Condensed Statements Of Consolidated Comprehensive Income (Loss) - USD ($) $ in Millions |
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Jun. 30, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Jun. 30, 2018 |
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Statement of Comprehensive Income [Abstract] | ||||
Net income (loss) | $ 354 | $ 105 | $ 578 | $ (201) |
Other comprehensive income, net of tax effects: | ||||
Effects related to pension and other retirement benefit obligations (net of tax benefit of $— in all periods) | 0 | 0 | 1 | 1 |
Total other comprehensive income | 0 | 0 | 1 | 1 |
Comprehensive income (loss) | 354 | 105 | 579 | (200) |
Comprehensive loss attributable to noncontrolling interest | 2 | 3 | 3 | 3 |
Comprehensive income (loss) attributable to Vistra Energy | $ 356 | $ 108 | $ 582 | $ (197) |
Condensed Statements Of Consolidated Comprehensive Income (Loss) (Parenthetical) - USD ($) $ in Millions |
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Jun. 30, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Jun. 30, 2018 |
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Statement of Comprehensive Income [Abstract] | ||||
Effects related to pension and other retirement benefit obligations (net of tax benefit of $— in all periods) | $ 0 | $ 0 | $ 0 | $ 0 |
Condensed Consolidated Balance Sheets Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares |
Jun. 30, 2019 |
Dec. 31, 2018 |
Jun. 30, 2018 |
Apr. 09, 2018 |
Dec. 31, 2017 |
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Statement of Changes in Financial Position [Abstract] | |||||
Common stock, par or stated value per share | $ 0.01 | ||||
Common stock, shares authorized | 1,800,000,000 | 1,800,000,000 | |||
Common stock, shares outstanding | 476,166,856 | 493,215,309 | 521,214,879 | 522,932,453 | 428,398,802 |
Business And Significant Accounting Policies |
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Accounting Policies [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Business And Significant Accounting Policies | BUSINESS AND SIGNIFICANT ACCOUNTING POLICIES Description of Business References in this report to "we," "our," "us" and "the Company" are to Vistra Energy and/or its subsidiaries, as apparent in the context. See Glossary for defined terms. Vistra Energy is a holding company operating an integrated retail and generation business in markets throughout the U.S. Through our subsidiaries, we are engaged in competitive electricity market activities including power generation, wholesale energy sales and purchases, commodity risk management and retail sales of electricity to end users. Vistra Energy has six reportable segments: (i) Retail, (ii) ERCOT, (iii) PJM, (iv) NY/NE (comprising NYISO and ISO-NE), (v) MISO and (vi) Asset Closure. See Note 18 for further information concerning reportable business segments. Acquisition of Crius On July 15, 2019, an indirect, wholly owned subsidiary of Vistra Energy completed the acquisition of the equity interests of two wholly owned subsidiaries of Crius that indirectly own the operating business of Crius (Crius Transaction). Because the Crius Transaction closed on July 15, 2019, Vistra Energy's condensed consolidated financial statements and the notes related thereto for the period ending June 30, 2019 do not include the financial condition or the operating results of Crius and its subsidiaries. See Note 2 for a summary of the Crius Transaction. Dynegy Merger Transaction On the Merger Date, Vistra Energy and Dynegy completed the transactions contemplated by the Merger Agreement. Pursuant to the Merger Agreement, Dynegy merged with and into Vistra Energy, with Vistra Energy continuing as the surviving corporation. Because the Merger closed on April 9, 2018, Vistra Energy's condensed consolidated financial statements and the notes related thereto do not include the financial condition or the operating results of Dynegy prior to April 9, 2018. See Note 2 for a summary of the Merger transaction and business combination accounting. Basis of Presentation The condensed consolidated financial statements have been prepared in accordance with U.S. GAAP and on the same basis as the audited financial statements included in our annual report on Form 10-K for the year ended December 31, 2018. Adjustments (consisting of normal recurring accruals) necessary for a fair presentation of the results of operations and financial position have been included therein. All intercompany items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with U.S. GAAP have been omitted pursuant to the rules and regulations of the SEC. Because the condensed consolidated interim financial statements do not include all of the information and footnotes required by U.S. GAAP, they should be read in conjunction with the audited financial statements and related notes contained in our annual report on Form 10-K for the year ended December 31, 2018. The results of operations for an interim period may not give a true indication of results for a full year. All dollar amounts in the financial statements and tables in the notes are stated in millions of U.S. dollars unless otherwise indicated. Use of Estimates Preparation of financial statements requires estimates and assumptions about future events that affect the reporting of assets and liabilities at the balance sheet dates and the reported amounts of revenue and expense, including fair value measurements, estimates of expected obligations, judgment related to the potential timing of events and other estimates. In the event estimates and/or assumptions prove to be different from actual amounts, adjustments are made in subsequent periods to reflect more current information. Leases At the inception of a contract we determine if it is or contains a lease, which involves the contract conveying the right to control the use of explicitly or implicitly identified property, plant, or equipment for a period of time in exchange for consideration. Right-of-use (ROU) assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. ROU assets and lease liabilities are recognized at the commencement date of the underlying lease based on the present value of lease payments over the lease term. We use our secured incremental borrowing rate based on the information available at the lease commencement date to determine the present value of lease payments. Operating leases are included in operating lease ROU assets, operating lease liabilities (current) and operating lease liabilities (noncurrent) on our condensed consolidated balance sheet. Finance leases are included in property, plant and equipment, other current liabilities and other noncurrent liabilities and deferred credits on our condensed consolidated balance sheet. Lease term includes options to extend or terminate the lease when it is reasonably certain that we will exercise the option. We have elected the practical expedient which permits us to not reassess under the new standard our prior conclusion about lease classification and initial direct costs. We have also elected the practical expedient to not separate lease and non-lease components for a majority of the lease asset classes. We have also elected the hindsight practical expedient to determine the lease term. Leases with an initial lease term of 12 months or less are not recorded on the balance sheet; we recognize lease expense for these leases on a straight-line basis over the lease term. We also present lessor sublease income on a net basis against the related lessee lease expense. Adoption of New Accounting Standards Leases — On January 1, 2019, we adopted Accounting Standards Update (ASU) 2016-02, Leases (Topic 842) and all related amendments (new lease standard) using the modified retrospective method with the cumulative-effect adjustment to the opening balance of retained earnings for all contracts outstanding at the time of adoption. The comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. We expect the impact of the adoption of the new lease standard to be immaterial to our net income on an ongoing basis. The impact of adopting the new lease standard primarily relates to recognition of lease liabilities and ROU assets for all leases classified as operating leases. Under the new lease standard, each ROU asset will be amortized over the lease term and liability settled at the end of the lease term. We recognized the effect of initially applying the new lease standard by recording ROU assets of $85 million and lease liabilities of $123 million in our condensed consolidated balance sheet. As of January 1, 2019, the cumulative effect of the changes made to our condensed consolidated balance sheet for the adoption of the new lease standard was as follows:
See Note 12 for the disclosures required by the new lease standard. Changes in Accounting Standards In August 2018, the Financial Accounting Standards Board (FASB) issued ASU 2018-13, Changes to the Disclosure Requirements for Fair Value Measurement. The ASU will be effective for fiscal years beginning after December 15, 2019 and early adoption is permitted. The ASU removes disclosure requirements for (a) the reasons for transfers between Level 1 and Level 2, (b) the policy for timing of transfers between levels and (c) the valuation processes for Level 3. The ASU will require new disclosures around (a) the changes in unrealized gains and losses for the period included in other comprehensive income for recurring Level 3 fair value measurements held at the end of the reporting period and (b) the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. We are currently evaluating the impact of this ASU on our disclosures. In August 2018, the FASB issued ASU 2018-15, Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract. The ASU will be effective for fiscal years beginning after December 15, 2019 and early adoption is permitted. The ASU requires a customer in a cloud hosting arrangement that is a service contract to determine which implementation costs to capitalize and which costs to expense based on the project stage of the implementation. The ASU also requires the customer to expense the capitalized implementation costs over the term of the hosting arrangement. The customer is required to apply the existing impairment and abandonment guidance on the capitalized implementation costs. We are currently evaluating the impact of this ASU on our financial statements.
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Acquisition of Crius, Dynegy Merger Transaction and Business Combination Accounting (Notes) |
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Business Combinations [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Merger Transaction [Text Block] | ACQUISITION OF CRIUS, DYNEGY MERGER TRANSACTION AND BUSINESS COMBINATION ACCOUNTING Acquisition of Crius On July 15, 2019 (Acquisition Date), Vienna Acquisition B.C. Ltd., an indirect, wholly owned subsidiary of Vistra Energy, completed the acquisition of the equity interests of two wholly owned subsidiaries of Crius that indirectly own the operating business of Crius. Crius is an energy retailer selling both electricity and natural gas products to residential and small business customers in 19 states and the District of Columbia. The Crius Transaction is expected to (i) reduce risk and expand into higher margin channels by improving Vistra Energy's match of its generation to load profile due to a high degree of overlap with Vistra Energy's generation fleet with Crius' approximately 11.6 TWh of annual load, (ii) establish a platform for future growth by leveraging Vistra Energy's existing retail marketing capabilities and Crius' experienced team and (iii) enhance the integrated value proposition through collateral and transaction efficiencies, particularly via Crius' retail portfolio. The Crius Transaction is being accounted for in accordance with ASC 805, Business Combinations (ASC 805), with identifiable assets acquired and liabilities assumed recorded at their estimated fair values on the Acquisition Date. Due to the limited time between the Acquisition Date and this filing, our purchase price allocation for the assets acquired and the liabilities assumed in the Merger has not been completed. The results of operations of Crius will be reported in our consolidated financial statements beginning as of the Acquisition Date. Vistra Energy funded the purchase price of approximately $400 million (including $380 million for outstanding trust units) using cash on hand and assumption of Crius' net debt of approximately $111 million. Our initial accounting for the purchase price allocation for the assets acquired and the liabilities assumed in the Crius Transaction and the supplemental pro forma financial results is currently underway and will be presented no later than the third quarter of 2019. Dynegy Merger Transaction On the Merger Date, Vistra Energy and Dynegy completed the transactions contemplated by the Merger Agreement. Pursuant to the Merger Agreement, Dynegy merged with and into Vistra Energy, with Vistra Energy continuing as the surviving corporation. The Merger was intended to qualify as a tax-free reorganization under the Internal Revenue Code, as amended, so that none of Vistra Energy, Dynegy or any of the Dynegy stockholders would recognize any gain or loss in the transaction, except that Dynegy stockholders could recognize a gain or loss with respect to cash received in lieu of fractional shares of Vistra Energy's common stock. Vistra Energy is the acquirer for both federal tax and accounting purposes. At the closing of the Merger, each issued and outstanding share of Dynegy common stock, par value $0.01 per share, other than shares owned by Vistra Energy or its subsidiaries, held in treasury by Dynegy or held by a subsidiary of Dynegy, was automatically converted into 0.652 shares of common stock, par value $0.01 per share, of Vistra Energy (the Exchange Ratio), except that cash was paid in lieu of fractional shares, which resulted in Vistra Energy issuing 94,409,573 shares of Vistra Energy common stock to the former Dynegy stockholders, as well as converting stock options, equity-based awards, tangible equity units and warrants. The total number of Vistra Energy shares outstanding at the close of the Merger was 522,932,453 shares. Dynegy stock options and equity-based awards outstanding immediately prior to the Merger Date were generally automatically converted upon completion of the Merger into stock options and equity-based awards, respectively, with respect to Vistra Energy's common stock, after giving effect to the Exchange Ratio. Dynegy Business Combination Accounting We believe the Merger has provided and continues to provide significant strategic benefits and opportunities to Vistra Energy, including increased scale and market diversification, rebalanced asset portfolio and improved earnings and cash flow. The Merger was accounted for in accordance with ASC 805, Business Combinations (ASC 805), with identifiable assets acquired and liabilities assumed recorded at their estimated fair values on the Merger Date. The combined results of operations are reported in our consolidated financial statements beginning as of the Merger Date. A summary of the techniques used to estimate the fair value of the identifiable assets and liabilities, as well as their classification within the fair value hierarchy (see Note 15), is listed below:
The following table summarizes the consideration paid and the final allocation of the purchase price to the fair value amounts recognized for the assets acquired and liabilities assumed related to the Merger as of the Merger Date. Based on the opening price of Vistra Energy common stock on the Merger Date, the purchase price was approximately $2.3 billion. During the three months ended March 31, 2019, the purchase price allocation was completed. During the period from April 9, 2018 through March 31, 2019, we updated the initial purchase price allocation with final valuations by increasing property, plant and equipment by $173 million, decreasing intangible assets by $36 million, increasing goodwill by $175 million, decreasing accounts receivable, inventory, prepaid expenses and other current assets by $10 million, increasing accumulated deferred tax asset by $127 million, decreasing other noncurrent assets by $113 million, increasing trade accounts payable and other current liabilities by $89 million, increasing other noncurrent liabilities by $177 million, increasing asset retirement obligations, including amounts due currently, by $56 million, as well as other minor adjustments. The valuation revisions were a result of updated inputs used in determining the fair value of the acquired assets and liabilities.
Acquisition costs incurred in the Merger totaled less than $1 million and $50 million for the three months ended June 30, 2019 and 2018, respectively, and less than $1 million and $52 million for the six months ended June 30, 2019 and 2018, respectively. Unaudited Pro Forma Financial Information — The following unaudited pro forma financial information for the six months ended June 30, 2018 assumes that the Merger occurred on January 1, 2018. The unaudited pro forma financial information is provided for information purposes only and is not necessarily indicative of the results of operations that would have occurred had the Merger been completed on January 1, 2018, nor is the unaudited pro forma financial information indicative of future results of operations, which may differ materially from the pro forma financial information presented here.
The unaudited pro forma financial information presented above includes adjustments for incremental depreciation and amortization as a result of the fair value determination of the net assets acquired, interest expense on debt assumed in the Merger, effects of the Merger on tax expense (benefit), changes in the expected impacts of the tax receivable agreement due to the Merger, and other related adjustments.
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Acquisition and Development of Generation Facilities (Notes) |
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Acquisition And Development Of Generation Facilities [Abstract] | |
Business Combination Disclosure [Text Block] | ACQUISITION AND DEVELOPMENT OF GENERATION FACILITIES Battery Energy Storage Projects We have completed the construction of our first battery energy storage system (ESS). In October 2018, we were awarded a $1 million grant from the TCEQ for our battery ESS at our Upton 2 solar facility. The grant is part of the Texas Emissions Reduction Plan. The 10 MW lithium-ion ESS captures excess solar energy produced during the day and releases the energy in late afternoon and early evening, when demand is highest. The Upton 2 battery ESS became operational in December 2018. In June 2019, East Bay Community Energy signed a ten-year contract to receive resource adequacy capacity from the planned development of a 20 MW battery ESS at our Oakland Power Plant site in California. The contract is now pending utility review and signature and will then be sent to the California Public Utilities Commission (CPUC) for approval. In June 2018, we announced that, subject to approval by the CPUC, we would enter into a 20-year resource adequacy contract with Pacific Gas and Electric Company (PG&E) to develop a 300 MW battery ESS at our Moss Landing Power Plant site in California. PG&E filed its application with the CPUC in June 2018 and the CPUC approved the resource adequacy contract in November 2018. At June 30, 2019, we had accumulated approximately $15 million in construction work-in-process for this ESS. We anticipate the Moss Landing battery ESS will commence commercial operations by the fourth quarter of 2020. PG&E filed for Chapter 11 bankruptcy protection in January 2019. If the terms of the resource adequacy contract are not honored by PG&E or the resource adequacy contract is rejected through the bankruptcy process, we could have future impairment losses. Upton 2 Solar Development In May 2017, we acquired the rights to develop, construct and operate a utility scale solar photovoltaic power generation facility in Upton County, Texas (Upton 2). As part of this project, we entered a turnkey engineering, procurement and construction agreement to construct the approximately 180 MW facility. During 2017 and 2018, we spent approximately $231 million related to this project primarily for progress payments under the engineering, procurement and construction agreement and the acquisition of the development rights. The facility began test operations in March 2018 and commercial operations began in June 2018.
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Retirement of Generation Facilities (Notes) |
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Retirement of generation facilities | RETIREMENT OF GENERATION FACILITIES In August 2018, we filed a notice of suspension of operation with PJM and other mandatory regulatory notifications related to the retirement of our 51 MW Northeastern Power Company waste coal facility in McAdoo, Pennsylvania (Northeastern Facility). We decided to retire the Northeastern Facility due to its uneconomic operations and financial outlook. Following the receipt of regulatory approvals, the Northeastern Facility was retired in October 2018. The decision to retire the Northeastern Facility did not result in a material impact to the financial statements, and the operational results of the Northeastern Facility are included in our Asset Closure segment. Two of our non-operated, jointly held power plants acquired in the Merger, for which our proportional generation capacity was 883 MW, were retired in May 2018. These units were retired as previously scheduled. No gain or loss was recorded in conjunction with the retirement of these units, and the operational results of these facilities are included in our Asset Closure segment. The following table details the units retired.
