30, 2019 (571) 1,356 346 100 67 (50) (670) — 578 Capital expenditures, including nuclear fuel and excluding LTSA prepayments and development and growth expenditures: June 30, 2020 $ 1 $ 141 $ 53 $ 14 $ 7 $ — $ 43 $ — $ 259 June 30, 2019 1 161 20 5 15 — 27 — 229 ___________ (a) The following unrealized net gains (losses) from mark-to-market valuations of commodity positions are included in operating revenues: Three months ended Retail ERCOT PJM NY/NE MISO Asset Closure Corporate and Other (b) Eliminations (1) Consolidated June 30, 2020 $ (5) $ 180 $ (76) $ (55) $ (31) $ — $ (8) $ (74) $ (69) June 30, 2019 6 1,050 184 31 67 — 3 (803) $ 538 Six months ended Retail ERCOT PJM NY/NE MISO Asset Closure Corporate and Other (b) Eliminations (1) Consolidated June 30, 2020 $ (5) $ 383 $ 4 $ (24) $ (33) $ — $ (1) $ (193) $ 131 June 30, 2019 5 1,287 276 32 46 — 19 (968) $ 697 ____________ (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.

Supplementary Financial Informa

Supplementary Financial Information (Notes)	6 Months Ended
	Jun. 30, 2020
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, 2020 and 2019, 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 2020 2019 2020 2019 2020 2019 2020 2019 Service cost $ 2 $ 2 $ 4 $ 4 $ — $ — $ — $ — Other costs — — 1 — 2 2 4 4 Net periodic benefit cost $ 2 $ 2 $ 5 $ 4 $ 2 $ 2 $ 4 $ 4 Impairment of Long-Lived Assets In March 2020, we recognized an impairment loss of $52 million related to our Joppa/EEI coal generation facility in Illinois as a result of a significant decrease in the estimated useful life of the facility, reflecting a decrease in the economic forecast of the facility and changes to the operating assumption based on lower forecasted wholesale electricity prices. We also recorded a $32 million impairment to a capacity contract which was linked in part to the Joppa/EEI facility and therefore determined to have a significant decrease in estimated useful life. The impairments are reported in our MISO segment and include a $45 million write-down of property, plant and equipment, a $32 million write-down of intangible assets and a $7 million write-down of inventory. Material impairments may occur in the future at coal generation facilities if forward wholesale electricity prices continue to decline or if additional environmental regulations increase the cost of producing electricity at our generation facilities. Specifically, a resolution to the CCR and/or ELG matters could result in increased operating costs and impact the economic viability of our MISO and PJM coal generation facilities (see Note 12). Interest Expense and Related Charges Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 Interest paid/accrued $ 121 $ 154 $ 249 $ 305 Unrealized mark-to-market net losses on interest rate swaps 18 119 192 199 Amortization of debt issuance costs, discounts and premiums 4 — 8 (2) Debt extinguishment gain (3) (3) (11) (10) Capitalized interest (5) (3) (9) (7) Other 6 7 11 10 Total interest expense and related charges $ 141 $ 274 $ 440 $ 495 The weighted average interest rate applicable to the Vistra Operations Credit Facilities, taking into account the interest rate swaps discussed in Note 11, was 3.53% and 4.03% at June 30, 2020 and 2019. Other Income and Deductions Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 Other income: Insurance settlement (a) $ 2 $ 8 $ 5 $ 19 Funds released from escrow to settle pre-petition claims of our predecessor — — — 9 Interest income 1 3 1 7 All other 2 2 6 4 Total other income $ 5 $ 13 $ 12 $ 39 Other deductions: Loss on disposal of investment in NELP (b) $ 1 $ — $ 29 $ — All other 3 2 6 5 Total other deductions $ 4 $ 2 $ 35 $ 5 ____________ (a) The amount for the three months ended June 30, 2020 reported in the ERCOT segment. For the six months ended June 30, 2020, $3 million reported in the Corporate and Other non-segment and $2 million reported in the ERCOT segment. The amounts for the three and six months ended June 30, 2019 reported in the ERCOT segment. (b) For the six months ended June 30, 2020, loss of $15 million reported in the NY/NE segment and $14 million in the PJM segment. Restricted Cash June 30, 2020 December 31, 2019 Current Assets Noncurrent Assets Current Assets Noncurrent Assets Amounts related to remediation escrow accounts $ 20 $ 24 $ 15 $ 28 Amounts related to restructuring escrow accounts 4 — 43 — Amounts related to Ambit customer deposits — — 19 — Amounts related to Ambit commodity trading agreement — — 62 — Amounts related to Ambit letters of credit (Note 11) 3 — 8 — Total restricted cash $ 27 $ 24 $ 147 $ 28 Trade Accounts Receivable June 30, December 31, Wholesale and retail trade accounts receivable $ 1,310 $ 1,401 Allowance for uncollectible accounts (38) (36) Trade accounts receivable — net $ 1,272 $ 1,365 Gross trade accounts receivable at June 30, 2020 and December 31, 2019 included unbilled retail revenues of $483 million and $494 million, respectively. Allowance for Uncollectible Accounts Receivable Six Months Ended June 30, 2020 2019 Allowance for uncollectible accounts receivable at beginning of period (a) $ 42 $ 19 Increase for bad debt expense 45 29 Decrease for account write-offs (49) (31) Allowance for uncollectible accounts receivable at end of period $ 38 $ 17 ____________ (a) Includes a $6 million increase recorded due to the adoption of ASU 2016-13, Financial Instruments—Credit Losses (see Note 1). Inventories by Major Category June 30, December 31, Materials and supplies $ 274 $ 278 Fuel stock 250 172 Natural gas in storage 17 19 Total inventories $ 541 $ 469 Investments June 30, December 31, Nuclear plant decommissioning trust $ 1,466 $ 1,451 Assets related to employee benefit plans 37 37 Land 49 49 Total investments $ 1,552 $ 1,537 Investment in Unconsolidated Subsidiary 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 December 31, 2019, our investment in NELP totaled $123 million. In December 2019, Dynegy Northeast Generation GP, Inc. and Dynegy Northeast Associates LP, Inc., indirect subsidiaries of Vistra, entered into a transaction agreement with NELP and certain indirect subsidiaries of NextEra Energy, Inc. wherein the indirect subsidiaries of Vistra redeemed their ownership interest in NELP in exchange for 100% ownership interest in NJEA, the company which owns the Sayreville facility. The NELP Transaction was approved by FERC in February 2020, and the NELP Transaction closed on March 2, 2020. As a result of the NELP Transaction, Vistra indirectly owns 100% of the Sayreville facility and no longer has any ownership interest in the Bellingham NEA facility. A loss of $29 million was recognized in connection with the NELP Transaction, reflecting the difference between our derecognized investment in NELP and the value of our acquired 100% interest in North Jersey Energy Associates, which was measured in accordance with ASC 805. The loss is reported in our condensed consolidated statements of operations in other deductions. Equity earnings related to our investment in NELP totaled $3 million for the three months ended June 30, 2019 and $3 million and $9 million for the six months ended June 30, 2020 and 2019, respectively, recorded in equity in earnings (loss) of unconsolidated investment in our condensed consolidated statements of operations. We received distributions totaling $9 million for the three months ended June 30, 2019 and $3 million and $14 million for the six months ended June 30, 2020 and 2019, 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 (and prior to the Effective Date, a subsidiary of TCEH) in the trust fund. Income and expense, including gains and losses associated with the trust fund assets and the decommissioning liability are offset by a corresponding change in a regulatory asset/liability (currently a regulatory asset reported in other noncurrent assets) 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, provided that Vistra complied with PUCT rules and regulations regarding decommissioning trusts. A summary of the fair market value of investments in the fund follows: June 30, December 31, 2019 Debt securities (a) $ 588 $ 521 Equity securities (b) 878 930 Total $ 1,466 $ 1,451 ____________ (a) 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 3.16% and 3.42% at June 30, 2020 and December 31, 2019, respectively, and an average maturity of ten years and nine years at June 30, 2020 and December 31, 2019, respectively. (b) 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, 2020 mature as follows: $194 million in one to five years, $165 million in five to 10 years and $229 million after 10 years. The following table summarizes proceeds from sales of securities and investments in new securities. Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 Proceeds from sales of securities $ 149 $ 214 $ 224 $ 292 Investments in securities $ (154) $ (219) $ (234) $ (302) Property, Plant and Equipment June 30, December 31, Power generation and structures $ 15,479 $ 15,205 Land 623 622 Office and other equipment 171 164 Total 16,273 15,991 Less accumulated depreciation (3,160) (2,553) Net of accumulated depreciation 13,113 13,438 Finance lease right-of-use assets 56 59 Nuclear fuel (net of accumulated amortization of $159 million and $216 million) 211 197 Construction work in progress 501 220 Property, plant and equipment — net $ 13,881 $ 13,914 Depreciation expenses totaled $356 million and $312 million for the three months ended June 30, 2020 and 2019, respectively, and $685 million and $647 million for six months ended June 30, 2020 and 2019, respectively. Asset Retirement and Mining Reclamation Obligations (ARO) These liabilities primarily relate to nuclear generation plant decommissioning, land reclamation related to lignite mining, remediation or closure of coal ash basins, and generation plant 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. We have also identified conditional AROs for asbestos removal and disposal, which are specific to certain generation assets. However, because the period of remediation is indeterminable no removal liabilities have been recognized. At June 30, 2020, the carrying value of our ARO related to our nuclear generation plant decommissioning totaled $1.561 billion, which is higher 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 asset has been recorded to our condensed consolidated balance sheet of $95 million in other noncurrent assets. The following table summarizes the changes to these obligations, reported as AROs (current and noncurrent liabilities) in our condensed consolidated balance sheets, for the six months ended June 30, 2020 and 2019. Six Months Ended June 30, 2020 Six Months Ended June 30, 2019 Nuclear Plant Decom- Mining Land Reclamation Coal Ash and Other Total Nuclear Plant Decom- Mining Land Reclamation Coal Ash and Other Total Liability at beginning of period $ 1,320 $ 410 $ 508 $ 2,238 $ 1,276 $ 442 $ 655 $ 2,373 Additions: Accretion 22 10 13 45 22 11 16 49 Adjustment for change in estimates (a) 219 (4) (2) 213 — (3) (3) (6) Adjustment for obligations assumed through acquisitions — — — — — — (3) (3) Reductions: Payments — (28) (16) (44) — (32) (16) (48) Liability at end of period 1,561 388 503 2,452 1,298 418 649 2,365 Less amounts due currently — (92) (46) (138) — (132) (100) (232) Noncurrent liability at end of period $ 1,561 $ 296 $ 457 $ 2,314 1,298 286 549 2,133 ____________ (a) The adjustment for nuclear plant decommissioning resulted from a new cost estimate completed in the second quarter of 2020. Under applicable accounting standards, the liability is remeasured when significant changes in the amount or timing of cash flows occur, and the PUCT requires a new cost estimate at least every five years. The increase in the liability was driven by changes in assumptions including increased costs for labor, equipment and services and a delay in timing of when the U.S. Department of Energy is estimated to begin accepting spent fuel offsite. 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 (a) $ 324 $ 295 Identifiable intangible liabilities (Note 6) 294 286 Regulatory liability — 131 Finance lease liabilities 79 78 Uncertain tax positions, including accrued interest 10 10 Liability for third-party remediation 37 41 Environmental allowances 53 52 Other accrued expenses 154 96 Total other noncurrent liabilities and deferred credits $ 951 $ 989 ____________ (a) We have applied settlement accounting in 2020 due to distributions exceeding the current period service and interest costs. For the three and six months ended June 30, 2020, the remeasurement of our pension plan in connection with settlement accounting resulted in an increase in the benefit obligation liability of $1 million and $33 million, respectively, pretax other comprehensive loss of zero and $30 million, respectively, and settlement expense of $1 million and $3 million, respectively, recognized as other deductions in our condensed consolidated statements of operations. Fair Value of Debt June 30, 2020 December 31, 2019 Long-term debt (see Note 11): Fair Value Hierarchy Carrying Amount Fair Carrying Amount Fair Long-term debt under the Vistra Operations Credit Facilities Level 2 $ 2,594 $ 2,489 $ 2,715 $ 2,717 Vistra Operations Senior Notes Level 2 6,629 6,890 6,620 6,926 Vistra Senior Notes Level 2 179 173 774 772 Forward Capacity Agreements Level 3 99 99 155 155 Equipment Financing Agreements Level 3 80 80 87 87 Building Financing Level 2 13 13 16 16 Other debt Level 3 4 4 12 12 We determine fair value in accordance with accounting standards as discussed in Note 14. 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 consolidated statements of cash flows to the amounts reported in our condensed consolidated balance sheets at June 30, 2020 and December 31, 2019: June 30, December 31, Cash and cash equivalents $ 382 $ 300 Restricted cash included in current assets 27 147 Restricted cash included in noncurrent assets 24 28 Total cash, cash equivalents and restricted cash $ 433 $ 475 The following table summarizes our supplemental cash flow information for the six months ended June 30, 2020 and 2019: Six Months Ended June 30, 2020 2019 Cash payments related to: Interest paid $ 262 $ 307 Capitalized interest (9) (7) Interest paid (net of capitalized interest) $ 253 $ 300 Income taxes paid (refunds received) (a) $ (32) $ 9 Noncash investing and financing activities: Construction expenditures (b) $ 51 $ 41 Disposition of investment in NELP $ 123 $ — Acquisition of investment in North Jersey Energy Associates $ 90 $ — ____________ (a) For the six months ended June 30, 2020 and 2019, we paid state income taxes of $5 million and $30 million, respectively, and received federal tax refunds of $37 million and $21 million, respectively. (b) Represents end-of-period accruals for ongoing construction projects.

Business And Significant Acco_2

Business And Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2020
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 2019 Form 10-K. The condensed consolidated financial information herein reflects all adjustments which are, in the opinion of management, necessary to fairly state the results for the interim periods presented. All such adjustments are of a normal nature. 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 2019 Form 10-K. The results of operations for an interim period may not give a true indication of results for a full year. All dollar amounts in the financial statements and tables in the notes are stated in millions of 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, judgments 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.

Acquisitions, Merger Transact_2

Acquisitions, Merger Transaction and Business Combination Accounting (Tables)	6 Months Ended
	Jun. 30, 2020
Ambit And Crius Transactions [Member]
Business Acquisition [Line Items]
Schedule of recognized identified assets acquired and liabilities assumed	The following table summarizes the allocation of the purchase price to the fair value amounts recognized for the assets acquired and liabilities assumed related to the Ambit Transaction and Crius Transaction, respectively, as of the Ambit Acquisition Date and Crius Acquisition Date, respectively. The Ambit Transaction purchase price was $555 million (including cash acquired and net working capital), and the Crius Transaction purchase price was $400 million. The Ambit Transaction purchase price allocation is ongoing and is dependent upon final valuation determinations, which have not been completed. The Ambit Transaction preliminary values included below represent our current best estimates for identifiable intangible assets, goodwill and net working capital. The Ambit Transaction purchase price allocation is preliminary and each of the values included below may change materially based upon the receipt of more detailed information, additional analyses and completed valuations. The final purchase price allocation was completed in the second quarter of 2020 for the Crius Transaction and will be completed no later than the third quarter of 2020 for the Ambit Transaction. Ambit Transaction Preliminary Purchase Price Allocation and Crius Transaction Final Purchase Price Allocation Ambit Transaction Crius Transaction Updated Preliminary Purchase Price Allocation Measurement Period Adjustments recorded through Final Measurement Period Adjustments recorded through Cash and cash equivalents $ 49 $ — $ 26 $ — Net working capital 35 6 (9) (42) Accumulated deferred income taxes — — — (36) Identifiable intangible assets 230 (33) 317 23 Goodwill 243 29 243 38 Commodity and other derivative contractual assets 23 — 18 — Other noncurrent assets 13 — 17 (3) Total assets acquired 593 2 612 (20) Identifiable intangible liabilities — — 2 (34) Long-term debt, including amounts due currently — — 140 — Commodity and other derivative contractual liabilities 28 — 40 — Accumulated deferred income taxes — — 14 14 Other noncurrent liabilities and deferred credits 10 2 16 — Total liabilities assumed 38 2 212 (20) Identifiable net assets acquired $ 555 $ — $ 400 $ —

