← Filings of VST
Tables in the 10-Q of Vistra Corp.
122 tables with numbers, filed Aug 6, 2018. Each one downloads as a CSV for Excel or
Google Sheets, with the filing's address in the last row. Only the layout is tidied (a "$" or ")" in a cell of its own is joined to its number); no value is changed.
Open the filing on sec.gov ↗
| | PAGE |
| GLOSSARY | | ii |
| PART I. | FINANCIAL INFORMATION | |
| Item 1. | Financial Statements (Unaudited) | |
| Condensed Statements of Consolidated Income (Loss) — Three and Six Months Ended June 30, 2018 and 2017 | 1 |
| Condensed Statements of Consolidated Comprehensive Income (Loss) — Three and Six Months Ended June 30, 2018 and 2017 | 1 |
| Condensed Statements of Consolidated Cash Flows — Six Months Ended June 30, 2018 and 2017 | 2 |
| Condensed Consolidated Balance Sheets — June 30, 2018 and December 31, 2017 | 3 |
First 8 of 21 rows. The CSV has all of them.
Table 2 after “When the following terms and abbreviations appear in the text of this report, they have the meanings indicated below.”
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| 2017 Form 10-K | Vistra Energy's annual report on Form 10-K for the year ended December 31, 2017, filed with the SEC on February 26, 2018, except for Part II, Items 7 and 8, which were amended in Vistra Energy's current report on Form 8-K filed with the SEC on June 15, 2018 |
| ARO | asset retirement and mining reclamation obligation |
| CAA | Clean Air Act |
| CAISO | The California Independent System Operator |
| CCGT | combined cycle gas turbine |
| CFTC | U.S. Commodity Futures Trading Commission |
| CME | Chicago Mercantile Exchange |
| CO2 | carbon dioxide |
First 8 of 28 rows. The CSV has all of them.
| Merger Date | April 9, 2018, the date Vistra Energy and Dynegy completed the transactions contemplated by the Merger Agreement |
| MISO | Midcontinent Independent System Operator, Inc. |
| MMBtu | million British thermal units |
| MW | megawatts |
| MWh | megawatt-hours |
| NERC | North American Electricity Reliability Corporation |
| NRC | U.S. Nuclear Regulatory Commission |
| NYMEX | the New York Mercantile Exchange, a commodity derivatives exchange |
First 8 of 28 rows. The CSV has all of them.
Table 4 after “(Unaudited) (Millions of Dollars, Except Per Share Amounts)”
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| Three Months Ended June 30, | Six Months Ended June 30, | | | | |
| 2018 | 2017 | | 2018 | 2017 | |
| Operating revenues (Note 5) | $2,574 | | $1,296 | | $3,338 | $2,653 |
| Fuel, purchased power costs and delivery fees | (1,216) | | (729) | | (1,866) | (1,411) |
| Operating costs | (386) | | (195) | | (580) | (409) |
| Depreciation and amortization | (389) | | (172) | | (542) | (341) |
| Selling, general and administrative expenses | (352) | | (147) | | (514) | (285) |
| Operating income (loss) | 231 | | 53 | | (164) | 207 |
First 8 of 24 rows. The CSV has all of them.
Table 5 after “(Unaudited) (Millions of Dollars)”
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| Three Months Ended June 30, | Six Months Ended June 30, | | | | |
| 2018 | 2017 | | 2018 | 2017 | |
| Net income (loss) | $105 | | $(26) | | $(201) | $52 |
| Other comprehensive income (loss), net of tax effects: | | | | | | |
| Effect related to pension and other retirement benefit obligations (net of tax benefit of $— in all periods) | — | | — | | 1 | — |
| Total other comprehensive income | — | | — | | 1 | — |
| Comprehensive income (loss) | $105 | | $(26) | | $(200) | $52 |
| Less: Comprehensive loss attributable to noncontrolling interest | (3) | | — | | (3) | — |
First 8 of 9 rows. The CSV has all of them.
| VISTRA ENERGY CORP.CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS(Unaudited) (Millions of Dollars) | | | |
| Six Months Ended June 30, | | |
| 2018 | 2017 | |
| Cash flows — operating activities: | | | |
| Net income (loss) | $(201) | | $52 |
| Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities: | | | |
| Depreciation and amortization | 619 | | 437 |
| Deferred income tax (benefit) expense, net | (159) | | 29 |
First 8 of 39 rows. The CSV has all of them.
| VISTRA ENERGY CORP.CONDENSED CONSOLIDATED BALANCE SHEETS(Unaudited) (Millions of Dollars) | | | |
| June 30, 2018 | December 31, 2017 | |
| ASSETS | | | |
| Current assets: | | | |
| Cash and cash equivalents | $757 | | $1,487 |
| Restricted cash (Note 19) | 59 | | 59 |
| Trade accounts receivable — net (Note 19) | 1,149 | | 582 |
| Income taxes receivable | 11 | | — |
First 8 of 43 rows. The CSV has all of them.
| VISTRA ENERGY CORP.CONDENSED CONSOLIDATED BALANCE SHEETS(Unaudited) (Millions of Dollars) | | | |
| June 30, 2018 | December 31, 2017 | |
| Commitments and Contingencies (Note 11) | | | |
| Total equity (Note 12): | | | |
| Common stock (par value — $0.01; number of shares authorized — 1,800,000,000) (shares outstanding: June 30, 2018 — 521,214,879; December 31, 2017 — 428,398,802) | 5 | | 4 |
| Additional paid-in-capital | 10,015 | | 7,765 |
| Retained deficit | (1,591) | | (1,410) |
| Accumulated other comprehensive income | (16) | | (17) |
First 8 of 12 rows. The CSV has all of them.
Table 9 after “As of January 1, 2018, the cumulative effect of the changes made to our condensed consolidated balance sheet for the adoption of the new rev”
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| December 31, 2017 | Adoption of New Revenue Standard | | January 1, 2018 | |
| Impact on condensed consolidated balance sheet: | | | | | |
| Assets | | | | | |
| Prepaid expense and other current assets | $72 | | $5 | | $77 |
| Accumulated deferred income taxes | $710 | | $(4) | | $706 |
| Other noncurrent assets | $162 | | $16 | | $178 |
| Equity | | | | | |
| Retained deficit | $(1,410) | | $17 | | $(1,393) |
Table 10 after “The disclosure of the impact of adoption on our condensed statement of consolidated income (loss) and condensed consolidated balance sheet w”
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| Three Months Ended June 30, 2018 | Six Months Ended June 30, 2018 | | | | | | | | |
| As Reported | Amount Without Adoption of New Revenue Standard | | Effect of Change Higher (Lower) | As Reported | Amount Without Adoption of New Revenue Standard | | Effect of Change Higher (Lower) | | |
| Impact on condensed statement of consolidated income (loss): | | | | | | | | | | |
| Operating revenues | $2,574 | | $2,573 | | $1 | | $3,338 | | $3,336 | $2 |
| Selling, general and administrative expenses | (352) | | (355) | | 3 | | (514) | | (520) | 6 |
| Net income (loss) | 105 | | 102 | | 3 | | (201) | | (207) | 6 |
| June 30, 2018 | | | | |
| As Reported | Balances Without Adoption of New Revenue Standard | | Effect of Change Higher (Lower) | |
| Impact on condensed consolidated balance sheet: | | | | | |
| Assets | | | | | |
| Prepaid expense and other current assets | $135 | | $129 | | $6 |
| Accumulated deferred income taxes | 1,260 | | 1,264 | | (4) |
| Other noncurrent assets | 581 | | 558 | | 23 |
| Equity | | | | | |
First 8 of 9 rows. The CSV has all of them.
Table 12 after “. The purchase price allocation is ongoing and is dependent upon final valuation determinations, which have not been completed. The prelimin”
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| Dynegy shares outstanding as of April 9, 2018 (in millions) | 173 |
| Exchange Ratio | 0.652 |
| Vistra Energy shares issued for Dynegy shares outstanding (in millions) | 113 |
| Opening price of Vistra Energy common stock on April 9, 2018 | $19.87 |
| Purchase price for common stock | $2,245 |
| Fair value of outstanding stock compensation awards attributable to pre-combination service | $26 |
| Fair value of outstanding warrants | $2 |
| Total purchase price | $2,273 |
| Preliminary Purchase Price Allocation | |
| Cash and cash equivalents | $445 |
| Trade accounts receivables, inventories, prepaid expenses and other current assets | 863 |
| Property, plant and equipment | 10,362 |
| Accumulated deferred income taxes | 391 |
| Identifiable intangible assets | 387 |
| Other noncurrent assets | 532 |
| Total assets acquired | 12,980 |
First 8 of 17 rows. The CSV has all of them.
Table 14 after “assumes that the Merger occurred on January 1, 2017. The unaudited pro forma financial information is provided for information purposes only”
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| Six Months Ended June 30, | | |
| 2018 | 2017 | |
| Revenues | $4,789 | | $5,213 |
| Net income (loss) | $(439) | | $18 |
| Net income (loss) attributable to Vistra Energy | $(435) | | $7 |
| Net income (loss) attributable to Vistra Energy per weighted average share of common stock outstanding — basic | $(0.83) | | $0.01 |
| Net income (loss) attributable to Vistra Energy per weighted average share of common stock outstanding — diluted | $(0.83) | | $0.01 |
Table 15 after “MW, were retired in May 2018. These units were retired as previously scheduled. No gain or loss was recorded in conjunction with the retirem”
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| Name | Location | Fuel Type | Net Generation Capacity (MW) | Ownership Interest | | Date Units Taken Offline | |
| Killen | Manchester, Ohio | Coal | 204 | | 33% | | May 31, 2018 |
| Stuart | Aberdeen, Ohio | Coal | 679 | | 39% | | May 24, 2018 |
| Total | | | 883 | | | | |
Table 16 after “MW. Luminant decided to retire these units because they were projected to be uneconomic based on then current market conditions and would ha”
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| Name | Location (all in the state of Texas) | Fuel Type | Installed Nameplate Generation Capacity (MW) | Number of Units | | Date Units Taken Offline | |
| Monticello | Titus County | Lignite/Coal | 1,880 | | 3 | | January 4, 2018 |
| Sandow | Milam County | Lignite | 1,137 | | 2 | | January 11, 2018 |
| Big Brown | Freestone County | Lignite/Coal | 1,150 | | 2 | | February 12, 2018 |
| Total | | | 4,167 | | 7 | | |
Table 17 after “The following tables disaggregate our revenue by major source:”
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| Three Months Ended June 30, 2018 | | | | | | | | | | | | |
| Retail | ERCOT | | PJM | NY/NE | MISO | | Asset Closure | CAISO/Eliminations | Consolidated | | | |
| Revenue from contracts with customers: | | | | | | | | | | | | | |
| Retail energy charge in ERCOT | $1,111 | | $— | | $— | | $— | | $— | | $— | $— | $1,111 |
| Retail energy charge in Northeast/Midwest | 336 | | — | | — | | — | | — | | — | — | 336 |
| Wholesale generation revenue from ISO | — | | 208 | | 367 | | 118 | | 180 | | 15 | 13 | 901 |
| Capacity revenue | — | | — | | 119 | | 82 | | 29 | | 10 | 11 | 251 |
| Revenue from other wholesale contracts | — | | 50 | | 8 | | 6 | | 12 | | — | 2 | 78 |
First 8 of 15 rows. The CSV has all of them.