In January and February 2018, we retired three power plants with a total installed nameplate generation capacity of 4,167 MW. We decided to retire these units because they were projected to be uneconomic based on then current market conditions and would have faced significant environmental costs associated with operating such units. In the case of the Sandow units, the decision also reflected the execution of a contract termination agreement pursuant to which the Company and Alcoa agreed to an early settlement of a long-standing power and mining agreement. Expected retirement expenses were accrued in the third and fourth quarter of 2017 and, as a result, no retirement expenses were recorded related to these facilities in the three and six months ended June 30, 2018. The operational results of these facilities are included in our Asset Closure segment, which is engaged in the decommissioning and reclamation of retired plants and mines. The following table details the units retired.
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Revenue (Notes) |
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Revenue Recognition and Deferred Revenue [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Revenue from Contract with Customer [Text Block] | REVENUE The following tables disaggregate our revenue by major source:
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Performance Obligations As of June 30, 2019, we have future performance obligations that are unsatisfied, or partially unsatisfied, relating to capacity auction volumes awarded through capacity auctions held by the ISO or RTO or through bilateral sales. Therefore, an obligation exists as of the date of the results of the respective ISO or RTO capacity auction or the contract execution date for bilateral customers. The transaction price is also set by the results of the capacity auction and/or executed contract. These obligations total $440 million, $770 million, $720 million, $423 million and $96 million that will be recognized in the balance of the year ended December 31, 2019 and the years ending December 31, 2020, 2021, 2022 and 2023, respectively, and $65 million thereafter. Capacity revenues are recognized as capacity services are provided to the related ISOs or RTOs or bilateral counterparties. Accounts Receivable The following table presents trade accounts receivable (net of allowance for uncollectible accounts) relating to both contracts with customers and other activities:
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Goodwill and Identifiable Intangible Assets and Liabilities (Notes) |
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Goodwill and Intangible Assets Disclosure [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Goodwill And Identifiable Intangible Assets | GOODWILL AND IDENTIFIABLE INTANGIBLE ASSETS AND LIABILITIES Goodwill The carrying value of goodwill totaled $2.082 billion and $2.068 billion at June 30, 2019 and December 31, 2018, respectively. Of the total goodwill at June 30, 2019, $175 million arose in connection with the Merger, and $122 million is recorded in our ERCOT Generation and Wholesale reporting unit and $53 million is recorded in our ERCOT Retail reporting unit. The remaining $1.907 billion arose in connection with our application of fresh start reporting at Emergence and was allocated entirely to our ERCOT Retail reporting unit. Of the goodwill recorded at Emergence, $1.686 billion is deductible for tax purposes over 15 years on a straight-line basis. Identifiable Intangible Assets and Liabilities Identifiable intangible assets are comprised of the following:
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Identifiable intangible liabilities are comprised of the following:
Amortization expense related to finite-lived identifiable intangible assets and liabilities (including the classification in the condensed statements of consolidated income (loss)) consisted of:
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Estimated Amortization of Identifiable Intangible Assets and Liabilities As of June 30, 2019, the estimated aggregate amortization expense of identifiable intangible assets and liabilities for each of the next five fiscal years is as shown below.
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Income Taxes (Notes) |
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Taxes | INCOME TAXES Income Tax Expense The calculation of our effective tax rate is as follows:
For the three months ended June 30, 2019, the effective tax rate of 29.5% related to our income tax expense was higher than the U.S. federal statutory rate of 21% due primarily to nondeductible impacts of the TRA and state income taxes, including the impact of a partial valuation allowance on the state of Illinois net operating loss. For the six months ended June 30, 2019, the effective tax rate of 28.0% related to our income tax expense was higher than the U.S. federal statutory rate of 21% due primarily to nondeductible impacts of the TRA and state income taxes, including the impact of a partial valuation allowance on the state of Illinois net operating loss. For the three months ended June 30, 2018, the effective tax rate of (238.7)% related to our income tax benefit was lower than the U.S. federal statutory rate of 21% due primarily to Vistra Energy's expanded state tax footprint requiring a one-time remeasurement of historical Vistra Energy deferred tax balances, partially offset by an increase in state tax expense. For the six months ended June 30, 2018, the effective tax rate of 44.8% related to our income tax benefit was higher than the U.S. federal statutory rate of 21% due primarily to Vistra Energy's expanded state tax footprint requiring a one-time remeasurement of historical Vistra Energy deferred tax balances and an increase in state tax expense. Liability for Uncertain Tax Positions Vistra Energy and its subsidiaries file income tax returns in U.S. federal and state jurisdictions and are expected to be subject to examinations by the IRS and other taxing authorities. Vistra Energy is not currently under audit by the IRS for any period, although review of Dynegy tax years 2017 and 2018 continue to progress through the IRS's Compliance Assurance Process audit program. Uncertain tax positions totaling $39 million at both June 30, 2019 and December 31, 2018 arose in connection with the Merger.
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Tax Receivable Agreement Obligation (Notes) |
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Tax Receivables Agreement Obligation | TAX RECEIVABLE AGREEMENT OBLIGATION On the Effective Date, Vistra Energy entered into a tax receivable agreement (the TRA) with a transfer agent on behalf of certain former first lien creditors of TCEH. The TRA generally provides for the payment by us to holders of TRA Rights of 85% of the amount of cash savings, if any, in U.S. federal and state income tax that we realize in periods after Emergence as a result of (a) certain transactions consummated pursuant to the Plan of Reorganization (including the step-up in tax basis in our assets resulting from the PrefCo Preferred Stock Sale), (b) the tax basis of all assets acquired in connection with the acquisition of two CCGT natural gas-fueled generation facilities in April 2016 and (c) tax benefits related to imputed interest deemed to be paid by us as a result of payments under the TRA, plus interest accruing from the due date of the applicable tax return. Pursuant to the TRA, we issued the TRA Rights for the benefit of the first lien secured creditors of TCEH entitled to receive such TRA Rights under the Plan of Reorganization. Such TRA Rights are entitled to certain registration rights more fully described in the Registration Rights Agreement (see Note 17). During the three months ended June 30, 2019, we recorded a decrease to the carrying value of the TRA obligation totaling approximately $48 million as a result of the decrease in forecasted taxable income over the projected life of the TRA. During the three months ended March 31, 2019, we recorded a decrease to the carrying value of the TRA obligation totaling approximately $19 million as a result of adjustments to forecasted taxable income and higher net operating losses acquired in the Merger. During the three months ended June 30, 2018, we recorded an increase to the carrying value of the TRA obligation totaling approximately $46 million related to changes in the timing of estimated payments and new multistate tax impacts resulting from the Merger. The following table summarizes the changes to the TRA obligation, reported as other current liabilities and Tax Receivable Agreement obligation in our condensed consolidated balance sheets, for the six months ended June 30, 2019 and 2018:
As of June 30, 2019, the estimated carrying value of the TRA obligation totaled $384 million, which represents the discounted amount of projected payments under the TRA. The projected payments are based on certain assumptions, including but not limited to (a) the federal corporate income tax rate of 21%, (b) estimates of our taxable income in the current and future years and (c) additional states that Vistra Energy now operates in, including the relevant tax rate and apportionment factor for each state. Our taxable income takes into consideration the current federal tax code, various relevant state tax laws and reflects our current estimates of future results of the business. These assumptions are subject to change, and those changes could have a material impact on the carrying value of the TRA obligation. As of June 30, 2019, the aggregate amount of undiscounted federal and state payments under the TRA is estimated to be approximately $1.3 billion, with more than half of such amount expected to be attributable to the first 15 tax years following Emergence, and the final payment expected to be made approximately 40 years following Emergence (if the TRA is not terminated earlier pursuant to its terms). The carrying value of the obligation is being accreted to the amount of the gross expected obligation using the effective interest method. Changes in the amount of this obligation resulting from changes to either the timing or amount of TRA payments are recognized in the period of change and measured using the discount rate inherent in the initial fair value of the obligation.
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Earnings Per Share (Notes) |
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Earnings Per Share [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earnings Per Share | EARNINGS PER SHARE Basic earnings per share available to common shareholders are based on the weighted average number of common shares outstanding during the period. Diluted earnings per share is calculated using the treasury stock method and includes the effect of all potential issuances of common shares under stock-based incentive compensation arrangements.
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Stock-based incentive compensation plan awards excluded from the calculation of diluted earnings per share because the effect would have been antidilutive totaled 2,910,226 and 8,064,657 shares for the three months ended June 30, 2019 and 2018, respectively, and 7,577,246 and 18,392,470 shares for the six months ended June 30, 2019 and 2018, respectively.
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Accounts Receivable Securitization Program (Notes) |
6 Months Ended |
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Jun. 30, 2019 | |
Accounts Receivable Securitization Program [Abstract] | |
Accounts Receivable Securitization Program [Text Block] | ACCOUNTS RECEIVABLE SECURITIZATION PROGRAM TXU Energy Receivables Company LLC (RecCo), an indirect subsidiary of Vistra Energy, has an accounts receivable financing facility (Receivables Facility) provided by issuers of asset-backed commercial paper and commercial banks (Purchasers). At June 30, 2019, the Receivables Facility provided RecCo with the ability to borrow up to $450 million, pursuant to an amendment to the terms of the Receivables Facility in April 2019. The Receivables Facility was renewed in July 2019, extending its scheduled termination from August 2019 to July 2020, with the ability to borrow up to $600 million until the settlement date in November 2019, after which the amount available for RecCo to borrow will revert to $450 million. Under the Receivables Facility, TXU Energy and Dynegy Energy Services are obligated to sell or contribute, on an ongoing basis and without recourse, their accounts receivable to TXU Energy's special purpose subsidiary, RecCo, a consolidated, wholly owned, bankruptcy-remote, direct subsidiary of TXU Energy. RecCo, in turn, is subject to certain conditions, and may, from time to time, sell an undivided interest in all the receivables acquired from TXU Energy and Dynegy Energy Services to the Purchasers, and its assets and credit are not available to satisfy the debts and obligations of any person, including affiliates of RecCo. Amounts funded by the Purchasers to RecCo are reflected as short-term borrowings on the condensed consolidated balance sheets. Proceeds and repayments under the Receivables Facility are reflected as cash flows from financing activities in our condensed statements of consolidated cash flows. Receivables transferred to the Purchasers remain on Vistra Energy's balance sheet and Vistra Energy reflects a liability equal to the amount advanced by the Purchasers. The Company records interest expense on amounts advanced. TXU Energy continues to service, administer and collect the trade receivables on behalf of RecCo and the Purchasers, as applicable. As of June 30, 2019, outstanding borrowings under the receivables facility totaled $430 million and were supported by $662 million of RecCo gross receivables. As of December 31, 2018, outstanding borrowings under the receivables facility totaled $339 million.
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Long-Term Debt (Notes) |
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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.
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Vistra Operations Credit Facilities At June 30, 2019, the Vistra Operations Credit Facilities consisted of up to $6.523 billion in senior secured, first lien revolving credit commitments and outstanding term loans, which consisted of revolving credit commitments of up to $2.725 billion, including a $2.35 billion letter of credit sub-facility (Revolving Credit Facility) and term loans of $1.897 billion (Term Loan B-1 Facility) and $1.901 billion (Term Loan B-3 Facility). In June 2019, Vistra Operations used the net proceeds from the Senior Secured Notes Offering described below to repay $889 million under the Term Loan B-1 Facility, the entire amount outstanding of $977 million under Term Loan B-2 Facility (and together with the Term Loan B-1 Facility and the Term Loan B-3 Facility, the Term Loan B Facility) and $134 million under the Term Loan B-3 Facility. We recorded an extinguishment loss of $4 million on the transactions in the three months ended June 30, 2019. These amounts reflect amendments to the Vistra Operations Credit Facilities in March 2019 and May 2019 whereby we obtained $225 million of incremental Revolving Credit Facility commitments. The letter of credit sub-facility was also increased by $50 million. Fees and expenses related to the amendments to the Vistra Operations Credit Facilities totaled $2 million in the six months ended June 30, 2019, which were capitalized as a noncurrent asset. These amounts also reflect an amendment to the Vistra Operations Credit Facilities in June 2018 whereby we incurred $2.050 billion of borrowings under the new Term Loan B-3 Facility and obtained $1.640 billion of incremental Revolving Credit Facility commitments. The letter of credit sub-facility was also increased by $1.585 billion. The maturity date of the Revolving Credit Facility was extended from August 4, 2021 to June 14, 2023. As discussed below, the proceeds from the Term Loan B-3 Facility were used to repay borrowings under the credit agreement that Vistra Energy assumed from Dynegy in connection with the Merger. Additionally, letter of credit term loans totaling $500 million (Term Loan C Facility) were repaid using $500 million of cash from collateral accounts used to backstop letters of credit. Fees and expenses related to the amendment to the Vistra Operations Credit Facilities totaled $42 million in the six months ended June 30, 2018, of which $23 million was recorded as interest expense and other charges on the statements of consolidated income (loss), $9 million was capitalized as a reduction in the carrying amount of the debt and $10 million was capitalized as a noncurrent asset. The Vistra Operations Credit Facilities and related available capacity at June 30, 2019 are presented below.