Retirement of Generation Faci_2

Retirement of Generation Facilities (Tables)	6 Months Ended
	Jun. 30, 2020
MISO Segment [Member]
Planned retirements of generation capacity	MISO — In September 2019, we announced the settlement of a lawsuit alleging violations of opacity and particulate matter limits at our Edwards facility in Bartonville, Illinois. As part of the settlement, which was approved by the U.S. District Court for the Central District of Illinois in November 2019, we will retire the Edwards facility by the end of 2022 (see Note 12). In August 2019, we announced the planned retirement of four power plants in Illinois with a total installed nameplate generation capacity of 2,068 MW. We retired these units due to changes in the Illinois multi-pollutant standard rule (MPS rule) that require us to retire approximately 2,000 MW of generation capacity (see Note 12). In light of the provisions of the Federal Power Act and the FERC regulations thereunder, the affected subsidiaries of Vistra identified the retired units by analyzing the economics of each of our Illinois plants and designating the least economic units for retirement. Expected plant retirement expenses of $47 million, driven by severance costs, were accrued in the three months ended September 30, 2019 and were included primarily in operating costs of our Asset Closure segment. In August 2019, we remeasured our pension and OPEB plans resulting in an increase to the benefit obligation liability of $21 million, pretax other comprehensive loss of $18 million and curtailment expense of $3 million recognized as other deductions in our condensed consolidated statements of operations. The following table details the units in Illinois totaling 2,653 MW that have been or will be retired. Operational results for retired plants are included in the Asset Closure segment, which is engaged in the decommissioning and reclamation of retired plants and mines. Name Location Fuel Type Net Generation Capacity (MW) Number of Units Dates Units Retired or Coffeen Coffeen, IL Coal 915 2 November 1, 2019 Duck Creek Canton, IL Coal 425 1 December 15, 2019 Havana Havana, IL Coal 434 1 November 1, 2019 Hennepin Hennepin, IL Coal 294 2 November 1, 2019 Edwards Bartonville, IL Coal 585 2 By the end of 2022 Total 2,653 8

Revenue (Tables)

Revenue (Tables)	6 Months Ended
	Jun. 30, 2020
Revenue Recognition and Deferred Revenue [Abstract]
Disaggregation of revenue	Three Months Ended June 30, 2020 Retail ERCOT PJM NY/NE MISO Asset CAISO/Eliminations Consolidated Revenue from contracts with customers: Retail energy charge in ERCOT $ 1,411 $ — $ — $ — $ — $ — $ — $ 1,411 Retail energy charge in Northeast/Midwest 540 — — — — — — 540 Wholesale generation revenue from ISO/RTO — 76 71 16 3 — 13 179 Capacity revenue from ISO/RTO — — 15 10 4 — — 29 Revenue from other wholesale contracts — 63 137 26 54 — 21 301 Total revenue from contracts with customers 1,951 139 223 52 61 — 34 2,460 Other revenues: Intangible amortization (5) — — — (7) — — (12) Hedging and other revenues (a) 10 62 (6) (10) (6) — 11 61 Affiliate sales — 664 195 89 73 — (1,021) — Total other revenues 5 726 189 79 60 — (1,010) 49 Total revenues $ 1,956 $ 865 $ 412 $ 131 $ 121 $ — $ (976) $ 2,509 ____________ (a) Includes $69 million of unrealized net losses from mark-to-market valuations of commodity positions. See Note 17 for unrealized net gains (losses) by segment. Three Months Ended June 30, 2019 Retail ERCOT PJM NY/NE MISO Asset 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 33 43 22 497 Capacity revenue from ISO/RTO — — 53 72 8 3 — 136 Revenue from other wholesale contracts — 52 87 6 40 1 4 190 Total revenue from contracts with customers 1,406 240 270 159 81 47 26 2,229 Other revenues: Intangible amortization (10) — — (1) (4) — 1 (14) Hedging and other revenues (a) 25 404 81 61 15 11 20 617 Affiliate sales — 1,027 335 35 96 — (1,493) — Total other revenues 15 1,431 416 95 107 11 (1,472) 603 Total revenues $ 1,421 $ 1,671 $ 686 $ 254 $ 188 $ 58 $ (1,446) $ 2,832 ____________ (a) Includes $538 million of unrealized net gains from mark-to-market valuations of commodity positions. See Note 17 for unrealized net gains (losses) by segment. Six Months Ended June 30, 2020 Retail ERCOT PJM NY/NE MISO Asset CAISO/Eliminations Consolidated Revenue from contracts with customers: Retail energy charge in ERCOT $ 2,665 $ — $ — $ — $ — $ — $ — $ 2,665 Retail energy charge in Northeast/Midwest 1,180 — — — — — — 1,180 Wholesale generation revenue from ISO/RTO — 174 148 58 17 — 46 443 Capacity revenue from ISO/RTO — — 30 35 9 — — 74 Revenue from other wholesale contracts — 113 288 38 103 — 25 567 Total revenue from contracts with customers 3,845 287 466 131 129 — 71 4,929 Other revenues: Intangible amortization (8) — — — (11) — — (19) Hedging and other revenues (a) 27 313 32 29 2 — 54 457 Affiliate sales — 1,131 562 257 143 — (2,093) — Total other revenues 19 1,444 594 286 134 — (2,039) 438 Total revenues $ 3,864 $ 1,731 $ 1,060 $ 417 $ 263 $ — $ (1,968) $ 5,367 ____________ (a) Includes $131 million of unrealized net gains from mark-to-market valuations of commodity positions. See Note 17 for unrealized net gains (losses) by segment. Six Months Ended June 30, 2019 Retail ERCOT PJM NY/NE MISO Asset 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 — 435 351 276 104 110 95 1,371 Capacity revenue from ISO/RTO — — 120 152 18 6 — 296 Revenue from other wholesale contracts — 97 159 12 55 2 6 331 Total revenue from contracts with customers 2,779 532 630 440 177 118 101 4,777 Other revenues: Intangible amortization (19) — — (3) (9) — 2 (29) Hedging and other revenues (a) 46 562 171 113 29 25 61 1,007 Affiliate sales — 1,531 590 49 160 — (2,330) — Total other revenues 27 2,093 761 159 180 25 (2,267) 978 Total revenues $ 2,806 $ 2,625 $ 1,391 $ 599 $ 357 $ 143 $ (2,166) $ 5,755 ____________ (a) Includes $697 million of unrealized net gains from mark-to-market valuations of commodity positions. See Note 17 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, 2019 Trade accounts receivable from contracts with customers — net $ 1,197 $ 1,246 Other trade accounts receivable — net 75 119 Total trade accounts receivable — net $ 1,272 $ 1,365

Goodwill and Identifiable Int_2

Goodwill and Identifiable Intangible Assets and Liabilities (Tables)	6 Months Ended
	Jun. 30, 2020
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of goodwill	The following table provides information regarding our goodwill balance. There have been no impairments of goodwill. Balance at December 31, 2019 $ 2,553 Measurement period adjustments recorded in connection with the Ambit Transaction 29 Measurement period adjustments recorded in connection with the Crius Transaction (14) Balance at June 30, 2020 $ 2,568
Schedule of identifiable intangible assets	Identifiable intangible assets are comprised of the following: June 30, 2020 December 31, 2019 Identifiable Intangible Asset Gross Carrying Amount Accumulated Net Gross Carrying Amount Accumulated Net Retail customer relationship $ 2,087 $ 1,302 $ 785 $ 2,078 $ 1,151 $ 927 Software and other technology-related assets 364 151 213 341 125 216 Retail and wholesale contracts 272 195 77 315 182 133 Contractual service agreements (a) 55 2 53 59 5 54 Other identifiable intangible assets (b) 45 17 28 40 15 25 Total identifiable intangible assets subject to amortization $ 2,823 $ 1,667 1,156 $ 2,833 $ 1,478 1,355 Retail trade names (not subject to amortization) 1,374 1,391 Mineral interests (not currently subject to amortization) 2 2 Total identifiable intangible assets $ 2,532 $ 2,748 ____________ (a) At June 30, 2020, 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 (emissions allowances and renewable energy certificates).
Schedule of identifiable intangible liabilities	Identifiable intangible liabilities are comprised of the following: Identifiable Intangible Liability June 30, December 31, 2019 Contractual service agreements $ 127 $ 110 Purchase and sale of power and capacity 92 100 Fuel and transportation purchase contracts 75 76 Total identifiable intangible liabilities $ 294 $ 286
Schedule of amortization expense related to intangible assets	Expense related to finite-lived identifiable intangible assets and liabilities (including the classification in the condensed consolidated statements of operations) consisted of: Identifiable Intangible Assets and Liabilities Condensed Consolidated Statements of Operations Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 Retail customer relationship Depreciation and amortization $ 77 $ 55 $ 151 $ 111 Software and other technology-related assets Depreciation and amortization 21 15 38 29 Retail and wholesale contracts/purchase and sale/fuel and transportation contracts Operating revenues/fuel, purchased power costs and delivery fees 13 12 15 24 Other identifiable intangible assets Operating revenues/fuel, purchased power costs and delivery fees/depreciation and amortization 44 15 96 39 Total intangible asset expense (a) $ 155 $ 97 $ 300 $ 203 ____________ (a) Amounts recorded in depreciation and amortization totaled $99 million and $72 million for the three months ended June 30, 2020 and 2019, respectively, and $190 million and $141 million for the six months ended June 30, 2020 and 2019, respectively. Amounts exclude contractual services agreements. Amounts include all expenses associated with environmental allowances including expenses accrued to comply with emissions allowance programs and renewable portfolio standards which are presented in fuel, purchased power costs and delivery fees on our condensed consolidated statements of operations. Emissions allowance obligations are accrued as associated electricity is generated and renewable energy credit obligations are accrued as retail electricity delivery occurs.
Schedule of estimated amortization expense of identifiable intangible assets	As of June 30, 2020, 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 2020 $ 369 2021 $ 257 2022 $ 161 2023 $ 116 2024 $ 78

Income Taxes (Tables)

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2020
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, 2020 2019 2020 2019 Income before income taxes $ 232 $ 502 $ 293 $ 803 Income tax expense $ (68) $ (148) $ (84) $ (225) Effective tax rate 29.3 % 29.5 % 28.7 % 28.0 %

Tax Receivable Agreement Obli_2

Tax Receivable Agreement Obligation (Tables)	6 Months Ended
	Jun. 30, 2020
Income Tax Disclosure [Abstract]
Schedule of 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, 2020 and 2019: Six Months Ended June 30, 2020 2019 TRA obligation at the beginning of the period $ 455 $ 420 Accretion expense 34 31 Changes in tax assumptions impacting timing of payments (a) (20) (67) Impacts of Tax Receivable Agreement 14 (36) TRA obligation at the end of the period 469 384 Less amounts due currently (1) — TRA obligation at the end of the period (noncurrent) $ 468 $ 384 ____________ (a) During the three and six months ended June 30, 2020, we recorded decreases to the carrying value of the TRA obligation totaling $11 million and $20 million, respectively, as a result of adjustments to forecasted taxable income, including the impacts of the CARES Act changes to Section 163(j) percentage limitation amount. During the three and six months ended June 30, 2019, we recorded decreases to the carrying value of the TRA obligation totaling $48 million and $67 million, respectively, as a result of adjustments to forecasted taxable income and higher net operating losses acquired in the Merger.

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2020
Earnings Per Share [Abstract]
Schedule of earnings per share, basic and diluted	Basic earnings per share available to common stockholders 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, 2020 2019 2020 2019 Net income attributable to common stock — basic $ 166 $ 356 $ 222 $ 581 Weighted average shares of common stock outstanding — basic (a) 488,680,442 499,778,235 488,312,503 499,213,522 Net income per weighted average share of common stock outstanding — basic $ 0.34 $ 0.71 $ 0.45 $ 1.16 Dilutive securities: Stock-based incentive compensation plan 1,788,293 7,722,148 2,397,429 8,035,398 Weighted average shares of common stock outstanding — diluted 490,468,735 507,500,383 490,709,932 507,248,920 Net income per weighted average share of common stock outstanding — diluted $ 0.34 $ 0.70 $ 0.45 $ 1.15

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2020
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 $ 2,586 $ 2,700 Vistra Operations Senior Secured Notes: 3.550% Senior Secured Notes, due July 15, 2024 1,500 1,500 3.700% Senior Secured Notes, due January 30, 2027 800 800 4.300% Senior Secured Notes, due July 15, 2029 800 800 Total Vistra Operations Senior Secured Notes 3,100 3,100 Vistra Operations Senior Unsecured Notes: 5.500% Senior Unsecured Notes, due September 1, 2026 1,000 1,000 5.625% Senior Unsecured Notes, due February 15, 2027 1,300 1,300 5.000% Senior Unsecured Notes, due July 31, 2027 1,300 1,300 Total Vistra Operations Senior Unsecured Notes 3,600 3,600 Vistra Senior Unsecured Notes: 5.875% Senior Unsecured Notes, due June 1, 2023 — 500 8.000% Senior Unsecured Notes, due January 15, 2025 — 81 8.125% Senior Unsecured Notes, due January 30, 2026 (a) 166 166 Total Vistra Senior Unsecured Notes 166 747 Other: Forward Capacity Agreements 101 161 Equipment Financing Agreements 91 99 8.82% Building Financing due semiannually through February 11, 2022 (b) 13 15 Other 4 12 Total other long-term debt 209 287 Unamortized debt premiums, discounts and issuance costs (c) (63) (55) Total long-term debt including amounts due currently 9,598 10,379 Less amounts due currently (337) (277) Total long-term debt less amounts due currently $ 9,261 $ 10,102 ____________ (a) Vistra redeemed all of its outstanding 8.125% senior unsecured notes due 2026 in July 2020. (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.
Schedule of line of credit facilities	The Vistra Operations Credit Facilities and related available capacity at June 30, 2020 are presented below. June 30, 2020 Vistra Operations Credit Facilities Maturity Date Facility Cash Available Revolving Credit Facility (a) June 14, 2023 $ 2,725 $ 550 $ 1,287 Term Loan B-3 Facility December 31, 2025 2,586 2,586 — Total Vistra Operations Credit Facilities $ 5,311 $ 3,136 $ 1,287 ___________ (a) Facility to be used for general corporate purposes. Facility includes a $2.35 billion letter of credit sub-facility, of which $888 million of letters of credit were outstanding at June 30, 2020 and which reduce our available capacity. Cash borrowings under the Revolving Credit Facility are reported in short-term borrowings in our condensed consolidated balance sheets.
Schedule of interest rate derivatives	Interest Rate Swaps — Vistra employs interest rate swaps to hedge our exposure to variable rate debt. As of June 30, 2020, Vistra has entered into the following series of interest rate swap transactions. Notional Amount Expiration Date Rate Range Swapped to fixed $3,000 July 2023 3.67 % - 3.91% Swapped to variable $700 July 2023 3.20 % - 3.23% Swapped to fixed $720 February 2024 3.71 % - 3.72% Swapped to variable $720 February 2024 3.20 % - 3.20% Swapped to fixed (a) $3,000 July 2026 4.72 % - 4.79% Swapped to variable (a) $700 July 2026 3.28 % - 3.33% ____________ (a) Effective from July 2023 through July 2026.
Schedule of debt securities issued, secured	In the six months ended June 30, 2019, Vistra Operations issued and sold $2.0 billion aggregate principal amount of senior secured notes (June 2019 Senior Secured Notes) in offerings to eligible purchasers under Rule 144A and Regulation S under the Securities Act (June 2019 Senior Secured Notes Offerings) consisting of the following: Senior Secured Notes Maturity Year Interest Terms June 2019 3.550% Senior Secured Notes 2024 January 15 and July 15 $ 1,200 4.300% Senior Secured Notes 2029 January 15 and July 15 800 Total senior secured notes $ 2,000 Net proceeds $ 1,976 Debt issuance and other fees (b) $ 20 ___________ (a) The June 2019 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. Net proceeds, 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 Facility's Term Loan B Facility. (b) Capitalized as a reduction in the carrying amount of the debt.
Schedule of debt securities issued, unsecured	In the six months ended June 30, 2019, Vistra Operations issued and sold $2.6 billion aggregate principal amount of senior unsecured notes in offerings (the February 2019 Senior Unsecured Notes Offering and the June 2019 Senior Unsecured Notes Offering) to eligible purchasers under Rule 144A and Regulation S under the Securities Act consisting of the following: Senior Unsecured Notes Maturity Year Interest Terms February 2019 Senior Unsecured Notes Offering (a) June 2019 5.625% Senior Unsecured Notes 2027 February 15 and August 15 1,300 — 5.000% Senior Unsecured Notes 2027 January 31 and July 31 — 1,300 Total $ 1,300 $ 1,300 Net Proceeds $ 1,287 $ 1,287 Debt issuance and other fees (c) $ 16 $ 13 ___________ (a) The 5.625% senior unsecured notes due 2027 (the February 2019 Senior Unsecured 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. Net proceeds, 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 (defined below) and (ii) the redemption of approximately $35 million aggregate principal amount of our 7.375% senior unsecured notes due 2022 (7.375% senior notes) and approximately $25 million aggregate principal amount of our outstanding 8.034% senior unsecured notes due 2024 (8.034% senior notes). (b) The 5.000% senior unsecured notes due 2027 (the June 2019 Senior Unsecured 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. Net proceeds, 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 (defined below) and (ii) the redemption of approximately $306 million of our outstanding 7.375% senior notes and approximately $87 million of our 7.625% senior unsecured notes due 2024 (7.625% senior notes) in July 2019. We recorded an extinguishment gain of $2 million on the redemptions in the six months ended June 30, 2019. (c) Capitalized as a reduction in the carrying amount of the debt.
Schedule of maturities of long-term debt	Long-term debt maturities at June 30, 2020 are as follows: June 30, 2020 Remainder of 2020 $ 263 2021 96 2022 44 2023 40 2024 1,540 Thereafter 7,678 Unamortized premiums, discounts and debt issuance costs (63) Total long-term debt, including amounts due currently $ 9,598

