State of Incorporation | I.R.S. Employer Identification No. | |
Delaware | 20-5653152 | |
601 Travis, Suite 1400 | ||
Houston, Texas | 77002 | |
(Address of principal executive offices) | (Zip Code) |
Large accelerated filer ý | Accelerated filer o | |
Non-accelerated filer o | Smaller reporting company o | |
(Do not check if a smaller reporting company) |
Page | ||
Item 1. | ||
Item 2. | ||
Item 3. | ||
Item 4. | ||
Item 1. | ||
Item 1A. | ||
Item 6. | ||
CAA | Clean Air Act | |
CAISO | The California Independent System Operator | |
CPUC | California Public Utility Commission | |
CT | Combustion Turbine | |
EPA | Environmental Protection Agency | |
ERCOT | Electric Reliability Council of Texas | |
FCA | Forward Capacity Auction | |
FERC | Federal Energy Regulatory Commission | |
FTR | Financial Transmission Rights | |
IMA | In-market Asset Availability | |
IPCB | Illinois Pollution Control Board | |
IPH | IPH, LLC (formerly known as Illinois Power Holdings, LLC) | |
ISO | Independent System Operator | |
ISO-NE | Independent System Operator New England | |
kW | Kilowatt | |
LIBOR | London Interbank Offered Rate | |
MISO | Midcontinent Independent System Operator, Inc. | |
MMBtu | One Million British Thermal Units | |
Moody’s | Moody’s Investors Service Inc. | |
MW | Megawatts | |
MWh | Megawatt Hour | |
NM | Not Meaningful | |
NYISO | New York Independent System Operator | |
PJM | PJM Interconnection, LLC | |
PRIDE | Producing Results through Innovation by Dynegy Employees | |
RGGI | Regional Greenhouse Gas Initiative | |
RMR | Reliability Must Run | |
S&P | Standard & Poor’s Ratings Services | |
SEC | U.S. Securities and Exchange Commission |
September 30, 2016 | December 31, 2015 | |||||||
ASSETS | ||||||||
Current Assets | ||||||||
Cash and cash equivalents | $ | 1,458 | $ | 505 | ||||
Restricted cash | 85 | 39 | ||||||
Accounts receivable, net of allowance for doubtful accounts of $1 and $1, respectively | 374 | 402 | ||||||
Inventory | 447 | 597 | ||||||
Assets from risk management activities | 73 | 100 | ||||||
Intangible assets | 54 | 102 | ||||||
Prepayments and other current assets | 148 | 187 | ||||||
Total Current Assets | 2,639 | 1,932 | ||||||
Property, Plant and Equipment, Net | 7,252 | 8,347 | ||||||
Investment in unconsolidated affiliate | 173 | 190 | ||||||
Restricted cash | 2,000 | — | ||||||
Assets from risk management activities | 40 | 18 | ||||||
Goodwill | 799 | 797 | ||||||
Intangible assets | 28 | 62 | ||||||
Other long-term assets | 93 | 113 | ||||||
Total Assets | $ | 13,024 | $ | 11,459 |
September 30, 2016 | December 31, 2015 | |||||||
LIABILITIES AND EQUITY | ||||||||
Current Liabilities | ||||||||
Accounts payable | $ | 263 | $ | 292 | ||||
Accrued interest | 191 | 74 | ||||||
Intangible liabilities | 33 | 85 | ||||||
Accrued liabilities and other current liabilities | 120 | 125 | ||||||
Liabilities from risk management activities | 92 | 103 | ||||||
Asset retirement obligations | 45 | 50 | ||||||
Debt, current portion, net | 167 | 80 | ||||||
Total Current Liabilities | 911 | 809 | ||||||
Debt, long-term portion, net | 9,356 | 7,129 | ||||||
Liabilities from risk management activities | 69 | 105 | ||||||
Asset retirement obligations | 238 | 230 | ||||||
Deferred income taxes | 36 | 29 | ||||||
Intangible liabilities | 39 | 55 | ||||||
Other long-term liabilities | 168 | 183 | ||||||
Total Liabilities | 10,817 | 8,540 | ||||||
Commitments and Contingencies (Note 14) | ||||||||
Stockholders’ Equity | ||||||||
Preferred stock, $0.01 par value, 20,000,000 shares authorized: | ||||||||
Series A 5.375% mandatory convertible preferred stock, $0.01 par value; 4,000,000 shares issued and outstanding, respectively | 400 | 400 | ||||||
Common stock, $0.01 par value, 420,000,000 shares authorized; 128,619,600 shares issued and 117,293,478 shares outstanding at September 30, 2016; 128,228,477 shares issued and 116,902,355 outstanding at December 31, 2015 | 1 | 1 | ||||||
Additional paid-in capital | 3,541 | 3,187 | ||||||
Accumulated other comprehensive income, net of tax | 15 | 19 | ||||||
Accumulated deficit | (1,746 | ) | (686 | ) | ||||
Total Dynegy Stockholders’ Equity | 2,211 | 2,921 | ||||||
Noncontrolling interest | (4 | ) | (2 | ) | ||||
Total Equity | 2,207 | 2,919 | ||||||
Total Liabilities and Equity | $ | 13,024 | $ | 11,459 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2016 | 2015 | 2016 | 2015 | |||||||||||||
Revenues | $ | 1,184 | $ | 1,232 | $ | 3,211 | $ | 2,854 | ||||||||
Cost of sales, excluding depreciation expense | (660 | ) | (621 | ) | (1,698 | ) | (1,494 | ) | ||||||||
Gross margin | 524 | 611 | 1,513 | 1,360 | ||||||||||||
Operating and maintenance expense | (218 | ) | (219 | ) | (695 | ) | (580 | ) | ||||||||
Depreciation expense | (163 | ) | (174 | ) | (494 | ) | (413 | ) | ||||||||
Impairments | (212 | ) | (74 | ) | (857 | ) | (74 | ) | ||||||||
General and administrative expense | (41 | ) | (29 | ) | (117 | ) | (94 | ) | ||||||||
Acquisition and integration costs | (7 | ) | (8 | ) | (8 | ) | (121 | ) | ||||||||
Other | — | — | (16 | ) | (1 | ) | ||||||||||
Operating income (loss) | (117 | ) | 107 | (674 | ) | 77 | ||||||||||
Earnings (losses) from unconsolidated investment | 4 | (4 | ) | 7 | (1 | ) | ||||||||||
Interest expense | (166 | ) | (145 | ) | (449 | ) | (413 | ) | ||||||||
Other income and expense, net | 29 | 46 | 60 | 45 | ||||||||||||