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In February 2018 and June 2018, certain pricing terms for the Vistra Operations Credit Facilities were amended. We accounted for these transactions as modifications of debt. At June 30, 2019, cash borrowings under the Revolving Credit Facility would bear interest based on applicable LIBOR rates, plus a fixed spread of 1.75%, and there were no outstanding borrowings. Letters of credit issued under the Revolving Credit Facility bear interest of 1.75%. Amounts borrowed under the Term Loan B-1 and B-3 Facilities bear interest based on applicable LIBOR rates plus fixed spreads of 2.00% and 2.00%, respectively. At June 30, 2019, the weighted average interest rates before taking into consideration interest rate swaps on outstanding borrowings was 4.40% and 4.40% under the Term Loan B-1 and B-3 Facilities, respectively. The Vistra Operations Credit Facilities also provide for certain additional fees payable to the agents and lenders, including fronting fees with respect to outstanding letters of credit and availability fees payable with respect to any unused portion of the available Revolving Credit Facility. Obligations under the Vistra Operations Credit Facilities are secured by a lien covering substantially all of Vistra Operations' (and its subsidiaries') consolidated assets, rights and properties, subject to certain exceptions set forth in the Vistra Operations Credit Facilities, provided that the amount of loans outstanding under the Vistra Operations Credit Facilities that may be secured by a lien covering certain principal properties of the Company is expressly limited by the terms of the Vistra Operations Credit Facilities. The Vistra Operations Credit Facilities also permit certain hedging agreements to be secured on a pari-passu basis with the Vistra Operations Credit Facilities in the event those hedging agreements met certain criteria set forth in the Vistra Operations Credit Facilities. The Vistra Operations Credit Facilities provide for affirmative and negative covenants applicable to Vistra Operations (and its restricted subsidiaries), including affirmative covenants requiring it to provide financial and other information to the agents under the Vistra Operations Credit Facilities and to not change its lines of business, and negative covenants restricting Vistra Operations' (and its restricted subsidiaries') ability to incur additional indebtedness, make investments, dispose of assets, pay dividends, grant liens or take certain other actions, in each case, except as permitted in the Vistra Operations Credit Facilities. Vistra Operations' ability to borrow under the Vistra Operations Credit Facilities is subject to the satisfaction of certain customary conditions precedent set forth therein. The Vistra Operations Credit Facilities provide for certain customary events of default, including events of default resulting from non-payment of principal, interest or fees when due, material breaches of representations and warranties, material breaches of covenants in the Vistra Operations Credit Facilities or ancillary loan documents, cross-defaults under other agreements or instruments and the entry of material judgments against Vistra Operations. Solely with respect to the Revolving Credit Facility, and solely during a compliance period (which, in general, is applicable when the aggregate revolving borrowings and issued revolving letters of credit (in excess of $300 million) exceed 30% of the revolving commitments), the agreement includes a covenant that requires the consolidated first lien net leverage ratio, which is based on the ratio of net first lien debt compared to an EBITDA calculation defined under the terms of the facilities, not to exceed 4.25 to 1.00. Although the period ended June 30, 2019 was not a compliance period, we would have been in compliance with this financial covenant if it was required to be tested at such date. Upon the existence of an event of default, the Vistra Operations Credit Facilities provide that all principal, interest and other amounts due thereunder will become immediately due and payable, either automatically or at the election of specified lenders. Interest Rate Swaps — Effective January 2017, we entered into $3.0 billion notional amount of interest rate swaps to hedge a portion of our exposure to our variable rate debt. The interest rate swaps expire in July 2023. In May 2018 and June 2018, we entered into $3.0 billion notional amount of interest rate swaps that become effective in July 2023 and expire in July 2026. In June 2018, we completed the novation of $1.959 billion notional amount of Vistra Energy (legacy Dynegy) interest rate swaps to Vistra Operations. In June 2019, we terminated $841 million notional amount of these interest rate swaps. At June 30, 2019, $720 million notional amount of these interest rate swaps remained in effect with an expiration date of February 2024. The interest rate swaps that are currently effective and expire in July 2023 and February 2024 effectively fix the interest rates between 3.92% and 4.16% on $3.720 billion of our variable rate debt. The interest rate swaps that become effective in July 2023 and expire in July 2026 effectively fix the interest rates between 4.97% and 5.04% on $3.0 billion of our variable rate debt during the period. The interest rate swaps are secured by a first lien secured interest on a pari-passu basis with the Vistra Operations Credit Facilities. Alternate Letter of Credit Facilities Two alternate letter of credit facilities (each, an Alternative LOC Facility, and collectively, the Alternate LOC Facilities) with an aggregate facility limit of $500 million became effective in the six months ended June 30, 2019. At June 30, 2019, $500 million of letters of credit were outstanding under the Alternate LOC Facilities. Of the total facility limit, $250 million matures in December 2020 and $250 million matures in December 2021. Vistra Energy (legacy Dynegy) Credit Agreement On the Merger Date, Vistra Energy assumed the obligations under Dynegy's $3.563 billion credit agreement consisting of a $2.018 billion senior secured term loan facility due 2024 and a $1.545 billion senior secured revolving credit facility. As of the Merger Date, there were no cash borrowings and $656 million of letters of credit outstanding under the senior secured revolving credit facility. On April 23, 2018, $70 million of the senior secured revolving credit facility matured. In June 2018, the $2.018 billion senior secured term loan facility due 2024 was repaid using proceeds from the Term Loan B-3 Facility. In addition, all letters of credit outstanding under the senior secured revolving credit facility were replaced with letters of credit under the amended Vistra Operations Credit Facilities discussed above, and the revolving credit facility assumed from Dynegy in connection with the Merger was paid off in full and terminated. Vistra Operations Senior Secured Notes In June 2019, Vistra Operations issued and sold $2.0 billion aggregate principal amount of senior secured notes (Senior Secured Notes), consisting of $1.2 billion aggregate principal amount of 3.55% senior secured notes due 2024 (3.55% senior secured notes) at a price to the public of 99.807% of their face value and $800 million aggregate principal amount of 4.30% senior secured notes due 2029 (4.30% senior secured notes) at a price to the public of 99.784% of their face value in an offering to eligible purchasers under Rule 144A and Regulation S under the Securities Act (Senior Secured Notes Offering). The Senior Secured Notes were sold pursuant to a purchase agreement by and among Vistra Operations, certain direct and indirect subsidiaries of Vistra Operations and Citigroup Global Markets Inc., as representative of the several initial purchasers. Fees and expenses related to the offering totaled $20 million in the three months ended June 30, 2019, which were capitalized as a reduction in the carrying amount of the debt. Net proceeds from the Senior Secured Notes Offering totaling $1.976 billion, together with cash on hand, were used to prepay certain amounts outstanding and accrued interest (together with fees and expenses) under the Vistra Operations Credit Facilities' Term Loan B Facility. Interest on the Senior Secured Notes is payable in cash semiannually in arrears on January 15 and July 15 beginning January 15, 2020. The Senior Secured Notes are and will be fully and unconditionally guaranteed by certain of Vistra Operations' current and future subsidiaries that also guarantee the Vistra Operations Credit Facilities. The Senior Secured Notes are secured by a first-priority security interest in the same collateral that is pledged for the benefit of the lenders under the Vistra Operations Credit Facilities, which consists of a substantial portion of the property, assets and rights owned by Vistra Operations and certain direct and indirect subsidiaries of Vistra Operations as subsidiary guarantors (collectively, the Guarantor Subsidiaries) as well as the stock of Vistra Operations held by Vistra Intermediate. The collateral securing the Senior Secured Notes will be released if Vistra Operations' senior, unsecured long-term debt securities obtain an investment grade rating from two out of the three rating agencies, subject to reversion if such rating agencies withdraw the investment grade rating of Vistra Operations' senior, unsecured long-term debt securities or downgrade such rating below investment grade. Vistra Operations Senior Unsecured Notes In June 2019, Vistra Operations issued and sold $1.3 billion aggregate principal amount of 5.00% senior unsecured notes due 2027 (5.00% senior notes) in an offering to eligible purchasers under Rule 144A and Regulation S under the Securities Act (the June 2019 Notes Offering). The 5.00% senior notes were sold pursuant to a purchase agreement by and among Vistra Operations, the Guarantor Subsidiaries and Goldman Sachs & Co. LLC, as representative of the several initial purchasers. Fees and expenses related to the offering totaled $13 million in the three months ended June 30, 2019, which were capitalized as a reduction in the carrying amount of the debt. Net proceeds from the June 2019 Notes Offering totaling approximately $1.287 billion, together with cash on hand, were used to pay the purchase price and accrued interest (together with fees and expenses) required in connection with (i) the June 2019 Tender Offer described below and (ii) the redemption of approximately $306 million of our outstanding 7.375% senior unsecured notes due 2022 (7.375% senior notes) and approximately $87 million of our 7.625% senior unsecured notes due 2024 (7.625% senior notes) in July 2019. The 5.00% senior notes mature in July 2027, with interest payable in cash semiannually in arrears on January 31and July 31 beginning January 31, 2020. In February 2019, Vistra Operations issued and sold $1.3 billion aggregate principal amount of 5.625% senior unsecured notes due 2027 (5.625% senior notes) in an offering to eligible purchasers under Rule 144A and Regulation S under the Securities Act (the February 2019 Notes Offering). The 5.625% senior notes were sold pursuant to a purchase agreement by and among Vistra Operations, the Guarantor Subsidiaries and J.P. Morgan Securities LLC, as representative of the several initial purchasers. Fees and expenses related to the offering totaled $16 million in the three months ended March 31, 2019, which were capitalized as a reduction in the carrying amount of the debt. Net proceeds from the February 2019 Notes Offering totaling approximately $1.287 billion, together with cash on hand, were used to pay the purchase price and accrued interest (together with fees and expenses) required in connection with (i) the February 2019 Tender Offer described below, (ii) the redemption of approximately $35 million aggregate principal amount of our 7.375% senior notes and (iii) the redemption of approximately $25 million aggregate principal amount of our outstanding 8.034% senior unsecured notes due 2024 (8.034% senior notes). The 5.625% senior notes mature in February 2027, with interest payable in cash semiannually in arrears on February 15 and August 15 beginning August 15, 2019. In August 2018, Vistra Operations issued $1.0 billion principal amount of 5.500% senior unsecured notes due 2026 (5.500% senior notes, and together with the 5.00% senior notes and the 5.625% senior notes, the Vistra Operations Senior Unsecured Notes) in an offering to eligible purchasers under Rule 144A and Regulation S under the Securities Act (the 2018 Notes Offering). The 5.500% senior notes were sold pursuant to a purchase agreement by and among Vistra Operations, the Guarantor Subsidiaries and Citigroup Global Markets Inc., as representative of the several initial purchasers. Fees and expenses related to the offering totaled $12 million in the three months ended September 30, 2018, which were capitalized as a reduction in the carrying amount of the debt. Net proceeds from the 2018 Notes Offering totaling approximately $990 million, together with cash on hand and cash received from the funding of the Receivables Facility (see Note 10), were used to pay the purchase price and accrued interest (together with fees and expenses) required in connection with the 2018 Tender Offers described below. The 5.500% senior notes mature in September 2026, with interest payable in cash semiannually in arrears on March 1 and September 1 beginning March 1, 2019. The indentures governing the 5.00% senior notes, the 5.625% senior notes and the 5.500% senior notes (collectively, as each may be amended or supplemented from time to time, the Vistra Operations Senior Unsecured Indentures) provide for the full and unconditional guarantee by the Guarantor Subsidiaries of the punctual payment of the principal and interest on such notes. The Vistra Operations Senior Unsecured Indentures contain certain covenants and restrictions, including, among others, restrictions on the ability of the Issuer and its subsidiaries, as applicable, to create certain liens, merge or consolidate with another entity, and sell all or substantially all of their assets. Vistra Energy Senior Unsecured Notes Bond Repurchase Program — In November 2018, our board of directors (the Board) authorized a bond repurchase program under which up to $200 million principal amount of outstanding Vistra Energy Senior Unsecured Notes could be repurchased. Through June 30, 2019, $119 million principal amount of Vistra Energy Senior Unsecured Notes had been repurchased. No repurchases were made in the three and six months ended June 30, 2019. June 2019 Tender Offer — In June 2019, Vistra Energy used the net proceeds from the June 2019 Notes Offering to fund a cash tender offer (the June 2019 Tender Offer) to purchase for cash $845 million aggregate principal amount of certain notes assumed in the Merger, including $173 million of 7.375% senior notes and $672 million of 7.625% senior notes. We recorded an extinguishment gain of $7 million on the transactions in the three months ended June 30, 2019. In July 2019, Vistra Energy accepted and settled an additional approximately $1 million aggregate principal amount of outstanding 7.625% senior notes that were tendered after the early tender date of the 2019 Tender Offer. February 2019 Tender Offer and Consent Solicitation — In February 2019, Vistra Energy used the net proceeds from the February 2019 Notes Offering to fund a cash tender offer (the February 2019 Tender Offer) to purchase for cash $1.193 billion aggregate principal amount of 7.375% senior notes assumed in the Merger. We recorded an extinguishment gain of $7 million on the transactions in the three months ended March 31, 2019. In connection with the February 2019 Tender Offer, Vistra Energy also commenced solicitation of consents from holders of the 7.375% senior notes. Vistra Energy received the requisite consents from the holders of the 7.375% senior notes and amended the indenture governing these senior notes to, among other things, eliminate substantially all of the restrictive covenants and certain events of default. August 2018 Tender Offers and Consent Solicitations — In August 2018, Vistra Energy used the net proceeds from the 2018 Notes Offering, proceeds from the Receivables Facility (see Note 10) and cash on hand to fund cash tender offers (the 2018 Tender Offers) to purchase for cash $1.542 billion aggregate principal amount of Vistra Energy Senior Unsecured Notes assumed in the Merger. We recorded an extinguishment loss of $27 million on the transactions in the three months ended September 30, 2018. Notes purchased consisted of the following:
In connection with the 2018 Tender Offers, Vistra Energy also commenced solicitations of consents from holders of the 7.375% senior notes, the 7.625% senior notes, the 8.034% senior notes, the 8.000% senior notes and the 8.125% senior notes to amend certain provisions of the applicable indentures governing each series of senior notes and the registration rights agreement with respect to the 8.125% senior notes. Vistra Energy received the requisite consents from the holders of the 8.034% senior notes, the 8.000% senior notes and the 8.125% senior notes (collectively, the Consent Senior Notes) and amended (a) the indentures governing each series of the applicable senior notes to, among other things, eliminate substantially all of the restrictive covenants and certain events of default and (b) the registration rights agreement with respect to the 8.125% senior notes to remove, among other things, the requirement that Vistra Energy commence an exchange offer to issue registered securities in exchange for the existing, nonregistered notes. Assumption of Senior Notes in Merger — On the Merger Date, Vistra Energy assumed $6.138 billion principal amount of Dynegy's senior unsecured notes. In May 2018, $850 million of outstanding 6.75% senior unsecured notes due 2019 were redeemed at a redemption price of 101.688% of the aggregate principal amount, plus accrued and unpaid interest up to but not including the date of redemption. Fees and expenses related to the redemption totaled $14 million in the three months ended June 30, 2018 and were recorded as interest expense and other charges on the condensed statements of consolidated income (loss). In June 2018, each of the Company's subsidiaries that guaranteed the Vistra Operations Credit Facilities (and did not already guarantee the senior notes) provided a guarantee on the senior notes that remained outstanding. The senior notes that remain outstanding after the closing of the Tender Offers are unsecured and unsubordinated obligations of Vistra Energy and are guaranteed by substantially all of its current and future wholly owned domestic subsidiaries that from time to time are a borrower or guarantor under the agreement governing the Vistra Operations Credit Facilities (Credit Facilities Agreement) (see Note 20). Except with respect to the Consent Senior Notes, the respective indentures of the senior notes of Vistra Energy (collectively, as each may be amended or supplemented from time to time, the Vistra Energy Senior Unsecured Indentures) limit, among other things, the ability of the Company or any of the guarantors to create liens upon any principal property to secure debt for borrowed money in excess of, among other limitations, 30% of total assets. The Vistra Energy Senior Unsecured Indentures also contain customary events of default which would permit the holders of the applicable series of senior notes to declare such notes to be immediately due and payable if not cured within applicable grace periods, including the failure to make timely principal or interest payments on such notes or (except with respect to the Consent Senior Notes) other indebtedness aggregating $100 million or more, and, except with respect to the Consent Senior Notes, the failure to satisfy covenants, and specified events of bankruptcy and insolvency. Amortizing Notes On the Merger Date, Vistra Energy assumed the obligations of Dynegy's senior unsecured amortizing note (Amortizing Notes) that matured on July 1, 2019. The Amortizing Notes were issued in connection with the issuance of the tangible equity units (TEUs) by Dynegy (see Note 14). Each installment payment per Amortizing Note was paid in cash and constituted a partial repayment of principal and a payment of interest, computed at an annual rate of 7.00%. Interest was calculated on the basis of a 360-day year consisting of twelve 30-day months. Payments were applied first to the interest due and payable and then to the reduction of the unpaid principal amount, allocated as set forth in the indenture (Amortizing Notes Indenture). On the maturity date, the Company paid all amounts due under the Amortizing Notes Indenture and the Amortizing Notes Indenture ceased to be of further force and effect. Forward Capacity Agreements On the Merger Date, the Company assumed the obligation of Dynegy's agreements under which a portion of the PJM capacity that cleared for Planning Years 2018-2019, 2019-2020 and 2020-2021 was sold to a financial institution (Forward Capacity Agreements). The buyer in this transaction will receive capacity payments from PJM during the Planning Years 2019-2020 and 2020-2021 in the amounts of $112 million and $110 million, respectively. We will continue to be subject to the performance obligations as well as any associated performance penalties and bonus payments for those planning years. As a result, this transaction is accounted for as long-term debt of $222 million with an implied interest rate of 3.36%. Equipment Financing Agreements On the Merger Date, the Company assumed Dynegy's Equipment Financing Agreements. Under certain of our contractual service agreements in which we receive maintenance and capital improvements for our gas-fueled generation fleet, we have obtained parts and equipment intended to increase the output, efficiency and availability of our generation units. We have financed these parts and equipment under agreements with maturities ranging from 2019 to 2026. The portion of future payments attributable to principal will be classified as cash outflows from financing activities, and the portion of future payments attributable to interest will be classified as cash outflows from operating activities in our condensed statements of consolidated cash flows. Maturities Long-term debt maturities (including mandatory amortization of the Term Loan B Facility) at June 30, 2019 are as follows:
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Leases | LEASES Vistra has operating leases for real estate, rail cars, rental tanks and equipment. Our leases have remaining lease terms for 1 to 38 years. Our leases include options to renew up to 14 years. Certain leases also contain options to terminate the lease. Lease Cost The following table presents costs related to lease activities:
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Balance Sheet Information The following table presents lease related balance sheet information:
Cash Flow and Other Information The following table presents lease related cash flow and other information:
Weighted Average Remaining Lease Term The following table presents weighted average remaining lease term information:
Maturity of Lease Liabilities The following table presents maturity of lease liabilities:
As of June 30, 2019, we have no material operating or finance leases that have not yet commenced.
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Leases | LEASES Vistra has operating leases for real estate, rail cars, rental tanks and equipment. Our leases have remaining lease terms for 1 to 38 years. Our leases include options to renew up to 14 years. Certain leases also contain options to terminate the lease. Lease Cost The following table presents costs related to lease activities:
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Balance Sheet Information The following table presents lease related balance sheet information:
Cash Flow and Other Information The following table presents lease related cash flow and other information:
Weighted Average Remaining Lease Term The following table presents weighted average remaining lease term information:
Maturity of Lease Liabilities The following table presents maturity of lease liabilities:
As of June 30, 2019, we have no material operating or finance leases that have not yet commenced.