Table 18 after “The following tables disaggregate our revenue by major source:”
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| Six Months Ended June 30, 2018 | | | | | | | | | | | | |
| Retail | ERCOT | | PJM | NY/NE | MISO | | Asset Closure | CAISO/Eliminations | Consolidated | | | |
| Revenue from contracts with customers: | | | | | | | | | | | | | |
| Retail energy charge in ERCOT | $2,059 | | $— | | $— | | $— | | $— | | $— | $— | $2,059 |
| Retail energy charge in Northeast/Midwest | 336 | | — | | — | | — | | — | | — | — | 336 |
| Wholesale generation revenue from ISO | — | | 383 | | 367 | | 118 | | 180 | | 51 | 13 | 1,112 |
| Capacity revenue | — | | — | | 119 | | 82 | | 29 | | 10 | 11 | 251 |
| Revenue from other wholesale contracts | — | | 102 | | 8 | | 6 | | 12 | | 1 | 2 | 131 |
First 8 of 15 rows. The CSV has all of them.
| Performance Obligations as of June 30, 2018 | | | | | | | | | |
| 2018 | 2019 | | 2020 | 2021 | 2022 | | Thereafter (a) | | |
| Total capacity sold (MW) | 17,829 | 17,429 | | 14,826 | 13,619 | 5,947 | | 338 | | |
| Average price per kW-month | $5.66 | | $4.99 | | $4.22 | | $4.46 | | $4.76 | $4.39 |
Table 20 after “The following table presents trade accounts receivable relating to both contracts with customers and other activities:”
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| June 30, 2018 |
| Trade accounts receivable from contracts with customers — net | $1,044 |
| Other trade accounts receivable — net | 105 |
| Total trade accounts receivable — net | $1,149 |
Table 21 after “Identifiable intangible assets and liabilities are comprised of the following:”
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| June 30, 2018 | December 31, 2017 | | | | | | | | | |
| Identifiable Intangible Asset | GrossCarryingAmount | AccumulatedAmortization | | Net | GrossCarryingAmount | AccumulatedAmortization | | Net | | | |
| Retail customer relationship | $1,678 | | $722 | | $956 | | $1,648 | | | $572 | $1,076 |
| Software and other technology-related assets | 227 | | 76 | | 151 | | 183 | | | 47 | 136 |
| Retail and wholesale contracts | 445 | | 126 | | 319 | | 154 | | | 87 | 67 |
| Other identifiable intangible assets (a) | 34 | | 11 | | 23 | | 33 | | | 11 | 22 |
| Total identifiable intangible assets subject to amortization | $2,384 | | $935 | | 1,449 | | $2,018 | | | $717 | 1,301 |
| Retail trade names (not subject to amortization) | | | | 1,245 | | | | | 1,225 | | |
First 8 of 14 rows. The CSV has all of them.
Table 22 after “Amortization expense related to finite-lived identifiable intangible assets and liabilities (including the classification in the condensed s”
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| Identifiable Intangible Assets and Liabilities | | Condensed Statements of Consolidated Income (Loss) Line | Three Months Ended June 30, | | Six Months Ended June 30, | | | | | |
| 2018 | | 2017 | | 2018 | | 2017 | | | |
| Retail customer relationship | | Depreciation and amortization | $77 | | | $105 | | $150 | | $210 |
| Software and other technology-related assets | | Depreciation and amortization | 19 | | | 9 | | 30 | | 17 |
| Retail and wholesale contracts/purchase and sales contracts | | Operating revenues/fuel, purchased power costs and delivery fees | 23 | | | 21 | | 32 | | 45 |
| Other identifiable intangible assets | | Operating revenues/fuel, purchased power costs and delivery fees/depreciation and amortization | 2 | | | 4 | | 3 | | 8 |
| Total amortization expense (a) | $121 | | | $139 | | | $215 | | $280 | |
Table 23 after “, the estimated aggregate amortization expense of identifiable intangible assets and liabilities for each of the next five fiscal years is a”
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| Year | Estimated Amortization Expense |
| 2018 | $401 |
| 2019 | $321 |
| 2020 | $245 |
| 2021 | $175 |
| 2022 | $109 |
Table 24 after “The calculation of our effective tax rate is as follows:”
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| Three Months Ended June 30, | Six Months Ended June 30, | | | | |
| 2018 | 2017 | | 2018 | 2017 | |
| Income (loss) before income taxes | $31 | | $(34) | | $(364) | $85 |
| Income tax benefit (expense) | $74 | | $8 | | $163 | $(33) |
| Effective tax rate | (238.7)% | | 23.5% | | 44.8% | 38.8% |
| Six Months Ended June 30, | | |
| 2018 | 2017 | |
| TRA obligation at the beginning of the period | $357 | | $596 |
| Accretion expense | 36 | | 42 |
| Changes in tax assumptions impacting timing of payments | 46 | | — |
| TRA obligation at the end of the period | 439 | | 638 |
| Less amounts due currently | (25) | | (16) |
| Noncurrent TRA obligation at the end of the period | $414 | | $622 |
Table 26 after “Basic earnings per share available to common shareholders are based on the weighted average number of common shares outstanding during the p”
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| Three Months Ended June 30, 2018 | Three Months Ended June 30, 2017 | | | | | | | | |
| Net Income | Shares | | Per Share Amount | Net Loss | Shares | | Per Share Amount | | |
| Net income (loss) available for common stock — basic (a) | $108 | | 526,332,862 | | $0.21 | | $(26) | | 427,587,401 | $(0.06) |
| Dilutive securities: | | | | | | | | | | |
| Stock-based incentive compensation plan | — | | 7,453,962 | | 0.01 | | — | | — | — |
| Net income (loss) available for common stock — diluted | $108 | | 533,786,824 | | $0.20 | | $(26) | | 427,587,401 | $(0.06) |
| Six Months Ended June 30, 2018 | Six Months Ended June 30, 2017 | | | | | | | | |
| Net Loss | Shares | | Per Share Amount | Net Income | Shares | | Per Share Amount | | |
First 8 of 12 rows. The CSV has all of them.
Table 27 after “Amounts in the table below represent the categories of long-term debt obligations incurred by the Company.”
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| June 30, 2018 | December 31, 2017 | |
| Vistra Operations Credit Facilities | $5,842 | | $4,311 |
| Senior Notes: | | | |
| 7.375% Senior Notes, due November 1, 2022 | 1,750 | | — |
| 5.875% Senior Notes, due June 1, 2023 | 500 | | — |
| 7.625% Senior Notes, due November 1, 2024 | 1,250 | | — |
| 8.034% Senior Notes, due February 2, 2024 | 188 | | — |
| 8.000% Senior Notes, due January 15, 2025 | 750 | | — |
First 8 of 21 rows. The CSV has all of them.
| | June 30, 2018 | | | | |
| Vistra Operations Credit Facilities | Maturity Date | FacilityLimit | CashBorrowings | | Available Capacity | |
| Revolving Credit Facility (a) | June 14, 2023 | $2,500 | | $— | | $1,065 |
| Term Loan B-1 Facility (b) | August 4, 2023 | 2,807 | | 2,807 | | — |
| Term Loan B-2 Facility (b) | December 14, 2023 | 985 | | 985 | | — |
| Term Loan B-3 Facility (b) | December 31, 2025 | 2,050 | | 2,050 | | — |
| Total Vistra Operations Credit Facilities | | $8,342 | | $5,842 | | $1,065 |
| June 30, 2018 |
| Remainder of 2018 | $85 |
| 2019 | 182 |
| 2020 | 204 |
| 2021 | 130 |
| 2022 | 1,824 |
| Thereafter | 9,216 |
| Unamortized premiums, discounts and debt issuance costs | 322 |
First 8 of 9 rows. The CSV has all of them.
| Common Stock (a) | Additional Paid-in Capital | | Retained Earnings (Deficit) | Accumulated Other Comprehensive Income (Loss) | Noncontrolling Interest | | Total Equity | | |
| Balance at December 31, 2017 | $4 | | $7,765 | | $(1,410) | | $(17) | | $— | $6,342 |
| Stock issued in connection with the Merger | 1 | | 1,891 | | — | | — | | — | 1,892 |
| Net loss | — | | — | | (198) | | — | | — | (198) |
| Adoption of accounting standard (Note 1) | — | | — | | 17 | | — | | — | 17 |
| Treasury stock | — | | (75) | | — | | — | | — | (75) |
| Effects of stock-based incentive compensation plans | — | | 63 | | — | | — | | — | 63 |
| Tangible equity units acquired | — | | 369 | | — | | — | | — | 369 |
First 8 of 12 rows. The CSV has all of them.
| Common Stock (a) | Additional Paid-in Capital | | Retained Earnings (Deficit) | Accumulated Other Comprehensive Income (Loss) | Total Shareholders' Equity | | |
| Balance at December 31, 2016 | $4 | | $7,742 | | $(1,155) | | $6 | $6,597 |
| Net income | — | | — | | 52 | | — | 52 |
| Effects of stock-based incentive compensation plans | — | | 8 | | — | | — | 8 |
| Other | — | | — | | 1 | | — | 1 |
| Balance at June 30, 2017 | $4 | | $7,750 | | $(1,102) | | $6 | $6,658 |
Table 32 after “Assets and liabilities measured at fair value on a recurring basis consisted of the following at the respective balance sheet dates shown be”
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| June 30, 2018 | | | | | | | | |
| Level 1 | Level 2 | | Level 3 (a) | Reclassification (b) | Total | | |
| Assets: | | | | | | | | |
| Commodity contracts | $156 | | $325 | | $164 | | $48 | $693 |
| Interest rate swaps | — | | 149 | | — | | — | 149 |
| Nuclear decommissioning trust – equity securities (c) | 480 | | — | | — | | — | 480 |
| Nuclear decommissioning trust – debt securities (c) | — | | 429 | | — | | — | 429 |
| Sub-total | $636 | | $903 | | $164 | | $48 | 1,751 |
First 8 of 15 rows. The CSV has all of them.