Income (loss) before income taxes | (250 | ) | 4 | (1,056 | ) | (292 | ) | |||||||||
Income tax benefit (expense) (Note 15) | 1 | (28 | ) | (6 | ) | 473 | ||||||||||
Net income (loss) | (249 | ) | (24 | ) | (1,062 | ) | 181 | |||||||||
Less: Net loss attributable to noncontrolling interest | — | — | (2 | ) | (3 | ) | ||||||||||
Net income (loss) attributable to Dynegy Inc. | (249 | ) | (24 | ) | (1,060 | ) | 184 | |||||||||
Less: Dividends on preferred stock | 5 | 5 | 16 | 16 | ||||||||||||
Net income (loss) attributable to Dynegy Inc. common stockholders | $ | (254 | ) | $ | (29 | ) | $ | (1,076 | ) | $ | 168 | |||||
Earnings (Loss) Per Share (Note 18): | ||||||||||||||||
Basic earnings (loss) per share attributable to Dynegy Inc. common stockholders | $ | (1.81 | ) | $ | (0.23 | ) | $ | (8.54 | ) | $ | 1.33 | |||||
Diluted earnings (loss) per share attributable to Dynegy Inc. common stockholders | $ | (1.81 | ) | $ | (0.23 | ) | $ | (8.54 | ) | $ | 1.31 | |||||
Basic shares outstanding | 140 | 126 | 126 | 126 | ||||||||||||
Diluted shares outstanding | 140 | 126 | 126 | 140 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2016 | 2015 | 2016 | 2015 | |||||||||||||
Net income (loss) | $ | (249 | ) | $ | (24 | ) | $ | (1,062 | ) | $ | 181 | |||||
Other comprehensive income (loss) before reclassifications: | ||||||||||||||||
Actuarial gain and plan amendments (net of tax of zero, $2, zero, and $2 for each respective period) | — | 13 | — | 8 | ||||||||||||
Amounts reclassified from accumulated other comprehensive income: | ||||||||||||||||
Amortization of unrecognized prior service credit (net of tax of zero for each respective period) | (2 | ) | (1 | ) | (4 | ) | (3 | ) | ||||||||
Other comprehensive income (loss), net of tax | (2 | ) | 12 | (4 | ) | 5 | ||||||||||
Comprehensive income (loss) | (251 | ) | (12 | ) | (1,066 | ) | 186 | |||||||||
Less: Comprehensive income (loss) attributable to noncontrolling interest | — | 1 | (2 | ) | (2 | ) | ||||||||||
Total comprehensive income (loss) attributable to Dynegy Inc. | $ | (251 | ) | $ | (13 | ) | $ | (1,064 | ) | $ | 188 |
Nine Months Ended September 30, | ||||||||
2016 | 2015 | |||||||
CASH FLOWS FROM OPERATING ACTIVITIES: | ||||||||
Net income (loss) | $ | (1,062 | ) | $ | 181 | |||
Adjustments to reconcile net income (loss) to net cash flows from operating activities: | ||||||||
Depreciation expense | 494 | 413 | ||||||
Non-cash interest expense | 37 | 25 | ||||||
Amortization of intangibles | 17 | (18 | ) | |||||
Risk management activities | (75 | ) | (117 | ) | ||||
(Earnings) losses from unconsolidated investment | (7 | ) | 1 | |||||
Deferred income taxes | 6 | (473 | ) | |||||
Impairments | 857 | 74 | ||||||
Change in value of common stock warrants | (5 | ) | (43 | ) | ||||
Other | 1 | 38 | ||||||
Changes in working capital: | ||||||||
Accounts receivable, net | 32 | (48 | ) | |||||
Inventory | 153 | (52 | ) | |||||
Prepayments and other current assets | 179 | 95 | ||||||
Accounts payable and accrued liabilities | 104 | 227 | ||||||
Distributions from unconsolidated investment | 1 | 3 | ||||||
Changes in restricted cash | (1 | ) | — | |||||
Changes in non-current assets | (94 | ) | (23 | ) | ||||
Changes in non-current liabilities | 12 | 19 | ||||||
Net cash provided by operating activities | 649 | 302 | ||||||
CASH FLOWS FROM INVESTING ACTIVITIES: | ||||||||
Capital expenditures | (259 | ) | (171 | ) | ||||
Acquisitions, net of cash acquired | — | (6,078 | ) | |||||
Decrease (increase) in restricted cash | (2,045 | ) | 5,148 | |||||
Distributions from unconsolidated affiliate | 14 | 8 | ||||||
Other investing | 10 | (6 | ) | |||||
Net cash used in investing activities | (2,280 | ) | (1,099 | ) | ||||
CASH FLOWS FROM FINANCING ACTIVITIES: | ||||||||
Proceeds from long-term borrowings, net of debt issuance costs | 2,277 | 57 | ||||||
Repayments of borrowings | (21 | ) | (29 | ) | ||||
Proceeds from issuance of equity, net of issuance costs | 359 | (6 | ) | |||||
Preferred stock dividends paid | (16 | ) | (17 | ) | ||||
Interest rate swap settlement payments | (13 | ) | (13 | ) | ||||
Repurchase of common stock | — | (127 | ) | |||||
Other financing | (2 | ) | (4 | ) | ||||
Net cash provided by (used in) financing activities | 2,584 | (139 | ) | |||||
Net increase (decrease) in cash and cash equivalents | 953 | (936 | ) | |||||
Cash and cash equivalents, beginning of period | 505 | 1,870 | ||||||
Cash and cash equivalents, end of period | $ | 1,458 | $ | 934 | ||||
Other non-cash investing and financing activity: | ||||||||
Change in capital expenditures included in accounts payable | $ | (10 | ) | $ | (6 | ) | ||
Non-cash consideration transferred for Acquisitions | $ | — | $ | (105 | ) | |||
Change in capital expenditures pursuant to an equipment financing agreement | $ | 11 | $ | 63 |
(amounts in millions) | EquiPower Acquisition | Duke Midwest Acquisition | Total | |||||||||
Cash | $ | 3,350 | $ | 2,800 | $ | 6,150 | ||||||
Equity instruments (3,460,053 common shares of Dynegy) | 105 | — | 105 | |||||||||
Net working capital adjustment | 206 | (9 | ) | 197 | ||||||||
Fair value of total consideration transferred | $ | 3,661 | $ | 2,791 | $ | 6,452 | ||||||
Cash | $ | 267 | $ | — | $ | 267 | ||||||
Accounts receivable | 49 | 126 | 175 | |||||||||
Inventory | 167 | 105 | 272 | |||||||||
Assets from risk management activities (including current portion of $4 million and $30 million, respectively) | 4 | 33 | 37 | |||||||||