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Commitments and Contingencies (Notes) |
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Commitments And Contingencies | COMMITMENTS AND CONTINGENCIES Guarantees We have entered into contracts, including the assumed Dynegy senior unsecured notes described above, that contain guarantees to unaffiliated parties that could require performance or payment under certain conditions. As of June 30, 2019, there are no material outstanding claims related to our guarantee obligations, and we do not anticipate we will be required to make any material payments under these guarantees. Letters of Credit At June 30, 2019, we had outstanding letters of credit totaling $1.052 billion as follows:
Surety Bonds At June 30, 2019, we had outstanding surety bonds totaling $27 million to support performance under various contracts and legal obligations in the normal course of business. Litigation Gas Index Pricing Litigation — We, through our subsidiaries, and other energy companies are named as defendants in several lawsuits claiming damages resulting from alleged price manipulation through false reporting of natural gas prices to various index publications, wash trading and churn trading from 2000-2002. The cases allege that the defendants engaged in an antitrust conspiracy to inflate natural gas prices in three states (Kansas, Missouri and Wisconsin) during the relevant time period and seek damages under the respective state antitrust statutes. The cases had been consolidated (along with other similar cases) in a multi-district litigation (MDL) proceeding in the U.S. District Court for Nevada, but in January 2019 the MDL judge issued an order remanding the consolidated cases back to their respective courts of origin. Along with the other defendants, we had previously reached settlement terms in the Kansas and Missouri class action cases, and plaintiffs in those cases filed a Notice of Settlement with the judge in the multi-district court proceeding. We remain as defendants in two putative class actions (Wisconsin) and one individual action (Kansas) on behalf of Farmland Industries, Inc. While we cannot predict the outcome of these legal proceedings, or estimate a range of costs, they could have a material impact on our results of operations, liquidity or financial condition. Advatech Dispute — In September 2016, Illinois Power Generating Company (Genco), terminated its Second Amended and Restated Newton Flue Gas Desulfurization System Engineering, Procurement, Construction and Commissioning Services Contract dated as of December 15, 2014 with Advatech, LLC (Advatech). Advatech issued Genco its final invoice in September 2016 totaling $81 million. Genco contested the invoice in October 2016 and believes the proper amount is less than $1 million. In October 2016, Advatech initiated the dispute resolution process under the contract and filed for arbitration in March 2017. The arbitration hearing occurred in October 2018, and the arbitration panel issued a final award in June 2019, including pre-award and post-award interest and fees totaling approximately $46 million, of which $42 million was recorded as a liability as part of our purchase price allocation of the Merger, $2 million was recorded as interest expense in our condensed statements of consolidated income (loss) and $2 million was recorded as selling, general and administrative expense in our condensed statements of consolidated income (loss). In June 2019, Genco moved to vacate the award in the U.S. District Court for the Southern District of Illinois, and Advatech moved to confirm the award in the U.S. District Court for the Northern District of Illinois. Wood River Rail Dispute — In November 2017, Dynegy Midwest Generation, LLC (DMG) received notification that BNSF Railway Company and Norfolk Southern Railway Company were initiating dispute resolution related to DMG's suspension of its Wood River Rail Transportation Agreement with the railroads. Settlement discussions required under the dispute resolution process have been unsuccessful. In March 2018, BNSF Railway Company and Norfolk Southern Railway Company filed a demand for arbitration. The arbitration hearing on the merits is scheduled for February 2020. We dispute the railroads' allegations and will defend our position vigorously. While we cannot predict the outcome of this legal proceeding, or estimate a range of costs, it could have a material impact on our results of operations, liquidity or financial condition. Greenhouse Gas Emissions In August 2015, the EPA finalized rules to address greenhouse gas emissions (GHG) from electricity generation units, referred to as the Clean Power Plan, including rules for existing facilities that would establish state-specific emissions rate goals to reduce nationwide CO2 emissions. Various parties (including Luminant) filed petitions for review in the U.S. Court of Appeals for the District of Columbia Circuit (D.C. Circuit Court) and subsequently, in January 2016, a coalition of state, industry (including Luminant) and other parties filed applications with the U.S. Supreme Court (Supreme Court) asking that the Supreme Court stay the rule pending review by the D.C. Circuit Court. In February 2016, the Supreme Court stayed the rule. After oral argument in September 2016, the case was placed in abeyance and remains pending before the D.C. Circuit Court. In July 2019, petitioners filed a joint motion to dismiss in light of the EPA's new rule, the Affordable Clean Energy rule, that replaces the Clean Power Plan discussed below. That motion remains pending before the D.C. Circuit Court. In July 2019, the EPA finalized a rule to repeal the Clean Power Plan, with new regulations addressing GHG emissions from existing coal-fueled electric generation units, referred to as the Affordable Clean Energy (ACE) rule. The ACE rule develops emission guidelines that states must use when developing plans to regulate GHG emissions from existing coal-fueled electric generating units. States must submit their plans for regulating GHG emissions from existing facilities by July 2022. Environmental groups filed a petition for review of the ACE rule and the repeal of the Clean Power Plan in the D.C. Circuit Court. Additionally, in December 2018, the EPA issued proposed revisions to the emission standards for new, modified and reconstructed units. Vistra submitted comments on that proposed rulemaking. While we cannot predict the outcome of these rulemakings and related legal proceedings, or estimate a range of reasonably probable costs, the rules, if implemented, could have a material impact on our results of operations, liquidity or financial condition. Regional Haze — Reasonable Progress and Best Available Retrofit Technology (BART) for Texas In January 2016, the EPA issued a final rule approving in part and disapproving in part Texas's 2009 State Implementation Plan (SIP) as it relates to the reasonable progress component of the Regional Haze program and issuing a Federal Implementation Plan (FIP). The EPA's emission limits in the FIP assume additional control equipment for specific lignite/coal-fueled generation units across Texas, including new flue gas desulfurization systems (scrubbers) at seven electricity generation units (including Big Brown Units 1 and 2, Monticello Units 1 and 2 and Coleto Creek) and upgrades to existing scrubbers at seven generation units (including Martin Lake Units 1, 2 and 3, Monticello Unit 3 and Sandow Unit 4). In March 2016, various parties (including Luminant and the State of Texas) filed petitions for review in the U.S. Court of Appeals for the Fifth Circuit (Fifth Circuit Court) challenging the FIP's Texas requirements. In July 2016, the Fifth Circuit Court granted motions to stay the rule pending final review of the petitions for review. In March 2017, the Fifth Circuit Court granted a motion by the EPA to remand the rule back to the EPA for reconsideration. The stay of the rule (and the emission control requirements) remains in effect. The retirements of our Monticello, Big Brown and Sandow 4 plants should have a favorable impact on this rulemaking and litigation. While we cannot predict the outcome of the rulemaking and legal proceedings, or estimate a range of reasonably possible costs, the result could have a material impact on our results of operations, liquidity or financial condition. In September 2017, the EPA signed a final rule addressing BART for Texas electricity generation units, with the rule serving as a partial approval of Texas's 2009 SIP and a partial FIP. For SO2, the rule creates an intrastate Texas emission allowance trading program as a "BART alternative" that operates in a similar fashion to a CSAPR trading program. The program includes 39 generating units (including our Martin Lake, Big Brown, Monticello, Sandow 4, Coleto Creek, Stryker 2 and Graham 2 plants). The compliance obligations in the program started on January 1, 2019. We believe the retirements of our Monticello, Big Brown and Sandow 4 plants will enhance our ability to comply with this BART rule for SO2. For NOX, the rule adopts the CSAPR's ozone program as BART and for particulate matter, the rule approves Texas's SIP that determines that no electricity generation units are subject to BART for particulate matter. Various parties filed a petition challenging the rule in the Fifth Circuit Court as well as a petition for reconsideration filed with the EPA. Luminant intervened on behalf of the EPA in the Fifth Circuit Court action. In March 2018, the Fifth Circuit Court abated its proceedings until the EPA concludes the reconsideration process. In August 2018, the EPA issued a proposed rule affirming the prior BART final rule and seeking comments on that proposal, which were due in October 2018. While we cannot predict the outcome of the rulemaking and legal proceedings, we believe the rule, if ultimately implemented or upheld as issued, will not have a material impact on our results of operations, liquidity or financial condition. Affirmative Defenses During Malfunctions In May 2015, the EPA finalized a rule requiring 36 states, including Texas, Illinois and Ohio, to remove or replace either EPA-approved exemptions or affirmative defense provisions for excess emissions during upset events and unplanned maintenance and startup and shutdown events, referred to as the SIP Call. Various parties (including Luminant, the State of Texas and the State of Ohio) filed petitions for review of the EPA's final rule, and all of those petitions were consolidated in the D.C. Circuit Court. In April 2017, the D.C. Circuit Court ordered the case to be held in abeyance. In April 2019, the EPA Region 6 proposed a rule to withdraw the SIP Call with respect to the Texas affirmative defense provisions. We submitted comments on that proposed rulemaking. We cannot predict the timing or outcome of this proceeding, or estimate a range of reasonably possible costs, but implementation of the 2015 rule as finalized could have a material impact on our results of operations, liquidity or financial condition. Illinois Multi-Pollutant Standards (MPS) In 2007, our MISO coal-fueled generation facilities became subject to the Illinois multi-pollutant standard rule (MPS rule), which requires compliance with NOX, SO2 and mercury emissions limits. We are in compliance with the MPS rule. In October 2017, the Illinois Environmental Protection Agency (IEPA) filed a proposed rule with the Illinois Pollution Control Board (IPCB) that would amend the MPS rule by replacing the two separate group-wide annual emission rate limits that currently apply to our eight downstate Illinois coal-fueled stations with tonnage limits for both SO2 (annual) and NOX (annual and seasonal) that apply to the eight stations as a single group. In March 2019, we were asked to agree to even further reduced emission caps and in order to move the rule forward, committed to 2,000 MW of coal plant retirements following finalization of the rule. Under the proposal, allowable annual emissions of SO2 would be 48% lower than the current rule and NOX emission would be 42% lower. All other federal and state air quality regulations, including health-based standards, would remain unchanged and in place. The proposed rule also would impose new requirements to ensure the continuous operation of existing selective catalytic reduction (SCR) control systems during the ozone season, require SCR-controlled units to meet an ozone season NOX emission rate limit, and set an additional, site-specific annual SO2 limit for our Joppa Power Station. In June 2019, the IPCB voted to approve the rule and it now awaits review by the Joint Committee on Administrative Rules. We are supportive of the proposed rule as it would provide operational flexibility to our MISO fleet while also providing a number of regulatory and environmental benefits. We expect the rule to be finalized in 2019. 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 addition, with respect to Monticello and Big Brown, the retirement of those plants should favorably impact our legal challenge to the nonattainment designations in that the nonattainment designations for Freestone County and Titus County are based solely on the Sierra Club modeling, which we dispute, of SO2 emissions from Monticello and Big Brown. Regardless, considering these retirements, the nonattainment designations for those counties are no longer supported. While we cannot predict the outcome of this matter, or estimate a range of reasonably possible costs, the result could have a material impact on our results of operations, liquidity or financial condition. Effluent Limitation Guidelines (ELGs) In November 2015, the EPA revised the ELGs for steam electricity generation facilities, which will impose more stringent standards (as individual permits are renewed) for wastewater streams, such as flue gas desulfurization (FGD), fly ash, bottom ash and flue gas mercury control wastewaters. Various parties filed petitions for review of the ELG rule, and the petitions were consolidated in the Fifth Circuit Court. In April 2017, the EPA granted petitions requesting reconsideration of the ELG final rule and administratively stayed the rule's compliance date deadlines. In August 2017, the EPA announced that its reconsideration of the 2015 ELG final rule would be limited to a review of the effluent limitations applicable to FGD and bottom ash wastewaters and the agency subsequently postponed the earliest compliance dates in the 2015 ELG Rule for the application of effluent limitations for FGD and bottom ash wastewaters from November 1, 2018 to November 1, 2020. Based on these administrative developments, the Fifth Circuit Court agreed to sever and hold in abeyance challenges to effluent limitations. The remainder of the case proceeded, and in April 2019 the Fifth Circuit Court vacated and remanded portions of the EPA's ELG rule pertaining to effluent limitations for legacy wastewater and leachate. The EPA has not yet proposed or finalized a rule reconsidering the FGD and bottom ash wastewater provisions of the 2015 ELG rule. Given the EPA's decision to reconsider the FGD and bottom ash wastewater provisions of the ELG rule, the rule postponing the ELG rule's earliest compliance dates for those provisions, the uncertainty stemming from the vacatur of the effluent limitations for legacy wastewater and leachate, and the intertwined relationship of the ELG rule with the Coal Combustion Residuals rule discussed below, which is also being reconsidered by the EPA, as well as pending legal challenges concerning both rules, substantial uncertainty exists regarding our projected capital expenditures for ELG compliance, including the timing of such expenditures. While we cannot predict the outcome of this matter, or estimate a range of costs, it could have a material impact on our results of operations, liquidity or financial condition. New Source Review and CAA Matters New Source Review — Since 1999, the EPA has engaged in a nationwide enforcement initiative to determine whether coal-fueled power plants failed to comply with the requirements of the New Source Review (NSR) and New Source Performance Standard provisions under the CAA when the plants implemented changes. The EPA's NSR initiative focuses on whether projects performed at power plants triggered various permitting requirements, including the need to install pollution control equipment. In August 2013, the U.S. Department of Justice (DOJ), acting as the attorneys for the EPA, filed a civil enforcement lawsuit against Luminant in federal district court in Dallas, alleging violations of the CAA, including its NSR standards, at our Big Brown and Martin Lake generation facilities. The lawsuit requests (i) the maximum civil penalties available under the CAA to the government of up to $32,500 to $37,500 per day for each alleged violation, depending on the date of the alleged violation, and (ii) injunctive relief, including an order to apply for pre-construction permits which may require the installation of best available control technology at the affected units. In August 2015, the district court granted Luminant's motion to dismiss seven of the nine claims asserted by the EPA in the lawsuit. In January 2017, the EPA dismissed its two remaining claims with prejudice and the district court entered final judgment in Luminant's favor. In March 2017, the EPA and the Sierra Club appealed the final judgment to the Fifth Circuit Court. In October 2018, the Fifth Circuit Court affirmed in part, reversed in part, and remanded to the district court. The Fifth Circuit Court's decision held that the district court properly dismissed all of the civil penalties as time-barred. The Fifth Circuit Court further held that the grounds cited by the district court did not support dismissal of the injunctive relief claims at this early stage of the case and remanded the case back to the district court for further consideration. In November 2018, we filed a petition for rehearing en banc on two issues and the EPA has filed a response to that petition. In July 2019, the full Fifth Circuit Court granted our en banc petition and oral argument will be held in September 2019. We believe that we have complied with all requirements of the CAA and intend to continue to vigorously defend against the remaining allegations. An adverse outcome could require substantial capital expenditures that cannot be determined at this time or retirement of the remaining plant at issue, Martin Lake. The retirement of the Big Brown plant should have a favorable impact on this litigation. Zimmer NOVs — In December 2014, the EPA issued a notice of violation (NOV) alleging violation of opacity standards at the Zimmer facility. The EPA previously had issued NOVs to Zimmer in 2008 and 2010 alleging violations of the CAA, the Ohio State Implementation Plan and the station's air permits including standards applicable to opacity, sulfur dioxide, sulfuric acid mist and heat input. The NOVs remain unresolved. Edwards CAA Citizen Suit — In April 2013, environmental groups filed a CAA citizen suit in the U.S. District Court for the Central District of Illinois alleging violations of opacity and particulate matter limits at our MISO segment's Edwards facility. In August 2016, the district court granted the plaintiffs' motion for summary judgment on certain liability issues. In March 2019, the court denied the parties' motions for summary judgment on remedy issues. A bench trial on the remedy issues is scheduled for the end of September 2019. We dispute the allegations and will defend the case vigorously. Ultimate resolution of any of these CAA matters could have a material adverse impact on our future financial condition, results of operations, and cash flows. A resolution could result in increased capital expenditures for the installation of pollution control equipment, increased operations and maintenance expenses, and penalties, or could result in an order or a decision to retire these plants. While we cannot predict the outcome of these legal proceedings, or estimate a range of costs, they could have a material impact on our results of operations, liquidity or financial condition. Coal Combustion Residuals/Groundwater In July 2018, the EPA published a final rule, which became effective in August 2018, that amends certain provisions of the Coal Combustion Residuals (CCR) rule that the agency issued in 2015. Among other changes, the 2018 revisions extend closure deadlines to October 31, 2020, related to the aquifer location restriction and groundwater monitoring requirements. Also, on August 21, 2018, the D.C. Circuit Court issued a decision that vacates and remands certain provisions of the 2015 CCR rule, including an applicability exemption for legacy impoundments. The EPA is expected to undertake further revisions to its CCR regulations in response to the D.C. Circuit Court's ruling. In October 2018, the rule that extends certain closure deadlines to 2020 was challenged in the D.C. Circuit Court. In March 2019, the D.C. Circuit Court granted the EPA's request for remand without vacatur. The EPA is expected to issue proposed rules on these and other aspects of the CCR rule in the near term. While we cannot predict the impacts of these rule revisions (including whether and if so how the states in which we operate will utilize the authority delegated to the states through the revisions), or estimate a range of reasonably possible costs related to these revisions, the changes that result from these revisions could have a material impact on our results of operations, liquidity or financial condition. MISO Segment — In 2012, the Illinois Environmental Protection Agency (IEPA) issued violation notices alleging violations of groundwater standards onsite at our Baldwin and Vermilion facilities' CCR surface impoundments. In 2016, the IEPA approved our closure and post-closure care plans for the Baldwin old east, east, and west fly ash CCR surface impoundments. We are working towards implementation of those closure plans. At our retired Vermilion facility, which was not subject to the EPA's 2015 CCR rule until the aforementioned D.C. Circuit court decision in August 2018, we submitted proposed corrective action plans involving closure of two CCR surface impoundments (i.e., the old east and the north impoundments) to the IEPA in 2012, with revised plans submitted in 2014. In May 2017, in response to a request from the IEPA for additional information regarding the closure of these Vermilion surface impoundments, we agreed to perform additional