Table 33 after “Assets and liabilities measured at fair value on a recurring basis consisted of the following at the respective balance sheet dates shown be”
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| December 31, 2017 | | | | | | | | |
| Level 1 | Level 2 | | Level 3 (a) | Reclassification (b) | Total | | |
| Assets: | | | | | | | | |
| Commodity contracts | $47 | | $98 | | $75 | | $2 | $222 |
| Interest rate swaps | — | | 18 | | — | | 8 | 26 |
| Nuclear decommissioning trust – equity securities (c) | 468 | | — | | — | | — | 468 |
| Nuclear decommissioning trust – debt securities (c) | — | | 430 | | — | | — | 430 |
| Sub-total | $515 | | $546 | | $75 | | $10 | 1,146 |
First 8 of 15 rows. The CSV has all of them.
| June 30, 2018 | | | | | | | | | | |
| Fair Value | | | | | | | | | |
| Contract Type (a) | Assets | Liabilities | | Total | Valuation Technique | Significant Unobservable Input | | Range (b) | | |
| Electricity purchases and sales | $27 | | $(146) | | $(119) | | Valuation Model | | Hourly price curve shape (c) | $0 to $75/ MWh |
| | | | | | Illiquid delivery periods for ERCOT hub power prices and heat rates (d) | | $20 to $120/ MWh | | |
| Electricity and weather options | 9 | | (177) | | (168) | | Option Pricing Model | | Gas to power correlation (e) | 15% to 100% |
| | | | | | Power volatility (e) | | 5% to 375% | | |
| Financial transmission rights | 85 | | (21) | | 64 | | Market Approach (f) | | Illiquid price differences between settlement points (g) | $0 to $30/ MWh |
First 8 of 10 rows. The CSV has all of them.
| December 31, 2017 | | | | | | | | | | |
| Fair Value | | | | | | | | | |
| Contract Type (a) | Assets | Liabilities | | Total | Valuation Technique | Significant Unobservable Input | | Range (b) | | |
| Electricity purchases and sales | $12 | | $(33) | | $(21) | | Valuation Model | | Hourly price curve shape (c) | $0 to $40/ MWh |
| | | | | | Illiquid delivery periods for ERCOT hub power prices and heat rates (d) | | $20 to $70/ MWh | | |
| Electricity and weather options | 10 | | (91) | | (81) | | Option Pricing Model | | Gas to power correlation (e) | 30% to 100% |
| | | | | | Power volatility (e) | | 5% to 180% | | |
| Financial transmission rights | 45 | | (4) | | 41 | | Market Approach (f) | | Illiquid price differences between settlement points (g) | $0 to $15/ MWh |
First 8 of 10 rows. The CSV has all of them.
| Three Months Ended June 30, | Six Months Ended June 30, | | | | |
| 2018 | 2017 | | 2018 | 2017 | |
| Net asset (liability) balance at beginning of period | $(224) | | $107 | | $(53) | $83 |
| Total unrealized valuation gains (losses) | (18) | | (32) | | (230) | 8 |
| Purchases, issuances and settlements (a): | | | | | | |
| Purchases | 29 | | 26 | | 58 | 35 |
| Issuances | (4) | | (3) | | (7) | (14) |
| Settlements | 29 | | (23) | | 45 | (42) |
First 8 of 14 rows. The CSV has all of them.
Table 37 after “. Derivative asset and liability totals represent the net value of the contract, while the balance sheet totals represent the gross value of”
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| June 30, 2018 | | | | | | | |
| Derivative Assets | Derivative Liabilities | | | | | | |
| Commodity Contracts | Interest Rate Swaps | | Commodity Contracts | Interest Rate Swaps | Total | | |
| Current assets | $575 | | $15 | | $8 | | $— | $598 |
| Noncurrent assets | 100 | | 134 | | 10 | | — | 244 |
| Current liabilities | (2) | | — | | (877) | | (4) | (883) |
| Noncurrent liabilities | (28) | | — | | (453) | | (14) | (495) |
| Net assets (liabilities) | $645 | | $149 | | $(1,312) | | $(18) | $(536) |
Table 38 after “. Derivative asset and liability totals represent the net value of the contract, while the balance sheet totals represent the gross value of”
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| December 31, 2017 | | | | | | | |
| Derivative Assets | Derivative Liabilities | | | | | | |
| Commodity Contracts | Interest Rate Swaps | | Commodity Contracts | Interest Rate Swaps | Total | | |
| Current assets | $190 | | $— | | $— | | $— | $190 |
| Noncurrent assets | 30 | | 22 | | 2 | | 4 | 58 |
| Current liabilities | — | | (4) | | (216) | | (4) | (224) |
| Noncurrent liabilities | — | | — | | (102) | | — | (102) |
| Net assets (liabilities) | $220 | | $18 | | $(316) | | $— | $(78) |
Table 39 after “The following table presents the pretax effect of derivative gains (losses) on net income, including realized and unrealized effects. Amount”
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| Derivative (condensed statements of consolidated income (loss) presentation) | Three Months Ended June 30, | | Six Months Ended June 30, | | | | |
| 2018 | | 2017 | | 2018 | 2017 | | |
| Commodity contracts (Operating revenues) | $69 | | | $(8) | | $(376) | $166 |
| Commodity contracts (Fuel, purchased power costs and delivery fees) | 13 | | | (1) | | 12 | (5) |
| Interest rate swaps (Interest expense and related charges) | 22 | | | (23) | | 78 | (20) |
| Net gain (loss) | $104 | | | $(32) | | $(286) | $141 |
Table 40 after “The following tables reconcile our derivative assets and liabilities on a contract basis to net amounts after taking into consideration nett”
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| June 30, 2018 | December 31, 2017 | | | | | | | | | | | |
| Derivative Assets and Liabilities | Offsetting Instruments (a) | | Cash Collateral (Received) Pledged (b) | Net Amounts | Derivative Assets and Liabilities | | Offsetting Instruments (a) | Cash Collateral (Received) Pledged (b) | Net Amounts | | | |
| Derivative assets: | | | | | | | | | | | | | |
| Commodity contracts | $645 | | $(462) | | $(1) | | $182 | | $220 | | $(113) | $(1) | $106 |
| Interest rate swaps | 149 | | (15) | | — | | 134 | | 18 | | — | — | 18 |
| Total derivative assets | 794 | | (477) | | (1) | | 316 | | 238 | | (113) | (1) | 124 |
| Derivative liabilities: | | | | | | | | | | | | | |
| Commodity contracts | (1,312) | | 462 | | 95 | | (755) | | (316) | | 113 | 1 | (202) |
First 8 of 11 rows. The CSV has all of them.
| June 30, 2018 | December 31, 2017 | | |
| Derivative type | Notional Volume | Unit of Measure | | |
| Natural gas (a) | 4,214 | | 1,259 | Million MMBtu |
| Electricity | 237,133 | | 114,129 | GWh |
| Financial Transmission Rights (b) | 192,072 | | 110,913 | GWh |
| Coal | 51 | | 2 | Million U.S. tons |
| Fuel oil | 14 | | 5 | Million gallons |
| Uranium | 75 | | 325 | Thousand pounds |
First 8 of 10 rows. The CSV has all of them.
Table 42 after “The following table presents the commodity derivative liabilities subject to credit risk-related contingent features that are not fully coll”
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| June 30, 2018 | December 31, 2017 | |
| Fair value of derivative contract liabilities (a) | $(862) | | $(204) |
| Offsetting fair value under netting arrangements (b) | 287 | | 103 |
| Cash collateral and letters of credit | 262 | | 41 |
| Liquidity exposure | $(313) | | $(60) |
Table 43 after “, net periodic benefit costs consisted of the following:”
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| Pension Benefits | OPEB Benefits | | | | | | | | | | | |
| Three Months Ended June 30, | Six Months Ended June 30, | | Three Months Ended June 30, | Six Months Ended June 30, | | | | | | | | |
| 2018 | 2017 | | 2018 | 2017 | 2018 | | 2017 | 2018 | 2017 | | | |
| Service cost | $4 | | $1 | | $5 | | $3 | | $1 | | $1 | $1 | $1 |
| Other costs | — | | — | | — | | — | | 1 | | 1 | 2 | 2 |
| Net periodic benefit cost | $4 | | $1 | | $5 | | $3 | | $2 | | $2 | $3 | $3 |
Table 44 after “At the Merger Date, Dynegy stock options and equity-based awards outstanding immediately prior to the Merger Date were generally automatical”
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| Instrument Type | Dynegy Awards Prior to the Merger Date | Vistra Awards Converted at the Merger Date | Fair Value of Awards (a) | |
| Stock Options | 4,096,027 | | 2,670,610 | $10 |
| Restricted Stock Units | 5,718,148 | | 3,056,689 | 61 |
| Performance Units | 1,538,133 | | 938,721 | 18 |
| Total | | | $89 | |
Table 45 after “to the Financial Statements in our 2017 Form 10-K. Our chief operating decision maker uses more than one measure to assess segment performan”
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| Three Months Ended June 30, | Six Months Ended June 30, | | | | |
| 2018 | 2017 | | 2018 | 2017 | |
| Operating revenues (a) | | | | | | |
| Retail | $1,454 | | $986 | | $2,426 | $1,850 |
| ERCOT | 1,327 | | 319 | | 794 | 1,104 |
| PJM | 485 | | — | | 485 | — |
| NY/NE | 187 | | — | | 187 | — |
| MISO | 257 | | — | | 257 | — |
First 8 of 12 rows. The CSV has all of them.