Prepayments and other current assets | 32 | 69 | 101 | |||||||||
Property, plant and equipment | 2,773 | 2,734 | 5,507 | |||||||||
Investment in unconsolidated affiliate | 200 | — | 200 | |||||||||
Intangible assets (including current portion of $67 million and $36 million, respectively) | 111 | 84 | 195 | |||||||||
Other long-term assets | 28 | 35 | 63 | |||||||||
Total assets acquired | 3,631 | 3,186 | 6,817 | |||||||||
Accounts payable | 27 | 96 | 123 | |||||||||
Accrued liabilities and other current liabilities | 21 | 10 | 31 | |||||||||
Debt, current portion | 39 | — | 39 | |||||||||
Liabilities from risk management activities (including current portion of $41 million and zero, respectively) | 57 | 107 | 164 | |||||||||
Asset retirement obligations | 43 | 49 | 92 | |||||||||
Intangible liabilities (including current portion of $24 million and $58 million, respectively) | 73 | 93 | 166 | |||||||||
Deferred income taxes, net | 509 | — | 509 | |||||||||
Other long-term liabilities | — | 40 | 40 | |||||||||
Total liabilities assumed | 769 | 395 | 1,164 | |||||||||
Identifiable net assets acquired | 2,862 | 2,791 | 5,653 | |||||||||
Goodwill | 799 | — | 799 | |||||||||
Net assets acquired | $ | 3,661 | $ | 2,791 | $ | 6,452 |
(amounts in millions) | Nine Months Ended September 30, 2015 | |||
Revenues | $ | 3,844 | ||
Net income | $ | 442 | ||
Net loss attributable to noncontrolling interests | $ | (3 | ) | |
Net income attributable to Dynegy Inc. | $ | 445 |
Contract Type | Quantity | Unit of Measure | Fair Value (1) | ||||||
(dollars and quantities in millions) | Purchases (Sales) | Asset (Liability) | |||||||
Commodity contracts: | |||||||||
Electricity derivatives (2) | (58 | ) | MWh | $ | 25 | ||||
Electricity basis derivatives (3) | (30 | ) | MWh | $ | (8 | ) | |||
Natural gas derivatives (2) | 362 | MMBtu | $ | (64 | ) | ||||
Natural gas basis derivatives | 64 | MMBtu | $ | (22 | ) | ||||
Coal derivatives (4) | — | Metric Ton | $ | (7 | ) | ||||
Emissions derivatives | 5 | Metric Ton | $ | (5 | ) | ||||
Interest rate swaps | 771 | U.S. Dollar | $ | (40 | ) | ||||
Common stock warrants (5) | 16 | Warrant | $ | (2 | ) |
(1) | Includes both asset and liability risk management positions but excludes margin and collateral netting of $73 million. |
(2) | Mainly comprised of swaps, options, and physical forwards. |
(3) | Comprised of FTRs and swaps. |
(4) | Our net position rounds to less than 1 million tons. |
(5) | Each warrant is convertible into one share of Dynegy common stock. |
September 30, 2016 | |||||||||||||||||||
Gross amounts offset in the balance sheet | |||||||||||||||||||
Contract Type | Location on Balance Sheet | Gross Fair Value | Contract Netting | Collateral or Margin Received or Paid | Net Fair Value | ||||||||||||||
(amounts in millions) | |||||||||||||||||||
Derivative assets: | |||||||||||||||||||
Commodity contracts | Assets from risk management activities | $ | 351 | $ | (238 | ) | $ | — | $ | 113 | |||||||||
Total derivative assets | $ | 351 | $ | (238 | ) | $ | — | $ | 113 | ||||||||||
Derivative liabilities: | |||||||||||||||||||
Commodity contracts | Liabilities from risk management activities | $ | (432 | ) | $ | 238 | $ | 73 | $ | (121 | ) | ||||||||
Interest rate contracts | Liabilities from risk management activities | (40 | ) | — | — | (40 | ) | ||||||||||||
Common stock warrants | Other long-term liabilities | (2 | ) | — | — | (2 | ) | ||||||||||||
Total derivative liabilities | $ | (474 | ) | $ | 238 | $ | 73 | $ | (163 | ) | |||||||||
Total derivatives | $ | (123 | ) | $ | — | $ | 73 | $ | (50 | ) |
December 31, 2015 | |||||||||||||||||||
Gross amounts offset in the balance sheet | |||||||||||||||||||
Contract Type | Location on Balance Sheet | Gross Fair Value | Contract Netting | Collateral or Margin Received or Paid | Net Fair Value | ||||||||||||||
(amounts in millions) | |||||||||||||||||||
Derivative assets: | |||||||||||||||||||
Commodity contracts | Assets from risk management activities | $ | 403 | $ | (285 | ) | $ | — | $ | 118 | |||||||||
Total derivative assets | $ | 403 | $ | (285 | ) | $ | — | $ | 118 | ||||||||||
Derivative liabilities: | |||||||||||||||||||
Commodity contracts | Liabilities from risk management activities | $ | (557 | ) | $ | 285 | $ | 106 | $ | (166 | ) | ||||||||
Interest rate contracts | Liabilities from risk management activities | (42 | ) | — | — | (42 | ) | ||||||||||||
Common stock warrants | Other long-term liabilities | (7 | ) | — | — | (7 | ) | ||||||||||||
Total derivative liabilities | $ | (606 | ) | $ | 285 | $ | 106 | $ | (215 | ) | |||||||||
Total derivatives | $ | (203 | ) | $ | — | $ | 106 | $ | (97 | ) |
Location on Balance Sheet | September 30, 2016 | December 31, 2015 | ||||||
(amounts in millions) | ||||||||
Gross collateral posted with counterparties | $ | 119 | $ | 162 | ||||
Less: Collateral netted against risk management liabilities | 73 | 106 | ||||||
Net collateral within Prepayments and other current assets | $ | 46 | $ | 56 |
Derivatives Not Designated as Hedges | Location of Gain (Loss) Recognized in Income on Derivatives | Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
2016 | 2015 | 2016 | 2015 | |||||||||||||||
(amounts in millions) | ||||||||||||||||||
Commodity contracts | Revenues | $ | (27 | ) | $ | 48 | $ | 188 | $ | 120 | ||||||||
Interest rate contracts | Interest expense | $ | 1 | $ | (9 | ) | $ | (11 | ) | $ | (17 | ) | ||||||