Equity (Tables)

Equity (Tables)	6 Months Ended
	Jun. 30, 2020
Stockholders' Equity Note [Abstract]
Schedule of stockholders equity	Equity The following table presents the changes to equity for the three months ended June 30, 2020: Common Treasury Stock Additional Paid-in Capital Retained Earnings (Deficit) Accumulated Other Comprehensive Income (Loss) Total Stockholders' Equity Noncontrolling Interest Total Equity Balance at March 31, 2020 $ 5 $ (973) $ 9,737 $ (780) $ (53) $ 7,936 $ (10) $ 7,926 Dividends declared on common stock — — — (66) — (66) — (66) Effects of stock-based incentive compensation plans — — 16 — — 16 — 16 Net income (loss) — — — 166 — 166 (2) 164 Change in accumulated other comprehensive income (loss) — — — — 1 1 — 1 Other — — 1 2 — 3 — 3 Balance at June 30, 2020 $ 5 $ (973) $ 9,754 $ (678) $ (52) $ 8,056 $ (12) $ 8,044 The following table presents the changes to equity for the six months ended June 30, 2020: Common Treasury Stock Additional Paid-in Capital Retained Earnings (Deficit) Accumulated Other Comprehensive Income (Loss) Total Stockholders' Equity Noncontrolling Interest Total Equity Balance at December 31, 2019 $ 5 $ (973) $ 9,721 $ (764) $ (30) $ 7,959 $ 1 $ 7,960 Dividends declared on common stock — — — (132) — (132) — (132) Effects of stock-based incentive compensation plans — — 30 — — 30 — 30 Net income (loss) — — — 222 — 222 (13) 209 Adoption of accounting standard — — — (4) — (4) — (4) Change in accumulated other comprehensive income (loss) — — — — (22) (22) — (22) Other — — 3 — — 3 — 3 Balance at June 30, 2020 $ 5 $ (973) $ 9,754 $ (678) $ (52) $ 8,056 $ (12) $ 8,044 ________________ (a) Authorized shares totaled 1,800,000,000 at June 30, 2020. Outstanding common shares totaled 488,772,572 and 487,698,111 at June 30, 2020 and December 31, 2019, respectively. Treasury shares totaled 41,043,224 at both June 30, 2020 and December 31, 2019. The following table presents the changes to equity for the three months ended June 30, 2019: Common Treasury Stock 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 $ (1,014) $ 10,119 $ (1,285) $ (21) $ 7,804 $ 2 $ 7,806 Stock repurchase — (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 $ (1,226) $ 10,135 $ (989) $ (21) $ 7,904 $ — $ 7,904 The following table presents the changes to equity for the six months ended June 30, 2019: Common Treasury Stock 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 $ (778) $ 10,107 $ (1,449) $ (22) $ 7,863 $ 4 $ 7,867 Stock repurchase — (448) — — — (448) — (448) Dividends declared on common stock — — — (120) — (120) — (120) Effects of stock-based incentive compensation plans — — 28 — — 28 — 28 Net income — — — 581 — 581 (3) 578 Adoption of accounting standard — — — (2) — (2) — (2) Change in accumulated other comprehensive income (loss) — — — — 1 1 — 1 Other — — — 1 — 1 (1) — Balance at June 30, 2019 $ 5 $ (1,226) $ 10,135 $ (989) $ (21) $ 7,904 $ — $ 7,904 ________________ (a) Authorized shares totaled 1,800,000,000 at June 30, 2019. Outstanding common shares totaled 476,166,856 and 493,215,309 at June 30, 2019 and December 31, 2018, respectively. Treasury shares totaled 51,323,829 and 32,815,783 at June 30, 2019 and December 31, 2018, respectively.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2020
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, 2020 December 31, 2019 Level Level Level Reclass Total Level Level Level Reclass Total Assets: Commodity contracts $ 1,033 $ 158 $ 314 $ 36 $ 1,541 $ 1,047 $ 172 $ 239 $ 11 $ 1,469 Interest rate swaps — 86 — — 86 — — — — — Nuclear decommissioning trust – equity securities (c) 523 — — 523 564 — — 564 Nuclear decommissioning trust – debt securities (c) — 588 — 588 — 521 — 521 Sub-total $ 1,556 $ 832 $ 314 $ 36 2,738 $ 1,611 $ 693 $ 239 $ 11 2,554 Assets measured at net asset value (d): Nuclear decommissioning trust – equity securities (c) 355 366 Total assets $ 3,093 $ 2,920 Liabilities: Commodity contracts $ 970 $ 484 $ 200 $ 36 $ 1,690 $ 985 $ 439 $ 313 $ 11 $ 1,748 Interest rate swaps — 455 — — 455 — 177 — — 177 Total liabilities $ 970 $ 939 $ 200 $ 36 $ 2,145 $ 985 $ 616 $ 313 $ 11 $ 1,925 ___________ (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 18. (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, 2020 and December 31, 2019: June 30, 2020 Fair Value Contract Type (a) Assets Liabilities Total Valuation Technique Significant Unobservable Input Range (b) Average (b) Electricity purchases and sales $ 149 $ (32) $ 117 Valuation Model Hourly price curve shape (c) $ — to $105 $53 MWh Illiquid delivery periods for ERCOT hub power prices and heat rates (d) $ 20 to $120 $73 MWh Options 74 (121) (47) Option Pricing Model Gas to power correlation (e) 25 % to 100% 63% Power and gas volatility (e) 5 % to 675% 341% Financial transmission rights 76 (13) 63 Market Approach (f) Illiquid price differences between settlement points (g) $ (5) to $50 $22 MWh Other (h) 15 (34) (19) Total $ 314 $ (200) $ 114 December 31, 2019 Fair Value Contract Type (a) Assets Liabilities Total Valuation Technique Significant Unobservable Input Range (b) Average (b) Electricity purchases and sales $ 64 $ (53) $ 11 Valuation Model Hourly price curve shape (c) $ — to $115 $58 MWh Illiquid delivery periods for ERCOT hub power prices and heat rates (d) $ 20 to $120 $70 MWh Options 38 (188) (150) Option Pricing Model Gas to power correlation (e) 10 % to 100% 55% Power and gas volatility (e) 5 % to 440% 223% Financial transmission rights 120 (26) 94 Market Approach (f) Illiquid price differences between settlement points (g) $ (10) to $40 $15 MWh Other (h) 17 (46) (29) Total $ 239 $ (313) $ (74) ____________ (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 are referred to as congestion revenue rights in ERCOT and financial transmission rights in PJM, NYISO, ISO-NE and MISO regions. Options consist of physical electricity options, spread options, swaptions and natural gas options. (b) The range of the inputs may be influenced by factors such as time of day, delivery period, season and location. The average represents the arithmetic average of the inputs and is not weighted by the related fair value or notional amount. (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) Primarily based on the 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 historical price differences between settlement points within ERCOT hubs and load zones. (h) Other includes contracts for natural gas, coal 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, 2020 and 2019. Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 Net asset (liability) balance at beginning of period $ 28 $ (113) $ (74) $ (135) Total unrealized valuation gains 104 87 98 125 Purchases, issuances and settlements (a): Purchases 34 61 89 79 Issuances (3) (10) (6) (17) Settlements (34) (20) (47) (42) Transfers into Level 3 (b) (2) 3 (1) 5 Transfers out of Level 3 (b) (13) (4) 55 (11) Net change (c) 86 117 188 139 Net asset balance at end of period $ 114 $ 4 $ 114 $ 4 Unrealized valuation gains relating to instruments held at end of period $ 123 $ 92 $ 137 $ 110 ____________ (a) Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received and purchases of Financial Transmission Rights. (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 the three months ended June 30, 2020, transfers out of Level 3 primarily consist of power derivatives where forward pricing inputs have become observable. For the six months ended June 30, 2020, transfers out of Level 3 primarily consist of gas, power and 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 consolidated statements of operations.

Commodity and Other Derivativ_2

Commodity and Other Derivative Contractual Assets and Liabilities (Tables)	6 Months Ended
	Jun. 30, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of commodity and other derivative contractual assets and liabilities as reported in the balance sheets	ubstantially 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, 2020 and December 31, 2019. 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, 2020 Derivative Assets Derivative Liabilities Commodity Contracts Interest Rate Swaps Commodity Contracts Interest Rate Swaps Total Current assets $ 1,313 $ 19 $ 18 $ — $ 1,350 Noncurrent assets 208 67 2 — 277 Current liabilities (3) — (1,473) (70) (1,546) Noncurrent liabilities (13) — (201) (385) (599) Net assets (liabilities) $ 1,505 $ 86 $ (1,654) $ (455) $ (518) December 31, 2019 Derivative Assets Derivative Liabilities Commodity Contracts Interest Rate Swaps Commodity Contracts Interest Rate Swaps Total Current assets $ 1,323 $ — $ 10 $ — $ 1,333 Noncurrent assets 136 — — — 136 Current liabilities (1) — (1,510) (18) (1,529) Noncurrent liabilities — — (237) (159) (396) Net assets (liabilities) $ 1,458 $ — $ (1,737) $ (177) $ (456)
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 consolidated statements of operations presentation) Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 Commodity contracts (Operating revenues) $ 6 $ 549 $ 263 $ 776 Commodity contracts (Fuel, purchased power costs and delivery fees) 48 (24) (58) 3 Interest rate swaps (Interest expense and related charges) (29) (108) (207) (183) Net gain (loss) $ 25 $ 417 $ (2) $ 596
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, 2020 December 31, 2019 Derivative Assets Offsetting Instruments (a) Cash Collateral (Received) Pledged (b) Net Amounts Derivative Assets Offsetting Instruments (a) Cash Collateral (Received) Pledged (b) Net Amounts Derivative assets: Commodity contracts $ 1,505 $ (1,171) $ (8) $ 326 $ 1,458 $ (1,113) $ — $ 345 Interest rate swaps 86 (86) — — — — — — Total derivative assets 1,591 (1,257) (8) 326 1,458 (1,113) — 345 Derivative liabilities: Commodity contracts (1,654) 1,171 30 (453) (1,737) 1,113 40 (584) Interest rate swaps (455) 86 — (369) (177) — — (177) Total derivative liabilities (2,109) 1,257 30 (822) (1,914) 1,113 40 (761) Net amounts $ (518) $ — $ 22 $ (496) $ (456) $ — $ 40 $ (416) ____________ (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, and to a lesser extent, initial margin requirements.
Schedule of gross notional amounts of derivative volumes	The following table presents the gross notional amounts of derivative volumes at June 30, 2020 and December 31, 2019: June 30, 2020 December 31, 2019 Derivative type Notional Volume Unit of Measure Natural gas (a) 5,395 6,160 Million MMBtu Electricity 436,983 428,367 GWh Financial transmission rights (b) 212,461 199,648 GWh Coal 17 22 Million U.S. tons Fuel oil 165 33 Million gallons Emissions 37 20 Million tons Renewable energy certificates 12 11 Million certificates Interest rate swaps – variable/fixed (c) $ 6,720 $ 6,720 Million U.S. dollars Interest rate swaps – fixed/variable (c) $ 2,120 $ 2,120 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 regions. (c) Includes notional amounts of interest rate swaps with maturity dates through July 2026.
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) $ (930) $ (692) Offsetting fair value under netting arrangements (b) 303 167 Cash collateral and letters of credit 91 67 Liquidity exposure $ (536) $ (458) ____________ (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, 2020
Segment Reporting [Abstract]
Schedule of segment reporting information, by segment	Three months ended Retail ERCOT PJM NY/NE MISO Asset Closure Corporate and Other (b) Eliminations Consolidated Operating revenues (a): June 30, 2020 $ 1,956 $ 865 $ 412 $ 131 $ 121 $ — $ 46 $ (1,022) $ 2,509 June 30, 2019 1,421 1,671 686 254 188 58 47 (1,493) 2,832 Depreciation and amortization: June 30, 2020 $ (82) $ (130) $ (165) $ (48) $ (9) $ — $ (21) $ — $ (455) June 30, 2019 (59) (128) (134) (39) (3) — (21) — (384) Operating income (loss): June 30, 2020 $ 232 $ 296 $ (66) $ (18) $ (32) $ (14) $ (21) $ — $ 377 June 30, 2019 (581) 1,047 185 78 46 (27) (19) — 729 Net income (loss): June 30, 2020 $ 229 $ 299 $ (66) $ (18) $ (32) $ (14) $ (234) $ — $ 164 June 30, 2019 (585) 1,056 183 79 46 (26) (399) — 354 Six months ended Retail ERCOT PJM NY/NE MISO Asset Closure Corporate and Other (b) Eliminations Consolidated Operating revenues (a): June 30, 2020 $ 3,864 $ 1,731 $ 1,060 $ 417 $ 263 $ — $ 127 $ (2,095) $ 5,367 June 30, 2019 2,806 2,625 1,391 599 357 143 164 (2,330) 5,755 Depreciation and amortization: June 30, 2020 $ (162) $ (253) $ (303) $ (97) $ (20) $ — $ (40) $ — $ (875) June 30, 2019 (118) (259) (265) (104) (7) — (37) — (790) Operating income (loss): June 30, 2020 $ 329 $ 552 $ 68 $ 10 $ (114) $ (30) $ (49) $ — $ 766 June 30, 2019 (563) 1,335 348 94 67 (51) (12) — 1,218 Net income (loss): June 30, 2020 $ 323 $ 557 $ 53 $ (3) $ (111) $ (31) $ (579) $ — $ 209 June 30, 2019 (571) 1,356 346 100 67 (50) (670) — 578 Capital expenditures, including nuclear fuel and excluding LTSA prepayments and development and growth expenditures: June 30, 2020 $ 1 $ 141 $ 53 $ 14 $ 7 $ — $ 43 $ — $ 259 June 30, 2019 1 161 20 5 15 — 27 — 229 ___________ (a) The following unrealized net gains (losses) from mark-to-market valuations of commodity positions are included in operating revenues: Three months ended Retail ERCOT PJM NY/NE MISO Asset Closure Corporate and Other (b) Eliminations (1) Consolidated June 30, 2020 $ (5) $ 180 $ (76) $ (55) $ (31) $ — $ (8) $ (74) $ (69) June 30, 2019 6 1,050 184 31 67 — 3 (803) $ 538 Six months ended Retail ERCOT PJM NY/NE MISO Asset Closure Corporate and Other (b) Eliminations (1) Consolidated June 30, 2020 $ (5) $ 383 $ 4 $ (24) $ (33) $ — $ (1) $ (193) $ 131 June 30, 2019 5 1,287 276 32 46 — 19 (968) $ 697 ____________ (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.