| Three Months Ended June 30, | Six Months Ended June 30, | | | | |
| 2018 | 2017 | | 2018 | 2017 | |
| Depreciation and amortization | | | | | | |
| Retail | $(80) | | $(108) | | $(157) | $(214) |
| ERCOT | (108) | | (54) | | (173) | (107) |
| PJM | (125) | | — | | (125) | — |
| NY/NE | (49) | | — | | (49) | — |
| MISO | (3) | | — | | (3) | — |
First 8 of 30 rows. The CSV has all of them.
| Three Months Ended June 30, | Six Months Ended June 30, | | | | |
| 2018 | 2017 | | 2018 | 2017 | |
| Retail | $1 | | $1 | | $13 | $9 |
| ERCOT | 668 | | (147) | | (398) | 148 |
| PJM | (10) | | — | | (10) | — |
| NY/NE | (24) | | — | | (24) | — |
| MISO | 30 | | — | | 30 | — |
| Corporate and Other (b) | 1 | | — | | 1 | — |
First 8 of 10 rows. The CSV has all of them.
| June 30, 2018 | December 31, 2017 | |
| Total assets | | | |
| Retail | $7,252 | | $6,156 |
| ERCOT | 9,018 | | 6,834 |
| PJM | 7,932 | | — |
| NY/NE | 2,619 | | — |
| MISO | 500 | | — |
| Asset Closure | 234 | | 235 |
First 8 of 10 rows. The CSV has all of them.
Table 49 after “Interest Expense and Related Charges”
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| Three Months Ended June 30, | Six Months Ended June 30, | | | | |
| 2018 | 2017 | | 2018 | 2017 | |
| Interest paid/accrued | $166 | | $52 | | $216 | $105 |
| Unrealized mark-to-market net (gains) losses on interest rate swaps | (25) | | 15 | | (86) | 6 |
| Amortization of debt issuance costs, discounts and premiums | 3 | | — | | 4 | — |
| Debt extinguishment gain | — | | — | | — | (21) |
| Capitalized interest | (4) | | (1) | | (7) | (4) |
| Other | 6 | | 3 | | 10 | 7 |
First 8 of 9 rows. The CSV has all of them.
| Three Months Ended June 30, | Six Months Ended June 30, | | | | |
| 2018 | 2017 | | 2018 | 2017 | |
| Other income: | | | | | | |
| Office space sublease rental income (a) | $2 | | $3 | | $4 | $6 |
| Mineral rights royalty income (b) | — | | 1 | | — | 2 |
| Sale of land (b) | — | | 1 | | 1 | 3 |
| Interest income | 4 | | 4 | | 10 | 5 |
| All other | 1 | | — | | 3 | 2 |
First 8 of 12 rows. The CSV has all of them.
| June 30, 2018 | December 31, 2017 | | | | |
| Current Assets | Noncurrent Assets | | Current Assets | Noncurrent Assets | |
| Amounts related to the Vistra Operations Credit Facilities (Note 10) | $— | | $— | | $— | $500 |
| Amounts related to restructuring escrow accounts | 59 | | — | | 59 | — |
| Total restricted cash | $59 | | $— | | $59 | $500 |
| June 30, 2018 | December 31, 2017 | |
| Wholesale and retail trade accounts receivable | $1,163 | | $596 |
| Allowance for uncollectible accounts | (14) | | (14) |
| Trade accounts receivable — net | $1,149 | | $582 |
Table 53 after “Allowance for Uncollectible Accounts Receivable”
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| Six Months Ended June 30, | | |
| 2018 | 2017 | |
| Allowance for uncollectible accounts receivable at beginning of period | $14 | | $10 |
| Increase for bad debt expense | 22 | | 16 |
| Decrease for account write-offs | (22) | | (17) |
| Allowance for uncollectible accounts receivable at end of period | $14 | | $9 |
| June 30, 2018 | December 31, 2017 | |
| Materials and supplies | $266 | | $149 |
| Fuel stock | 181 | | 83 |
| Natural gas in storage | 18 | | 21 |
| Total inventories | $465 | | $253 |
| June 30, 2018 | December 31, 2017 | |
| Nuclear plant decommissioning trust | $1,207 | | $1,188 |
| Assets related to employee benefit plans (Note 15) | 34 | | — |
| Land | 49 | | 49 |
| Miscellaneous other | — | | 3 |
| Total other investments | $1,290 | | $1,240 |
Table 56 after “Investments in a trust that will be used to fund the costs to decommission the Comanche Peak nuclear generation plant are carried at fair va”
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| June 30, 2018 | | | | | |
| Cost (a) | Unrealized gain | | Unrealized loss | Fair marketvalue | |
| Debt securities (b) | $432 | | $6 | | $(9) | $429 |
| Equity securities (c) | 272 | | 506 | | — | 778 |
| Total | $704 | | $512 | | $(9) | $1,207 |
Table 57 after “Investments in a trust that will be used to fund the costs to decommission the Comanche Peak nuclear generation plant are carried at fair va”
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| December 31, 2017 | | | | | |
| Cost (a) | Unrealized gain | | Unrealized loss | Fair marketvalue | |
| Debt securities (b) | $418 | | $14 | | $(2) | $430 |
| Equity securities (c) | 265 | | 495 | | (2) | 758 |
| Total | $683 | | $509 | | $(4) | $1,188 |
Table 58 after “The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from such sale”
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| Three Months Ended June 30, | Six Months Ended June 30, | | | | |
| 2018 | 2017 | | 2018 | 2017 | |
| Realized gains | $1 | | $1 | | $1 | $2 |
| Realized losses | $(1) | | $— | | $(3) | $(2) |
| Proceeds from sales of securities | $47 | | $19 | | $93 | $98 |
| Investments in securities | $(52) | | $(23) | | $(103) | $(107) |
| Nuclear Plant Decommissioning | Mining Land Reclamation | | Coal Ash and Other | Total | |
| Liability at December 31, 2017 | $1,233 | | $438 | | $265 | $1,936 |
| Additions: | | | | | | |
| Accretion | 21 | | 11 | | 12 | 44 |
| Adjustment for change in estimates | — | | 7 | | (43) | (36) |
| Obligations assumed in the Merger | — | | 2 | | 417 | 419 |
| Reductions: | | | | | | |
| Payments | — | | (35) | | (6) | (41) |
First 8 of 11 rows. The CSV has all of them.
Table 60 after “The balance of other noncurrent liabilities and deferred credits consists of the following:”
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| June 30, 2018 | December 31, 2017 | |
| Uncertain tax positions, including accrued interest | $11 | | $— |
| Other, including retirement and other employee benefits | 334 | | 220 |
| Total other noncurrent liabilities and deferred credits | $345 | | $220 |
| | June 30, 2018 | December 31, 2017 | | | | |
| Debt: | Fair Value Hierarchy | Carrying Amount | Fair Value | | Carrying Amount | Fair Value | |
| Long-term debt under the Vistra Operations Credit Facilities (Note 10) | Level 2 | $5,856 | | $5,796 | | $4,323 | $4,334 |
| Senior Notes (Note 10) | Level 2 | 5,632 | | 5,598 | | — | — |
| 7.000% Amortizing Notes (Note 10) | Level 2 | 38 | | 39 | | — | — |
| Forward Capacity Agreements (Note 10) | Level 3 | 221 | | 221 | | — | — |
| Equipment Financing Agreements (Note 10) | Level 3 | 120 | | 120 | | — | — |
| Mandatorily redeemable subsidiary preferred stock (Note 10) | Level 2 | 70 | | 70 | | 70 | 70 |
First 8 of 9 rows. The CSV has all of them.
| June 30, 2018 | December 31, 2017 | |
| Cash and cash equivalents | $757 | | $1,487 |
| Restricted cash included in current assets | 59 | | 59 |
| Restricted cash included in noncurrent assets | — | | 500 |
| Total cash, cash equivalents and restricted cash | $816 | | $2,046 |
| Six Months Ended June 30, | | |
| 2018 | 2017 | |
| Cash payments related to: | | | |
| Interest paid | $344 | | $142 |
| Capitalized interest | (7) | | (4) |
| Interest paid (net of capitalized interest) | $337 | | $138 |
| Income taxes | $58 | | $43 |
| Noncash investing and financing activities: | | | |
First 8 of 11 rows. The CSV has all of them.
| Parent (Issuer) | Guarantor Subsidiaries | | Non-Guarantor Subsidiaries | Eliminations | Consolidated | | |
| Operating revenues | $— | | $2,508 | | $68 | | $(2) | $2,574 |
| Fuel, purchased power costs and delivery fees | — | | (1,166) | | (51) | | 1 | (1,216) |
| Operating costs | — | | (370) | | (16) | | — | (386) |
| Depreciation and amortization | — | | (371) | | (18) | | — | (389) |
| Selling, general and administrative expenses | (192) | | (160) | | (2) | | 2 | (352) |
| Operating income (loss) | (192) | | 441 | | (19) | | 1 | 231 |
| Other income | 3 | | 5 | | — | | (1) | 7 |
First 8 of 16 rows. The CSV has all of them.
| Parent (Issuer) | Guarantor Subsidiaries | | Non-Guarantor Subsidiaries | Eliminations | Consolidated | | |
| Operating revenues | $— | | $1,296 | | $— | | $— | $1,296 |
| Fuel, purchased power costs and delivery fees | — | | (729) | | — | | — | (729) |
| Operating costs | — | | (195) | | — | | — | (195) |
| Depreciation and amortization | — | | (172) | | — | | — | (172) |
| Selling, general and administrative expenses | (9) | | (138) | | — | | — | (147) |
| Operating income (loss) | (9) | | 62 | | — | | — | 53 |
| Other income | — | | 9 | | — | | — | 9 |
First 8 of 15 rows. The CSV has all of them.