Common stock warrants | Other income and (expense), net | $ | 4 | $ | 45 | $ | 5 | $ | 43 |
Fair Value as of September 30, 2016 | ||||||||||||||||
(amounts in millions) | Level 1 | Level 2 | Level 3 | Total | ||||||||||||
Assets: | ||||||||||||||||
Assets from commodity risk management activities: | ||||||||||||||||
Electricity derivatives | $ | — | $ | 248 | $ | 38 | $ | 286 | ||||||||
Natural gas derivatives | — | 51 | 10 | 61 | ||||||||||||
Emissions derivatives | — | 3 | — | 3 | ||||||||||||
Coal derivatives | — | — | 1 | 1 | ||||||||||||
Total assets from commodity risk management activities | $ | — | $ | 302 | $ | 49 | $ | 351 | ||||||||
Liabilities: | . | |||||||||||||||
Liabilities from commodity risk management activities: | ||||||||||||||||
Electricity derivatives | $ | — | $ | (221 | ) | $ | (48 | ) | $ | (269 | ) | |||||
Natural gas derivatives | — | (123 | ) | (24 | ) | (147 | ) | |||||||||
Emissions derivatives | — | (8 | ) | — | (8 | ) | ||||||||||
Coal derivatives | — | (8 | ) | — | (8 | ) | ||||||||||
Total liabilities from commodity risk management activities | — | (360 | ) | (72 | ) | (432 | ) | |||||||||
Liabilities from interest rate contracts | — | (40 | ) | — | (40 | ) | ||||||||||
Liabilities from outstanding common stock warrants | (2 | ) | — | — | (2 | ) | ||||||||||
Total liabilities | $ | (2 | ) | $ | (400 | ) | $ | (72 | ) | $ | (474 | ) |
Fair Value as of December 31, 2015 | ||||||||||||||||
(amounts in millions) | Level 1 | Level 2 | Level 3 | Total | ||||||||||||
Assets: | ||||||||||||||||
Assets from commodity risk management activities: | ||||||||||||||||
Electricity derivatives | $ | — | $ | 308 | $ | 40 | $ | 348 | ||||||||
Natural gas derivatives | — | 40 | 2 | 42 | ||||||||||||
Coal derivatives | — | 10 | 3 | 13 | ||||||||||||
Total assets from commodity risk management activities | $ | — | $ | 358 | $ | 45 | $ | 403 | ||||||||
Liabilities: | ||||||||||||||||
Liabilities from commodity risk management activities: | ||||||||||||||||
Electricity derivatives | $ | — | $ | (267 | ) | $ | (58 | ) | $ | (325 | ) | |||||
Natural gas derivatives | — | (158 | ) | (34 | ) | (192 | ) | |||||||||
Diesel derivatives | — | (4 | ) | — | (4 | ) | ||||||||||
Coal derivatives | — | (35 | ) | (1 | ) | (36 | ) | |||||||||
Total liabilities from commodity risk management activities | — | (464 | ) | (93 | ) | (557 | ) | |||||||||
Liabilities from interest rate contracts | — | (42 | ) | — | (42 | ) | ||||||||||
Liabilities from outstanding common stock warrants | (7 | ) | — | — | (7 | ) | ||||||||||
Total liabilities | $ | (7 | ) | $ | (506 | ) | $ | (93 | ) | $ | (606 | ) |
Transaction Type | Quantity | Unit of Measure | Net Fair Value | Valuation Technique | Significant Unobservable Input | Significant Unobservable Input Range | |||||||||
(dollars in millions) | |||||||||||||||
Electricity derivatives: | |||||||||||||||
Forward contracts—power (1) | (10 | ) | Million MWh | $ | (7 | ) | Basis spread + liquid location | Basis spread | $5.00 - $7.00 | ||||||
FTRs | (26 | ) | Million MWh | $ | (3 | ) | Historical congestion | Forward price | $0 - $6.00 | ||||||
Natural gas derivatives (1) | 78 | Million MMBtu | $ | (14 | ) | Illiquid location fixed price | Forward price | $1.05 - $1.35 | |||||||
Coal derivatives (1) | — | Thousand Tons | $ | 1 | Illiquid location fixed price | Forward price | $6.10 - $7.45 |
(1) | Represents forward financial and physical transactions at illiquid pricing locations. |
Three Months Ended September 30, 2016 | ||||||||||||||||
(amounts in millions) | Electricity Derivatives | Natural Gas Derivatives | Coal Derivatives | Total | ||||||||||||
Balance at June 30, 2016 | $ | (24 | ) | $ | (15 | ) | $ | 1 | $ | (38 | ) | |||||
Total gains (losses) included in earnings | 9 | (4 | ) | 1 | 6 | |||||||||||
Settlements (1) | 5 | 5 | (1 | ) | 9 | |||||||||||
Balance at September 30, 2016 | $ | (10 | ) | $ | (14 | ) | $ | 1 | $ | (23 | ) | |||||
Unrealized gains (losses) relating to instruments held as of September 30, 2016 | $ | 9 | $ | (4 | ) | $ | 1 | $ | 6 |
Nine Months Ended September 30, 2016 | ||||||||||||||||
(amounts in millions) | Electricity Derivatives | Natural Gas Derivatives | Coal Derivatives | Total | ||||||||||||
Balance at December 31, 2015 | $ | (18 | ) | $ | (32 | ) | $ | 2 | $ | (48 | ) | |||||
Total gains included in earnings | 4 | — | — | 4 | ||||||||||||
Settlements (1) | 4 | 18 | (1 | ) | 21 | |||||||||||
Balance at September 30, 2016 | $ | (10 | ) | $ | (14 | ) | $ | 1 | $ | (23 | ) | |||||
Unrealized gains relating to instruments held as of September 30, 2016 | $ | 4 | $ | — | $ | — | $ | 4 |
Three Months Ended September 30, 2015 | ||||||||||||||||||||
(amounts in millions) | Electricity Derivatives | Natural Gas Derivatives | Heat Rate Derivatives | Coal Derivatives | Total | |||||||||||||||
Balance at June 30, 2015 | $ | (54 | ) | $ | (11 | ) | $ | (7 | ) | $ | 4 | $ | (68 | ) | ||||||
Total gains (losses) included in earnings | 2 | (3 | ) | — | — | (1 | ) | |||||||||||||
Settlements (1) | 3 | — | 5 | (1 | ) | 7 | ||||||||||||||
Balance at September 30, 2015 | $ | (49 | ) | $ | (14 | ) | $ | (2 | ) | $ | 3 | $ | (62 | ) | ||||||
Unrealized gains (losses) relating to instruments held as of September 30, 2015 | $ | 2 | $ | (3 | ) | $ | — | $ | — | $ | (1 | ) |
Nine Months Ended September 30, 2015 | ||||||||||||||||||||