groundwater sampling and closure options and riverbank stabilizing options. In May 2018, Prairie Rivers Network filed a citizen suit against our subsidiary Dynegy Midwest Generation, LLC (DMG), alleging violations of the Clean Water Act for alleged unauthorized discharges. In August 2018, we filed a motion to dismiss the lawsuit. In November 2018, the district court granted our motion to dismiss and judgment was entered in our favor. Plaintiffs have appealed the judgment to the U.S Court of Appeals for the Seventh Circuit. That appeal is now stayed. In April 2019, PRN also filed a complaint against DMG before the IPCB, alleging that groundwater flows allegedly associated with the ash impoundments at the Vermilion site have resulted in exceedances both of surface water standards and Illinois groundwater standards dating back to 1992. This matter is in very early stages and we dispute the allegations in the complaint. We dispute the allegations in both of these matters and will vigorously defend our position. In 2012, the IEPA issued violation notices alleging violations of groundwater standards at the Newton and Coffeen facilities' CCR surface impoundments. We are addressing these CCR surface impoundments in accordance with the federal CCR rule. In June 2018, the IEPA issued a violation notice for alleged seep discharges claimed to be coming from the surface impoundments at our retired Vermilion facility and that notice has since been referred to the Illinois Attorney General. In December 2018, the Sierra Club filed a complaint with the IPCB alleging the disposal and storage of coal ash at the Coffeen, Edwards and Joppa generation facilities are causing exceedances of the applicable groundwater standards. We dispute the allegations and will vigorously defend our position. In May 2019, coal ash disposal and storage legislation passed the Illinois legislature and is now awaiting signature by the Illinois Governor. The legislation addresses state requirements for the proper closure of coal ash ponds in the state of Illinois. The legislation tasks the IEPA and the IPCB to set up a series of guidelines, rules and permit requirements for closure of ash ponds. Assuming the legislation is signed, we expect the rulemaking process should take about 18 months to complete. Under the legislation, coal ash impoundment owners would be required to submit a closure alternative analysis to the IEPA for the selection of the best method for coal ash remediation at a particular site. The legislation does not mandate closure by removal at any site. With respect to near-term costs, the legislation requires that operators pay a one-time fee of $50,000 for each closed site and $75,000 for each open site. This one-time fee is paid six months after the effective date of the legislation. The legislation also requires annual permit fees. While we cannot predict the outcome of these proceedings, or estimate a range of costs, they could have a material impact on our results of operations, liquidity or financial condition. For all of the above matters, if remediation measures concerning groundwater are necessary at any of our coal-fueled facilities, we may incur significant costs that could have a material adverse effect on our financial condition, results of operations, and cash flows. At this time, in part because of the revisions to the CCR rule that the EPA published in July 2018 and the D.C. Circuit Court's vacatur and remand of certain provisions of the EPA's 2015 CCR rule and the Illinois coal ash legislation, we cannot reasonably estimate the costs, or range of costs, of groundwater remediation, if any, that ultimately may be required. Current CCR surface impoundment and landfill closure costs, as determined by our operations and environmental services teams, are reflected in our AROs. MISO 2015-2016 Planning Resource Auction In May 2015, three complaints were filed at FERC regarding the Zone 4 results for the 2015-2016 planning resource auction (PRA) conducted by MISO. Dynegy is a named party in one of the complaints. The complainants, Public Citizen, Inc., the Illinois Attorney General and Southwestern Electric Cooperative, Inc. (Complainants), challenged the results of the PRA as unjust and unreasonable, requested rate relief/refunds, and requested changes to the MISO planning resource auction structure going forward. Complainants also alleged that Dynegy may have engaged in economic or physical withholding in Zone 4 constituting market manipulation in the PRA. The Independent Market Monitor for MISO (MISO IMM), which was responsible for monitoring the PRA, determined that all offers were competitive and that no physical or economic withholding occurred. The MISO IMM also stated, in a filing responding to the complaints, that there is no basis for the remedies sought by the Complainants. We filed our answer to these complaints explaining that we complied fully with the terms of the MISO tariff in connection with the PRA and disputing the allegations. The Illinois Industrial Energy Consumers filed a related complaint at FERC against MISO in June 2015 requesting prospective changes to the MISO tariff. Dynegy also responded to this complaint with respect to Dynegy's conduct alleged in the complaint. In October 2015, FERC issued an order of nonpublic, formal investigation (the investigation) into whether market manipulation or other potential violations of FERC orders, rules and regulations occurred before or during the PRA. In December 2015, FERC issued an order on the complaints requiring a number of prospective changes to the MISO tariff provisions effective as of the 2016-2017 planning resource auction. The order did not address the arguments of the Complainants regarding the PRA and stated that those issues remained under consideration and would be addressed in a future order. In July 2019, FERC issued an order denying the remaining issues raised by the complaints and noted that the investigation into Dynegy was closed. FERC found that Dynegy's conduct did not constitute market manipulation and the results of the PRA were just and reasonable because the PRA was conducted in accordance with MISO's tariff. With the issuance of the order, this matter has been resolved in Dynegy's favor. The order remains subject to rehearing at FERC and appeal. Other Matters We are involved in various legal and administrative proceedings in the normal course of business, the ultimate resolutions of which, in the opinion of management, are not anticipated to have a material effect on our results of operations, liquidity or financial condition.
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Equity (Notes) |
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Stockholders' Equity Note [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Equity | EQUITY Share Repurchase Program In November 2018, we announced that the Board had authorized an incremental share repurchase program (Program) under which up to $1.250 billion of our outstanding stock may be purchased. In the three months ended June 30, 2019, 8,558,712 shares of our common stock were repurchased for $212 million (including related fees and expenses) at an average price of $24.72 per share of common stock. In the six months ended June 30, 2019, 18,100,329 shares of our common stock were repurchased for $448 million (including related fees and expenses) at an average price of $24.75 per share of common stock. On a cumulative basis, 30,173,420 shares of our common stock have been repurchased under the Program for $726 million (including related fees and expenses) at an average price of $24.05 per share of common stock. At June 30, 2019, $524 million was available for additional repurchases under the Program, and we intend to implement the Program opportunistically from time to time in 2019 and 2020. Shares of the Company's common stock may be repurchased in open market transactions at prevailing market prices, in privately negotiated transactions, pursuant to plans complying with the Exchange Act, or by other means in accordance with federal securities laws. The actual timing, number and value of shares repurchased under the Program will be determined at our discretion and will depend on a number of factors, including the market price of our stock, general market and economic conditions, applicable legal requirements and compliance with the terms of our debt agreements and the Tax Matters Agreement. Dividends In November 2018, Vistra Energy announced the Board had adopted a dividend program pursuant to which Vistra Energy would initiate an annual dividend of approximately $0.50 per share expected to begin in the first quarter of 2019. Each dividend under the program will be subject to the declaration by the Board and, thus, may be subject to numerous factors in existence at the time of any such declaration including, but not limited to, prevailing market conditions, Vistra Energy's results of operations, financial condition and liquidity and Delaware law. In February 2019 and May 2019, the Board declared quarterly dividends of $0.125 per share that were paid in March 2019 and June 2019, respectively. In July 2019, the Board declared a quarterly dividend of $0.125 per share that will be paid in September 2019. Vistra Energy did not declare or pay any dividends during the six months ended June 30, 2018. Dividend Restrictions The agreement governing the Credit Facilities Agreement generally restricts the ability of Vistra Operations to make distributions to any direct or indirect parent unless such distributions are expressly permitted thereunder. As of June 30, 2019, Vistra Operations can distribute approximately $6.3 billion to Parent under the Credit Facilities Agreement without the consent of any party. The amount that can be distributed by Vistra Operations to Parent was partially reduced by distributions made by Vistra Operations to Parent of approximately $1.645 billion and $3.195 billion during the three and six months ended June 30, 2019, respectively, and approximately $4.7 billion and $1.1 billion during the years ended December 31, 2018 and 2017, respectively. Additionally, Vistra Operations may make distributions to Parent in amounts sufficient for Parent to make any payments required under the TRA or the Tax Matters Agreement or, to the extent arising out of Parent's ownership or operation of Vistra Operations, to pay any taxes or general operating or corporate overhead expenses. As of June 30, 2019, the maximum amount of restricted net assets of Vistra Operations that may not be distributed to Parent totaled approximately $1.9 billion. Under applicable Delaware General Corporate Law, we are prohibited from paying any distribution to the extent that such distribution exceeds the value of our "surplus," which is defined as the excess of our net assets above our capital (the aggregate par value of all outstanding shares of our stock). Warrants At the Merger Date, the Company entered into an agreement whereby holders of each outstanding warrant previously issued by Dynegy will be entitled to receive, upon exercise, the equity securities to which the holder would have been entitled to receive of Dynegy common stock converted into shares of Vistra Energy common stock at the Exchange Ratio. As of June 30, 2019, nine million warrants expiring in 2024 with an exercise price of $35.00 (subject to adjustment from time to time) were outstanding, each of which can be redeemed for 0.652 share of Vistra Energy common stock. The warrants are recorded as equity in our condensed consolidated balance sheet. Tangible Equity Units (TEUs) At the Merger Date, the Company assumed the obligations of Dynegy's 4,600,000 7.00% TEUs, each with a stated amount of $100.00 and each comprised of (i) a prepaid stock purchase contract that delivered to the holder, on July 1, 2019, 4.0813 shares of Vistra Energy common stock per contract with cash paid in lieu of any fractional shares at a rate of $22.5954 per share and (ii) a senior amortizing note with an outstanding principal amount of $38 million at the Merger Date that paid an equal quarterly cash installment of $1.75 per amortizing note (see Note 11). In the aggregate, the annual quarterly cash installments were equivalent to a 7.00% cash payment per year with respect to each $100.00 stated amount of TEUs. The amortizing notes were accounted for as debt while the stock purchase contract was included in equity based on the fair value of the contract at the Merger Date (see Note 11). The entire class of TEUs were suspended from trading on the New York Stock Exchange on July 1, 2019 and removed from listing and registration on July 12, 2019. On July 1, 2019, approximately 18.8 million treasury shares of Vistra Energy common stock were issued in connection with the settlement of the TEUs. Equity The following table presents the changes to equity for the three months ended June 30, 2019:
The following table presents the changes to equity for the six months ended June 30, 2019:
________________
The following table presents the changes to equity for the three months ended June 30, 2018:
The following table presents the changes to equity for the six months ended June 30, 2018:
________________ (a) Authorized shares totaled 1,800,000,000 at June 30, 2018. Outstanding shares totaled 521,214,879 and 428,398,802 at June 30, 2018 and December 31, 2017, respectively.
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Fair Value Measurements (Notes) |
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Fair Value Disclosures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Measurements | FAIR VALUE MEASUREMENTS We utilize several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those items that are measured on a recurring basis. We use a mid-market valuation convention (the mid-point price between bid and ask prices) as a practical expedient to measure fair value for the majority of our assets and liabilities and use valuation techniques to maximize the use of observable inputs and minimize the use of unobservable inputs. Our valuation policies and procedures were developed, maintained and validated by a centralized risk management group that reports to the Vistra Energy Chief Financial Officer. Fair value measurements of derivative assets and liabilities incorporate an adjustment for credit-related nonperformance risk. These nonperformance risk adjustments take into consideration master netting arrangements, credit enhancements and the credit risks associated with our credit standing and the credit standing of our counterparties (see Note 16 for additional information regarding credit risk associated with our derivatives). We utilize credit ratings and default rate factors in calculating these fair value measurement adjustments. We categorize our assets and liabilities recorded at fair value based upon the following fair value hierarchy:
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:
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Commodity contracts consist primarily of natural gas, electricity, coal and emissions agreements and include financial instruments entered into for economic hedging purposes as well as physical contracts that have not been designated as normal purchases or sales. Interest rate swaps are used to reduce exposure to interest rate changes by converting floating-rate interest to fixed rates. See Note 16 for further discussion regarding derivative instruments. Nuclear decommissioning trust assets represent securities held for the purpose of funding the future retirement and decommissioning of our nuclear generation facility. These investments include equity, debt and other fixed-income securities consistent with investment rules established by the NRC and the PUCT. The following tables present the fair value of the Level 3 assets and liabilities by major contract type and the significant unobservable inputs used in the valuations at June 30, 2019 and December 31, 2018:
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There were no transfers between Level 1 and Level 2 of the fair value hierarchy for the three and six months ended June 30, 2019 and 2018. See the table below for discussion of transfers between Level 2 and Level 3 for the three and six months ended June 30, 2019 and 2018. The following table presents the changes in fair value of the Level 3 assets and liabilities for the three and six months ended June 30, 2019 and 2018.
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(c) Activity excludes change in fair value in the month positions settle. Substantially all changes in values of commodity contracts (excluding the net liabilities assumed in connection with the Merger) are reported as operating revenues in our condensed statements of consolidated income (loss).
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Commodity and Other Derivative Contractual Assets and Liabilities (Notes) |
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Derivative Instruments and Hedging Activities Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Commodity And Other Derivative Contractual Assets And Liabilities | COMMODITY AND OTHER DERIVATIVE CONTRACTUAL ASSETS AND LIABILITIES Strategic Use of Derivatives We transact in derivative instruments, such as options, swaps, futures and forward contracts, to manage commodity price and interest rate risk. See Note 15 for a discussion of the fair value of derivatives. Commodity Hedging and Trading Activity — We utilize natural gas and electricity derivatives to reduce exposure to changes in electricity prices primarily to hedge future revenues from electricity sales from our generation assets. We also utilize short-term electricity, natural gas, coal, and emissions derivative instruments for fuel hedging and other purposes. Counterparties to these transactions include energy companies, financial institutions, electric utilities, independent power producers, oil and gas producers, local distribution companies and energy marketing companies. Unrealized gains and losses arising from changes in the fair value of derivative instruments as well as realized gains and losses upon settlement of the instruments are reported in our condensed statements of consolidated income (loss) in operating revenues and fuel, purchased power costs and delivery fees. Interest Rate Swaps — Interest rate swap agreements are used to reduce exposure to interest rate changes by converting floating-rate interest rates to fixed rates, thereby hedging future interest costs and related cash flows. Unrealized gains and losses arising from changes in the fair value of the swaps as well as realized gains and losses upon settlement of the swaps are reported in our condensed statements of consolidated income (loss) in interest expense and related charges. Financial Statement Effects of Derivatives Substantially all derivative contractual assets and liabilities are accounted for under mark-to-market accounting consistent with accounting standards related to derivative instruments and hedging activities. The following tables provide detail of derivative contractual assets and liabilities as reported in our condensed consolidated balance sheets at June 30, 2019 and December 31, 2018. Derivative asset and liability totals represent the net value of the contract, while the balance sheet totals represent the gross value of the contract.
At June 30, 2019 and December 31, 2018, there were no derivative positions accounted for as cash flow or fair value hedges. The following table presents the pretax effect of derivative gains (losses) on net income, including realized and unrealized effects. Amount represents changes in fair value of positions in the derivative portfolio during the period, as realized amounts related to positions settled are assumed to equal reversals of previously recorded unrealized amounts.
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:
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Derivative Volumes The following table presents the gross notional amounts of derivative volumes at June 30, 2019 and December 31, 2018:
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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:
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Concentrations of Credit Risk Related to Derivatives We have concentrations of credit risk with the counterparties to our derivative contracts. At June 30, 2019, total credit risk exposure to all counterparties related to derivative contracts totaled $1,675 million (including associated accounts receivable). The net exposure to those counterparties totaled $398 million at June 30, 2019, after taking into effect netting arrangements, setoff provisions and collateral, with the largest net exposure to a single counterparty totaling $119 million. At June 30, 2019, the credit risk exposure to the banking and financial sector represented 71% of the total credit risk exposure and 23% of the net exposure. Exposure to banking and financial sector counterparties is considered to be within an acceptable level of risk tolerance because all of this exposure is with counterparties with investment grade credit ratings. However, this concentration increases the risk that a default by any of these counterparties would have a material effect on our financial condition, results of operations and liquidity. The transactions with these counterparties contain certain provisions that would require the counterparties to post collateral in the event of a material downgrade in their credit rating. We maintain credit risk policies with regard to our counterparties to minimize overall credit risk. These policies authorize specific risk mitigation tools including, but not limited to, use of standardized master agreements that allow for netting of positive and negative exposures associated with a single counterparty. Credit enhancements such as parent guarantees, letters of credit, surety bonds, liens on assets and margin deposits are also utilized. Prospective material changes in the payment history or financial condition of a counterparty or downgrade of its credit quality result in the reassessment of the credit limit with that counterparty. The process can result in the subsequent reduction of the credit limit or a request for additional financial assurances. An event of default by one or more counterparties could subsequently result in termination-related settlement payments that reduce available liquidity if amounts are owed to the counterparties related to the derivative contracts or delays in receipts of expected settlements if the counterparties owe amounts to us.