| Parent (Issuer) | Guarantor Subsidiaries | | Non-Guarantor Subsidiaries | Eliminations | Consolidated | | |
| Operating revenues | $— | | $3,272 | | $68 | | $(2) | $3,338 |
| Fuel, purchased power costs and delivery fees | — | | (1,816) | | (51) | | 1 | (1,866) |
| Operating costs | — | | (564) | | (16) | | — | (580) |
| Depreciation and amortization | — | | (524) | | (18) | | — | (542) |
| Selling, general and administrative expenses | (226) | | (288) | | (2) | | 2 | (514) |
| Operating income (loss) | (226) | | 80 | | (19) | | 1 | (164) |
| Other income | 6 | | 12 | | 1 | | (1) | 18 |
First 8 of 16 rows. The CSV has all of them.
| Parent (Issuer) | Guarantor Subsidiaries | | Non-Guarantor Subsidiaries | Eliminations | Consolidated | | |
| Operating revenues | $— | | $2,653 | | $— | | $— | $2,653 |
| Fuel, purchased power costs and delivery fees | — | | (1,411) | | — | | — | (1,411) |
| Operating costs | — | | (409) | | — | | — | (409) |
| Depreciation and amortization | — | | (341) | | — | | — | (341) |
| Selling, general and administrative expenses | (14) | | (271) | | — | | — | (285) |
| Operating income (loss) | (14) | | 221 | | — | | — | 207 |
| Other income | — | | 18 | | — | | — | 18 |
First 8 of 15 rows. The CSV has all of them.
| Parent (Issuer) | Guarantor Subsidiaries | | Non-Guarantor Subsidiaries | Eliminations | Consolidated | | |
| Net income (loss) | $105 | | $343 | | $(14) | | $(329) | $105 |
| Other comprehensive income (loss), net of tax effects: | | | | | | | | |
| Effect related to pension and other retirement benefit obligations | — | | — | | — | | — | — |
| Total other comprehensive income | — | | — | | — | | — | — |
| Comprehensive income (loss) | $105 | | $343 | | $(14) | | $(329) | $105 |
| Parent (Issuer) | Guarantor Subsidiaries | | Non-Guarantor Subsidiaries | Eliminations | Consolidated | | |
| Net income (loss) | $(26) | | $(9) | | $— | | $9 | $(26) |
| Other comprehensive income (loss), net of tax effects: | | | | | | | | |
| Effect related to pension and other retirement benefit obligations | — | | — | | — | | — | — |
| Total other comprehensive income | — | | — | | — | | — | — |
| Comprehensive income (loss) | $(26) | | $(9) | | $— | | $9 | $(26) |
| Parent (Issuer) | Guarantor Subsidiaries | | Non-Guarantor Subsidiaries | Eliminations | Consolidated | | |
| Net income (loss) | $(201) | | $71 | | $(14) | | $(57) | $(201) |
| Other comprehensive income (loss), net of tax effects: | | | | | | | | |
| Effect related to pension and other retirement benefit obligations | 1 | | — | | — | | — | 1 |
| Total other comprehensive income | 1 | | — | | — | | — | 1 |
| Comprehensive income (loss) | $(200) | | $71 | | $(14) | | $(57) | $(200) |
| Parent (Issuer) | Guarantor Subsidiaries | | Non-Guarantor Subsidiaries | Eliminations | Consolidated | | |
| Net income (loss) | $52 | | $82 | | $— | | $(82) | $52 |
| Other comprehensive income (loss), net of tax effects: | | | | | | | | |
| Effect related to pension and other retirement benefit obligations | — | | — | | — | | — | — |
| Total other comprehensive income | — | | — | | — | | — | — |
| Comprehensive income (loss) | $52 | | $82 | | $— | | $(82) | $52 |
| Parent (Issuer) | Guarantor Subsidiaries | | Non-Guarantor Subsidiaries | Eliminations | Consolidated | | |
| Cash flows — operating activities: | | | | | | | | |
| Cash provided by (used in) operating activities | $(280) | | $(109) | | $360 | | $— | $(29) |
| Cash flows — financing activities: | | | | | | | | |
| Repayments/repurchases of debt | (840) | | (498) | | — | | — | (1,338) |
| Stock repurchase | (63) | | — | | — | | — | (63) |
| Debt financing fee | (29) | | (17) | | — | | — | (46) |
| Other, net | — | | 4 | | — | | — | 4 |
First 8 of 21 rows. The CSV has all of them.
| Parent (Issuer) | Guarantor Subsidiaries | | Non-Guarantor Subsidiaries | Eliminations | Consolidated | | |
| Cash flows — operating activities: | | | | | | | | |
| Cash provided by operating activities | $111 | | $222 | | $— | | | $333 |
| Cash flows — financing activities: | | | | | | | | |
| Repayments/repurchases of debt | — | | (24) | | — | | — | (24) |
| Debt financing fee | — | | (3) | | — | | — | (3) |
| Cash used in financing activities | — | | (27) | | — | | — | (27) |
| Cash flows — investing activities: | | | | | | | | |
First 8 of 18 rows. The CSV has all of them.
| Parent (Issuer) | Guarantor Subsidiaries | | Non-Guarantor Subsidiaries | Eliminations | Consolidated | | |
| ASSETS | | | | | | | | |
| Current assets: | | | | | | | | |
| Cash and cash equivalents | $322 | | $422 | | $13 | | $— | $757 |
| Restricted cash | 59 | | — | | — | | — | 59 |
| Trade accounts receivable — net | 8 | | 1,142 | | 1 | | (2) | 1,149 |
| Accounts receivable — affiliates | — | | 275 | | — | | (275) | — |
| Notes due from affiliates | — | | 101 | | — | | (101) | — |
First 8 of 48 rows. The CSV has all of them.
| Parent (Issuer) | Guarantor Subsidiaries | | Non-Guarantor Subsidiaries | Eliminations | Consolidated | | |
| ASSETS | | | | | | | | |
| Current assets: | | | | | | | | |
| Cash and cash equivalents | $1,124 | | $363 | | $— | | $— | $1,487 |
| Restricted cash | 59 | | — | | — | | — | 59 |
| Trade accounts receivable — net | 4 | | 578 | | — | | — | 582 |
| Inventories | — | | 253 | | — | | — | 253 |
| Commodity and other derivative contractual assets | — | | 190 | | — | | — | 190 |
First 8 of 42 rows. The CSV has all of them.
Table 76 after “, respectively. Generation volumes hedged in PJM, NYISO, ISO-NE, MISO and CAISO at June 29, 2018 were as follows:”
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| 2018 | 2019 | |
| PJM | 78% | | 63% |
| NYISO/ISO-NE | 77% | | 47% |
| MISO/CAISO | 74% | | 57% |
Table 77 after “The following sensitivity tables provide approximate estimates of the potential impact of movements in natural gas prices and market heat ra”
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| Balance 2018 (a) | 2019 |
| ERCOT: | | |
| $0.50/MMBtu increase in natural gas price (b) | $ ~25 | $ ~50 |
| $0.50/MMBtu decrease in natural gas price (b) | $ ~(20) | $ ~(30) |
| 1.0/MMBtu/MWh increase in market heat rate (c) | $ ~30 | $ ~110 |
| 1.0/MMBtu/MWh decrease in market heat rate (c) | $ ~(15) | $ ~(95) |
| PJM: | | |
| $0.50/MMBtu increase in natural gas price (d) | $ ~20 | $ ~51 |
First 8 of 21 rows. The CSV has all of them.
| Three Months Ended June 30, | Favorable (Unfavorable) $ Change | | Six Months Ended June 30, | | Favorable (Unfavorable) $ Change | | | | |
| 2018 | 2017 | | | 2018 | | 2017 | | | |
| Operating revenues | $2,574 | | $1,296 | | | $1,278 | | $3,338 | $2,653 | $685 |
| Fuel, purchased power costs and delivery fees | (1,216) | | (729) | | | (487) | | (1,866) | (1,411) | (455) |
| Operating costs | (386) | | (195) | | | (191) | | (580) | (409) | (171) |
| Depreciation and amortization | (389) | | (172) | | | (217) | | (542) | (341) | (201) |
| Selling, general and administrative expenses | (352) | | (147) | | | (205) | | (514) | (285) | (229) |
| Operating income (loss) | 231 | | 53 | | | 178 | | (164) | 207 | (371) |
First 8 of 16 rows. The CSV has all of them.
| Three Months Ended June 30, 2018 | | | | | | | | | | | | |
| Retail | ERCOT | | PJM | NY/NE | MISO | | Asset Closure | Eliminations / Corporate and Other | Vistra Energy Consolidated | | | |
| Operating revenues | $1,454 | | $1,327 | | $485 | | $187 | | $257 | | $21 | $(1,157) | $2,574 |
| Fuel, purchased power costs and delivery fees | (1,566) | | (337) | | (239) | | (108) | | (133) | | (10) | 1,177 | (1,216) |
| Operating costs | (9) | | (182) | | (82) | | (25) | | (76) | | (6) | (6) | (386) |
| Depreciation and amortization | (80) | | (108) | | (125) | | (49) | | (3) | | — | (24) | (389) |
| Selling, general and administrative expenses | (102) | | (20) | | (15) | | (12) | | (14) | | (4) | (185) | (352) |
| Operating income (loss) | (303) | | 680 | | 24 | | (7) | | 31 | | 1 | (195) | 231 |
First 8 of 16 rows. The CSV has all of them.
| Three Months Ended June 30, 2017 | | | | | | | |
| Retail | ERCOT | | Asset Closure | Eliminations / Corporate and Other | Vistra Energy Consolidated | | |
| Operating revenues | $986 | | $319 | | $265 | | $(274) | $1,296 |
| Fuel, purchased power costs and delivery fees | (596) | | (245) | | (161) | | 273 | (729) |
| Operating costs | (3) | | (140) | | (52) | | — | (195) |
| Depreciation and amortization | (108) | | (54) | | — | | (10) | (172) |
| Selling, general and administrative expenses | (103) | | (32) | | (4) | | (8) | (147) |
| Operating income (loss) | 176 | | (152) | | 48 | | (19) | 53 |
First 8 of 15 rows. The CSV has all of them.