(amounts in millions) | Electricity Derivatives | Natural Gas Derivatives | Heat Rate Derivatives | Coal Derivatives | Total | |||||||||||||||
Balance at December 31, 2014 | $ | (4 | ) | $ | — | $ | — | $ | — | $ | (4 | ) | ||||||||
Acquisitions | (54 | ) | (14 | ) | (9 | ) | 5 | (72 | ) | |||||||||||
Total gains included in earnings | 7 | — | — | — | 7 | |||||||||||||||
Settlements (1) | 2 | — | 7 | (2 | ) | 7 | ||||||||||||||
Balance at September 30, 2015 | $ | (49 | ) | $ | (14 | ) | $ | (2 | ) | $ | 3 | $ | (62 | ) | ||||||
Unrealized gains relating to instruments held as of September 30, 2015 | $ | 7 | $ | — | $ | — | $ | — | $ | 7 |
(1) | For purposes of these tables, we define settlements as the beginning of period fair value of contracts that settled during the period. |
September 30, 2016 | December 31, 2015 | |||||||||||||||||
(amounts in millions) | Fair Value Hierarchy | Carrying Amount | Fair Value | Carrying Amount | Fair Value | |||||||||||||
Dynegy Inc.: | ||||||||||||||||||
6.75% Senior Notes, due 2019 (1) | Level 2 | $ | (2,081 | ) | $ | (2,168 | ) | $ | (2,077 | ) | $ | (1,985 | ) | |||||
Tranche B-2 Term Loan, due 2020 (1) | Level 2 | $ | (762 | ) | $ | (779 | ) | $ | (766 | ) | $ | (754 | ) | |||||
7.375% Senior Notes, due 2022 (1) | Level 2 | $ | (1,731 | ) | $ | (1,724 | ) | $ | (1,729 | ) | $ | (1,531 | ) | |||||
5.875% Senior Notes, due 2023 (1) | Level 2 | $ | (492 | ) | $ | (450 | ) | $ | (491 | ) | $ | (404 | ) | |||||
7.625% Senior Notes, due 2024 (1) | Level 2 | $ | (1,236 | ) | $ | (1,225 | ) | $ | (1,235 | ) | $ | (1,078 | ) | |||||
7.00% Amortizing Notes, due 2019 (TEUs) (1) | Level 2 | $ | (84 | ) | $ | (88 | ) | $ | — | $ | — | |||||||
Forward capacity agreement (1) | Level 3 | $ | (203 | ) | $ | (203 | ) | $ | — | $ | — | |||||||
Inventory financing agreements | Level 3 | $ | (136 | ) | $ | (135 | ) | $ | (136 | ) | $ | (137 | ) | |||||
Equipment financing agreements (1) | Level 3 | $ | (75 | ) | $ | (75 | ) | $ | (61 | ) | $ | (61 | ) | |||||
Interest rate derivatives | Level 2 | $ | (40 | ) | $ | (40 | ) | $ | (42 | ) | $ | (42 | ) | |||||
Commodity-based derivative contracts (2) | Various | $ | (81 | ) | $ | (81 | ) | $ | (154 | ) | $ | (154 | ) | |||||
Common stock warrants | Level 1 | $ | (2 | ) | $ | (2 | ) | $ | (7 | ) | $ | (7 | ) | |||||
Dynegy Finance IV, Inc.: | ||||||||||||||||||
Tranche C Term Loan, due 2023 (1) | Level 2 | $ | (1,995 | ) | $ | (2,015 | ) | $ | — | $ | — | |||||||
Genco: | ||||||||||||||||||
7.00% Senior Notes Series H, due 2018 (1) | Level 2 | $ | (284 | ) | $ | (119 | ) | $ | (276 | ) | $ | (204 | ) | |||||
6.30% Senior Notes Series I, due 2020 (1) | Level 2 | $ | (218 | ) | $ | (99 | ) | $ | (213 | ) | $ | (148 | ) | |||||
7.95% Senior Notes Series F, due 2032 (1) | Level 2 | $ | (226 | ) | $ | (107 | ) | $ | (225 | ) | $ | (162 | ) |
(1) | Carrying amounts include unamortized discounts and debt issuance costs. Please read Note 13—Debt for further discussion. |
(2) | Carrying amounts exclude $73 million and $106 million of cash posted as collateral, as of September 30, 2016 and December 31, 2015, respectively. |
Nine Months Ended September 30, | ||||||||
(amounts in millions) | 2016 | 2015 | ||||||
Beginning of period | $ | 19 | $ | 20 | ||||
Other comprehensive income (loss) before reclassifications: | ||||||||
Actuarial gain and plan amendments (net of tax of zero and $2, respectively) | — | 7 | ||||||
Amounts reclassified from accumulated other comprehensive income: | ||||||||
Amortization of unrecognized prior service credit (net of tax of zero and zero, respectively) (1) | (4 | ) | (3 | ) | ||||
Net current period other comprehensive income (loss), net of tax | (4 | ) | 4 | |||||
End of period | $ | 15 | $ | 24 |
(1) | Amounts are associated with our defined benefit pension and other post-employment benefit plans and are included in the computation of net periodic pension cost (gain). Please read Note 16—Pension and Other Post-Employment Benefit Plans for further discussion. |
(amounts in millions) | September 30, 2016 | December 31, 2015 | ||||||
Materials and supplies | $ | 183 | $ | 178 | ||||
Coal (1) | 233 | 350 | ||||||
Fuel oil (1) | 17 | 17 | ||||||
Emissions allowances (2) | 14 | 51 | ||||||
Other | — | 1 | ||||||
Total | $ | 447 | $ | 597 |
(1) | At September 30, 2016, approximately $47 million and $16 million of the coal and fuel oil inventory, respectively, are part of an inventory financing agreement. At December 31, 2015, approximately $44 million and $16 million of the coal and fuel oil inventory, respectively, were part of an inventory financing agreement. Please read Note 13—Debt—Brayton Point Inventory Financing for further discussion. |
(2) | At September 30, 2016 and December 31, 2015, a portion of this inventory was held as collateral by one of our counterparties as part of an inventory financing agreement. Please read Note 13—Debt—Emissions Repurchase Agreements for further discussion. |
(amounts in millions) | September 30, 2016 | December 31, 2015 | ||||||
Power generation | $ | 7,481 | $ | 8,178 | ||||
Buildings and improvements | 938 | 956 | ||||||
Office and other equipment | 103 | 101 | ||||||
Property, plant and equipment | 8,522 | 9,235 | ||||||
Accumulated depreciation | (1,270 | ) | (888 | ) | ||||
Property, plant and equipment, net | $ | 7,252 | $ | 8,347 |
September 30, 2016 | |||||||||||||||||||