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Related Party Transactions (Notes) |
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Jun. 30, 2019 | |||||||||
Related Party Transactions [Abstract] | |||||||||
Related Party Transactions | RELATED PARTY TRANSACTIONS In connection with Emergence, we entered into agreements with certain of our affiliates and with parties who received shares of common stock and TRA Rights in exchange for their claims. Registration Rights Agreement Pursuant to the Plan of Reorganization, on the Effective Date, we entered into a Registration Rights Agreement (the Registration Rights Agreement) with certain selling stockholders providing for registration of the resale of the Vistra Energy common stock held by such selling stockholders. In December 2016, we filed a Form S-1 registration statement with the SEC to register for resale the shares of Vistra Energy common stock held by certain significant stockholders pursuant to the Registration Rights Agreement, which was declared effective by the SEC in May 2017. The registration statement was amended in March 2018. Pursuant to the Registration Rights Agreement, in June 2018, we filed a post-effective amendment to the Form S-1 registration statement on Form S-3, which was declared effective by the SEC in July 2018. Among other things, under the terms of the Registration Rights Agreement:
All expenses of registration under the Registration Rights Agreement, including the legal fees of one counsel retained by or on behalf of the selling stockholders, will be paid by us. Legal fee expenses paid or accrued by Vistra Energy on behalf of the selling stockholders totaled less than $1 million during both the three and six months ended June 30, 2019 and 2018. Tax Receivable Agreement On the Effective Date, Vistra Energy entered into the TRA with a transfer agent on behalf of certain former first lien creditors of TCEH. See Note 8 for discussion of the TRA.
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Segment Information (Notes) |
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Segment Reporting [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Segment Information | SEGMENT INFORMATION The operations of Vistra Energy are aligned into six reportable business segments: (i) Retail, (ii) ERCOT, (iii) PJM, (iv) NY/NE, (v) MISO and (vi) Asset Closure. Our chief operating decision maker reviews the results of these segments separately and allocates resources to the respective segments as part of our strategic operations. The Retail segment is engaged in retail sales of electricity and related services to residential, commercial and industrial customers. Substantially all of these activities are conducted by TXU Energy and Value Based Brands in Texas, Dynegy Energy Services in Massachusetts, Ohio, Illinois and Pennsylvania and Homefield Energy in Illinois. The ERCOT, PJM, NY/NE (comprising NYISO and ISO-NE) and MISO segments are engaged in electricity generation, wholesale energy sales and purchases, commodity risk management activities, fuel production and fuel logistics management, all largely within their respective RTO/ISO market. The PJM, NY/NE and MISO segments were established on the Merger Date to reflect markets served by businesses acquired in the Merger. The Asset Closure segment is engaged in the decommissioning and reclamation of retired plants and mines. Separately reporting the Asset Closure segment provides management with better information related to the performance and earnings power of Vistra Energy's ongoing operations and facilitates management's focus on minimizing the cost associated with decommissioning and reclamation of retired plants and mines. We have not allocated any unrealized gains or losses on commodity risk management activities to the Asset Closure segment for the generation plants that were retired in January, February and May 2018. Corporate and Other represents the remaining non-segment operations consisting primarily of (i) general corporate expenses, interest, taxes and other expenses related to our support functions that provide shared services to our operating segments and (ii) CAISO operations. Except as noted in Note 1, the accounting policies of the business segments are the same as those described in the summary of significant accounting policies in Note 1. Our chief operating decision maker uses more than one measure to assess segment performance, including segment net income (loss), which is the measure most comparable to consolidated net income (loss) prepared based on U.S. GAAP. We account for intersegment sales and transfers as if the sales or transfers were to third parties, that is, at market prices. Certain shared services costs are allocated to the segments.
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Supplementary Financial Information (Notes) |
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Supplementary Financial Information [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Supplementary Financial Information | SUPPLEMENTARY FINANCIAL INFORMATION Pension and OPEB Plans — Components of Net Benefit Cost For the three and six months ended June 30, 2019 and 2018, net periodic benefit costs consisted of the following:
Interest Expense and Related Charges
The weighted average interest rate applicable to the Vistra Operations Credit Facilities, taking into account the interest rate swaps discussed in Note 11, was 4.03% at June 30, 2019. Other Income and Deductions
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Restricted Cash
Trade Accounts Receivable
Gross trade accounts receivable at June 30, 2019 and December 31, 2018 included unbilled retail revenues of $375 million and $350 million, respectively. Allowance for Uncollectible Accounts Receivable
Inventories by Major Category
Investments
Investment in Unconsolidated Subsidiaries On the Merger Date, we assumed Dynegy's 50% interest in Northeast Energy, LP (NELP), a joint venture with NextEra Energy, Inc., which indirectly owns the Bellingham NEA facility and the Sayreville facility. At June 30, 2019, our investment in NELP totaled $125 million. Our risk of loss related to our equity method investment is limited to our investment balance. Equity earnings related to our investment in NELP totaled $3 million and $4 million for the three months ended June 30, 2019 and 2018, respectively, and $9 million and $4 million for the six months ended June 30, 2019 and 2018, respectively, recorded in equity in earnings (loss) of unconsolidated investment in our condensed statements of consolidated net income (loss). We received distributions totaling $9 million and $6 million for the three months ended June 30, 2019 and 2018, respectively, and $14 million and $6 million for the six months ended June 30, 2019 and 2018, respectively. Nuclear Decommissioning Trust Investments in a trust that will be used to fund the costs to decommission the Comanche Peak nuclear generation plant are carried at fair value. Decommissioning costs are being recovered from Oncor Electric Delivery Company LLC's (Oncor) customers as a delivery fee surcharge over the life of the plant and deposited by Vistra Energy (and prior to the Effective Date, a subsidiary of TCEH) in the trust fund. Income and expense associated with the trust fund and the decommissioning liability are offset by a corresponding change in a regulatory asset/liability (currently a regulatory liability reported in other noncurrent liabilities and deferred credits) that will ultimately be settled through changes in Oncor's delivery fees rates. If funds recovered from Oncor's customers held in the trust fund are determined to be inadequate to decommission the Comanche Peak nuclear generation plant, Oncor would be required to collect all additional amounts from its customers, with no obligation from Vistra Energy, provided that Vistra Energy complied with PUCT rules and regulations regarding decommissioning trusts. A summary of investments in the fund follows:
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Debt securities held at June 30, 2019 mature as follows: $186 million in one to five years, $134 million in five to 10 years and $182 million after 10 years. The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from such sales.
Property, Plant and Equipment
Depreciation expenses totaled $312 million and $292 million for the three months ended June 30, 2019 and 2018, respectively, and $647 million and $360 million for six months ended June 30, 2019 and 2018, respectively. Asset Retirement and Mining Reclamation Obligations (ARO) These liabilities primarily relate to nuclear generation plant decommissioning, land reclamation related to lignite mining, removal of coal/lignite fueled plant ash treatment facilities and generation plant asbestos removal and disposal costs. There is no earnings impact with respect to changes in the nuclear plant decommissioning liability, as all costs are recoverable through the regulatory process as part of delivery fees charged by Oncor. At June 30, 2019, the carrying value of our ARO related to our nuclear generation plant decommissioning totaled $1.298 billion, which is lower than the fair value of the assets contained in the nuclear decommissioning trust. Since the costs to ultimately decommission that plant are recoverable through the regulatory rate making process as part of Oncor's delivery fees, a corresponding regulatory liability has been recorded to our condensed consolidated balance sheet of $44 million in other noncurrent liabilities and deferred credits. The following tables summarize the changes to these obligations, reported as asset retirement obligations (current and noncurrent liabilities) in our condensed consolidated balance sheets, for the six months ended June 30, 2019 and 2018.
Other Noncurrent Liabilities and Deferred Credits The balance of other noncurrent liabilities and deferred credits consists of the following:
Fair Value of Debt
We determine fair value in accordance with accounting standards as discussed in Note 15. We obtain security pricing from an independent party who uses broker quotes and third-party pricing services to determine fair values. Where relevant, these prices are validated through subscription services, such as Bloomberg. Supplemental Cash Flow Information The following table reconciles cash, cash equivalents and restricted cash reported in our condensed statements of consolidated cash flows to the amounts reported in our condensed balance sheets at June 30, 2019 and December 31, 2018:
The following table summarizes our supplemental cash flow information for the six months ended June 30, 2019 and 2018:
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(b) Represents end-of-period accruals for ongoing construction projects.
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Supplemental Condensed Consolidating Financial Information Supplemental Condensed Consolidating Financial Information (Notes) |
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Supplemental Condensed Consolidating Financial Information [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Supplemental Condensed Consolidating Financial Information [Text Block] | SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION Our senior unsecured notes are guaranteed by substantially all of our wholly owned subsidiaries. The following condensed consolidating financial statements present the financial information of (i) Vistra Energy Corp. (Parent), which is the ultimate parent company and issuer of the senior notes with effect as of the Merger Date, on a stand-alone, unconsolidated basis, (ii) the guarantor subsidiaries of Vistra Energy (Guarantor Subsidiaries), (iii) the non-guarantor subsidiaries of Vistra Energy (Non-Guarantor Subsidiaries) and (iv) the eliminations necessary to arrive at the information for Vistra Energy on a consolidated basis. The Guarantor Subsidiaries consist of the wholly-owned subsidiaries, which jointly, severally, fully and unconditionally, guarantee the payment obligations under the senior notes. See Note 11 for discussion of the senior notes. These statements should be read in conjunction with the unaudited condensed consolidated financial statements and notes thereto of Vistra Energy. The supplemental condensed consolidating financial information has been prepared pursuant to the rules and regulations for condensed financial information and does not include all disclosures included in annual financial statements. The inclusion of Vistra Energy's subsidiaries as either Guarantor Subsidiaries or Non-Guarantor Subsidiaries in the condensed consolidating financial information is determined as of the most recent balance sheet date presented. The Parent files a consolidated U.S. federal income tax return. All consolidated income tax expense or benefits and deferred tax assets and liabilities have been allocated to the respective subsidiary columns in accordance with the accounting rules that apply to separate financial statements of subsidiaries. Vistra Energy Corp. (Parent) received $3.195 billion in dividends from its consolidated subsidiaries in the six months ended June 30, 2019. Condensed Statements of Consolidating Income (Loss) for the Three Months Ended June 30, 2019 (Millions of Dollars)
Condensed Statements of Consolidating Income (Loss) for the Three Months Ended June 30, 2018 (Millions of Dollars)
Condensed Statements of Consolidating Income (Loss) for the Six Months Ended June 30, 2019 (Millions of Dollars)
Condensed Statements of Consolidating Income (Loss) for the Six Months Ended June 30, 2018 (Millions of Dollars)
Condensed Statements of Consolidating Comprehensive Income (Loss) for the Three Months Ended June 30, 2019 (Millions of Dollars)
Condensed Statements of Consolidating Comprehensive Income (Loss) for the Three Months Ended June 30, 2018 (Millions of Dollars)
Condensed Statements of Consolidating Comprehensive Income (Loss) for the Six Months Ended June 30, 2019 (Millions of Dollars)
Condensed Statements of Consolidating Comprehensive Income (Loss) for the Six Months Ended June 30, 2018 (Millions of Dollars)
Condensed Statements of Consolidating Cash Flows for the Six Months Ended June 30, 2019 (Millions of Dollars)
Condensed Statements of Consolidating Cash Flows for the Six Months Ended June 30, 2018 (Millions of Dollars)
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Business And Significant Accounting Policies (Policies) |
6 Months Ended |
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Jun. 30, 2019 | |
Accounting Policies [Abstract] | |
Basis of Presentation | Basis of Presentation The condensed consolidated financial statements have been prepared in accordance with U.S. GAAP and on the same basis as the audited financial statements included in our annual report on Form 10-K for the year ended December 31, 2018. Adjustments (consisting of normal recurring accruals) necessary for a fair presentation of the results of operations and financial position have been included therein. All intercompany items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with U.S. GAAP have been omitted pursuant to the rules and regulations of the SEC. Because the condensed consolidated interim financial statements do not include all of the information and footnotes required by U.S. GAAP, they should be read in conjunction with the audited financial statements and related notes contained in our annual report on Form 10-K for the year ended December 31, 2018. The results of operations for an interim period may not give a true indication of results for a full year. All dollar amounts in the financial statements and tables in the notes are stated in millions of U.S. dollars unless otherwise indicated.
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Use of Estimates | Use of Estimates Preparation of financial statements requires estimates and assumptions about future events that affect the reporting of assets and liabilities at the balance sheet dates and the reported amounts of revenue and expense, including fair value measurements, estimates of expected obligations, judgment related to the potential timing of events and other estimates. In the event estimates and/or assumptions prove to be different from actual amounts, adjustments are made in subsequent periods to reflect more current information. |
Lessee, Leases [Policy Text Block] | Leases At the inception of a contract we determine if it is or contains a lease, which involves the contract conveying the right to control the use of explicitly or implicitly identified property, plant, or equipment for a period of time in exchange for consideration. Right-of-use (ROU) assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. ROU assets and lease liabilities are recognized at the commencement date of the underlying lease based on the present value of lease payments over the lease term. We use our secured incremental borrowing rate based on the information available at the lease commencement date to determine the present value of lease payments. Operating leases are included in operating lease ROU assets, operating lease liabilities (current) and operating lease liabilities (noncurrent) on our condensed consolidated balance sheet. Finance leases are included in property, plant and equipment, other current liabilities and other noncurrent liabilities and deferred credits on our condensed consolidated balance sheet. Lease term includes options to extend or terminate the lease when it is reasonably certain that we will exercise the option. We have elected the practical expedient which permits us to not reassess under the new standard our prior conclusion about lease classification and initial direct costs. We have also elected the practical expedient to not separate lease and non-lease components for a majority of the lease asset classes. We have also elected the hindsight practical expedient to determine the lease term. Leases with an initial lease term of 12 months or less are not recorded on the balance sheet; we recognize lease expense for these leases on a straight-line basis over the lease term. We also present lessor sublease income on a net basis against the related lessee lease expense.
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Business And Significant Accounting Policies (Tables) |
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Accounting Policies [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of new accounting pronouncements and changes in accounting principles | As of January 1, 2019, the cumulative effect of the changes made to our condensed consolidated balance sheet for the adoption of the new lease standard was as follows:
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Acquisition of Crius, Dynegy Merger Transaction and Business Combination Accounting (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Business Combinations [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block] | The following table summarizes the consideration paid and the final allocation of the purchase price to the fair value amounts recognized for the assets acquired and liabilities assumed related to the Merger as of the Merger Date. Based on the opening price of Vistra Energy common stock on the Merger Date, the purchase price was approximately $2.3 billion. During the three months ended March 31, 2019, the purchase price allocation was completed. During the period from April 9, 2018 through March 31, 2019, we updated the initial purchase price allocation with final valuations by increasing property, plant and equipment by $173 million, decreasing intangible assets by $36 million, increasing goodwill by $175 million, decreasing accounts receivable, inventory, prepaid expenses and other current assets by $10 million, increasing accumulated deferred tax asset by $127 million, decreasing other noncurrent assets by $113 million, increasing trade accounts payable and other current liabilities by $89 million, increasing other noncurrent liabilities by $177 million, increasing asset retirement obligations, including amounts due currently, by $56 million, as well as other minor adjustments. The valuation revisions were a result of updated inputs used in determining the fair value of the acquired assets and liabilities.
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Unaudited Pro Forma Financial Information [Table Text Block] | Unaudited Pro Forma Financial Information — The following unaudited pro forma financial information for the six months ended June 30, 2018 assumes that the Merger occurred on January 1, 2018. The unaudited pro forma financial information is provided for information purposes only and is not necessarily indicative of the results of operations that would have occurred had the Merger been completed on January 1, 2018, nor is the unaudited pro forma financial information indicative of future results of operations, which may differ materially from the pro forma financial information presented here.
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Retirement of Generation Facilities (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Retirement of Generation Facilities [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Retirements of generation capacity | Two of our non-operated, jointly held power plants acquired in the Merger, for which our proportional generation capacity was 883 MW, were retired in May 2018. These units were retired as previously scheduled. No gain or loss was recorded in conjunction with the retirement of these units, and the operational results of these facilities are included in our Asset Closure segment. The following table details the units retired.
In January and February 2018, we retired three power plants with a total installed nameplate generation capacity of 4,167 MW. We decided to retire these units because they were projected to be uneconomic based on then current market conditions and would have faced significant environmental costs associated with operating such units. In the case of the Sandow units, the decision also reflected the execution of a contract termination agreement pursuant to which the Company and Alcoa agreed to an early settlement of a long-standing power and mining agreement. Expected retirement expenses were accrued in the third and fourth quarter of 2017 and, as a result, no retirement expenses were recorded related to these facilities in the three and six months ended June 30, 2018. The operational results of these facilities are included in our Asset Closure segment, which is engaged in the decommissioning and reclamation of retired plants and mines. The following table details the units retired.