| Six Months Ended June 30, 2018 | | | | | | | | | | | | |
| Retail | ERCOT | | PJM | NY/NE | MISO | | Asset Closure | Eliminations / Corporate and Other | Vistra Energy Consolidated | | | |
| Operating revenues | $2,426 | | $794 | | $485 | | $187 | | $257 | | $49 | $(860) | $3,338 |
| Fuel, purchased power costs and delivery fees | (1,601) | | (627) | | (239) | | (108) | | (133) | | (36) | 878 | (1,866) |
| Operating costs | (13) | | (347) | | (82) | | (25) | | (76) | | (30) | (7) | (580) |
| Depreciation and amortization | (157) | | (173) | | (125) | | (49) | | (3) | | — | (35) | (542) |
| Selling, general and administrative expenses | (200) | | (56) | | (15) | | (12) | | (14) | | (5) | (212) | (514) |
| Operating income (loss) | 455 | | (409) | | 24 | | (7) | | 31 | | (22) | (236) | (164) |
First 8 of 16 rows. The CSV has all of them.
| Six Months Ended June 30, 2017 | | | | | | | |
| Retail | ERCOT | | Asset Closure | Eliminations / Corporate and Other | Vistra Energy Consolidated | | |
| Operating revenues | $1,850 | | $1,104 | | $451 | | $(752) | $2,653 |
| Fuel, purchased power costs and delivery fees | (1,368) | | (496) | | (300) | | 753 | (1,411) |
| Operating costs | (7) | | (293) | | (109) | | — | (409) |
| Depreciation and amortization | (214) | | (107) | | — | | (20) | (341) |
| Selling, general and administrative expenses | (204) | | (59) | | (9) | | (13) | (285) |
| Operating income (loss) | 57 | | 149 | | 33 | | (32) | 207 |
First 8 of 15 rows. The CSV has all of them.
| Three Months Ended June 30, | Favorable (Unfavorable) $ Change | | Six Months Ended June 30, | | Favorable (Unfavorable) $ Change | | | | |
| 2018 | 2017 | | | 2018 | | 2017 | | | |
| Net income (loss) | $105 | | $(26) | | | $131 | | $(201) | $52 | $(253) |
| Income tax expense (benefit) | (74) | | (8) | | | (66) | | (163) | 33 | (196) |
| Interest expense and related charges | 146 | | 69 | | | 77 | | 137 | 93 | 44 |
| Depreciation and amortization | 409 | | 189 | | | 220 | | 582 | 389 | 193 |
| EBITDA before Adjustments | 586 | | 224 | | | 362 | | 355 | 567 | (212) |
| Unrealized net (gain) loss resulting from hedging transactions | (216) | | 67 | | | (283) | | 199 | (54) | 253 |
First 8 of 15 rows. The CSV has all of them.
| Three Months Ended June 30, 2018 | | | | | | | | | | | | |
| Retail | ERCOT | | PJM | NY/NE | MISO | | Asset Closure | Eliminations / Corporate and Other | Vistra Energy Consolidated | | | |
| Net income (loss) | $(288) | | $679 | | $23 | | $(5) | | $31 | | $2 | $(337) | $105 |
| Income tax expense (benefit) | — | | — | | — | | — | | — | | — | (74) | (74) |
| Interest expense and related charges | — | | 7 | | 2 | | 1 | | — | | — | 136 | 146 |
| Depreciation and amortization (a) | 80 | | 128 | | 125 | | 49 | | 3 | | — | 24 | 409 |
| EBITDA before Adjustments | (208) | | 814 | | 150 | | 45 | | 34 | | 2 | (251) | 586 |
| Unrealized net (gain) loss resulting from hedging transactions | 462 | | (667) | | (1) | | 22 | | (32) | | — | — | (216) |
First 8 of 14 rows. The CSV has all of them.
| Three Months Ended June 30, 2017 | | | | | | | |
| Retail | ERCOT | | Asset Closure | Eliminations / Corporate and Other | Vistra Energy Consolidated | | |
| Net income (loss) | $183 | | $(155) | | $50 | | $(104) | $(26) |
| Income tax expense (benefit) | — | | — | | — | | (8) | (8) |
| Interest expense and related charges | — | | 4 | | — | | 65 | 69 |
| Depreciation and amortization (a) | 108 | | 71 | | — | | 10 | 189 |
| EBITDA before Adjustments | 291 | | (80) | | 50 | | (37) | 224 |
| Unrealized net (gain) loss resulting from hedging transactions | (89) | | 157 | | — | | (1) | 67 |
First 8 of 14 rows. The CSV has all of them.
| Six Months Ended June 30, 2018 | | | | | | | | | | | | |
| Retail | ERCOT | | PJM | NY/NE | MISO | | Asset Closure | Eliminations / Corporate and Other | Vistra Energy Consolidated | | | |
| Net income (loss) | $483 | | $(407) | | $23 | | $(5) | | $31 | | $(20) | $(306) | $(201) |
| Income tax expense (benefit) | — | | — | | — | | — | | — | | — | (163) | (163) |
| Interest expense and related charges | 1 | | 15 | | 2 | | 1 | | — | | — | 118 | 137 |
| Depreciation and amortization (a) | 157 | | 213 | | 125 | | 49 | | 3 | | — | 35 | 582 |
| EBITDA before Adjustments | 641 | | (179) | | 150 | | 45 | | 34 | | (20) | (316) | 355 |
| Unrealized net (gain) loss resulting from hedging transactions | (193) | | 403 | | (1) | | 22 | | (32) | | — | — | 199 |
First 8 of 14 rows. The CSV has all of them.
| Six Months Ended June 30, 2017 | | | | | | | |
| Retail | ERCOT | | Asset Closure | Eliminations / Corporate and Other | Vistra Energy Consolidated | | |
| Net income (loss) | $70 | | $147 | | $37 | | $(202) | $52 |
| Income tax expense (benefit) | — | | — | | — | | 33 | 33 |
| Interest expense and related charges | — | | 5 | | — | | 88 | 93 |
| Depreciation and amortization (a) | 214 | | 154 | | — | | 21 | 389 |
| EBITDA before Adjustments | 284 | | 306 | | 37 | | (60) | 567 |
| Unrealized net (gain) loss resulting from hedging transactions | 73 | | (127) | | — | | — | (54) |
First 8 of 14 rows. The CSV has all of them.
Table 88 after “, primarily due to the following:”
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| PJM, MISO and NY/NE segments acquired in the Merger | $246 |
| Increase in ERCOT segment driven by operations acquired in the Merger and the impact of the Comanche Peak outage in 2017 | 61 |
| Increase in Retail segment driven by favorable impacts of weather in ERCOT | 41 |
| Decrease in Asset Closure segment driven by retirement of facilities in first quarter of 2018, partially offset by the change in estimates for certain AROs | (49) |
| Corporate and Other | 14 |
| Total | $313 |
Table 89 after “, primarily due to the following:”
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| PJM, MISO and NY/NE segments acquired in the Merger | $246 |
| Increase in ERCOT segment driven by operations acquired in the Merger and the impact of the Comanche Peak outage in 2017, partially offset by partial Odessa earn-out buybacks | 27 |
| Increase in Retail segment driven by favorable impacts of weather in ERCOT | 58 |
| Decrease in Asset Closure segment driven by retirement of facilities in first quarter of 2018, partially offset by the change in estimates for certain AROs | (62) |
| Corporate and Other | 9 |
| Total | $278 |
| Three Months Ended June 30, | Favorable (Unfavorable) Change | | Six Months Ended June 30, | | Favorable (Unfavorable) Change | | | | | | |
| 2018 | 2017 | | | 2018 | | 2017 | | | | | |
| Operating revenues: | | | | | | | | | | | | |
| Revenues in ERCOT | $1,111 | | $964 | | | $147 | | | $2,059 | | $1,796 | $263 |
| Revenues in Northeast/Midwest | 336 | | — | | | 336 | | | 336 | | — | 336 |
| Amortization expense | (15) | | (20) | | | 5 | | | (27) | | (44) | 17 |
| Other revenues | 22 | | 42 | | | (20) | | | 58 | | 98 | (40) |
| Total operating revenues | 1,454 | | 986 | | | 468 | | | 2,426 | | 1,850 | 576 |
First 8 of 37 rows. The CSV has all of them.
Table 91 after “, primarily due to the following:”
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| Unfavorable impact of unrealized net losses on hedging activities | $(551) |
| Favorable margins primarily due to weather in ERCOT | 38 |
| Lower depreciation and amortization expenses driven by the retail customer relationship | 28 |
| Increased intercompany interest income and decreased corporate allocated costs | 6 |
| Lower impact from fresh start and purchase accounting related to retail contracts | 5 |
| Other | 3 |
| Total | $(471) |
Table 92 after “, primarily due to the following:”
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| Favorable impact of unrealized net gains on hedging activities | $266 |
| Lower depreciation and amortization expenses driven by the retail customer relationship | 57 |
| Favorable margins primarily due to weather in ERCOT | 54 |
| Lower impact from fresh start and purchase accounting related to retail contracts | 17 |
| Increased intercompany interest income | 15 |
| Other | 4 |
| Total | $413 |
| Three Months Ended June 30, | Favorable (Unfavorable) Change | | Six Months Ended June 30, | | Favorable (Unfavorable) Change | | | | |
| 2018 | 2017 | | | 2018 | | 2017 | | | |
| Operating revenues: | | | | | | | | | | |
| Wholesale electricity sales | $254 | | $95 | | | $159 | | $445 | $273 | $172 |
| Sales to affiliates | 405 | | 361 | | | 44 | | 751 | 669 | 82 |
| Rolloff of unrealized net gains (losses) representing positions settled in the current period | 131 | | (49) | | | 180 | | 167 | (90) | 257 |
| Unrealized net gains (losses) from changes in fair value | 102 | | (10) | | | 112 | | (359) | 156 | (515) |
| Unrealized net gains (losses) on hedging activities with affiliates | 435 | | (88) | | | 523 | | (208) | 82 | (290) |
First 8 of 38 rows. The CSV has all of them.
| Three Months Ended June 30, | Favorable (Unfavorable) Change | | Six Months Ended June 30, | | Favorable (Unfavorable) Change | | | | | | |
| 2018 | 2017 | | | 2018 | | 2017 | | | | | |
| Capacity factors: | | | | | | | | | | | | |
| Nuclear facilities | 105.1% | | 68.8% | | | | | 105.6% | | 87.2% | | |
| Lignite and coal facilities | 71.8% | | 76.7% | | | | | 68.8% | | 72.7% | | |
| CCGT facilities | 47.2% | | 59.5% | | | | | 55.9% | | 56.9% | | |
| Market pricing: | | | | | | | | | | | | |
| Average ERCOT North power price ($/MWh) | $27.76 | | $24.05 | | | $3.71 | | | $26.59 | | $22.63 | $3.96 |
Table 95 after “, primarily due to the following:”
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| Favorable impact of unrealized net gains on hedging activities | $824 |
| Operating results driven by operations acquired in the Merger | 24 |
| Impact related to Comanche Peak outage in second quarter of 2017 | 28 |
| Lower selling, general and administrative expenses | 12 |
| Insurance reimbursement for Comanche Peak in second quarter of 2018 | 5 |
| Increased depreciation driven by facilities acquired in the Merger | (54) |
| Partial buyback of the Odessa earn-out provision in 2018 (a) | (10) |
| Other | 5 |
First 8 of 9 rows. The CSV has all of them.