Supplementary Financial Infor_2

Supplementary Financial Information (Tables)	6 Months Ended
	Jun. 30, 2020
Supplementary Financial Information [Abstract]
Schedule of components of net benefit cost	Pension and OPEB Plans — Components of Net Benefit Cost For the three and six months ended June 30, 2020 and 2019, 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 2020 2019 2020 2019 2020 2019 2020 2019 Service cost $ 2 $ 2 $ 4 $ 4 $ — $ — $ — $ — Other costs — — 1 — 2 2 4 4 Net periodic benefit cost $ 2 $ 2 $ 5 $ 4 $ 2 $ 2 $ 4 $ 4
Schedule of interest expense and related charges	Interest Expense and Related Charges Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 Interest paid/accrued $ 121 $ 154 $ 249 $ 305 Unrealized mark-to-market net losses on interest rate swaps 18 119 192 199 Amortization of debt issuance costs, discounts and premiums 4 — 8 (2) Debt extinguishment gain (3) (3) (11) (10) Capitalized interest (5) (3) (9) (7) Other 6 7 11 10 Total interest expense and related charges $ 141 $ 274 $ 440 $ 495
Schedule of other income and deductions	Other Income and Deductions Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 Other income: Insurance settlement (a) $ 2 $ 8 $ 5 $ 19 Funds released from escrow to settle pre-petition claims of our predecessor — — — 9 Interest income 1 3 1 7 All other 2 2 6 4 Total other income $ 5 $ 13 $ 12 $ 39 Other deductions: Loss on disposal of investment in NELP (b) $ 1 $ — $ 29 $ — All other 3 2 6 5 Total other deductions $ 4 $ 2 $ 35 $ 5 ____________ (a) The amount for the three months ended June 30, 2020 reported in the ERCOT segment. For the six months ended June 30, 2020, $3 million reported in the Corporate and Other non-segment and $2 million reported in the ERCOT segment. The amounts for the three and six months ended June 30, 2019 reported in the ERCOT segment. (b) For the six months ended June 30, 2020, loss of $15 million reported in the NY/NE segment and $14 million in the PJM segment.
Schedule of restricted cash	Restricted Cash June 30, 2020 December 31, 2019 Current Assets Noncurrent Assets Current Assets Noncurrent Assets Amounts related to remediation escrow accounts $ 20 $ 24 $ 15 $ 28 Amounts related to restructuring escrow accounts 4 — 43 — Amounts related to Ambit customer deposits — — 19 — Amounts related to Ambit commodity trading agreement — — 62 — Amounts related to Ambit letters of credit (Note 11) 3 — 8 — Total restricted cash $ 27 $ 24 $ 147 $ 28
Schedule of accounts, notes, loans and financing receivable	Trade Accounts Receivable June 30, December 31, Wholesale and retail trade accounts receivable $ 1,310 $ 1,401 Allowance for uncollectible accounts (38) (36) Trade accounts receivable — net $ 1,272 $ 1,365 Gross trade accounts receivable at June 30, 2020 and December 31, 2019 included unbilled retail revenues of $483 million and $494 million, respectively. Allowance for Uncollectible Accounts Receivable Six Months Ended June 30, 2020 2019 Allowance for uncollectible accounts receivable at beginning of period (a) $ 42 $ 19 Increase for bad debt expense 45 29 Decrease for account write-offs (49) (31) Allowance for uncollectible accounts receivable at end of period $ 38 $ 17
Schedule of inventories by major category	Inventories by Major Category June 30, December 31, Materials and supplies $ 274 $ 278 Fuel stock 250 172 Natural gas in storage 17 19 Total inventories $ 541 $ 469
Summary of other investments	Investments June 30, December 31, Nuclear plant decommissioning trust $ 1,466 $ 1,451 Assets related to employee benefit plans 37 37 Land 49 49 Total investments $ 1,552 $ 1,537
Summary of fair value of investments in the Nuclear Decommissioning Trust fund	June 30, December 31, 2019 Debt securities (a) $ 588 $ 521 Equity securities (b) 878 930 Total $ 1,466 $ 1,451 ____________ (a) 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 3.16% and 3.42% at June 30, 2020 and December 31, 2019, respectively, and an average maturity of ten years and nine years at June 30, 2020 and December 31, 2019, respectively.
Summary of proceeds from sales of available-for-sale securities	The following table summarizes proceeds from sales of securities and investments in new securities. Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 Proceeds from sales of securities $ 149 $ 214 $ 224 $ 292 Investments in securities $ (154) $ (219) $ (234) $ (302)
Schedule of property, plant and equipment	Property, Plant and Equipment June 30, December 31, Power generation and structures $ 15,479 $ 15,205 Land 623 622 Office and other equipment 171 164 Total 16,273 15,991 Less accumulated depreciation (3,160) (2,553) Net of accumulated depreciation 13,113 13,438 Finance lease right-of-use assets 56 59 Nuclear fuel (net of accumulated amortization of $159 million and $216 million) 211 197 Construction work in progress 501 220 Property, plant and equipment — net $ 13,881 $ 13,914
Schedule of asset retirement and mining reclamation obligations	The following table summarizes the changes to these obligations, reported as AROs (current and noncurrent liabilities) in our condensed consolidated balance sheets, for the six months ended June 30, 2020 and 2019. Six Months Ended June 30, 2020 Six Months Ended June 30, 2019 Nuclear Plant Decom- Mining Land Reclamation Coal Ash and Other Total Nuclear Plant Decom- Mining Land Reclamation Coal Ash and Other Total Liability at beginning of period $ 1,320 $ 410 $ 508 $ 2,238 $ 1,276 $ 442 $ 655 $ 2,373 Additions: Accretion 22 10 13 45 22 11 16 49 Adjustment for change in estimates (a) 219 (4) (2) 213 — (3) (3) (6) Adjustment for obligations assumed through acquisitions — — — — — — (3) (3) Reductions: Payments — (28) (16) (44) — (32) (16) (48) Liability at end of period 1,561 388 503 2,452 1,298 418 649 2,365 Less amounts due currently — (92) (46) (138) — (132) (100) (232) Noncurrent liability at end of period $ 1,561 $ 296 $ 457 $ 2,314 1,298 286 549 2,133 ____________ (a) The adjustment for nuclear plant decommissioning resulted from a new cost estimate completed in the second quarter of 2020. Under applicable accounting standards, the liability is remeasured when significant changes in the amount or timing of cash flows occur, and the PUCT requires a new cost estimate at least every five years. The increase in the liability was driven by changes in assumptions including increased costs for labor, equipment and services and a delay in timing of when the U.S. Department of Energy is estimated to begin accepting spent fuel offsite.
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 (a) $ 324 $ 295 Identifiable intangible liabilities (Note 6) 294 286 Regulatory liability — 131 Finance lease liabilities 79 78 Uncertain tax positions, including accrued interest 10 10 Liability for third-party remediation 37 41 Environmental allowances 53 52 Other accrued expenses 154 96 Total other noncurrent liabilities and deferred credits $ 951 $ 989
Schedule of fair value of debt	Fair Value of Debt June 30, 2020 December 31, 2019 Long-term debt (see Note 11): Fair Value Hierarchy Carrying Amount Fair Carrying Amount Fair Long-term debt under the Vistra Operations Credit Facilities Level 2 $ 2,594 $ 2,489 $ 2,715 $ 2,717 Vistra Operations Senior Notes Level 2 6,629 6,890 6,620 6,926 Vistra Senior Notes Level 2 179 173 774 772 Forward Capacity Agreements Level 3 99 99 155 155 Equipment Financing Agreements Level 3 80 80 87 87 Building Financing Level 2 13 13 16 16 Other debt Level 3 4 4 12 12
Schedule of cash, cash equivalents and restricted cash	The following table reconciles cash, cash equivalents and restricted cash reported in our condensed consolidated statements of cash flows to the amounts reported in our condensed consolidated balance sheets at June 30, 2020 and December 31, 2019: June 30, December 31, Cash and cash equivalents $ 382 $ 300 Restricted cash included in current assets 27 147 Restricted cash included in noncurrent assets 24 28 Total cash, cash equivalents and restricted cash $ 433 $ 475
Schedule of supplemental cash flow information	The following table summarizes our supplemental cash flow information for the six months ended June 30, 2020 and 2019: Six Months Ended June 30, 2020 2019 Cash payments related to: Interest paid $ 262 $ 307 Capitalized interest (9) (7) Interest paid (net of capitalized interest) $ 253 $ 300 Income taxes paid (refunds received) (a) $ (32) $ 9 Noncash investing and financing activities: Construction expenditures (b) $ 51 $ 41 Disposition of investment in NELP $ 123 $ — Acquisition of investment in North Jersey Energy Associates $ 90 $ — ____________ (a) For the six months ended June 30, 2020 and 2019, we paid state income taxes of $5 million and $30 million, respectively, and received federal tax refunds of $37 million and $21 million, respectively. (b) Represents end-of-period accruals for ongoing construction projects.

Business And Significant Acco_3

Business And Significant Accounting Policies (Narrative) (Details)	6 Months Ended
	Jun. 30, 2020Reportable_segment
Business and Significant Accounting Policies
Number of reportable segments (in reportable segments)	6

Acquisitions, Merger Transact_3

Acquisitions, Merger Transaction and Business Combination Accounting (Ambit and Crius Transactions Narrative) (Details) $ in Millions	Nov. 01, 2019USD ($)TW	Jul. 15, 2019USD ($)TW
Numbers of states in which entity operates		19
Ambit Transaction [Member]
Numbers of states in which entity operates	17
Business Combination, consideration transferred	$ 555
Electricity load, annualized basis, In terawatts | TW	11
Long-term debt, including amounts due currently	$ 0
Cash and cash equivalents	$ 49
Crius Transaction [Member]
Numbers of states in which entity operates		19
Business Combination, consideration transferred		$ 400
Business Combination, consideration transferred to acquire outstanding trust units		$ 382
Electricity load, annualized basis, In terawatts | TW		10
Long-term debt, including amounts due currently		$ 140
Cash and cash equivalents		$ 26

Acquisitions, Merger Transact_4

Acquisitions, Merger Transaction and Business Combination Accounting (Ambit and Crius Transactions Purchase Price Allocation) (Details) - USD ($) $ in Millions	8 Months Ended	12 Months Ended
	Jun. 30, 2020	Jun. 30, 2020	Dec. 31, 2019	Nov. 01, 2019	Jul. 15, 2019
Goodwill	$ 2,568	$ 2,568	$ 2,553
Ambit Transaction [Member]
Cash and cash equivalents				$ 49
Net working capital				35
Accumulated deferred income taxes, assets				0
Identifiable intangible assets				230
Goodwill	243	243		243
Commodity and other derivative contractual assets				23
Other noncurrent assets				13
Total assets acquired				593
Identifiable intangible liabilities				0
Long-term debt, including amounts due currently				0
Commodity and other derivative contractual liabilities				28
Accumulated deferred income taxes, liabilities				0
Other noncurrent liabilities and deferred credits				10
Total liabilities assumed				38
Identifiable net assets acquired				$ 555
Cash and cash equivalents, period increase (decrease)	0
Net working capital, period increase (decrease)	6
Accumulated deferred income taxes, asset, period increase (decrease)	0
Identifiable intangible assets, period increase (decrease)	(33)
Goodwill, period increase (decrease)	29
Commodity and other derivative assets, period increase (decrease)	0
Other noncurrent assets, period increase (decrease)	0
Total assets acquired, period increase (decrease)	2
Identifiable intangible liabilities, period increase (decrease)	0
Long-term debt, including amounts due currently, period increase (decrease)	0
Commodity and other derivative contractual liabilities, period increase (decrease)	0
Accumulated deferred income taxes, liability, period increase (decrease)	0
Other noncurrent liabilities and deferred credits, period increase (decrease)	2
Total liabilities assumed, period increase (decrease)	2
Identifiable net assets acquired, period increase (decrease)	0
Crius Transaction [Member]
Cash and cash equivalents					$ 26
Net working capital					(9)
Accumulated deferred income taxes, assets					0
Identifiable intangible assets					317
Goodwill	$ 243	243			243
Commodity and other derivative contractual assets					18
Other noncurrent assets					17
Total assets acquired					612
Identifiable intangible liabilities					2
Long-term debt, including amounts due currently					140
Commodity and other derivative contractual liabilities					40
Accumulated deferred income taxes, liabilities					14
Other noncurrent liabilities and deferred credits					16
Total liabilities assumed					212
Identifiable net assets acquired					$ 400
Cash and cash equivalents, period increase (decrease)		0
Net working capital, period increase (decrease)		(42)
Accumulated deferred income taxes, asset, period increase (decrease)		(36)
Identifiable intangible assets, period increase (decrease)		23
Goodwill, period increase (decrease)		38
Commodity and other derivative assets, period increase (decrease)		0
Other noncurrent assets, period increase (decrease)		(3)
Total assets acquired, period increase (decrease)		(20)
Identifiable intangible liabilities, period increase (decrease)		(34)
Long-term debt, including amounts due currently, period increase (decrease)		0
Commodity and other derivative contractual liabilities, period increase (decrease)		0
Accumulated deferred income taxes, liability, period increase (decrease)		14
Other noncurrent liabilities and deferred credits, period increase (decrease)		0
Total liabilities assumed, period increase (decrease)		(20)
Identifiable net assets acquired, period increase (decrease)		$ 0

Acquisitions, Merger Transact_5

Acquisitions, Merger Transaction and Business Combination Accounting (Dynegy Merger Transaction) (Details) - $ / shares	Apr. 09, 2018	Jun. 30, 2020	Dec. 31, 2019	Jun. 30, 2019	Dec. 31, 2018
Common stock, par or stated value per share		$ 0.01
Common stock, shares, outstanding		488,772,572	487,698,111	476,166,856	493,215,309
Dynegy Merger [Member]
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
Dynegy Merger [Member] | Dynegy Inc. [Member]
Common stock, par or stated value per share	$ 0.01
Dynegy Merger [Member] | Vistra Corp. [Member]
Common stock, par or stated value per share	$ 0.01

Development of Generation Fac_2

Development of Generation Facilities (Battery Energy Storage Projects) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2020USD ($)MW	Dec. 31, 2019USD ($)	Jun. 30, 2019MW
Construction work in progress | $	$ 501	$ 220
Vistra Corp. [Member] | Oakland Power Plant (Battery Storage Project) [Member]
Electricity generation facility capacity	36.25		20
Vistra Corp. [Member] | Moss Landing Power Plant (Battery Storage Project) [Member] | Moss Landing Battery Energy Storage System Phase I [Member]
Electricity generation facility capacity	300
Proposed contract, duration, number of years	20
Construction work in progress | $	$ 315
Vistra Corp. [Member] | Moss Landing Power Plant (Battery Storage Project) [Member] | Moss Landing Battery Energy Storage System Phase II [Member]
Electricity generation facility capacity	100
Proposed contract, duration, number of years	10

Retirement of Generation Faci_3

Retirement of Generation Facilities (Retirement of Generation Facilities) (Details) $ in Millions	1 Months Ended	3 Months Ended
	Aug. 31, 2019USD ($)	Sep. 30, 2019USD ($)	Jun. 30, 2020MWgenerating_unitpower_plant
Illinois Environmental Protection Agency [Member]
Illinois Multi-Pollutant Standards, additional reduction in emissions, MW			2,000
Coffeen Power Station, Duck Creek Station, Havana Power Station, Hennepin Power Station [Member]
Number of electric generation plants announced retirement | power_plant			4
Electric generation facility capacity announced retirement			2,068
Coffeen Power Station, Duck Creek Station, Havana Power Station, Hennepin Power Station, Edwards Power Station [Member]
Electric generation facility capacity announced retirement			2,653
Number of electric generation units announced retirement | generating_unit			8
Costs associated with retirement of generation facilities | $		$ 47
Increase (decrease) in obligation, pension and other postretirement benefits | $	$ 21
Other comprehensive income (loss), defined denefit plan, gain (loss), reclassification adjustment from AOCI, before tax | $	18
Curtailment expense | $	$ 3
Coffeen Power Station [Member]
Electric generation facility capacity announced retirement			915
Number of electric generation units announced retirement | generating_unit			2
Duck Creek Station [Member]
Electric generation facility capacity announced retirement			425
Number of electric generation units announced retirement | generating_unit			1
Havana Power Station [Member]
Electric generation facility capacity announced retirement			434
Number of electric generation units announced retirement | generating_unit			1
Hennepin Power Station [Member]
Electric generation facility capacity announced retirement			294
Number of electric generation units announced retirement | generating_unit			2
Edwards Power Station [Member]
Electric generation facility capacity announced retirement			585
Number of electric generation units announced retirement | generating_unit			2