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Revenue (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Revenue Recognition and Deferred Revenue [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Disaggregation of revenue |
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____________ (a) Includes $208 million of unrealized net losses from mark-to-market valuations of commodity positions. See Note 18 for unrealized net gains (losses) by segment.
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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:
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Goodwill and Identifiable Intangible Assets and Liabilities (Tables) |
6 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Goodwill and Intangible Assets Disclosure [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of identifiable intangible assets reported in the balance sheet | Identifiable intangible assets are comprised of the following:
__________
Identifiable intangible liabilities are comprised of the following:
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Schedule of amortization expense related to intangible assets (including income statement line item) | Amortization expense related to finite-lived identifiable intangible assets and liabilities (including the classification in the condensed statements of consolidated income (loss)) consisted of:
____________ (a) Amounts recorded in depreciation and amortization totaled $72 million and $97 million for the three months ended June 30, 2019 and 2018, respectively, and $141 million and $182 million for the six months ended June 30, 2019 and 2018, respectively.
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Schedule of estimated amortization expense of identifiable intangible assets | As of June 30, 2019, the estimated aggregate amortization expense of identifiable intangible assets and liabilities for each of the next five fiscal years is as shown below.
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Income Taxes (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Calculation of effective income tax rate | The calculation of our effective tax rate is as follows:
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Tax Receivable Agreement Obligation (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Tax receivable agreement obligation | The following table summarizes the changes to the TRA obligation, reported as other current liabilities and Tax Receivable Agreement obligation in our condensed consolidated balance sheets, for the six months ended June 30, 2019 and 2018:
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Earnings Per Share (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earnings Per Share [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of earnings per share, basic and diluted | Basic earnings per share available to common shareholders are based on the weighted average number of common shares outstanding during the period. Diluted earnings per share is calculated using the treasury stock method and includes the effect of all potential issuances of common shares under stock-based incentive compensation arrangements.
____________ (a) The minimum settlement amount of tangible equity units, or 15,207,600 shares in both the three and six months ended June 30, 2019 and 15,056,260 shares in both the three and six months ended June 30, 2018, are considered to be outstanding and are included in the computation of basic net income per share
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Long-Term Debt (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Debt Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of long-term debt instruments | Amounts in the table below represent the categories of long-term debt obligations incurred by the Company.
____________
(c) Includes impact of recording debt assume
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Schedule of line of credit facilities | The Vistra Operations Credit Facilities and related available capacity at June 30, 2019 are presented below.
___________ (a) Facility to be used for general corporate purposes. Facility includes a $2.35 billion letter of credit sub-facility, of which $552 million of letters of credit were outstanding at June 30, 2019 and which reduce our available capacity.
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Schedule of maturities of long-term debt | Long-term debt maturities (including mandatory amortization of the Term Loan B Facility) at June 30, 2019 are as follows:
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Leases (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Leases [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Lease Cost and Supplemental Cash Flow Information | The following table presents lease related cash flow and other information:
The following table presents costs related to lease activities:
____________
(b) Represents sublease income related to real estate leases.
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Schedule of Lease Balance Sheet Information | The following table presents lease related balance sheet information:
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Schedule of Weighted Average Remaining Lease Terms and Discount Rates | The following table presents weighted average remaining lease term information:
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Schedule of Maturity of Operating Lease Liabilities | The following table presents maturity of lease liabilities:
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Schedule of Maturity of Finance Lease Liabilities | The following table presents maturity of lease liabilities:
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Equity (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stockholders' Equity Note [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of stockholders equity | Equity The following table presents the changes to equity for the three months ended June 30, 2019:
The following table presents the changes to equity for the six months ended June 30, 2019:
________________
The following table presents the changes to equity for the three months ended June 30, 2018:
The following table presents the changes to equity for the six months ended June 30, 2018:
________________ (a) Authorized shares totaled 1,800,000,000 at June 30, 2018. Outstanding shares totaled 521,214,879 and 428,398,802 at June 30, 2018 and December 31, 2017, respectively.
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Fair Value Measurements (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Disclosures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of assets and liabilities measured at fair value on a recurring basis | Assets and liabilities measured at fair value on a recurring basis consisted of the following at the respective balance sheet dates shown below:
____________
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Schedule of fair value of the Level 3 assets and liabilities by major contract type (all related to commodity contracts) and the significant unobservable inputs used in the valuations | The following tables present the fair value of the Level 3 assets and liabilities by major contract type and the significant unobservable inputs used in the valuations at June 30, 2019 and December 31, 2018:
____________
(h) Other includes contracts for natural gas, coal, coal option, power and gas swaption and emissions.
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Schedule of changes in fair value of the Level 3 assets and liabilities | The following table presents the changes in fair value of the Level 3 assets and liabilities for the three and six months ended June 30, 2019 and 2018.
____________
(c) Activity excludes change in fair value in the month positions settle. Substantially all changes in values of commodity contracts (excluding the net liabilities assumed in connection with the Merger) are reported as operating revenues in our condensed statements of consolidated income (loss).
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Commodity and Other Derivative Contractual Assets and Liabilities (Tables) |
6 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Derivative Instruments and Hedging Activities Disclosure [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of commodity and other derivative contractual assets and liabilities as reported in the balance sheets | Substantially all derivative contractual assets and liabilities are accounted for under mark-to-market accounting consistent with accounting standards related to derivative instruments and hedging activities. The following tables provide detail of derivative contractual assets and liabilities as reported in our condensed consolidated balance sheets at June 30, 2019 and December 31, 2018. Derivative asset and liability totals represent the net value of the contract, while the balance sheet totals represent the gross value of the contract.
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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.
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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:
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Schedule of gross notional amounts of derivative volumes | The following table presents the gross notional amounts of derivative volumes at June 30, 2019 and December 31, 2018:
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(c) Includes notional amounts of interest rate swaps with maturity dates through July 2026.
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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:
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(b) Amounts include the offsetting fair value of in-the-money derivative contracts and net accounts receivable under master netting arrangements.
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Segment Information (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Segment Reporting [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of segment reporting information, by segment | ts.
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Supplementary Financial Information (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2019 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Supplementary Financial Information [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of components of net benefit cost | For the three and six months ended June 30, 2019 and 2018, net periodic benefit costs consisted of the following:
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Schedule of interest expense and related charges | Interest Expense and Related Charges
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Schedule of other income and deductions | Other Income and Deductions
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(b) Reported in ERCOT segment.
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Schedule of restricted cash | Restricted Cash
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Schedule of accounts, notes, loans and financing receivable | Allowance for Uncollectible Accounts Receivable
Trade Accounts Receivable
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Schedule of inventories by major category | Inventories by Major Category
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Summary of other investments | Investments
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Summary of investments in the fund |
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Summary of proceeds from sales of available-for-sale securities and the related realized gains and losses from such sales | The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from such sales.
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Schedule of Property, Plant and Equipment | Property, Plant and Equipment
Depreciation expenses totaled $312 million and $292 million for the three months ended June 30, 2019 and 2018, respectively, and $647 million and $360 million for six months ended June 30, 2019 and 2018, respectively. |
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Schedule of asset retirement and mining reclamation obligations | The following tables summarize the changes to these obligations, reported as asset retirement obligations (current and noncurrent liabilities) in our condensed consolidated balance sheets, for the six months ended June 30, 2019 and 2018.
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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:
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Schedule of fair value of debt | Fair Value of Debt
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Schedule of cash, cash equivalents and restricted cash | The following table reconciles cash, cash equivalents and restricted cash reported in our condensed statements of consolidated cash flows to the amounts reported in our condensed balance sheets at June 30, 2019 and December 31, 2018:
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Schedule of supplemental cash flow information | The following table summarizes our supplemental cash flow information for the six months ended June 30, 2019 and 2018:
____________
(b) Represents end-of-period accruals for ongoing construction projects.
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Supplemental Condensed Consolidating Financial Information (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Supplemental Condensed Consolidating Financial Information [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Condensed Statements of Consolidating Income (Loss) |
Condensed Statements of Consolidating Income (Loss) for the Three Months Ended June 30, 2018 (Millions of Dollars)
Condensed Statements of Consolidating Income (Loss) for the Six Months Ended June 30, 2019 (Millions of Dollars)
Condensed Statements of Consolidating Income (Loss) for the Six Months Ended June 30, 2018 (Millions of Dollars)
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Condensed Statements of Consolidating Other Comprehensive Income (Loss) |
Condensed Statements of Consolidating Comprehensive Income (Loss) for the Three Months Ended June 30, 2018 (Millions of Dollars)
Condensed Statements of Consolidating Comprehensive Income (Loss) for the Six Months Ended June 30, 2019 (Millions of Dollars)
Condensed Statements of Consolidating Comprehensive Income (Loss) for the Six Months Ended June 30, 2018 (Millions of Dollars)
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Condensed Statements of Consolidating Cash Flows | Condensed Statements of Consolidating Cash Flows for the Six Months Ended June 30, 2019 (Millions of Dollars)
Condensed Statements of Consolidating Cash Flows for the Six Months Ended June 30, 2018 (Millions of Dollars)
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Condensed Consolidating Balance Sheets |
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Business And Significant Accounting Policies (Narrative) (Details) |
6 Months Ended |
---|---|
Jun. 30, 2019
Reportable_segment
| |
Business and Significant Accounting Policies | |
Number of reportable segments (in reportable segments) | 6 |
Acquisition of Crius, Dynegy Merger Transaction and Business Combination Accounting (Acquisition of Crius) (Details) $ in Millions |
Jul. 15, 2019
USD ($)
|
Apr. 09, 2018
USD ($)
|
Jul. 31, 2019
TW
|
---|---|---|---|
Business Combination, Consideration Transferred | $ 2,273 | ||
Subsequent Event [Member] | |||
Electricity Load, Annualized Basis | TW | 11.6 | ||
Business Combination, Consideration Transferred | $ 400 | ||
Business Combination, Consideration Transferred to Acquire Outstanding Trust Units | 380 | ||
Business Combination, Consideration Transferred, Liabilities Incurred | $ 111 |
Acquisition of Crius, Dynegy Merger Transaction and Business Combination Accounting (Dynegy Merger Transaction) (Details) - $ / shares |
Apr. 09, 2018 |
Jun. 30, 2019 |
Dec. 31, 2018 |
Jun. 30, 2018 |
Dec. 31, 2017 |
---|---|---|---|---|---|
Common stock, par or stated value per share | $ 0.01 | ||||
Merger agreement, common stock conversion ratio | 0.652 | ||||
Stock issued during period, shares, new issues | 94,409,573 | ||||
Common stock, shares outstanding | 522,932,453 | 476,166,856 | 493,215,309 | 521,214,879 | 428,398,802 |
Vistra Energy Corp. [Member] | |||||
Common stock, par or stated value per share | $ 0.01 | ||||
Dynegy Inc. [Member] | |||||
Common stock, par or stated value per share | $ 0.01 | ||||
Common stock, shares outstanding | 144,800,000 |
Acquisition of Crius, Dynegy Merger Transaction and Business Combination Accounting (Unaudited Pro Form Financial Information) (Details) $ / shares in Units, $ in Millions |
6 Months Ended |
---|---|
Jun. 30, 2018
USD ($)
$ / shares
| |
Business Combinations [Abstract] | |
Revenue | $ 4,789 |
Net loss | (439) |
Net loss attributable to Vistra Energy | $ (435) |
Net loss attributable to Vistra Energy per weighted average share of common stock outstanding — basic | $ / shares | $ (0.83) |
Net loss attributable to Vistra Energy per weighted average share of common stock outstanding — diluted | $ / shares | $ (0.83) |
Acquisition and Development of Generation Facilities (Battery Energy Storage Projects) (Details) $ in Millions |
1 Months Ended | 3 Months Ended | |
---|---|---|---|
Jun. 30, 2018 |
Dec. 31, 2018
USD ($)
|
Jun. 30, 2019
USD ($)
Megawatt-hour
|
|
Construction in Progress, Gross | $ | $ 277 | $ 135 | |
Vistra Energy Corp. [Member] | Upton County 2 Solar Facility (Battery Storage Project) [Member] | |||
Texas Emissions Reduction Plan, Grant Awarded | $ | $ 1 | ||
Electricity Generation Facility Capacity | Megawatt-hour | 10 | ||
Vistra Energy Corp. [Member] | Oakland Power Plant (Battery Storage Project) [Member] | |||
Electricity Generation Facility Capacity | Megawatt-hour | 20 | ||
Vistra Energy Corp. [Member] | Moss Landing Power Plant (Battery Storage Project) [Member] | |||
Electricity Generation Facility Capacity | Megawatt-hour | 300 | ||
Construction in Progress, Gross | $ | $ 15 | ||
Proposed Contract, Duration, Number Of Years | 20 years |
Acquisition and Development of Generation Facilities (Upton Solar Development) (Details) $ in Millions |
6 Months Ended | 20 Months Ended | |
---|---|---|---|
Jun. 30, 2019
USD ($)
Megawatt-hour
|
Jun. 30, 2018
USD ($)
|
Dec. 31, 2018
USD ($)
|
|
Development and growth expenditures | $ | $ (36) | $ (21) | $ (231) |
Luminant Generation Company LLC [Member] | Upton County 2 Solar Facility [Member] | |||