Table 96 after “, primarily due to the following:”
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| Unfavorable impact of unrealized net losses on hedging activities | $(530) |
| Increased depreciation driven by facilities acquired in the Merger | (66) |
| Partial buybacks of the Odessa earn-out provision in 2018 (a) | (31) |
| Impact related to Comanche Peak outage in second quarter of 2017 | 28 |
| Operating results driven by operations acquired in the Merger | 24 |
| Insurance reimbursement for Comanche Peak in second quarter of 2018 | 5 |
| Other | 16 |
| Total | $(554) |
Table 97 after “, primarily due to the following:”
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| Operating results driven by operations acquired in the Merger | $24 |
| Lower selling, general and administrative expenses | 12 |
| Impact related to Comanche Peak outage in second quarter of 2017 | 28 |
| Insurance reimbursement for Comanche Peak in second quarter of 2018 | 5 |
| Partial buybacks of the Odessa earn-out provision in 2018 | (10) |
| Other | 2 |
| Total | $61 |
Table 98 after “, primarily due to the following:”
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| Operating results driven by operations acquired in the Merger | $24 |
| Impact related to Comanche Peak outage in second quarter of 2017 | 28 |
| Insurance reimbursement for Comanche Peak in second quarter of 2018 | 5 |
| Partial buybacks of the Odessa earn-out provision in 2018 | (31) |
| Other | 1 |
| Total | $27 |
| Three and Six Months Ended June 30, 2018 |
| Operating revenues: | |
| Energy | $207 |
| Capacity | 119 |
| Unrealized net gains on hedging activities | 6 |
| Sales to affiliates | 168 |
| Unrealized net losses on hedging activities with affiliates | (16) |
| Other revenues | 1 |
First 8 of 37 rows. The CSV has all of them.
| Three and Six Months Ended June 30, 2018 |
| Average Market On-Peak Power Prices ($/MWh) (b): | |
| PJM West | $39.81 |
| AD Hub | $40.04 |
| Average natural gas price - TetcoM3 ($/MMBtu) (c) | $2.40 |
Table 101 after “, primarily reflecting the following:”
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| Generation revenue net of fuel on 11,250 GWh of production | $126 |
| Capacity revenue | 119 |
| Depreciation and amortization | (125) |
| Operating costs | (82) |
| Selling, general and administrative expenses | (15) |
| Unrealized net gains on hedging activities | 1 |
| Other | (1) |
| Total | $23 |
Table 102 after “, primarily reflecting the following:”
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| Generation revenue net of fuel on 11,250 GWh of production | $126 |
| Capacity revenue, net of capacity expense | 119 |
| Operating costs | (82) |
| Selling, general and administrative expenses | (15) |
| Equity income from unconsolidated investment and other | 6 |
| Total | $154 |
| Three and Six Months Ended June 30, 2018 |
| Operating revenues: | |
| Energy | $116 |
| Capacity | 82 |
| Unrealized net losses on hedging activities | (20) |
| Sales to affiliates | 16 |
| Unrealized net losses on hedging activities with affiliates | (4) |
| Other revenues | (3) |
First 8 of 38 rows. The CSV has all of them.
Table 104 after “, primarily reflecting the following:”
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| Capacity revenue | $82 |
| Generation revenue net of fuel on 3,765 GWh of production | 19 |
| Depreciation and amortization | (49) |
| Operating costs | (25) |
| Unrealized net losses on hedging activities | (22) |
| Selling, general and administrative expenses | (12) |
| Other | 2 |
| Total | (5) |
Table 105 after “, primarily reflecting the following:”
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| Capacity revenue | $82 |
| Generation revenue net of fuel on 3,765 GWh of production | 19 |
| Operating costs | (25) |
| Other | (2) |
| Total | $74 |
| Three and Six Months Ended June 30, 2018 |
| Operating revenues: | |
| Energy | $81 |
| Capacity | 29 |
| Unrealized net losses on hedging activities | (18) |
| Sales to affiliates | 115 |
| Unrealized net gains on hedging activities with affiliates | 48 |
| Other revenues | 2 |
First 8 of 32 rows. The CSV has all of them.
Table 107 after “, primarily reflecting the following:”
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| Generation revenue net of fuel on 6,340 GWh of production | $63 |
| Capacity revenue | 29 |
| Unrealized net gains on hedging activities | 32 |
| Operating costs | (76) |
| Selling, general and administrative expenses | (14) |
| Depreciation and amortization | (3) |
| Total | 31 |
Table 108 after “, primarily reflecting the following:”
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| Generation revenue net of fuel on 6,340 GWh of production | $63 |
| Capacity revenue | 29 |
| Operating costs | (76) |
| Other | 2 |
| Total | $18 |
| Three Months Ended June 30, | Favorable (Unfavorable) Change | | Six Months Ended June 30, | | Favorable (Unfavorable) Change | | | | |
| 2018 | 2017 | | | 2018 | | 2017 | | | |
| Operating revenues | $21 | | $265 | | | $(244) | | $49 | $451 | $(402) |
| Fuel, purchased power costs and delivery fees | (10) | | (161) | | | 151 | | (36) | (300) | 264 |
| Operating costs | (6) | | (52) | | | 46 | | (30) | (109) | 79 |
| Depreciation and amortization | — | | — | | | — | | — | — | — |
| Selling, general and administrative expenses | (4) | | (4) | | | — | | (5) | (9) | 4 |
| Operating income (loss) | 1 | | 48 | | | (47) | | (22) | 33 | (55) |
First 8 of 14 rows. The CSV has all of them.
Table 110 after “arising from mark-to-market accounting for positions in the commodity contract portfolio.”
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| Six Months Ended June 30, | | |
| 2018 | 2017 | |
| Commodity contract net asset (liability) at beginning of period | $(96) | | $64 |
| Settlements/termination of positions (a) | 165 | | (107) |
| Changes in fair value of positions in the portfolio (b) | (364) | | 161 |
| Acquired commodity contracts in Merger (c) | (452) | | — |
| Other activity (d) | 80 | | (12) |
| Commodity contract net asset (liability) at end of period | $(667) | | $106 |
Table 111 after “, scheduled by the source of fair value and contractual settlement dates of the underlying positions.”
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| Maturity dates of unrealized commodity contract net liability at June 30, 2018 | | | | | | | |
| Source of fair value | Less than1 year | 1-3 years | | 4-5 years | Excess of5 years | Total | | |
| Prices actively quoted | $(56) | | $(19) | | $(1) | | $— | $(76) |
| Prices provided by other external sources | (175) | | (194) | | — | | — | (369) |
| Prices based on models | (45) | | (150) | | (26) | | (1) | (222) |
| Total | $(276) | | $(363) | | $(27) | | $(1) | $(667) |
| June 30, 2018 | December 31, 2017 | | Change | |
| Cash and cash equivalents (a) | $757 | | $1,487 | | $(730) |
| Vistra Operations Credit Facilities — Revolving Credit Facility | 1,065 | | 834 | | 231 |
| Vistra Operations Credit Facilities — Term Loan C Facility (b) | — | | 7 | | (7) |
| Total available liquidity | $1,822 | | $2,328 | | $(506) |
Table 113 after “to the Financial Statements for additional disclosures regarding debts and noncancellable purchase obligations.”
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| Less ThanOne Year (a) | One toThreeYears | | Three toFiveYears | MoreThan FiveYears | Total | | |
| Debt – principal, including capital leases (b) | $85 | | $386 | | $1,954 | | $9,216 | $11,641 |
| Debt – interest | 339 | | 1,344 | | 1,310 | | 940 | 3,933 |
| Operating leases | 11 | | 32 | | 21 | | 151 | 215 |
| Obligations under commodity purchase and services agreements (c) | 1,011 | | 1,158 | | 448 | | 868 | 3,485 |
| Total contractual cash obligations | $1,446 | | $2,920 | | $3,733 | | $11,175 | $19,274 |
Table 114 after “— This measurement estimates the potential loss in value, due to changes in market conditions, of all underlying generation assets and contr”
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| Three Months Ended June 30, 2018 | Year Ended December 31, 2017 | |
| Month-end average VaR: | $143 | | $92 |
| Month-end high VaR: | $205 | | $140 |
| Month-end low VaR: | $65 | | $62 |
Table 115 after “. Credit collateral includes cash and letters of credit but excludes other credit enhancements such as guarantees or liens on assets.”