Revenue (Revenue Disaggregated

Revenue (Revenue Disaggregated By Major Source) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 2,460	$ 2,229	$ 4,929	$ 4,777
Revenues	2,509	2,832	5,367	5,755
Retail energy charge in ERCOT [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,411	1,091	2,665	2,116
Retail energy charge in Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	540	315	1,180	663
Wholesale generation revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	179	497	443	1,371
Capacity revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	29	136	74	296
Revenue from other wholesale contracts [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	301	190	567	331
Intangible amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	(12)	(14)	(19)	(29)
Hedging and other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	61	617	457	1,007
Affiliate sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	0	0	0	0
Total other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	49	603	438	978
CAISO / Eliminations
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	34	26	71	101
Revenues	(976)	(1,446)	(1,968)	(2,166)
CAISO / Eliminations | Retail energy charge in ERCOT [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
CAISO / Eliminations | Retail energy charge in Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
CAISO / Eliminations | Wholesale generation revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	13	22	46	95
CAISO / Eliminations | Capacity revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
CAISO / Eliminations | Revenue from other wholesale contracts [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	21	4	25	6
CAISO / Eliminations | Intangible amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	0	1	0	2
CAISO / Eliminations | Hedging and other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	11	20	54	61
CAISO / Eliminations | Affiliate sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	(1,021)	(1,493)	(2,093)	(2,330)
CAISO / Eliminations | Total other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	(1,010)	(1,472)	(2,039)	(2,267)
Retail Segment [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,951	1,406	3,845	2,779
Revenues	1,956	1,421	3,864	2,806
Retail Segment [Member] | Retail energy charge in ERCOT [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,411	1,091	2,665	2,116
Retail Segment [Member] | Retail energy charge in Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	540	315	1,180	663
Retail Segment [Member] | Wholesale generation revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
Retail Segment [Member] | Capacity revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
Retail Segment [Member] | Revenue from other wholesale contracts [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
Retail Segment [Member] | Intangible amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	(5)	(10)	(8)	(19)
Retail Segment [Member] | Hedging and other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	10	25	27	46
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	5	15	19	27
ERCOT Segment [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	139	240	287	532
Revenues	865	1,671	1,731	2,625
ERCOT Segment [Member] | Retail energy charge in ERCOT [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ERCOT Segment [Member] | Retail energy charge in Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ERCOT Segment [Member] | Wholesale generation revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	76	188	174	435
ERCOT Segment [Member] | Capacity revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ERCOT Segment [Member] | Revenue from other wholesale contracts [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	63	52	113	97
ERCOT Segment [Member] | Intangible amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	0	0	0	0
ERCOT Segment [Member] | Hedging and other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	62	404	313	562
ERCOT Segment [Member] | Affiliate sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	664	1,027	1,131	1,531
ERCOT Segment [Member] | Total other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	726	1,431	1,444	2,093
PJM Segment [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	223	270	466	630
Revenues	412	686	1,060	1,391
PJM Segment [Member] | Retail energy charge in ERCOT [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
PJM Segment [Member] | Retail energy charge in Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
PJM Segment [Member] | Wholesale generation revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	71	130	148	351
PJM Segment [Member] | Capacity revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	15	53	30	120
PJM Segment [Member] | Revenue from other wholesale contracts [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	137	87	288	159
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	(6)	81	32	171
PJM Segment [Member] | Affiliate sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	195	335	562	590
PJM Segment [Member] | Total other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	189	416	594	761
NY/NE Segment [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	52	159	131	440
Revenues	131	254	417	599
NY/NE Segment [Member] | Retail energy charge in ERCOT [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
NY/NE Segment [Member] | Retail energy charge in Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
NY/NE Segment [Member] | Wholesale generation revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	16	81	58	276
NY/NE Segment [Member] | Capacity revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	10	72	35	152
NY/NE Segment [Member] | Revenue from other wholesale contracts [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	26	6	38	12
NY/NE Segment [Member] | Intangible amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	0	(1)	0	(3)
NY/NE Segment [Member] | Hedging and other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	(10)	61	29	113
NY/NE Segment [Member] | Affiliate sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	89	35	257	49
NY/NE Segment [Member] | Total other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	79	95	286	159
MISO Segment [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	61	81	129	177
Revenues	121	188	263	357
MISO Segment [Member] | Retail energy charge in ERCOT [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
MISO Segment [Member] | Retail energy charge in Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
MISO Segment [Member] | Wholesale generation revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	3	33	17	104
MISO Segment [Member] | Capacity revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	4	8	9	18
MISO Segment [Member] | Revenue from other wholesale contracts [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	54	40	103	55
MISO Segment [Member] | Intangible amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	(7)	(4)	(11)	(9)
MISO Segment [Member] | Hedging and other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	(6)	15	2	29
MISO Segment [Member] | Affiliate sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	73	96	143	160
MISO Segment [Member] | Total other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	60	107	134	180
Asset Closure Segment [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	47	0	118
Revenues	0	58	0	143
Asset Closure Segment [Member] | Retail energy charge in ERCOT [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
Asset Closure Segment [Member] | Retail energy charge in Northeast/Midwest [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
Asset Closure Segment [Member] | Wholesale generation revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	43	0	110
Asset Closure Segment [Member] | Capacity revenue from ISO/RTO [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	3	0	6
Asset Closure Segment [Member] | Revenue from other wholesale contracts [Member]
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	1	0	2
Asset Closure Segment [Member] | Intangible amortization [Member]
Disaggregation of Revenue [Line Items]
Revenues	0	0	0	0
Asset Closure Segment [Member] | Hedging and other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	0	11	0	25
Asset Closure Segment [Member] | Affiliate sales [Member]
Disaggregation of Revenue [Line Items]
Revenues	0	0	0	0
Asset Closure Segment [Member] | Total other revenues [Member]
Disaggregation of Revenue [Line Items]
Revenues	0	11	0	25
Operating revenues [Member]
Disaggregation of Revenue [Line Items]
Unrealized gain (loss) on derivatives	(69)	538	131	697
Operating revenues [Member] | Retail Segment [Member]
Disaggregation of Revenue [Line Items]
Unrealized gain (loss) on derivatives	(5)	6	(5)	5
Operating revenues [Member] | ERCOT Segment [Member]
Disaggregation of Revenue [Line Items]
Unrealized gain (loss) on derivatives	180	1,050	383	1,287
Operating revenues [Member] | PJM Segment [Member]
Disaggregation of Revenue [Line Items]
Unrealized gain (loss) on derivatives	(76)	184	4	276
Operating revenues [Member] | NY/NE Segment [Member]
Disaggregation of Revenue [Line Items]
Unrealized gain (loss) on derivatives	(55)	31	(24)	32
Operating revenues [Member] | MISO Segment [Member]
Disaggregation of Revenue [Line Items]
Unrealized gain (loss) on derivatives	(31)	67	(33)	46
Operating revenues [Member] | Asset Closure Segment [Member]
Disaggregation of Revenue [Line Items]
Unrealized gain (loss) on derivatives	$ 0	$ 0	$ 0	$ 0

Revenue (Performance Obligation

Revenue (Performance Obligations) (Details) $ in Millions	Jun. 30, 2020USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 390
Revenue, remaining performance obligation, expected timing of satisfaction, period	6 months
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	$ 826
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
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	$ 479
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
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	$ 121
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
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	$ 38
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation, amount	$ 18
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year

Revenue (Accounts Receivable) (

Revenue (Accounts Receivable) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Trade accounts receivable — net	$ 1,272	$ 1,365
Trade accounts receivable from contracts with customers [Member]
Trade accounts receivable — net	1,197	1,246
Other trade accounts receivables [Member]
Trade accounts receivable — net	$ 75	$ 119

Goodwill and Identifiable Int_3

Goodwill and Identifiable Intangible Assets and Liabilities (Goodwill) (Details) - USD ($) $ in Millions	Nov. 01, 2019	Apr. 09, 2018	Jun. 30, 2020	Jun. 30, 2020	Jul. 15, 2019
Goodwill [Roll Forward]
Balance at beginning of period			$ 2,553
Balance at end of period			2,568
Goodwill			2,568	$ 2,568
Retail Reporting Unit [Member]
Goodwill [Roll Forward]
Balance at end of period			1,907
Goodwill			1,907	1,907
Goodwill, expected tax deductible amount				1,686
Business acquisition, goodwill, expected tax deductible term		15 years
Dynegy Merger [Member]
Goodwill [Roll Forward]
Balance at end of period			175
Goodwill			175	175
Dynegy Merger [Member] | Retail Reporting Unit [Member]
Goodwill [Roll Forward]
Balance at end of period			53
Goodwill			53	53
Dynegy Merger [Member] | ERCOT Generation Reporting Unit [Member]
Goodwill [Roll Forward]
Balance at end of period			122
Goodwill			122	122
Crius Transaction [Member]
Goodwill [Roll Forward]
Measurement period adjustments			(14)
Balance at end of period			243
Goodwill			243	243	$ 243
Ambit Transaction [Member]
Goodwill [Roll Forward]
Measurement period adjustments			29
Balance at end of period	$ 243		243
Goodwill	$ 243		$ 243	$ 243
Business acquisition, goodwill, expected tax deductible term	15 years

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, 2020	Dec. 31, 2019
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount	$ 2,823	$ 2,833
Accumulated amortization	1,667	1,478
Total identifiable intangible assets subject to amortization, net	1,156	1,355
Total identifiable intangible assets	2,532	2,748
Total identifiable intangible liabilities	294	286
Retail trade names (not subject to amortization) [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount, unamortized intangibles	1,374	1,391
Mineral interests (not currently subject to amortization) [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount, unamortized intangibles	2	2
Retail customer relationship [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount	2,087	2,078
Accumulated amortization	1,302	1,151
Total identifiable intangible assets subject to amortization, net	785	927
Software and other technology-related assets [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount	364	341
Accumulated amortization	151	125
Total identifiable intangible assets subject to amortization, net	213	216
Retail and wholesale contracts [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount	272	315
Accumulated amortization	195	182
Total identifiable intangible assets subject to amortization, net	77	133
Contractual service agreements [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount	55	59
Accumulated amortization	2	5
Total identifiable intangible assets subject to amortization, net	53	54
Total identifiable intangible liabilities	127	110
Other identifiable intangible assets [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross carrying amount	45	40
Accumulated amortization	17	15
Total identifiable intangible assets subject to amortization, net	28	25
Purchase and sale of power and capacity [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Total identifiable intangible liabilities	92	100
Fuel and transportation purchase contracts [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Total identifiable intangible liabilities	$ 75	$ 76

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, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Finite-Lived Intangible Assets and Liabilities [Line Items]
Amortization of intangible assets and liabilities	$ 155	$ 97	$ 300	$ 203
Depreciation and amortization [Member]
Finite-Lived Intangible Assets and Liabilities [Line Items]
Amortization of intangible assets and liabilities	99	72	190	141
Retail customer relationship [Member] | Depreciation and amortization [Member]
Finite-Lived Intangible Assets and Liabilities [Line Items]
Amortization of intangible assets and liabilities	77	55	151	111
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	21	15	38	29
Retail and wholesale contracts/purchase and sale/ fuel and transportation contracts | Operating revenues, fuel, purchased power costs and delivery fees [Member]
Finite-Lived Intangible Assets and Liabilities [Line Items]
Amortization of intangible assets and liabilities	13	12	15	24
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	$ 44	$ 15	$ 96	$ 39

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, 2020USD ($)
Goodwill and Intangible Assets Disclosure [Abstract]
2020	$ 369
2021	257
2022	161
2023	116
2024	$ 78

Income Taxes (Calculation of Ef

Income Taxes (Calculation of Effective Tax Rate) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Effective Income Tax Rate Reconciliation, Amount [Abstract]
Income before income taxes	$ 232	$ 502	$ 293	$ 803
Income tax expense	$ (68)	$ (148)	$ (84)	$ (225)
Effective tax rate	29.30%	29.50%	28.70%	28.00%
Effective tax rate at federal statutory rate	21.00%	21.00%	21.00%	21.00%

Income Taxes (CARES Act) (Detai

Income Taxes (CARES Act) (Details) - Internal Revenue Service (IRS) [Member] $ in Millions	6 Months Ended
	Jun. 30, 2020USD ($)
Income tax, deduction limitation, pre-CARES Act, interest expense, percent	30.00%
Income tax, deduction limitation, post-CARES Act, interest expense, percent	50.00%
Income Tax, alternative minimum tax, post-CARES Act, estimated refunds in 2020, amount	$ 64
Tax Years 2019 and 2020 [Member]
Income Tax, deduction, post-CARES Act, estimated interest expense deduction, amount	$ 550

Income Taxes (Uncertain Tax Pos

Income Taxes (Uncertain Tax Positions) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Unrecognized tax benefits	$ 125	$ 126

Tax Receivable Agreement Obli_3

Tax Receivable Agreement Obligation (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019	Dec. 31, 2018
Income Tax Disclosure [Abstract]
Percent of cash tax savings due Tax Receivable Agreement rights holders			85.00%
Changes in tax assumption impacting timing of payments	$ (11)	$ (48)	$ (20)	$ (67)
Effective tax rate at federal statutory rate	21.00%	21.00%	21.00%	21.00%
Estimated undiscounted future payments under Tax Receivable Agreement			$ 1,400
TRA obligation at the end of the period	$ 469	$ 384	$ 469	$ 384	$ 455	$ 420

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, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Income Tax Disclosure [Abstract]
TRA obligation at the beginning of the period			$ 455	$ 420
Accretion expense			34	31
Changes in tax assumption impacting timing of payments	$ (11)	$ (48)	(20)	(67)
Impacts of Tax Receivable Agreement	6	(33)	14	(36)
TRA obligation at the end of the period	469	384	$ 455	$ 420	$ 455
Less amounts due currently	(1)	0
TRA obligation at the end of the period (noncurrent)	$ 468	$ 384			$ 455

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, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Earnings Per Share [Abstract]
Net income attributable to Vistra	$ 166	$ 356	$ 222	$ 581
Weighted average shares of common stock outstanding - basic	488,680,442	499,778,235	488,312,503	499,213,522
Net income per weighted average share of common stock outstanding - basic	$ 0.34	$ 0.71	$ 0.45	$ 1.16
Dilutive securities - stock-based incentive compensation plan	1,788,293	7,722,148	2,397,429	8,035,398
Weighted average shares of common stock outstanding - diluted	490,468,735	507,500,383	490,709,932	507,248,920
Net income per weighted average share of common stock outstanding - diluted	$ 0.34	$ 0.70	$ 0.45	$ 1.15
Antidilutive securities excluded from computation of earnings per share	13,978,168	2,910,226	12,123,691	7,577,246

Accounts Receivable Securitiz_2

Accounts Receivable Securitization Program (Details) - USD ($) $ in Millions	Jul. 31, 2020	Jun. 30, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Accounts receivable securitization program, amounts borrowed		$ 450	$ 450
Accounts receivable securitization program, gross trade accounts receivable held by special purpose subsidiary		$ 639	$ 629
Subsequent Event [Member]
Debt Instrument [Line Items]
Accounts receivable securitization program, maximum borrowing capacity, July through August 2020	$ 550
Accounts receivable securitization program, maximum borrowing capacity, August through November 2020	625
Accounts receivable securitization program, maximum borrowing capacity, November through December	550
Accounts receivable securitization program, maximum borrowing capacity, December 2020 through July 2021	$ 450

Long-Term Debt (Long-Term Debt)

Long-Term Debt (Long-Term Debt) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	$ 9,598
Other Long-term Debt	209	$ 287
Unamortized debt premiums, discounts and issuance costs	(63)	(55)
Less amounts due currently	(337)	(277)
Total long-term debt less amounts due currently	9,261	10,102
Line of Credit | Vistra Operations Credit Facility [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	2,586	2,700
Vistra Operations Senior Secured Notes [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	$ 3,100	3,100
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	$ 1,500	1,500
Vistra Operations Senior Secured Notes [Member] | 3.700% Senior Secured Notes Due 2027 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	3.70%
Long-term debt, including amounts due currently	$ 800	800
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	800
Vistra Operations Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	$ 3,600	3,600
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%
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%
Long-term debt, including amounts due currently	$ 1,300	1,300
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	1,300
Vistra Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	$ 166	747
Vistra 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	$ 0	500
Vistra Senior Unsecured Notes [Member] | 8.000% Senior Notes Due 2025 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	8.00%
Long-term debt, including amounts due currently	$ 0	81
Vistra Senior Unsecured Notes [Member] | 8.125% Senior Notes Due 2026 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	8.125%
Long-term debt, including amounts due currently	$ 166	166
Secured Debt [Member] | Forward Capacity Agreement [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	101	161
Unsecured Debt [Member] | Equipment Financing Agreement [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	$ 91	99
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	$ 13	15
Other debt [Member] | Other debt [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	4	12
Long-term debt, including amounts due currently [Member]
Debt Instrument [Line Items]
Long-term debt, including amounts due currently	$ 9,598	$ 10,379

Long-Term Debt (Vistra Operatio

Long-Term Debt (Vistra Operations Credit Facilities) (Details) - USD ($)	1 Months Ended		3 Months Ended		6 Months Ended
	Mar. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Line of Credit Facility [Line Items]
Gain (loss) on extinguishment of debt			$ 3,000,000	$ 3,000,000	$ 11,000,000	$ 10,000,000
Repayments under Revolving Credit Facility					725,000,000	0
Borrowings under Revolving Credit Facility					925,000,000	0
Repayment/repurchases of debt					756,000,000	4,137,000,000
Vistra Senior Unsecured Notes [Member]
Line of Credit Facility [Line Items]
Gain (loss) on extinguishment of debt		$ (2,000,000)
Vistra Operations Company LLC | Line of Credit
Line of Credit Facility [Line Items]
Line of credit facility, maximum borrowing capacity			5,311,000,000		5,311,000,000
Line of credit facility, borrowings outstanding			3,136,000,000		3,136,000,000
Line of credit facility, remaining borrowing capacity			1,287,000,000		1,287,000,000
Debt fees and expenses						$ 2,000,000
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			2,725,000,000		2,725,000,000
Line of credit facility, borrowings outstanding			550,000,000		550,000,000
Line of credit facility, increase (decrease), net		225,000,000
Line of credit facility, remaining borrowing capacity			$ 1,287,000,000		$ 1,287,000,000
Debt instrument, basis spread on variable rate					1.75%
Line of credit facility, interest rate at period end			1.93%		1.93%
Debt covenant, outstanding borrowings to outstanding commitments threshold, amount of letters of credit excluded			$ 300,000,000		$ 300,000,000
Debt covenant, outstanding borrowings to outstanding commitments threshold, percent			30.00%		30.00%
Repayments under Revolving Credit Facility					$ 725,000,000
Borrowings under Revolving Credit Facility					$ 925,000,000
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
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			$ 2,350,000,000		$ 2,350,000,000
Line of credit facility, increase (decrease), net		50,000,000
Debt instrument, interest rate, stated percentage			1.75%		1.75%
Line of credit facility, letters of credit outstanding			$ 888,000,000		$ 888,000,000
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			2,586,000,000		2,586,000,000
Line of credit facility, borrowings outstanding			2,586,000,000		2,586,000,000
Line of credit facility, increase (decrease), net	$ (100,000,000)
Debt instrument, redemption price	93.875
Line of credit facility, remaining borrowing capacity			$ 0		$ 0
Gain (loss) on extinguishment of debt	$ 6,000,000
Debt instrument, basis spread on variable rate					1.75%
Line of credit facility, interest rate at period end			1.93%		1.93%
Repayment/repurchases of debt		134,000,000
Vistra Operations Company LLC | Line of Credit | Senior Secured Term Loan B-1 Facility [Member]
Line of Credit Facility [Line Items]
Gain (loss) on extinguishment of debt				$ (4,000,000)
Repayment/repurchases of debt		889,000,000
Vistra Operations Company LLC | Line of Credit | Senior Secured Term Loan B-2 Facility [Member]
Line of Credit Facility [Line Items]
Repayment/repurchases of debt		$ 977,000,000