Electricity Generation Facility Capacity | Megawatt-hour | 180 |
Revenue (Accounts Receivable) (Details) - USD ($) $ in Millions |
Jun. 30, 2019 |
Dec. 31, 2018 |
---|---|---|
Trade accounts receivable — net | $ 1,101 | $ 1,087 |
Trade Accounts Receivable From Contracts With Customers [Member] | ||
Trade accounts receivable — net | 977 | 951 |
Other Trade Accounts Receivables [Member] | ||
Trade accounts receivable — net | $ 124 | $ 136 |
Goodwill and Identifiable Intangible Assets and Liabilities (Goodwill) (Details) - USD ($) $ in Millions |
6 Months Ended | ||
---|---|---|---|
Jun. 30, 2019 |
Dec. 31, 2018 |
Apr. 09, 2018 |
|
Goodwill [Line Items] | |||
Goodwill | $ 2,082 | $ 2,068 | $ 175 |
ERCOT Retail Reporting Unit [Member] | |||
Goodwill [Line Items] | |||
Goodwill | 1,907 | ||
Goodwill, expected tax deductible amount | $ 1,686 | ||
Business acquisition, goodwill, expected tax deductible term | 15 years | ||
Dynegy Merger [Member] | |||
Goodwill [Line Items] | |||
Goodwill | $ 175 | ||
Dynegy Merger [Member] | ERCOT Generation and Wholesale Reporting Unit [Member] | |||
Goodwill [Line Items] | |||
Goodwill | 122 | ||
Dynegy Merger [Member] | ERCOT Retail Reporting Unit [Member] | |||
Goodwill [Line Items] | |||
Goodwill | $ 53 |
Goodwill and Identifiable Intangible Assets and Liabilities (Estimated Amortization of Identifiable Intangible Assets and Liabilities) (Details) $ in Millions |
Jun. 30, 2019
USD ($)
|
---|---|
Goodwill and Intangible Assets Disclosure [Abstract] | |
2019 | $ 309 |
2020 | 211 |
2021 | 164 |
2022 | 101 |
2023 | $ 76 |
Income Taxes (Calculation of Effective Tax Rate) (Details) - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended | |||
---|---|---|---|---|---|
Jun. 30, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Jun. 30, 2018 |
Dec. 31, 2018 |
|
Effective Income Tax Rate Reconciliation, Amount [Abstract] | |||||
Income (loss) before income taxes | $ 502 | $ 31 | $ 803 | $ (364) | |
Income tax (expense) benefit | $ (148) | $ 74 | $ (225) | $ 163 | |
Effective tax rate | 29.50% | (238.70%) | 28.00% | 44.80% | |
Effective tax rate at federal statutory rate | 21.00% | 21.00% | 21.00% | 21.00% | |
Unrecognized Tax Benefits | $ 39 | $ 39 | $ 39 |
Tax Receivable Agreement Obligation (Narrative) (Details) - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended | |||
---|---|---|---|---|---|
Jun. 30, 2019 |
Mar. 31, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Jun. 30, 2018 |
|
Income Tax Disclosure [Abstract] | |||||
Percent of cash tax savings due Tax Receivable Agreement rights holders | 85.00% | ||||
Effective tax rate at federal statutory rate | 21.00% | 21.00% | 21.00% | 21.00% | |
Estimated undiscounted future payments under Tax Receivable Agreement | $ 1,300 | ||||
Changes in tax assumptions impacting timing of payments | $ (48) | $ (19) | $ 46 | $ (67) | $ 46 |
Tax Receivable Agreement Obligation (Summary of Tax Receivable Agreement Obligation) (Details) - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended | ||||
---|---|---|---|---|---|---|
Jun. 30, 2019 |
Mar. 31, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Jun. 30, 2018 |
Dec. 31, 2018 |
|
Income Tax Disclosure [Abstract] | ||||||
TRA obligation at the beginning of the period | $ 420 | $ 420 | $ 357 | |||
Accretion expense | 31 | 36 | ||||
Changes in tax assumptions impacting timing of payments | $ (48) | $ (19) | $ 46 | (67) | 46 | |
Impacts of Tax Receivable Agreement | (33) | 64 | (36) | 82 | ||
TRA obligation at the end of the period | 384 | 439 | 384 | 439 | ||
Less amounts due currently | 0 | (25) | 0 | (25) | ||
Noncurrent TRA obligation at the end of the period | $ 384 | $ 414 | $ 384 | $ 414 | $ 420 |
Accounts Receivable Securitization Program (Details) - USD ($) $ in Millions |
6 Months Ended | ||||
---|---|---|---|---|---|
Jun. 30, 2019 |
Jun. 30, 2018 |
Nov. 30, 2019 |
Jul. 31, 2019 |
Dec. 31, 2018 |
|
Short-term Debt [Line Items] | |||||
Accretion expense | $ 31 | $ 36 | |||
Accounts receivable securitization program | 430 | $ 339 | |||
Accounts receivable securitization program, gross trade accounts receivable held by special purpose subsidiary | $ 662 | ||||
Subsequent Event [Member] | |||||
Short-term Debt [Line Items] | |||||
Accounts receivable securitization program, maximum borrowing capacity | $ 450 | $ 600 |
Long-Term Debt (Vistra Operations Senior Secured Notes) (Details) - Vistra Operations Senior Secured Notes [Member] $ in Millions |
1 Months Ended |
---|---|
Jun. 30, 2019
USD ($)
| |
Proceeds from issuance of debt | $ 2,000 |
Debt fees and expenses, capitalized as reduction of debt | 20 |
Proceeds from issuance of senior long-term debt | 1,976 |
3.550% Senior Secured Notes Due 2024 [Member] | |
Proceeds from issuance of debt | $ 1,200 |
Debt instrument, interest rate, stated percentage | 3.55% |
Issuance of debt, price to public, percentage of face value | 99.807% |
4.300% Senior Secured Notes Due 2029 [Member] | |
Proceeds from issuance of debt | $ 800 |
Debt instrument, interest rate, stated percentage | 4.30% |
Issuance of debt, price to public, percentage of face value | 99.784% |
Long-Term Debt (Maturities) (Details) $ in Millions |
Jun. 30, 2019
USD ($)
|
---|---|
Maturities [Abstract] | |
Remainder of 2019 | $ 93 |
2020 | 144 |
2021 | 70 |
2022 | 321 |
2023 | 2,408 |
Thereafter | 8,322 |
Unamortized premiums, discounts and debt issuance costs | (4) |
Long-term debt, including amounts due currently | $ 11,354 |
Leases - Narrative (Details) |
6 Months Ended |
---|---|
Jun. 30, 2019
USD ($)
| |
Lessee, Lease, Description [Line Items] | |
Renewal term | 14 years |
Leases not yet commenced | $ 0 |
Minimum | |
Lessee, Lease, Description [Line Items] | |
Remaining lease term | 1 year |
Maximum | |
Lessee, Lease, Description [Line Items] | |
Remaining lease term | 38 years |
Leases - Lease Cost (Details) - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended |
---|---|---|
Jun. 30, 2019 |
Jun. 30, 2019 |
|
Leases [Abstract] | ||
Operating lease cost | $ 3 | $ 7 |
Finance lease: | ||
Finance lease right-of-use asset amortization | 1 | 2 |
Interest on lease liabilities | 1 | 1 |
Total finance lease cost | 2 | 3 |
Variable lease cost | 6 | 12 |
Short-term lease cost | 8 | 13 |
Sublease income | (2) | (4) |
Net lease cost | $ 17 | $ 31 |
Leases - Balance Sheet Information Disclosure (Details) - USD ($) $ in Millions |
Jun. 30, 2019 |
Jan. 01, 2019 |
Dec. 31, 2018 |
---|---|---|---|
Lease assets | |||
Operating lease right-of-use assets | $ 34 | $ 70 | $ 0 |
Finance lease right-of-use assets (net of accumulated depreciation) | 61 | ||
Total lease right-of-use assets | 95 | ||
Current lease liabilities | |||
Operating lease liabilities | 13 | 0 | |
Finance lease liabilities | 5 | ||
Total current lease liabilities | 18 | ||
Noncurrent lease liabilities | |||
Operating lease liabilities | 40 | 0 | |
Finance lease liabilities | 74 | $ 0 | |
Total noncurrent lease liabilities | 114 | ||
Total lease liabilities | $ 132 |
Leases - Cash Flow Information Disclosure (Details) $ in Millions |
6 Months Ended |
---|---|
Jun. 30, 2019
USD ($)
| |
Cash paid for amounts included in the measurement of lease liabilities | |
Operating cash flows from operating leases | $ 7 |
Operating cash flow from finance leases | 2 |
Finance cash flow from finance leases | 1 |
Non-cash disclosure upon commencement of new lease | |
Right-of-use assets obtained in exchange for new operating lease liabilities | 72 |
Right-of-use assets obtained in exchange for new finance lease liabilities | 15 |
Non-cash disclosure upon modification of existing lease | |
Modification of operating lease right-of-use assets | (36) |
Modification of finance lease right-of-use assets | $ 50 |
Leases - Lease Term and Discount Rate (Details) |
Jun. 30, 2019 |
---|---|
Weighted average remaining lease term | |
Operating lease | 8 years |
Finance lease | 18 years |
Weighted average discount rate | |
Operating lease (as a percent) | 6.04% |
Finance lease (as a percent) | 6.07% |
Leases - Maturity of Lease Liabilities (Details) - USD ($) $ in Millions |
Jun. 30, 2019 |
Jan. 01, 2019 |
---|---|---|
Operating lease | ||
Remainder of 2019 | $ 7 | |
2020 | 14 | |
2021 | 9 | |
2022 | 7 | |
2023 | 6 | |
Thereafter | 22 | |
Total lease payments | 65 | |
Less: Interest | (12) | |
Present value of lease liabilities | 53 | $ 109 |
Finance lease | ||
Remainder of 2019 | 4 | |
2020 | 9 | |
2021 | 9 | |
2022 | 9 | |
2023 | 9 | |
Thereafter | 79 | |
Total lease payments | 119 | |
Less: Interest | (40) | |
Present value of lease liabilities | 79 | |
Total lease | ||
Remainder of 2019 | 11 | |
2020 | 23 | |
2021 | 18 | |
2022 | 16 | |
2023 | 15 | |
Thereafter | 101 | |
Total lease payments | 184 | |
Less: Interest | (52) | |
Present value of lease liabilities | $ 132 |
Fair Value Measurements (Schedule of Changes in Fair Value of the Level 3 Assets and Liabilities (All Related to Commodity Contracts)) (Details) - Level 3 [Member] - Commodity Contract [Member] - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Jun. 30, 2018 |
|
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||
Net liability balance at beginning of period | $ (113) | $ (224) | $ (135) | $ (53) |
Total unrealized valuation gains (losses) | 87 | (18) | 125 | (230) |
Purchases, issuances and settlements | ||||
Purchases | 61 | 29 | 79 | 58 |
Issuances | (10) | (4) | (17) | (7) |
Settlements | (20) | 29 | (42) | 45 |
Transfers into Level 3 | 3 | 2 | 5 | 1 |
Transfers out of Level 3 | (4) | 1 | (11) | 1 |
Net liabilities assumed in connection with the Merger | 0 | 37 | 0 | 37 |
Net change | 117 | 2 | 139 | (169) |
Net liability balance at end of period | 4 | (222) | 4 | (222) |
Unrealized valuation gains (losses) relating to instruments held at end of period | $ 92 | $ (17) | $ 110 | $ (226) |
Commodity and Other Derivative Contractual Assets and Liabilities (Derivative (Income Statement Presentation) and Derivative type (Income Statement Presentation of Loss Reclassified from Accumulated OCI into Income)) (Details) - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Jun. 30, 2018 |
|
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Net gain (loss) | $ 417 | $ 104 | $ 596 | $ (286) |
Operating revenues [Member] | Commodity contracts [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Net gain (loss) | 549 | 69 | 776 | (376) |
Fuel, purchased power costs and delivery fees [Member] | Commodity contracts [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Net gain (loss) | (24) | 13 | 3 | 12 |
Interest expense [Member] | Interest rate swap [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Net gain (loss) | $ (108) | $ 22 | $ (183) | $ 78 |
Commodity and Other Derivative Contractual Assets and Liabilities (Credit Risk-Related Contingent Features of Derivatives) (Details) - USD ($) $ in Millions |
Jun. 30, 2019 |
Dec. 31, 2018 |
---|---|---|
Credit Derivatives [Line Items] | ||
Derivative, Net Liability Position, Aggregate Fair Value | $ (631) | $ (856) |
Credit risk derivative with contingent feature [Member] | ||
Credit Derivatives [Line Items] | ||
Derivative, Net Liability Position, Aggregate Fair Value | 223 | 218 |
Collateral Already Posted, Aggregate Fair Value | 79 | 190 |
Cross-default credit derivative [Member] | ||
Credit Derivatives [Line Items] | ||
Assets Needed for Immediate Settlement, Aggregate Fair Value | $ (329) | $ (448) |
Commodity and Other Derivative Contractual Assets and Liabilities (Concentrations of Credit Risk Related to Derivatives) (Details) - Credit Risk Contract [Member] $ in Millions |
6 Months Ended |
---|---|
Jun. 30, 2019
USD ($)
| |
Derivative [Line Items] | |
Total credit risk exposure to all counterparties related to derivative contracts | $ 1,675 |
Net exposure to those counterparties after taking into effect master netting arrangements, setoff provisions and collateral | 398 |
Largest net exposure to single counterparty | $ 119 |
Credit risk exposure to Banking and financial sector percentage | 71.00% |
Net exposure to banking and financial sector percentage | 23.00% |
Related Party Transactions (Narrrative) (Details) - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Jun. 30, 2018 |
|
Maximum | ||||
Related Party Transaction [Line Items] | ||||
Registration Rights Agreement, Demand Registration, Number Of Days To File S-1 Registration Statement | 45 days | |||
Registration Rights Agreement, Demand Registration, Number Of Days To File S-3 Registration Statement | 30 days | |||
Registration Rights Agreement, Demand Registration, Number Of Days Between Initial Registration And Effective Date | 120 days | |||
Legal Expenses Paid On Behalf of Selling Stockholders [Member] | ||||
Related Party Transaction [Line Items] | ||||
Legal fees | $ 0 | $ 0 | $ 0 | $ 0 |
Supplementary Financial Information (Components of Net Benefit Cost) (Details) - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Jun. 30, 2018 |
|
Pension Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | $ 2 | $ 4 | $ 4 | $ 5 |
Other costs | 0 | 0 | 0 | 0 |
Net periodic benefit cost | 2 | 4 | 4 | 5 |
Other Postretirement Benefits Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | 0 | 1 | 0 | 1 |
Other costs | 2 | 1 | 4 | 2 |
Net periodic benefit cost | $ 2 | $ 2 | $ 4 | $ 3 |
Supplementary Financial Information (Interest Expense and Related Charges) (Details) - USD ($) $ in Millions |
1 Months Ended | 3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|---|
Jun. 30, 2019 |
Jun. 30, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Jun. 30, 2018 |
|
Interest Expense and Related Charges [Line Items] | |||||
Interest paid/accrued | $ 154 | $ 166 | $ 305 | $ 216 | |
Unrealized mark-to-market net (gains) losses on interest rate swaps | 119 | (25) | 199 | (86) | |
Amortization of debt issuance costs, discounts and premiums | 0 | 3 | (2) | 4 | |
Debt extinguishment gain | (3) | 0 | (10) | 0 | |
Capitalized interest | (3) | (4) | (7) | (7) | |
Other | 7 | 6 | 10 | 10 | |
Total interest expense and related charges | $ 274 | $ 146 | $ 495 | $ 137 | |
Vistra Operations Company LLC | Line of Credit | |||||
Interest Expense and Related Charges [Line Items] | |||||
Debt extinguishment gain | $ 4 | ||||
Debt Instrument, Interest Rate During Period | 4.03% |
Supplementary Financial Information (Other Income and Deductions) (Details) - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Jun. 30, 2018 |
|
Other income: | ||||
Insurance settlement | $ 8 | $ 0 | $ 19 | $ 0 |
Funds Released from Escrow to Settle Pre-petition Claims of Our Predecessor | 0 | 0 | 9 | 0 |
Interest income | 3 | 4 | 7 | 10 |
All other | 2 | 1 | 4 | 3 |
Total other income | 13 | 7 | 39 | 18 |
Other deductions: | ||||
All other | 2 | 1 | 5 | 3 |
Total other deductions | 2 | 1 | 5 | 3 |
Corporate and Other Nonsegment | ||||
Other income: | ||||
Office space sublease rental income | 0 | 2 | 0 | 4 |
ERCOT Segment | ||||
Other income: | ||||
Sale of land | $ 0 | $ 0 | $ 0 | $ 1 |
Supplementary Financial Information (Restricted Cash) (Details) - USD ($) $ in Millions |
Jun. 30, 2019 |
Dec. 31, 2018 |
---|---|---|
Restricted cash included in current assets | $ 42 | $ 57 |
Amounts related to restructuring escrow accounts [Member] | ||
Restricted cash included in current assets | $ 42 | $ 57 |
Supplementary Financial Information (Trade Accounts Receivable and Allowance for Doubtful Accounts) (Details) - USD ($) $ in Millions |
6 Months Ended | |||
---|---|---|---|---|
Jun. 30, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Dec. 31, 2018 |
|
Supplementary Financial Information [Abstract] | ||||
Wholesale and retail trade accounts receivable | $ 1,118 | $ 1,106 | ||
Allowance for uncollectible accounts | $ (19) | $ (14) | (17) | (19) |
Trade accounts receivable — net | 1,101 | 1,087 | ||
Unbilled Receivables, Current | $ 375 | $ 350 | ||
Accounts Receivable, Allowance for Credit Loss [Roll Forward] | ||||
Allowance for uncollectible accounts receivable at beginning of period | 19 | 14 | ||
Increase for bad debt expense | 29 | 22 | ||
Decrease for account write-offs | (31) | (22) | ||
Allowance for uncollectible accounts receivable at end of period | $ 17 | $ 14 |
Supplementary Financial Information (Inventories by Major Category and Other Investments) (Details) - USD ($) $ in Millions |
Jun. 30, 2019 |
Dec. 31, 2018 |
---|---|---|
Inventories by Major Category | ||
Materials and supplies | $ 290 | $ 286 |
Fuel stock | 172 | 115 |
Natural gas in storage | 14 | 11 |
Total inventories | 476 | 412 |
Investments | ||
Nuclear plant decommissioning trust | 1,342 | 1,170 |
Assets related to employee benefit plans | 31 | 31 |
Land | 49 | 49 |
Total investments | $ 1,422 | $ 1,250 |
Supplementary Financial Information (Investments) (Details) - USD ($) $ in Millions |
3 Months Ended | 6 Months Ended | |||
---|---|---|---|---|---|
Jun. 30, 2019 |
Jun. 30, 2018 |
Jun. 30, 2019 |
Jun. 30, 2018 |
Dec. 31, 2018 |
|
Investment in unconsolidated subsidiary | $ 127 | $ 127 | $ 131 | ||
Equity in earnings of unconsolidated subsidiary | 3 | $ 4 | 9 | $ 4 | |
Proceeds from Equity Method Investment, Distribution, Return of Capital | 9 | $ 6 | 14 | $ 6 | |
Northeast Energy, LP [Member] | |||||
Investment in unconsolidated subsidiary | $ 125 | $ 125 |
Supplementary Financial Information (Other Noncurrent Liabilities and Deferred Credits) (Details) - USD ($) $ in Millions |
Jun. 30, 2019 |
Dec. 31, 2018 |
---|---|---|
Supplementary Financial Information [Abstract] | ||
Retirement and other employee benefits | $ 273 | $ 270 |
Finance lease liabilities | 74 | 0 |
Uncertain tax positions, including accrued interest | 6 | 4 |
Other | 111 | 66 |
Total other noncurrent liabilities and deferred credits | $ 464 | $ 340 |
Supplementary Financial Information (Supplemental Cash Flow Information) (Details) - USD ($) shares in Millions, $ in Millions |
6 Months Ended | |||
---|---|---|---|---|
Jun. 30, 2019 |
Jun. 30, 2018 |
Dec. 31, 2018 |
Dec. 31, 2017 |
|
Supplementary Financial Information [Abstract] | ||||
Cash and cash equivalents | $ 964 | $ 636 | ||
Restricted cash included in current assets | 42 | 57 | ||
Total cash, cash equivalents and restricted cash | 1,006 | $ 816 | $ 693 | $ 2,046 |
Cash payments related to: | ||||
Interest paid | 307 | 344 | ||
Capitalized interest | (7) | (7) | ||
Interest paid (net of capitalized interest) | 300 | 337 | ||
Income taxes | 9 | 58 | ||
Noncash investing and financing activities: | ||||
Construction expenditures | $ 41 | $ 13 | ||
Vistra Energy common stock issued in the Merger | 0 | 2,245 |