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| ExposureBefore CreditCollateral | CreditCollateral | | NetExposure | |
| Investment grade | $284 | | $5 | | $279 |
| Below investment grade or no rating | 34 | | 10 | | 24 |
| Totals | $318 | | $15 | | $303 |
Table 116 after “The following table provides information about our repurchase of equity securities that are registered by us pursuant to Section 12 of the S”
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| Total Number of Shares Purchased | Average Price Paid per Share | Total Number of Shares Purchased as Part of a Publicly Announced Program | | Maximum Dollar Amount of Shares that may yet be Purchased under the Program (b) | |
| June 1 - June 30 (a) | 3,152,073 | $23.81 | | 3,152,073 | | $425,000,000 |
| For the quarter ended June 30, 2018 | 3,152,073 | $23.81 | | 3,152,073 | | $425,000,000 |
| Exhibits | Previously Filed With File Number* | AsExhibit | | |
| (2) | Plan of Acquisition, Reorganization, Arrangement, Liquidation, or Succession | | | |
| 2(a) | 001-38086Form 8-K (filed October 31, 2017) | 2.1 | — | Agreement and Plan of Merger, dated as of October 29, 2017, by and between Vistra Energy Corp. and Dynegy Inc. |
| (4) | Instruments Defining the Rights of Security Holders, Including Indentures | | | |
| 4(a) | 001-33443Form 8-K(filed on October 30, 2014) | 4.8 | — | 2022 Notes Indenture, dated October 27, 2014, among Dynegy Finance II, Inc. and the Trustee |
| 4(b) | 001-33443Form 8-K(filed on April7, 2015) | 4.11 | — | First Supplemental Indenture to the 2022 Notes Indenture, dated April 1, 2015, between Dynegy and the Trustee |
| 4(c) | 001-33443Form 8-K(filed on April 7, 2015) | 4.12 | — | Second Supplemental Indenture to the 2022 Notes Indenture, dated April 1, 2015, among Dynegy, the Subsidiary Guarantors and the Trustee |
| 4(d) | 001-33443Form 8-K(filed on April 8, 2015) | 4.17 | — | Third Supplemental Indenture to the 2022 Notes Indenture, dated April 2, 2015, among Dynegy, the Subsidiary Guarantors and the Trustee |
First 8 of 10 rows. The CSV has all of them.
| Exhibits | Previously Filed With File Number* | AsExhibit | | |
| 4(g) | 001-33443Form 10-K (Year ended December 31, 2016) (filed on February 24, 2017) | 4.24 | — | Sixth Supplemental Indenture to the 2022 Notes Indenture, dated February 2, 2017, among Dynegy, the Subsidiary Guarantors and the Trustee |
| 4(h) | 001-33443Form 10-K (Year ended December 31, 2016) (filed on February 24, 2017) | 4.25 | — | Seventh Supplemental Indenture to the 2022 Notes Indenture, dated February 7, 2017, among Dynegy, the Subsidiary Guarantors and the Trustee |
| 4(i) | 001-38086Form 8-K(filed on April 9, 2018) | 4.19 | — | Eighth Supplemental Indenture to the 2022 Notes Indenture, dated April 9, 2018, among the Company, the Subsidiary Guarantors and the Trustee |
| 4(j) | 001-38086Form 8-K(filed on June 15, 2018) | 4.1 | — | Ninth Supplemental Indenture to the 2022 Notes Indenture, dated June 14, 2018, among the Guaranteeing Subsidiaries, the Company, the Subsidiary Guarantors and the Trustee |
| 4(k) | 001-33443Form 8-K(filed on October 30, 2014) | 4.8 | — | Form of 7.375% Senior Note due 2022 |
| 4(l) | 001-33443Form 8-K(filed on May 21, 2013) | 4.1 | — | 2023 Notes Indenture, dated May 20, 2013, among Dynegy, the Subsidiary Guarantors and the Trustee |
| 4(m) | 001-33443Form 10-K (Year ended December 31, 2013)(filed on February 27, 2014) | 4.3 | — | First Supplemental Indenture to the 2023 Notes Indenture, dated as of December 5, 2014, among Dynegy, the Subsidiary Guarantors and the Trustee |
First 8 of 15 rows. The CSV has all of them.
| Exhibits | Previously Filed With File Number* | AsExhibit | | |
| 4(u) | 001-38086Form 8-K(filed on June 15, 2018) | 4.2 | — | Ninth Supplemental Indenture to the 2023 Notes Indenture, dated June 14, 2018, among the Guaranteeing Subsidiaries, the Company, the Subsidiary Guarantors and the Trustee |
| 4(v) | 001-33443Form 8-K(filed on May 21, 2013) | 4.1 | — | Form of 5.875% Senior Note due 2023 |
| 4(w) | 001-33443Form 8-K(filed on October 30, 2014) | 4.9 | — | 2024 7.625% Notes Indenture, dated October 27, 2014, among Dynegy Finance II, Inc. and the Trustee |
| 4(x) | 001-33443Form 8-K(filed on April 7, 2015) | 4.14 | — | First Supplemental Indenture to the 2024 7.625% Notes Indenture, dated April 1, 2015, between Dynegy and the Trustee |
| 4(y) | 001-33443Form 8-K(filed on April 7, 2015) | 4.15 | — | Second Supplemental Indenture to the 2024 7.625% Notes Indenture, dated April 1, 2015, among Dynegy, the Subsidiary Guarantors and the Trustee |
| 4(z) | 001-33443Form 8-K(filed on April 8, 2015) | 4.21 | — | Third Supplemental Indenture to the 2024 7.625% Notes Indenture, dated April 2, 2015, among Dynegy, the Subsidiary Guarantors and the Trustee |
| 4(aa) | 001-33443Form10-Q (Quarter ended June 30, 2015)(filed on August 7, 2015) | 4.3 | — | Fourth Supplemental Indenture to the 2024 7.625% Notes Indenture, dated May 11, 2015, among Dynegy, the Subsidiary Guarantors and the Trustee |
First 8 of 15 rows. The CSV has all of them.
| Exhibits | Previously Filed With File Number* | AsExhibit | | |
| 4(ii) | 001-33443Form10-K (Year ended December 31, 2016)(filed on February 24, 2017) | 4.41 | — | First Supplemental Indenture to the 2024 8.034% Notes Indenture, dated February 7, 2017, between Dynegy, the Subsidiary Guarantors and the Trustee |
| 4(jj) | 001-38086Form 8-K(filed on April 9, 2018) | 4.43 | — | Second Supplemental Indenture to the 2024 8.034% Notes Indenture, dated April 9, 2018, among the Company, the Subsidiary Guarantors and the Trustee |
| 4(kk) | 001-38086Form 8-K(filed on June 15, 2018) | 4.4 | — | Third Supplemental Indenture to the 2024 8.034% Notes Indenture, dated June 14, 2018, among the Guaranteeing Subsidiaries, the Company, the Subsidiary Guarantors and the Trustee |
| 4(ll) | 001-33443Form of 8-K(filed on February 7, 2017) | 4.2 | — | Form of 8.034% Senior Note due 2024 |
| 4(mm) | 001-33443 Form 8-K (filed on October 11, 2016) | 4.1 | — | 2025 Notes Indenture, dated October 11, 2016, between Dynegy and the Trustee |
| 4(nn) | 001-33443Form10-K (Year ended December 31, 2016)(filed on February 24, 2017) | 4.35 | — | First Supplemental Indenture to the 2025 Notes Indenture, dated February 2, 2017, between Dynegy, the Subsidiary Guarantors and the Trustee |
| 4(oo) | 001-33443Form10-K (Year ended December 31, 2016)(filed on February 24, 2017) | 4.36 | — | Second Supplemental Indenture to the 2025 Notes Indenture, dated February 7, 2017, between Dynegy, the Subsidiary Guarantors and the Trustee |
First 8 of 16 rows. The CSV has all of them.
| Exhibits | Previously Filed With File Number* | AsExhibit | | |
| 4(xx) | 001-33443Form 8-K(filed on June 21, 2016) | 4.3 | — | Purchase Contract Agreement, dated June 21, 2016, between Dynegy and the Trustee |
| 4(yy) | 001-38086Registration Statement on Form 8-A(filed on April 9, 2018) | 4.5 | — | First Supplement to the Purchase Contract Agreement, dated April 9, 2018, between the Company, the Purchase Contract Agent and the Trustee |
| 4(zz) | 001-33443Form 8-K(filed on June 21, 2016) | 4.3 | — | Form of Unit |
| 4(aaa) | 001-33443 Form 8-K(filed on June 21, 2016) | 4.3 | — | Form of Purchase Contract |
| 4(bbb) | 001-33443Form 8-K(filed on June 21, 2016) | 4.1 | — | Amortizing Notes Indenture, dated June 21, 2016, between Dynegy and the Trustee |
| 4(ccc) | 001-33443Form 8-K(filed on June 21, 2016) | 4.2 | — | First Supplemental Indenture to the Amortizing Notes Indenture, dated June 21, 2016, between Dynegy and the Trustee |
| 4(ddd) | 001-38086Registration Statement on Form 8-A(filed on April 9, 2018) | 4.3 | — | Second Supplemental Indenture to the Amortizing Notes Indenture, dated April 9, 2018, between the Company and the Trustee |
First 8 of 15 rows. The CSV has all of them.
| Exhibits | Previously Filed With File Number* | AsExhibit | | |
| 10(b) | 001-38086Form 8-K(filed on June 15, 2018) | 10.2 | — | Collateral Trust Agreement Amendment (amended pursuant to the Seventh Amendment), to the Collateral Trust Agreement, effective pursuant to the Seventh Amendment as of June 14, 2018, among Vistra Operations Company LLC, the other Grantors from time to time party thereto, Railroad Commission of Texas, as First-Out Representative, Credit Suisse AG, Cayman Islands Branch, as Senior Credit Agreement Agent, and Delaware Trust Company, as Collateral Trustee |
| 10(c) | 001-38086Form 8-K(filed on June 15, 2018) | 10.3 | — | Collateral Trust Joinder, dated June 14, 2018, between the Additional Grantors party thereto and Delaware Trust Company, as Collateral Trustee, to the Collateral Trust Agreement, effective pursuant to the Seventh Amendment as of June 14, 2018, among Vistra Operations Company LLC, the other Grantors from time to time party thereto, Railroad Commission of Texas, as First-Out Representative, Credit Suisse AG, Cayman Islands Branch, as Senior Credit Agreement Agent, and Delaware Trust Company, as Collateral Trustee |
| 10(d) | 001-38086Form 8-K(filed on April 27, 2018) | 10.1 | — | Termination of Stockholders' Agreement, dated April 24, 2018, by and among Vistra Energy Corp. and the Oaktree Stockholder party thereto |
| (31) | Rule 13a-14(a) / 15d-14(a) Certifications | | | |
| 31(a) | ** | | — | Certification of Curtis A. Morgan, principal executive officer of Vistra Energy Corp., pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 |
| 31(b) | ** | | — | Certification of J. William Holden, principal financial officer of Vistra Energy Corp., pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 |
| (32) | Section 1350 Certifications | | | |
First 8 of 19 rows. The CSV has all of them.