Long-Term Debt (Interest Rate S

Long-Term Debt (Interest Rate Swaps) (Details) $ in Millions	Jun. 30, 2020USD ($)
Long-term debt, amount of variable interest debt hedged	$ 2,300
Interest Rate Swap, Swapped To Fixed, Effective Through July 2023 [Member]
Derivative, notional amount	3,000
Interest Rate Swap, Swapped To Variable, Effective Through July 2023 [Member]
Derivative, notional amount	700
Interest Rate Swap, Swapped To Fixed, Legacy Swap Effective Through February 2024 [Member]
Derivative, notional amount	720
Interest Rate Swap, Swapped To Variable, Legacy Swap Effective Through February 2024 [Member]
Derivative, notional amount	720
Interest Rate Swap, Swapped To Fixed, Effective From July 2023 To July 2026 [Member]
Derivative, notional amount	3,000
Interest Rate Swap, Swapped To Variable, Effective From July 2023 To July 2026 [Member]
Derivative, notional amount	700
Interest Rate Swap, Swapped To Variable [Member]
Derivative, notional amount	$ 2,120
Minimum | Interest Rate Swap, Swapped To Fixed, Effective Through July 2023 [Member]
Effective Interest Rate, Debt Based On Derivative Contracts	3.67%
Minimum | Interest Rate Swap, Swapped To Variable, Effective Through July 2023 [Member]
Effective Interest Rate, Debt Based On Derivative Contracts	3.20%
Minimum | Interest Rate Swap, Swapped To Fixed, Legacy Swap Effective Through February 2024 [Member]
Effective Interest Rate, Debt Based On Derivative Contracts	3.71%
Minimum | Interest Rate Swap, Swapped To Variable, Legacy Swap Effective Through February 2024 [Member]
Effective Interest Rate, Debt Based On Derivative Contracts	3.20%
Minimum | Interest Rate Swap, Swapped To Fixed, Effective From July 2023 To July 2026 [Member]
Effective Interest Rate, Debt Based On Derivative Contracts	4.72%
Minimum | Interest Rate Swap, Swapped To Variable, Effective From July 2023 To July 2026 [Member]
Effective Interest Rate, Debt Based On Derivative Contracts	3.28%
Maximum | Interest Rate Swap, Swapped To Fixed, Effective Through July 2023 [Member]
Effective Interest Rate, Debt Based On Derivative Contracts	3.91%
Maximum | Interest Rate Swap, Swapped To Variable, Effective Through July 2023 [Member]
Effective Interest Rate, Debt Based On Derivative Contracts	3.23%
Maximum | Interest Rate Swap, Swapped To Fixed, Legacy Swap Effective Through February 2024 [Member]
Effective Interest Rate, Debt Based On Derivative Contracts	3.72%
Maximum | Interest Rate Swap, Swapped To Variable, Legacy Swap Effective Through February 2024 [Member]
Effective Interest Rate, Debt Based On Derivative Contracts	3.20%
Maximum | Interest Rate Swap, Swapped To Fixed, Effective From July 2023 To July 2026 [Member]
Effective Interest Rate, Debt Based On Derivative Contracts	4.79%
Maximum | Interest Rate Swap, Swapped To Variable, Effective From July 2023 To July 2026 [Member]
Effective Interest Rate, Debt Based On Derivative Contracts	3.33%

Long-Term Debt (Vistra Operat_2

Long-Term Debt (Vistra Operations Senior Secured Notes) (Details) - Vistra Operations Senior Secured Notes [Member] - USD ($) $ in Millions	1 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019
Debt Instrument [Line Items]
Proceeds from issuance of debt	$ 2,000	$ 2,000
Proceeds from issuance of senior long-term debt	1,976
Debt fees and expenses, capitalized as reduction of debt	20
3.550% Senior Secured Notes Due 2024 [Member]
Debt Instrument [Line Items]
Proceeds from issuance of debt	1,200
4.300% Senior Secured Notes Due 2029 [Member]
Debt Instrument [Line Items]
Proceeds from issuance of debt	$ 800

Long-Term Debt (Vistra Operat_3

Long-Term Debt (Vistra Operations Senior Unsecured Notes) (Details) - USD ($)	1 Months Ended			3 Months Ended		6 Months Ended
	Jul. 31, 2019	Jun. 30, 2019	Feb. 28, 2019	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Repayment/repurchases of debt						$ 756,000,000	$ 4,137,000,000
Gain (loss) on extinguishment of debt				$ 3,000,000	$ 3,000,000	$ 11,000,000	10,000,000
Vistra Operations Senior Unsecured Notes [Member] | 5.625% Senior Notes Due 2027 [Member]
Debt instrument, interest rate, stated percentage				5.625%		5.625%
Vistra Operations Senior Unsecured Notes [Member] | 5.000% Senior Notes due 2027 [Member]
Debt instrument, interest rate, stated percentage				5.00%		5.00%
Vistra Operations Senior Unsecured Notes [Member] | 5.50% Senior Notes Due 2026 [Member]
Debt instrument, interest rate, stated percentage				5.50%		5.50%
Vistra Senior Unsecured Notes [Member]
Repayment/repurchases of debt		$ 845,000,000
Gain (loss) on extinguishment of debt		7,000,000	$ 7,000,000
Vistra Senior Unsecured Notes [Member] | 7.375% Senior Notes Due 2022 [Member]
Debt instrument, interest rate, stated percentage				7.375%		7.375%
Repayment/repurchases of debt		173,000,000	1,193,000,000
Vistra Senior Unsecured Notes [Member] | 7.625% Senior Notes Due 2024 [Member]
Debt instrument, interest rate, stated percentage				7.625%		7.625%
Repayment/repurchases of debt	$ 1,000,000	672,000,000
Vistra Operations Unsecured Senior Notes [Member]
Proceeds from issuance of debt		1,300,000,000	1,300,000,000				$ 2,600,000,000
Debt fees and expenses, capitalized as reduction of debt		13,000,000	16,000,000
Proceeds from issuance of senior long-term debt		1,287,000,000	1,287,000,000
Vistra Operations Unsecured Senior Notes [Member] | 5.625% Senior Unsecured Notes Due 2027 [Member]
Proceeds from issuance of debt		0	1,300,000,000
Vistra Operations Unsecured Senior Notes [Member] | 5.000% Senior Unsecured Notes due 2027 [Member]
Proceeds from issuance of debt		1,300,000,000	0
Vistra Senior Unsecured Notes [Member]
Gain (loss) on extinguishment of debt		(2,000,000)
Vistra Senior Unsecured Notes [Member] | 7.375% Senior Notes Due 2022 [Member]
Debt instrument, interest rate, stated percentage				7.375%		7.375%
Repayment/repurchases of debt		306,000,000	35,000,000
Vistra Senior Unsecured Notes [Member] | 8.034% Senior Notes Due 2024 [Member]
Debt instrument, interest rate, stated percentage				8.034%		8.034%
Repayment/repurchases of debt			$ 25,000,000
Vistra Senior Unsecured Notes [Member] | 7.625% Senior Notes Due 2024 [Member]
Debt instrument, interest rate, stated percentage				7.625%		7.625%
Repayment/repurchases of debt		$ 87,000,000

Long-Term Debt (Vistra Senior U

Long-Term Debt (Vistra Senior Unsecured Notes) (Details) - USD ($)	1 Months Ended						3 Months Ended		6 Months Ended
	Jul. 31, 2020	Jun. 30, 2020	Jan. 31, 2020	Jul. 31, 2019	Jun. 30, 2019	Feb. 28, 2019	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Gain (loss) on extinguishment of debt							$ 3,000,000	$ 3,000,000	$ 11,000,000	$ 10,000,000
Repayment/repurchases of debt									$ 756,000,000	$ 4,137,000,000
Vistra Senior Unsecured Notes [Member]
Gain (loss) on extinguishment of debt					$ 7,000,000	$ 7,000,000
Repayment/repurchases of debt					845,000,000
Vistra Senior Unsecured Notes [Member] | 5.875% Senior Notes Due 2023 [Member]
Debt instrument, interest rate, stated percentage		5.875%					5.875%		5.875%
Vistra Senior Unsecured Notes [Member] | 8.000% Senior Notes Due 2025 [Member]
Debt instrument, interest rate, stated percentage		8.00%					8.00%		8.00%
Vistra Senior Unsecured Notes [Member] | 7.375% Senior Notes Due 2022 [Member]
Debt instrument, interest rate, stated percentage		7.375%					7.375%		7.375%
Repayment/repurchases of debt					173,000,000	1,193,000,000
Vistra Senior Unsecured Notes [Member] | 8.125% Senior Notes Due 2026 [Member]
Debt instrument, interest rate, stated percentage		8.125%					8.125%		8.125%
Vistra Senior Unsecured Notes [Member] | 7.625% Senior Notes Due 2024 [Member]
Debt instrument, interest rate, stated percentage		7.625%					7.625%		7.625%
Repayment/repurchases of debt				$ 1,000,000	672,000,000
Vistra Senior Unsecured Notes [Member]
Gain (loss) on extinguishment of debt					(2,000,000)
Vistra Senior Unsecured Notes [Member] | 5.875% Senior Notes Due 2023 [Member]
Repayments of unsecured debt		$ 500,000,000
Debt instrument, redemption price, percentage		100.979%
Gain (loss) on extinguishment of debt		$ 3,000,000
Vistra Senior Unsecured Notes [Member] | 8.000% Senior Notes Due 2025 [Member]
Repayments of unsecured debt			$ 81,000,000
Debt instrument, redemption price, percentage			104.00%
Gain (loss) on extinguishment of debt			$ 2,000,000
Vistra Senior Unsecured Notes [Member] | 7.375% Senior Notes Due 2022 [Member]
Debt instrument, interest rate, stated percentage		7.375%					7.375%		7.375%
Repayment/repurchases of debt					306,000,000	$ 35,000,000
Vistra Senior Unsecured Notes [Member] | 8.125% Senior Notes Due 2026 [Member] | Subsequent Event [Member]
Repayments of unsecured debt	$ 166,000,000
Debt instrument, redemption price, percentage	104.063%
Vistra Senior Unsecured Notes [Member] | 7.625% Senior Notes Due 2024 [Member]
Debt instrument, interest rate, stated percentage		7.625%					7.625%		7.625%
Repayment/repurchases of debt					$ 87,000,000

Long-Term Debt (Other Long-Term

Long-Term Debt (Other Long-Term Debt) (Details) - USD ($) $ in Millions	1 Months Ended					6 Months Ended		7 Months Ended	30 Months Ended
	Jul. 31, 2020	Jun. 30, 2020	Mar. 31, 2020	Jan. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Jul. 31, 2020	Jun. 30, 2020	Dec. 31, 2019
Repayment/repurchases of debt						$ 756	$ 4,137
Long-term debt, including amounts due currently		$ 9,598				9,598			$ 9,598
Bond Repurchase Program Authorized November 2018 [Member]
Bond Repurchase Program, authorized amount		200				200			200
Bond Repurchase Program Authorized July 2019 [Member]
Bond Repurchase Program, authorized amount		1,000				1,000			1,000
Bond Repurchase Program, Remaining Capacity		316				316			316
Repayment/repurchases of debt									684
Bond Repurchase Program Authorized April 2020 [Member]
Bond Repurchase Program, authorized amount		1,000				1,000			1,000
Bond Repurchase Program Authorized April 2020 [Member] | Subsequent Event [Member]
Repayment/repurchases of debt								$ 666
Vistra Senior Unsecured Notes [Member] | 8.000% Senior Notes Due 2025 [Member]
Repayments of unsecured debt				$ 81
Vistra Senior Unsecured Notes [Member] | 5.875% Senior Notes Due 2023 [Member]
Repayments of unsecured debt		500
Vistra Senior Unsecured Notes [Member] | 8.125% Senior Notes Due 2026 [Member] | Subsequent Event [Member]
Repayments of unsecured debt	$ 166
Secured Debt [Member] | Forward Capacity Agreement [Member]
Long-term debt, including amounts due currently		$ 101				$ 101			$ 101	$ 161
Debt instrument, interest rate, effective percentage		2.29%				2.29%			2.29%
Secured Debt [Member] | Forward Capacity Agreement [Member] | PJM Capacity Sold For Planning Years 2020-2021 [Member]
Long-term debt, including amounts due currently		$ 101				$ 101			$ 101
Line of Credit | Letter Of Credit Facility [Member]
Line of credit facility, letters of credit outstanding		3				3			3
Vistra Senior Unsecured Notes [Member]
Repayment/repurchases of debt					$ 845
Long-term debt, including amounts due currently		166				166			166	747
Vistra Senior Unsecured Notes [Member] | 8.000% Senior Notes Due 2025 [Member]
Long-term debt, including amounts due currently		$ 0				$ 0			$ 0	81
Debt instrument, interest rate, stated percentage		8.00%				8.00%			8.00%
Vistra Senior Unsecured Notes [Member] | 5.875% Senior Notes Due 2023 [Member]
Long-term debt, including amounts due currently		$ 0				$ 0			$ 0	500
Debt instrument, interest rate, stated percentage		5.875%				5.875%			5.875%
Vistra Senior Unsecured Notes [Member] | 8.125% Senior Notes Due 2026 [Member]
Long-term debt, including amounts due currently		$ 166				$ 166			$ 166	$ 166
Debt instrument, interest rate, stated percentage		8.125%				8.125%			8.125%
Vistra Operations Company LLC | Letter of Credit [Member] | Alternate Letter of Credit Facilities [Member]
Letter of Credit Facility, maximum borrowing capacity		$ 500				$ 500			$ 500
Letters of Credit Outstanding, Amount		500				500			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				250			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				$ 250			$ 250
Vistra Operations Company LLC | Line of Credit | Senior Secured Term Loan B-3 Facility [Member]
Repayment/repurchases of debt					$ 134
Line of credit facility, increase (decrease), net			$ (100)

Long-Term Debt (Maturities) (De

Long-Term Debt (Maturities) (Details) $ in Millions	Jun. 30, 2020USD ($)
Maturities [Abstract]
Remainder of 2020	$ 263
2021	96
2022	44
2023	40
2024	1,540
Thereafter	7,678
Unamortized premiums, discounts and debt issuance costs	(63)
Long-term debt, including amounts due currently	$ 9,598

Commitment and Contingencies (G

Commitment and Contingencies (Guarantees, Letters of Credit and Surety Bonds) (Details) - Vistra Operations Company LLC $ in Millions	Jun. 30, 2020USD ($)
Letters of Credit [Member]
Commitments and Contingencies [Line Items]
Letters of Credit Outstanding, Amount	$ 1,391
Letters 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 Outstanding, Amount	1,117
Letters of Credit [Member] | Support battery and solar development projects [Member]
Commitments and Contingencies [Line Items]
Letters of Credit Outstanding, Amount	108
Letters of Credit [Member] | Support executory contracts and insurance agreements [Member]
Commitments and Contingencies [Line Items]
Letters of Credit Outstanding, Amount	45
Letters 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 Outstanding, Amount	59
Letters of Credit [Member] | Miscellaneous credit support requirements [Member]
Commitments and Contingencies [Line Items]
Letters of Credit Outstanding, Amount	62
Surety Bonds [Member]
Commitments and Contingencies [Line Items]
Surety bonds outstanding	$ 71