(dollars in millions) | Ownership Interest | Property, Plant and Equipment | Accumulated Depreciation | Construction Work in Progress | Total | ||||||||||||||
Miami Fort | 64.0 | % | $ | 206 | $ | (33 | ) | $ | 3 | $ | 176 | ||||||||
Stuart (1) | 39.0 | % | $ | — | $ | — | $ | — | $ | — | |||||||||
Conesville (1) | 40.0 | % | $ | 61 | $ | (2 | ) | $ | 5 | $ | 64 | ||||||||
Zimmer | 46.5 | % | $ | 116 | $ | (21 | ) | $ | 4 | $ | 99 | ||||||||
Killen (1) | 33.0 | % | $ | 18 | $ | (1 | ) | $ | 2 | $ | 19 |
December 31, 2015 | |||||||||||||||||||
(dollars in millions) | Ownership Interest | Property, Plant and Equipment | Accumulated Depreciation | Construction Work in Progress | Total | ||||||||||||||
Miami Fort | 64.0 | % | $ | 207 | $ | (16 | ) | $ | 3 | $ | 194 | ||||||||
Stuart (1) | 39.0 | % | $ | 32 | $ | (4 | ) | $ | 20 | $ | 48 | ||||||||
Conesville (1) | 40.0 | % | $ | 61 | $ | (2 | ) | $ | 4 | $ | 63 | ||||||||
Zimmer | 46.5 | % | $ | 99 | $ | (10 | ) | $ | 11 | $ | 100 | ||||||||
Killen (1) | 33.0 | % | $ | 17 | $ | (1 | ) | $ | 2 | $ | 18 |
(1) | Facilities not operated by Dynegy. |
September 30, 2016 | December 31, 2015 | |||||||||||||||||||||||
(amounts in millions) | Gross Carrying Amount | Accumulated Amortization | Net Carrying Amount | Gross Carrying Amount | Accumulated Amortization | Net Carrying Amount | ||||||||||||||||||
Intangible Assets: | ||||||||||||||||||||||||
Electricity contracts | $ | 260 | $ | (187 | ) | $ | 73 | $ | 260 | $ | (126 | ) | $ | 134 | ||||||||||
Gas transport contracts | 46 | (37 | ) | 9 | 46 | (16 | ) | 30 | ||||||||||||||||
Total intangible assets | $ | 306 | $ | (224 | ) | $ | 82 | $ | 306 | $ | (142 | ) | $ | 164 | ||||||||||
Intangible Liabilities: | ||||||||||||||||||||||||
Electricity contracts | $ | (28 | ) | $ | 26 | $ | (2 | ) | $ | (30 | ) | $ | 19 | $ | (11 | ) | ||||||||
Coal contracts | (93 | ) | 76 | (17 | ) | (134 | ) | 82 | (52 | ) | ||||||||||||||
Coal transport contracts | (104 | ) | 85 | (19 | ) | (104 | ) | 64 | (40 | ) | ||||||||||||||
Gas transport contracts | (41 | ) | 7 | (34 | ) | (64 | ) | 27 | (37 | ) | ||||||||||||||
Total intangible liabilities | $ | (266 | ) | $ | 194 | $ | (72 | ) | $ | (332 | ) | $ | 192 | $ | (140 | ) | ||||||||
Intangible assets and liabilities, net | $ | 40 | $ | (30 | ) | $ | 10 | $ | (26 | ) | $ | 50 | $ | 24 |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
(amounts in millions) | 2016 | 2015 | 2016 | 2015 | ||||||||||||
Electricity contracts, net (1) | $ | 19 | $ | 21 | $ | 52 | $ | 53 | ||||||||
Coal contracts, net (2) | (9 | ) | (19 | ) | (32 | ) | (42 | ) | ||||||||
Coal transport contracts, net (2) | (7 | ) | (9 | ) | (21 | ) | (24 | ) | ||||||||
Gas transport contracts, net (2) | 1 | (2 | ) | 18 | (5 | ) | ||||||||||
Total | $ | 4 | $ | (9 | ) | $ | 17 | $ | (18 | ) |
(1) | The amortization of these contracts is recognized in Revenues in our unaudited consolidated statements of operations. |
(2) | The amortization of these contracts is recognized in Cost of sales in our unaudited consolidated statements of operations. |
(in millions, except price per TEU) | SPC | Amortizing Note | Total | |||||||||
Price per TEU | $ | 81 | $ | 19 | $ | 100 | ||||||
Gross proceeds | $ | 373 | $ | 87 | $ | 460 | ||||||
Less: Issuance costs | (14 | ) | (3 | ) | (17 | ) | ||||||
Net proceeds | $ | 359 | $ | 84 | $ | 443 |
VWAP of Dynegy Common Stock | Common Shares Issued | |
Equal to or greater than $19.92 | 5.0201 shares (minimum settlement rate) | |
Less than $19.92, but greater than $16.13 | $100 divided by VWAP | |
Less than or equal to $16.13 | 6.1996 shares (maximum settlement rate) |
(amounts in millions) | September 30, 2016 | December 31, 2015 | ||||||
Secured Obligations: | ||||||||
Dynegy Inc.: | ||||||||
Tranche B-2 Term Loan, due 2020 | $ | 774 | $ | 780 | ||||
Revolving Facility | — | — | ||||||
Forward Capacity Agreement | 219 | — | ||||||
Inventory Financing Agreements | 136 | 136 | ||||||
Dynegy Finance IV, Inc.: | ||||||||
Tranche C Term Loan, due 2023 (1) | 2,000 | — | ||||||
Subtotal secured obligations | 3,129 | 916 | ||||||
Unsecured Obligations: | ||||||||
Dynegy Inc.: | ||||||||
7.00% Amortizing Notes, due 2019 (TEUs) | 87 | — | ||||||
6.75% Senior Notes, due 2019 | 2,100 | 2,100 | ||||||
7.375% Senior Notes, due 2022 | 1,750 | 1,750 | ||||||
5.875% Senior Notes, due 2023 | 500 | 500 | ||||||
7.625% Senior Notes, due 2024 | 1,250 | 1,250 | ||||||
Equipment Financing Agreements | 100 | 75 | ||||||
Subtotal unsecured obligations | 5,787 | 5,675 | ||||||
Total Dynegy Inc. and Dynegy Finance IV, Inc. | 8,916 | 6,591 | ||||||
Genco Unsecured Obligations: | ||||||||
7.00% Senior Notes Series H, due 2018 | 300 | 300 | ||||||
6.30% Senior Notes Series I, due 2020 | 250 | 250 | ||||||
7.95% Senior Notes Series F, due 2032 | 275 | 275 | ||||||
Total Genco (2) | 825 | 825 | ||||||
Total debt obligations | 9,741 | 7,416 | ||||||
Unamortized debt discounts and issuance costs (3) | (218 | ) | (207 | ) | ||||
9,523 | 7,209 | |||||||
Less: Current maturities, including unamortized debt discounts and issuance costs, net | 167 | 80 | ||||||
Total Long-term debt | $ | 9,356 | $ | 7,129 |
(1) | At September 30, 2016, the Tranche C Term Loan, under the Finance IV Credit Agreement, was secured by first-priority liens on amounts in the applicable escrow account which was classified as long-term Restricted cash in our unaudited consolidated balance sheet. Upon the closing of the Delta Transaction, this debt obligation will become Dynegy Inc.’s secured obligation. Please read Finance IV Credit Agreement below for further discussion. |