Commitments And Contingencies_2

Commitments And Contingencies (Litigation, Regulatory and Environmental Proceedings) (Details)	6 Months Ended
	Jun. 30, 2020MW
Gas Index Pricing Litigation [Member] | Wisconsin
Commitments and Contingencies [Line Items]
Loss contingency, pending claims, number	2
Gas Index Pricing Litigation [Member] | Kansas
Commitments and Contingencies [Line Items]
Loss contingency, pending claims, number	1
MISO 2015-2016 Planning Resource Auction [Member]
Commitments and Contingencies [Line Items]
Loss contingency, pending claims, number	3
Vermillion Facility Old East And North Sites [Member]
Commitments and Contingencies [Line Items]
Site contingency, number of sites with regulatory violations	2
United States Environmental Protection Agency [Member]
Commitments and Contingencies [Line Items]
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, 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%
Illinois Multi-Pollutant Standards, additional reduction in emissions, MW	2,000
Dynegy Inc. [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) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended							3 Months Ended		6 Months Ended		12 Months Ended			30 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jun. 30, 2020
Share Repurchase Program
Stock Repurchase Program, authorized amount		$ 1,750						$ 1,750		$ 1,750					$ 1,750
Treasury Stock, shares, acquired															59,817,182
Treasury stock, value, acquired, cost method									$ 212		$ 448				$ 1,418
Treasury stock acquired, average cost per share															$ 23.72
Stock Repurchase Program, remaining authorized repurchase amount		$ 332						332		332					$ 332
Dividends and Dividend Restrictions
Common stock, dividends, per share, cash paid		$ 0.135	$ 0.135	$ 0.125	$ 0.125	$ 0.125	$ 0.125
Amount of restricted net assets for consolidated and unconsolidated subsidiaries		$ 1,500						$ 1,500		$ 1,500					$ 1,500
Warrants
Class of Warrant or Right, outstanding		9,000,000						9,000,000		9,000,000					9,000,000
Class of Warrant or Right, exercise price of warrants or rights		$ 35						$ 35		$ 35					$ 35
Class of Warrant or Right, effective exercise price of warrants or rights		$ 53.68						$ 53.68		$ 53.68					$ 53.68
Class of Warrant or Right, number of securities called by each warrant or right		0.652						0.652		0.652					0.652
Shares of Common Stock Authorized and Outstanding
Common stock, shares authorized		1,800,000,000				1,800,000,000		1,800,000,000	1,800,000,000	1,800,000,000	1,800,000,000				1,800,000,000
Common stock, shares, outstanding		488,772,572		487,698,111		476,166,856		488,772,572	476,166,856	488,772,572	476,166,856	487,698,111	493,215,309		488,772,572
Treasury stock, held in treasury		41,043,224		41,043,224		51,323,829		41,043,224	51,323,829	41,043,224	51,323,829	41,043,224	32,815,783		41,043,224
Vistra Operations Company LLC | Vistra Corp. [Member]
Dividends and Dividend Restrictions
Maximum allowable distribution to Parent Company by consolidated subsidiary without consent		$ 6,100						$ 6,100		$ 6,100					$ 6,100
Dividends paid								740		850		$ 3,900	$ 4,700	$ 1,100
Share Repurchase Program Approved By Board Of Directors In June 2018 [Member]
Share Repurchase Program
Stock Repurchase Program, authorized amount		500						500		500					500
Share Repurchase Program Approved By Board Of Directors In November 2018 [Member]
Share Repurchase Program
Stock Repurchase Program, authorized amount		$ 1,250						$ 1,250		$ 1,250					$ 1,250
Treasury Stock, shares, acquired									8,558,712		18,100,329
Treasury stock, value, acquired, cost method									$ 212		$ 448
Treasury stock acquired, average cost per share									$ 24.72		$ 24.75
Subsequent Event [Member]
Dividends and Dividend Restrictions
Common stock, dividends, per share, declared	$ 0.135

Equity (Changes to Equity) (Det

Equity (Changes to Equity) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		30 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2019	Dec. 31, 2018
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' equity attributable to Parent	$ 8,056		$ 8,056		$ 8,056		$ 7,959
Stockholders' equity attributable to noncontrolling interest	(12)		(12)		(12)		1
Beginning balance	7,926	$ 7,806	7,960	$ 7,867
Stock repurchase		(212)		(448)	(1,418)
Dividends paid to stockholders	(66)	(59)	(132)	(120)
Effects of stock-based incentive compensation plans	16	16	30	28
Net income (loss)	166	356	222	581
Net loss attributable to noncontrolling interest	2	2	13	3
Net income	164	354	209	578
Change in accumulated other comprehensive income (loss)	1		(22)	1
Other	3	(1)	3	0
Ending balance	8,044	7,904	8,044	7,904	8,044
Adjustment
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance			(4)	(2)
Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' equity attributable to Parent	5	5	5	5	5	$ 5	5	$ 5	$ 5
Other	0	0	0	0
Treasury Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' equity attributable to Parent	(973)	(1,226)	(973)	(1,226)	(973)	(973)	(973)	(1,014)	(778)
Stock repurchase		(212)		(448)
Other	0	0	0	0
Additional Paid-in Capital [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' equity attributable to Parent	9,754	10,135	9,754	10,135	9,754	9,737	9,721	10,119	10,107
Effects of stock-based incentive compensation plans	16	16	30	28
Other	1	0	3	0
Retained Earnings (Deficit) [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' equity attributable to Parent	(678)	(989)	(678)	(989)	(678)	(780)	(764)	(1,285)	(1,449)
Dividends paid to stockholders	(66)	(59)	(132)	(120)
Net income (loss)	166	356	222	581
Other	2	(1)	0	1
Retained Earnings (Deficit) [Member] | Adjustment
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance			(4)	(2)
Accumulated Other Comprehensive Income (Loss) [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' equity attributable to Parent	(52)	(21)	(52)	(21)	(52)	(53)	(30)	(21)	(22)
Change in accumulated other comprehensive income (loss)	1		(22)	1
Other	0	0	0	0
Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' equity attributable to Parent	8,056	7,904	8,056	7,904	8,056	7,936	7,959	7,804	7,863
Stock repurchase		(212)		(448)
Dividends paid to stockholders	(66)	(59)	(132)	(120)
Effects of stock-based incentive compensation plans	16	16	30	28
Net income (loss)	166	356	222	581
Change in accumulated other comprehensive income (loss)	1		(22)	1
Other	3	(1)	3	1
Parent [Member] | Adjustment
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning balance			(4)	(2)
Noncontrolling Interest [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' equity attributable to noncontrolling interest	(12)	0	(12)	0	$ (12)	$ (10)	$ 1	$ 2	$ 4
Net loss attributable to noncontrolling interest	(2)	(2)	(13)	(3)
Other	$ 0	$ 0	$ 0	$ (1)

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, 2020	Dec. 31, 2019
Assets:
Nuclear decommissioning trust, fair value	$ 1,466	$ 1,451
Equity securities [Member]
Assets:
Nuclear decommissioning trust, fair value	878	930
Debt securities [Member]
Assets:
Nuclear decommissioning trust, fair value	588	521
Fair Value, Recurring [Member]
Assets:
Sub-total	36	11
Liabilities:
Total liabilities	36	11
Fair Value, Recurring [Member] | Equity securities [Member]
Assets:
Assets measured at net asset value	355	366
Fair Value, Recurring [Member] | Commodity contracts [Member]
Assets:
Derivative Assets	36	11
Liabilities:
Derivative Liabilities	36	11
Fair Value, Recurring [Member] | Total [Member]
Assets:
Sub-total	2,738	2,554
Total assets	3,093	2,920
Liabilities:
Total liabilities	2,145	1,925
Fair Value, Recurring [Member] | Total [Member] | Equity securities [Member]
Assets:
Nuclear decommissioning trust, fair value	523	564
Fair Value, Recurring [Member] | Total [Member] | Debt securities [Member]
Assets:
Nuclear decommissioning trust, fair value	588	521
Fair Value, Recurring [Member] | Total [Member] | Commodity contracts [Member]
Assets:
Derivative Assets	1,541	1,469
Liabilities:
Derivative Liabilities	1,690	1,748
Fair Value, Recurring [Member] | Total [Member] | Interest rate swap [Member]
Assets:
Derivative Assets	86
Liabilities:
Derivative Liabilities	455	177
Level 1 [Member] | Fair Value, Recurring [Member]
Assets:
Sub-total	1,556	1,611
Liabilities:
Total liabilities	970	985
Level 1 [Member] | Fair Value, Recurring [Member] | Equity securities [Member]
Assets:
Nuclear decommissioning trust, fair value	523	564
Level 1 [Member] | Fair Value, Recurring [Member] | Commodity contracts [Member]
Assets:
Derivative Assets	1,033	1,047
Liabilities:
Derivative Liabilities	970	985
Level 2 [Member] | Fair Value, Recurring [Member]
Assets:
Sub-total	832	693
Liabilities:
Total liabilities	939	616
Level 2 [Member] | Fair Value, Recurring [Member] | Debt securities [Member]
Assets:
Nuclear decommissioning trust, fair value	588	521
Level 2 [Member] | Fair Value, Recurring [Member] | Commodity contracts [Member]
Assets:
Derivative Assets	158	172
Liabilities:
Derivative Liabilities	484	439
Level 2 [Member] | Fair Value, Recurring [Member] | Interest rate swap [Member]
Assets:
Derivative Assets	86
Liabilities:
Derivative Liabilities	455	177
Level 3 [Member]
Assets:
Sub-total	314	239
Liabilities:
Total liabilities	200	313
Level 3 [Member] | Fair Value, Recurring [Member]
Assets:
Sub-total	314	239
Liabilities:
Total liabilities	200	313
Level 3 [Member] | Fair Value, Recurring [Member] | Commodity contracts [Member]
Assets:
Derivative Assets	314	239
Liabilities:
Derivative Liabilities	$ 200	$ 313

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, 2020	Jun. 30, 2019	Dec. 31, 2019
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	$ 314,000,000		$ 239,000,000
Liabilities	(200,000,000)		(313,000,000)
Derivative Assets (Liabilities), at Fair Value, Net	114,000,000		(74,000,000)
Electricity purchases and sales [Member] | Valuation Model [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	149,000,000		64,000,000
Liabilities	(32,000,000)		(53,000,000)
Derivative Assets (Liabilities), at Fair Value, Net	117,000,000		11,000,000
Electricity purchases and sales [Member] | Minimum | Valuation Model [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Hourly price curve shape	0	$ 0
Fair Value Inputs, Illiquid delivery periods for ERCOT hub power prices and heat rates	20	20
Electricity purchases and sales [Member] | Maximum | Valuation Model [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Hourly price curve shape	105	115
Fair Value Inputs, Illiquid delivery periods for ERCOT hub power prices and heat rates	120	120
Electricity purchases and sales [Member] | Arithmetic Average | Valuation Model [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Hourly price curve shape	53	58
Fair Value Inputs, Illiquid delivery periods for ERCOT hub power prices and heat rates	73	$ 70
Options [Member] | Option Pricing Model Valuation Technique [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	74,000,000		38,000,000
Liabilities	(121,000,000)		(188,000,000)
Derivative Assets (Liabilities), at Fair Value, Net	$ (47,000,000)		(150,000,000)
Options [Member] | Minimum | Option Pricing Model Valuation Technique [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Gas to power correlation	25.00%	10.00%
Fair Value Inputs, Power and gas volatility	5.00%	5.00%
Options [Member] | Maximum | 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%	100.00%
Fair Value Inputs, Power and gas volatility	675.00%	440.00%
Options [Member] | Arithmetic Average | Option Pricing Model Valuation Technique [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Gas to power correlation	63.00%	55.00%
Fair Value Inputs, Power and gas volatility	341.00%	223.00%
Financial transmission rights [Member] | Market Approach [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	$ 76,000,000		120,000,000
Liabilities	(13,000,000)		(26,000,000)
Derivative Assets (Liabilities), at Fair Value, Net	63,000,000		94,000,000
Financial transmission rights [Member] | Minimum | Market Approach [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Illiquid price differences between settlement points	(5)	$ (10)
Financial transmission rights [Member] | Maximum | Market Approach [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Illiquid price differences between settlement points	50	40
Financial transmission rights [Member] | Arithmetic Average | Market Approach [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Illiquid price differences between settlement points	22	$ 15
Other [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	15,000,000		17,000,000
Liabilities	(34,000,000)		(46,000,000)
Derivative Assets (Liabilities), at Fair Value, Net	$ (19,000,000)		$ (29,000,000)

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, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net asset (liability) balance at beginning of period	$ 28	$ (113)	$ (74)	$ (135)
Total unrealized valuation gains	104	87	98	125
Purchases, issuances and settlements
Purchases	34	61	89	79
Issuances	(3)	(10)	(6)	(17)
Settlements	(34)	(20)	(47)	(42)
Transfers into Level 3	(2)	3	(1)	5
Transfers out of Level 3	(13)	(4)	55	(11)
Net change	86	117	188	139
Net asset balance at end of period	114	4	114	4
Unrealized valuation gains relating to instruments held at end of period	$ 123	$ 92	$ 137	$ 110

Commodity and Other Derivativ_3

Commodity and Other Derivative Contractual Assets and Liabilities (Financial Statement Effects of Derivatives) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 1,591	$ 1,458
Derivative liabilities, Fair Value, Gross Liability	(2,109)	(1,914)
Derivative, Fair Value, Net	(518)	(456)
Current assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets And Liability, Fair Value, Gross Assets	1,350	1,333
Noncurrent assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets And Liability, Fair Value, Gross Assets	277	136
Current liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets And Liability, Fair Value, Gross Liability	(1,546)	(1,529)
Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Assets And Liability, Fair Value, Gross Liability	(599)	(396)
Commodity contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1,505	1,458
Derivative liabilities, Fair Value, Gross Liability	(1,654)	(1,737)
Derivative asset, Fair Value, Net	1,505	1,458
Derivative liabilities, Fair Value, Net	(1,654)	(1,737)
Commodity contracts [Member] | Current assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1,313	1,323
Derivative liabilities, Fair Value, Gross Asset	18	10
Commodity contracts [Member] | Noncurrent assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	208	136
Derivative liabilities, Fair Value, Gross Asset	2	0
Commodity contracts [Member] | Current liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Liability	(3)	(1)
Derivative liabilities, Fair Value, Gross Liability	(1,473)	(1,510)
Commodity contracts [Member] | Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Liability	(13)	0
Derivative liabilities, Fair Value, Gross Liability	(201)	(237)
Interest rate swap [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	86	0
Derivative liabilities, Fair Value, Gross Liability	(455)	(177)
Derivative asset, Fair Value, Net	86	0
Derivative liabilities, Fair Value, Net	(455)	(177)
Interest rate swap [Member] | Current assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	19	0
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	67	0
Derivative liabilities, Fair Value, Gross Asset	0	0
Interest rate swap [Member] | Current liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Liability	0	0
Derivative liabilities, Fair Value, Gross Liability	(70)	(18)
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	$ (385)	$ (159)

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, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss)	$ 25	$ 417	$ (2)	$ 596
Operating revenues [Member] | Commodity contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss)	6	549	263	776
Fuel, purchased power costs and delivery fees [Member] | Commodity contracts [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss)	48	(24)	(58)	3
Interest expense [Member] | Interest rate swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss)	$ (29)	$ (108)	$ (207)	$ (183)

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, 2020	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Derivative assets: Derivative Assets and Liabilities	$ 1,591	$ 1,458
Derivative assets: Offsetting Instruments	(1,257)	(1,113)
Derivative assets: Cash Collateral (Received) Pledged	(8)	0
Derivative assets: Net Amounts	326	345
Derivative liabilities: Amounts Presented in Balance Sheet	(2,109)	(1,914)
Derivative liabilities: Derivative Assets and Liabilities	1,257	1,113
Derivative liabilities: Cash Collateral (Received) Pledged	30	40
Derivative liabilities: Net Amounts	(822)	(761)
Derivative, Fair Value, Net	(518)	(456)
Derivative (Assets) Liability, Fair Value of Collateral, Net	22	40
Derivative Assets (Liability), Fair Value, Amount Offset Against Collateral	(496)	(416)
Commodity contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative assets: Derivative Assets and Liabilities	1,505	1,458
Derivative assets: Offsetting Instruments	(1,171)	(1,113)
Derivative assets: Cash Collateral (Received) Pledged	(8)	0
Derivative assets: Net Amounts	326	345
Derivative liabilities: Amounts Presented in Balance Sheet	(1,654)	(1,737)
Derivative liabilities: Derivative Assets and Liabilities	1,171	1,113
Derivative liabilities: Cash Collateral (Received) Pledged	30	40
Derivative liabilities: Net Amounts	(453)	(584)
Interest rate swap [Member]
Derivatives, Fair Value [Line Items]
Derivative assets: Derivative Assets and Liabilities	86	0
Derivative assets: Offsetting Instruments	(86)	0
Derivative assets: Cash Collateral (Received) Pledged	0	0
Derivative assets: Net Amounts	0	0
Derivative liabilities: Amounts Presented in Balance Sheet	(455)	(177)
Derivative liabilities: Derivative Assets and Liabilities	86	0
Derivative liabilities: Cash Collateral (Received) Pledged	0	0
Derivative liabilities: Net Amounts	$ (369)	$ (177)

Commodity and Other Derivativ_6

Commodity and Other Derivative Contractual Assets and Liabilities (Derivative Volumes) (Details) number in Millions, gal in Millions, T in Millions, MMBTU in Millions, $ in Millions	Jun. 30, 2020USD ($)MMBTUTGWhgal	Dec. 31, 2019USD ($)GWhMMBTUTgal
Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | MMBTU	5,395	6,160
Electricity (in GWh) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | GWh	436,983	428,367
Financial transmission rights [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | GWh	212,461	199,648
Coal (in tons) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | T	17	22
Fuel oil (in gallons) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | gal	165	33
Emissions [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | T	37	20
Renewable Energy Certificate [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume	12	11
Interest rate swaps, floating to fixed [Member]
Derivatives, Fair Value [Line Items]
Derivative, notional amount | $	$ 6,720	$ 6,720
Interest rate swaps, fixed to floating [Member]
Derivatives, Fair Value [Line Items]
Derivative, notional amount | $	$ 2,120	$ 2,120

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, 2020	Dec. 31, 2019
Credit Derivatives [Line Items]
Derivative, net liability position, aggregate fair value	$ (930)	$ (692)
Credit risk derivative with contingent feature [Member]
Credit Derivatives [Line Items]
Derivative, net liability position, aggregate fair value	303	167
Cash collateral and letters of credit	91	67
Cross-default credit derivative [Member]
Credit Derivatives [Line Items]
Liquidity exposure	$ (536)	$ (458)

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, 2020USD ($)
Derivative [Line Items]
Total credit risk exposure to all counterparties related to derivative contracts	$ 1,712
Net exposure to those counterparties after taking into effect master netting arrangements, setoff provisions and collateral	378
Largest net exposure to single counterparty	$ 80
Credit risk exposure to banking and financial sector percentage	79.00%
Net exposure to banking and financial sector percentage	47.00%

Related Party Transactions (Nar

Related Party Transactions (Narrrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
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, 2020USD ($)	Jun. 30, 2019USD ($)	Jun. 30, 2020USD ($)Reportable_segment	Jun. 30, 2019USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments (in reportable segments) | Reportable_segment			6
Operating revenues	$ 2,509	$ 2,832	$ 5,367	$ 5,755
Depreciation and amortization	(455)	(384)	(875)	(790)
Operating income (loss)	377	729	766	1,218
Net income	164	354	209	578
Payments to acquire property, plant and equipment and nuclear fuel			259	229
Operating revenues [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on commodity positions	(69)	538	131	697
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	46	47	127	164
Depreciation and amortization	(21)	(21)	(40)	(37)
Operating income (loss)	(21)	(19)	(49)	(12)
Net income	(234)	(399)	(579)	(670)
Payments to acquire property, plant and equipment and nuclear fuel			43	27
Corporate, Non-Segment [Member] | Operating revenues [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on commodity positions	(8)	3	(1)	19
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Operating revenues	(1,022)	(1,493)	(2,095)	(2,330)
Depreciation and amortization	0	0	0	0
Operating income (loss)	0	0	0	0
Net income	0	0	0	0
Payments to acquire property, plant and equipment and nuclear fuel			0	0
Intersegment Eliminations [Member] | Operating revenues [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on commodity positions	(74)	(803)	(193)	(968)
Retail Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,956	1,421	3,864	2,806
Depreciation and amortization	(82)	(59)	(162)	(118)
Operating income (loss)	232	(581)	329	(563)
Net income	229	(585)	323	(571)
Payments to acquire property, plant and equipment and nuclear fuel			1	1
Retail Segment [Member] | Operating revenues [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on commodity positions	(5)	6	(5)	5
ERCOT Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	865	1,671	1,731	2,625
Depreciation and amortization	(130)	(128)	(253)	(259)
Operating income (loss)	296	1,047	552	1,335
Net income	299	1,056	557	1,356
Payments to acquire property, plant and equipment and nuclear fuel			141	161
ERCOT Segment [Member] | Operating revenues [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on commodity positions	180	1,050	383	1,287
PJM Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	412	686	1,060	1,391
Depreciation and amortization	(165)	(134)	(303)	(265)
Operating income (loss)	(66)	185	68	348
Net income	(66)	183	53	346
Payments to acquire property, plant and equipment and nuclear fuel			53	20
PJM Segment [Member] | Operating revenues [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on commodity positions	(76)	184	4	276
NY/NE Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	131	254	417	599
Depreciation and amortization	(48)	(39)	(97)	(104)
Operating income (loss)	(18)	78	10	94
Net income	(18)	79	(3)	100
Payments to acquire property, plant and equipment and nuclear fuel			14	5
NY/NE Segment [Member] | Operating revenues [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on commodity positions	(55)	31	(24)	32
MISO Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	121	188	263	357
Depreciation and amortization	(9)	(3)	(20)	(7)
Operating income (loss)	(32)	46	(114)	67
Net income	(32)	46	(111)	67
Payments to acquire property, plant and equipment and nuclear fuel			7	15
MISO Segment [Member] | Operating revenues [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on commodity positions	(31)	67	(33)	46
Asset Closure Segment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0	58	0	143
Depreciation and amortization	0	0	0	0
Operating income (loss)	(14)	(27)	(30)	(51)
Net income	(14)	(26)	(31)	(50)
Payments to acquire property, plant and equipment and nuclear fuel			0	0
Asset Closure Segment [Member] | Operating revenues [Member]
Segment Reporting Information [Line Items]
Unrealized mark-to-market net gains (losses) on commodity positions	$ 0	$ 0	$ 0	$ 0

Supplementary Financial Infor_3

Supplementary Financial Information (Components of Net Benefit Cost) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 2	$ 2	$ 4	$ 4
Other costs	0	0	1	0
Net periodic benefit cost	2	2	5	4
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	0	0	0	0
Other costs	2	2	4	4
Net periodic benefit cost	$ 2	$ 2	$ 4	$ 4

Supplementary Financial Infor_4

Supplementary Financial Information (Impairment of Long-Lived Assets) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of long-lived assets	$ 0	$ 0	$ 84	$ 0
MISO Segment [Member] | Joppa/EEI Power Plant Property, Plant and Equipment and Inventory [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of long-lived assets			52
MISO Segment [Member] | Joppa/EEI Power Plant Property, Plant and Equipment [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of long-lived assets			45
MISO Segment [Member] | Joppa/EEI Power Plant Property, Inventory [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of long-lived assets			7
MISO Segment [Member] | Joppa/EEI Power Plant Intangible Asset [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of long-lived assets			$ 32

Supplementary Financial Infor_5

Supplementary Financial Information (Interest Expense and Related Charges) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Interest Expense and Related Charges [Line Items]
Interest paid/accrued	$ 121	$ 154	$ 249	$ 305
Unrealized mark-to-market losses on interest rate swaps	18	119	192	199
Amortization of debt issuance costs, discounts and premiums	4	0	8	(2)
Debt extinguishment gain	(3)	(3)	(11)	(10)
Capitalized interest	(5)	(3)	(9)	(7)
Other	6	7	11	10
Total interest expense and related charges	$ 141	$ 274	$ 440	$ 495
Vistra Operations Company LLC | Line of Credit
Interest Expense and Related Charges [Line Items]
Debt instrument, interest rate during period			3.53%	4.03%

Supplementary Financial Infor_6

Supplementary Financial Information (Other Income and Deductions) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Other income:
Insurance settlement			$ 5
Funds released from escrow to settle pre-petition claims of our predecessor	$ 0	$ 0	0	$ 9
Interest income	1	3	1	7
All other	2	2	6	4
Total other income	5	13	12	39
Other deductions:
All other	3	2	6	5
Total other deductions	4	2	35	5
Loss on disposal of investment in NELP	1	0	29	0
Corporate, Non-Segment [Member]
Other income:
Insurance settlement			3
ERCOT Segment [Member]
Other income:
Insurance settlement	$ 2	$ 8	2	$ 19
NY/NE Segment [Member]
Other deductions:
Loss on disposal of investment in NELP			(15)
PJM Segment [Member]
Other deductions:
Loss on disposal of investment in NELP			$ (14)

Supplementary Financial Infor_7

Supplementary Financial Information (Restricted Cash) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Restricted cash included in current assets	$ 27	$ 147
Restricted cash included in noncurrent assets	24	28
Amounts related to remediation escrow accounts
Restricted cash included in current assets	20	15
Restricted cash included in noncurrent assets	24	28
Amounts related to restructuring escrow accounts
Restricted cash included in current assets	4	43
Restricted cash included in noncurrent assets	0	0
Amounts related to Ambit customer deposits
Restricted cash included in current assets	0	19
Restricted cash included in noncurrent assets	0	0
Amounts related to Ambit commodity trading agreement
Restricted cash included in current assets	0	62
Restricted cash included in noncurrent assets	0	0
Amounts related to Ambit letters of credit
Restricted cash included in current assets	3	8
Restricted cash included in noncurrent assets	$ 0	$ 0

Supplementary Financial Infor_8

Supplementary Financial Information (Trade Accounts Receivable and Allowance for Doubtful Accounts) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jan. 01, 2020	Dec. 31, 2019	Jan. 01, 2019
Wholesale and retail trade accounts receivable			$ 1,310		$ 1,401
Allowance for uncollectible accounts	$ (36)	$ (17)	(38)	$ (42)	(36)	$ (19)
Trade accounts receivable — net			1,272		1,365
Unbilled receivables, current			$ 483		$ 494
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowance for uncollectible accounts receivable at beginning of period (a)	36
Increase for bad debt expense	45	29
Decrease for account write-offs	(49)	(31)
Allowance for uncollectible accounts receivable at end of period	$ 38	$ 17
Accounting Standards Update 2016-13 [Member]
Allowance for uncollectible accounts				$ (6)

Supplementary Financial Infor_9

Supplementary Financial Information (Inventories by Major Category and Other Investments) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Inventories by Major Category
Materials and supplies	$ 274	$ 278
Fuel stock	250	172
Natural gas in storage	17	19
Total inventories	541	469
Investments
Nuclear plant decommissioning trust	1,466	1,451
Assets related to employee benefit plans	37	37
Land	49	49
Total investments	$ 1,552	$ 1,537

Supplementary Financial Info_10

Supplementary Financial Information (Investments in Unconsolidated Subsiaries) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Investment in unconsolidated subsidiary	$ 0		$ 0		$ 124
Equity in earnings of unconsolidated subsidiary		$ 3	3	$ 9
Proceeds from equity method investment, distribution		9	3	14
Loss on disposal of investment in NELP	$ (1)	$ 0	$ (29)	$ 0
Sayreville Plant [Member]
Jointly owned utility plant, proportionate ownership share	100.00%		100.00%
New Jersey Energy Associates [Member] | Sayreville Plant [Member]
Jointly owned utility plant, proportionate ownership share	100.00%		100.00%
Northeast Energy, LP [Member]
Investment in unconsolidated subsidiary					$ 123

Supplementary Financial Info_11

Supplementary Financial Information (Nuclear Decommissioning Trust) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Schedule of Schedule of Decommissioning Fund Investments [Line Items]
Nuclear decommissioning trust, fair value	$ 1,466		$ 1,466		$ 1,451
Proceeds from sales of securities	149	$ 214	224	$ 292
Investments in securities	(154)	$ (219)	(234)	$ (302)
Debt securities [Member]
Schedule of Schedule of Decommissioning Fund Investments [Line Items]
Nuclear decommissioning trust, fair value	$ 588		$ 588		$ 521
Debt, weighted average interest rate	3.16%		3.16%		3.42%
Decommissioning fund investments, debt securities average maturities			ten years	nine years
Decommissioning fund investments, debt maturities, one through five years, fair value	$ 194		$ 194
Decommissioning fund investments, debt maturities, five through ten years, fair value	165		165
Decommissioning fund investments, debt maturities, after ten years, fair value	229		229
Equity securities [Member]
Schedule of Schedule of Decommissioning Fund Investments [Line Items]
Nuclear decommissioning trust, fair value	$ 878		$ 878		$ 930

Supplementary Financial Info_12

Supplementary Financial Information (Property, Plant and Equipment) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Property, Plant and Equipment [Line Items]
Total	$ 16,273,000,000		$ 16,273,000,000		$ 15,991,000,000
Less accumulated depreciation	(3,160,000,000)		(3,160,000,000)		(2,553,000,000)
Net of accumulated depreciation	13,113,000,000		13,113,000,000		13,438,000,000
Finance lease right-of-use assets	56,000,000		56,000,000		59,000,000
Nuclear fuel (net of accumulated amortization)	211,000,000		211,000,000		197,000,000
Construction work in progress	501,000,000		501,000,000		220,000,000
Property, plant and equipment — net	13,881,000,000		13,881,000,000		13,914,000,000
Depreciation expense	356,000,000	$ 312,000,000	685,000,000	$ 647,000,000
Nuclear fuel
Property, Plant and Equipment [Line Items]
Less accumulated depreciation	(159,000,000)		(159,000,000)		(216,000,000)
Power generation and structures
Property, Plant and Equipment [Line Items]
Total	15,479,000,000		15,479,000,000		15,205,000,000
Land
Property, Plant and Equipment [Line Items]
Total	623,000,000		623,000,000		622,000,000
Office and other equipment
Property, Plant and Equipment [Line Items]
Total	$ 171,000,000		$ 171,000,000		$ 164,000,000

Supplementary Financial Info_13

Supplementary Financial Information (Asset Retirement and Mining Reclamation Obligations) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance, liability	$ 2,238	$ 2,373
Additions:
Accretion	45	49
Adjustment for change in estimate	213	(6)
Adjustment for obligations assumed through acquisitions	0	(3)
Reductions:
Payments	(44)	(48)
Ending balance, liability	2,452	2,365
Less amounts due currently	(138)	(232)	$ (141)
Noncurrent liability at end of period	2,314	2,133
Nuclear Plant Decommissioning [Member]
Asset Retirement Obligations [Line Items]
Regulatory assets	95
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance, liability	1,320	1,276
Additions:
Accretion	22	22
Adjustment for change in estimate	219	0
Adjustment for obligations assumed through acquisitions	0	0
Reductions:
Payments	0	0
Ending balance, liability	1,561	1,298
Less amounts due currently	0	0
Noncurrent liability at end of period	1,561	1,298
Mining Land Reclamation [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance, liability	410	442
Additions:
Accretion	10	11
Adjustment for change in estimate	(4)	(3)
Adjustment for obligations assumed through acquisitions	0	0
Reductions:
Payments	(28)	(32)
Ending balance, liability	388	418
Less amounts due currently	(92)	(132)
Noncurrent liability at end of period	296	286
Coal Ash and Other [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance, liability	508	655
Additions:
Accretion	13	16
Adjustment for change in estimate	(2)	(3)
Adjustment for obligations assumed through acquisitions	0	(3)
Reductions:
Payments	(16)	(16)
Ending balance, liability	503	649
Less amounts due currently	(46)	(100)
Noncurrent liability at end of period	$ 457	$ 549

Supplementary Financial Info_14

Supplementary Financial Information (Other Noncurrent Liabilities and Deferred Credits) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2020	Dec. 31, 2019
Retirement and other employee benefits	$ 324	$ 324	$ 295
Identifiable intangible liabilities	294	294	286
Regulatory liabilities	0	0	131
Finance lease liabilities	79	79	78
Uncertain tax positions, including accrued interest	10	10	10
Liability for third-party remediation	37	37	41
Environmental allowances	53	53	52
Other accrued expenses	154	154	96
Other noncurrent liabilities and deferred credits	951	951	$ 989
Pension Plan [Member]
Defined benefit plan, benefit obligation, (increase) decrease for remeasurement due to settlement	1	33
Other comprehensive income (loss), defined denefit plan, gain (loss), reclassification adjustment from AOCI, before tax	0	30
Defined benefit plan, accumulated benefit obligation, (increase) decrease for settlement and curtailment	$ 1	$ 3

Supplementary Financial Info_15

Supplementary Financial Information (Fair Value of Debt) (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Vistra Operations Credit Facility [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	$ 2,594	$ 2,715
Vistra Operations Senior Secured and Unsecured Notes | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	6,629	6,620
Vistra Senior Unsecured Notes [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	179	774
Secured Debt [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	99	155
Unsecured Debt [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	80	87
Construction Loans [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	13	16
Other debt | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	4	12
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	2,489	2,717
Fair Value, Inputs, Level 2 [Member] | Vistra Operations Senior Secured and Unsecured Notes | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	6,890	6,926
Fair Value, Inputs, Level 2 [Member] | Vistra 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	173	772
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	13	16
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	99	155
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	80	87
Level 3 [Member] | Other debt | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	$ 4	$ 12

Supplementary Financial Info_16

Supplementary Financial Information (Supplemental Cash Flow Information) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019	Dec. 31, 2018
Supplementary Financial Information [Abstract]
Cash and cash equivalents	$ 382		$ 300
Restricted cash included in current assets	27		147
Restricted cash included in noncurrent assets	24		28
Total cash, cash equivalents and restricted cash	433	$ 1,006	$ 475	$ 693
Cash payments related to:
Interest paid	262	307
Capitalized interest	(9)	(7)
Interest paid (net of capitalized interest)	253	300
Income taxes paid (refunds received)	(32)	9
Income taxes paid, state	5	30
Income tax refunds, federal	37	21
Noncash investing and financing activities:
Construction expenditures	51	41
Disposition of investment in NELP	123	0
Acquisition of investment in North Jersey Energy Associates	$ 90	$ 0