(2) | On October 14, 2016, we entered into a restructuring support agreement (“RSA”) with Genco and an ad hoc group of Genco bondholders (the “Ad Hoc Group”) to restructure the Genco Senior Notes. See Note 21—Subsequent Events—Genco Debt Restructure for further discussion. |
(3) | Includes $97 million and $111 million of unamortized debt discounts as of September 30, 2016 and December 31, 2015, respectively, relating to the Genco unsecured obligations. |
Required Ratio | ||
Restricted payment interest coverage ratio (1) | ≥1.75 | |
Additional indebtedness interest coverage ratio (2) | ≥2.50 | |
Additional indebtedness debt-to-capital ratio (2) | ≤60% |
(1) | As of the date of a restricted payment, as defined, the minimum ratio must have been achieved for the most recently ended four fiscal quarters and projected by management to be achieved for each of the subsequent four six-month periods. |
(2) | Ratios must be computed on a pro forma basis considering the additional indebtedness to be incurred and the related interest expense. Other borrowings from external, third-party sources are included in the definition of indebtedness and are subject to these incurrence tests. |
Pension Benefits | Other Benefits | |||||||||||||||
Three Months Ended September 30, | ||||||||||||||||
(amounts in millions) | 2016 | 2015 | 2016 | 2015 | ||||||||||||
Service cost benefits earned during period | $ | 4 | $ | 4 | $ | — | $ | 1 | ||||||||
Interest cost on projected benefit obligation | 5 | 4 | 1 | 1 | ||||||||||||
Expected return on plan assets | (5 | ) | (6 | ) | (1 | ) | (1 | ) | ||||||||
Amortization of prior service credit | (1 | ) | — | (1 | ) | (1 | ) | |||||||||
Net periodic benefit cost (gain) | $ | 3 | $ | 2 | $ | (1 | ) | $ | — |
Pension Benefits | Other Benefits | |||||||||||||||
Nine Months Ended September 30, | ||||||||||||||||
(amounts in millions) | 2016 | 2015 | 2016 | 2015 | ||||||||||||
Service cost benefits earned during period | $ | 12 | $ | 11 | $ | — | $ | 1 | ||||||||
Interest cost on projected benefit obligation | 15 | 13 | 3 | 3 | ||||||||||||
Expected return on plan assets | (17 | ) | (17 | ) | (3 | ) | (3 | ) | ||||||||
Amortization of prior service credit | (1 | ) | (1 | ) | (3 | ) | (2 | ) | ||||||||
Net periodic benefit cost (gain) | $ | 9 | $ | 6 | $ | (3 | ) | $ | (1 | ) |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||
(in millions, except per share amounts) | 2016 | 2015 | 2016 | 2015 | ||||||||||||
Income (loss) from continuing operations | $ | (249 | ) | $ | (24 | ) | $ | (1,062 | ) | $ | 181 | |||||
Less: Net loss attributable to noncontrolling interest | — | — | (2 | ) | (3 | ) | ||||||||||
Income (loss) from continuing operations attributable to Dynegy Inc. | (249 | ) | (24 | ) | (1,060 | ) | 184 | |||||||||
Less: Dividends on preferred stock | 5 | 5 | 16 | 16 | ||||||||||||
Income (loss) from continuing operations attributable to Dynegy Inc. common stockholders for basic earnings (loss) per share | (254 | ) | (29 | ) | (1,076 | ) | 168 | |||||||||
Add: Dividends on preferred stock (1) | — | — | — | 16 | ||||||||||||
Adjusted income (loss) from continuing operations attributable to Dynegy Inc. common stockholders for diluted earnings (loss) per share | $ | (254 | ) | $ | (29 | ) | $ | (1,076 | ) | $ | 184 | |||||
Basic weighted-average shares (2) | 140 | 126 | 126 | 126 | ||||||||||||
Effect of dilutive securities (3) | — | — | — | 14 | ||||||||||||
Diluted weighted-average shares | 140 | 126 | 126 | 140 | ||||||||||||
Earnings (loss) per share from continuing operations attributable to Dynegy Inc. common stockholders: | ||||||||||||||||
Basic (2) | $ | (1.81 | ) | $ | (0.23 | ) | $ | (8.54 | ) | $ | 1.33 | |||||
Diluted (3) | $ | (1.81 | ) | $ | (0.23 | ) | $ | (8.54 | ) | $ | 1.31 |
(1) | Excluded for the three and nine months ended September 30, 2016 and the three months ended September 30, 2015 due to a net loss from continuing operations for the respective periods. |
(2) | For the three and nine months ended September 30, 2016, the TEUs are assumed to be outstanding at the minimum settlement amount, or 23,092,460 shares, for weighted-average shares for basic earnings (loss) per share. Please read Note 12—Tangible Equity Units for further discussion. |
(3) | Entities with a net loss from continuing operations are prohibited from including potential common shares in the computation of diluted per share amounts. Accordingly, we have used the basic shares outstanding amount to calculate |
Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||
(in millions of shares) | 2016 | 2015 | 2016 | 2015 | ||||||||
Stock options | 2.8 | 1.8 | 2.8 | — | ||||||||
Restricted stock units | 1.3 | 1.5 | 1.3 | — | ||||||||
Performance stock units | 1.2 | 0.6 | 1.2 | — | ||||||||
Warrants | 15.6 | 15.6 | 15.6 | 15.6 | ||||||||
Series A 5.375% mandatory convertible preferred stock | 12.9 | 12.9 | 12.9 | — | ||||||||
Prepaid stock purchase contract (TEUs) | 5.4 | — | 5.4 | — | ||||||||
Total | 39.2 | 32.4 | 39.2 | 15.6 |
Parent | Guarantor Subsidiaries | Non-Guarantor Subsidiaries | Eliminations | Consolidated | |||||||||||||||
Current Assets | |||||||||||||||||||
Cash and cash equivalents | $ | 1,248 | $ | 69 | $ | 141 | $ | — | $ | 1,458 | |||||||||
Restricted cash | — | — | 85 | — | 85 | ||||||||||||||
Accounts receivable, net | 115 | 2,383 | 135 | (2,259 | ) | 374 | |||||||||||||
Inventory | — | 234 | 213 | — | 447 | ||||||||||||||
Other current assets | 11 | 235 | 31 | (2 | ) | 275 | |||||||||||||
Total Current Assets | 1,374 | 2,921 | 605 | (2,261 | ) | 2,639 | |||||||||||||
Property, plant and equipment, net | — | 6,901 | 351 | — | 7,252 | ||||||||||||||
Investment in affiliates | 12,335 | 173 | — | (12,335 | ) | 173 | |||||||||||||
Restricted cash | — | — | 2,000 | — | 2,000 | ||||||||||||||
Goodwill | — | 799 | — | — | 799 | ||||||||||||||
Other long-term assets | 4 | 112 | 45 | — | 161 | ||||||||||||||
Intercompany note receivable | — | — | 3 | (3 | ) | — | |||||||||||||
Total Assets | $ | 13,713 | $ | 10,906 | $ | 3,004 | $ | (14,599 | ) | $ | 13,024 | ||||||||
Current Liabilities | |||||||||||||||||||
Accounts payable | $ | 1,745 | $ | 226 | $ | 551 | $ | (2,259 | ) | $ | 263 | ||||||||
Other current liabilities | 224 | 293 | 133 | (2 | ) | 648 | |||||||||||||
Total Current Liabilities | 1,969 | 519 | 684 | (2,261 | ) | 911 | |||||||||||||
Debt, long-term portion, net | 6,355 | 288 | 2,713 | — | 9,356 | ||||||||||||||
Intercompany note payable | 3,042 | — | — | (3,042 | ) | — | |||||||||||||
Other long-term liabilities | 136 | 287 | 130 | (3 | ) | 550 | |||||||||||||
Total Liabilities | 11,502 | 1,094 | 3,527 | (5,306 | ) | 10,817 | |||||||||||||
Stockholders’ Equity | |||||||||||||||||||
Dynegy Stockholders’ Equity | 2,211 | 12,854 | (519 | ) | (12,335 | ) | 2,211 | ||||||||||||
Intercompany note receivable | — | (3,042 | ) | — | 3,042 | — | |||||||||||||
Total Dynegy Stockholders’ Equity | 2,211 | 9,812 | (519 | ) | (9,293 | ) | 2,211 | ||||||||||||
Noncontrolling interest | — | — | (4 | ) | — | (4 | ) | ||||||||||||
Total Equity | 2,211 | 9,812 | (523 | ) | (9,293 | ) | 2,207 | ||||||||||||
Total Liabilities and Equity | $ | 13,713 | $ | 10,906 | $ | 3,004 | $ | (14,599 | ) | $ | 13,024 |
Parent | Guarantor Subsidiaries | Non-Guarantor Subsidiaries | Eliminations | Consolidated | |||||||||||||||
Current Assets | |||||||||||||||||||
Cash and cash equivalents | $ | 327 | $ | 94 | $ | 84 | $ | — | $ | 505 | |||||||||
Restricted cash | — | — | 39 | — | 39 | ||||||||||||||
Accounts receivable, net | 499 | 1,503 | 130 | (1,730 | ) | 402 | |||||||||||||
Inventory | — | 331 | 266 | — | 597 | ||||||||||||||
Other current assets | 13 | 335 | 55 | (14 | ) | 389 | |||||||||||||
Total Current Assets | 839 | 2,263 | 574 | (1,744 | ) | 1,932 | |||||||||||||
Property, plant and equipment, net | — | 7,813 | 534 | — | 8,347 | ||||||||||||||
Investment in affiliates | 13,017 | 190 | — | (13,017 | ) | 190 | |||||||||||||
Other long-term assets | 10 | 133 | 50 | — | 193 | ||||||||||||||
Goodwill | — | 797 | — | — | 797 | ||||||||||||||
Intercompany note receivable | 17 | — | — | (17 | ) | — | |||||||||||||
Total Assets | $ | 13,883 | $ | 11,196 | $ | 1,158 | $ | (14,778 | ) | $ | 11,459 | ||||||||
Current Liabilities | |||||||||||||||||||
Accounts payable | $ | 1,388 | $ | 238 | $ | 396 | $ | (1,730 | ) | $ | 292 | ||||||||
Other current liabilities | 92 | 277 | 162 | (14 | ) | 517 | |||||||||||||
Total Current Liabilities | 1,480 | 515 | 558 | (1,744 | ) | 809 | |||||||||||||
Debt, long-term portion, net | 6,293 | 122 | 714 | — | 7,129 | ||||||||||||||
Intercompany note payable | 3,042 | — | 17 | (3,059 | ) | — | |||||||||||||
Other long-term liabilities | 147 | 317 | 138 | — | 602 | ||||||||||||||
Total Liabilities | 10,962 | 954 | 1,427 | (4,803 | ) | 8,540 | |||||||||||||
Stockholders’ Equity | |||||||||||||||||||
Dynegy Stockholders’ Equity | 2,921 | 13,284 | (267 | ) | (13,017 | ) | 2,921 | ||||||||||||
Intercompany note receivable | — | (3,042 | ) | — | 3,042 | — | |||||||||||||
Total Dynegy Stockholders’ Equity | 2,921 | 10,242 | (267 | ) | (9,975 | ) | 2,921 | ||||||||||||
Noncontrolling interest | — | — | (2 | ) | — | (2 | ) | ||||||||||||
Total Equity | 2,921 | 10,242 | (269 | ) | (9,975 | ) | 2,919 | ||||||||||||
Total Liabilities and Equity | $ | 13,883 | $ | 11,196 | $ | 1,158 | $ | (14,778 | ) | $ | 11,459 |
Parent | Guarantor Subsidiaries | Non-Guarantor Subsidiaries | Eliminations | Consolidated | |||||||||||||||
Revenues | $ | — | $ | 919 | $ | 267 | $ | (2 | ) | $ | 1,184 | ||||||||
Cost of sales, excluding depreciation expense | — | (501 | ) | (161 | ) | 2 | (660 | ) | |||||||||||
Gross margin | — | 418 | 106 | — | 524 | ||||||||||||||
Operating and maintenance expense | — | (152 | ) | (66 | ) | — | (218 | ) | |||||||||||
Depreciation expense | — | (147 | ) | (16 | ) | — | (163 | ) | |||||||||||
Impairments | — | (64 | ) | (148 | ) | — | (212 | ) | |||||||||||
General and administrative expense | (2 | ) | (28 | ) | (11 | ) | — | (41 | ) | ||||||||||
Acquisition and integration costs | (5 | ) | — | (2 | ) | — | (7 | ) | |||||||||||
Other | — | (1 | ) | 1 | — | — | |||||||||||||
Operating income (loss) | (7 | ) | 26 | (136 | ) | — | (117 | ) | |||||||||||
Earnings from unconsolidated investment | — | 4 | — | — | 4 | ||||||||||||||
Equity in losses from investments in affiliates | (153 | ) | — | — | 153 | — | |||||||||||||
Interest expense | (112 | ) | (5 | ) | (50 | ) | 1 | (166 | ) | ||||||||||
Other income and expense, net | 23 | 5 | 2 | (1 | ) | 29 | |||||||||||||
Income (loss) before income taxes | (249 | ) | 30 | (184 | ) | 153 | (250 | ) | |||||||||||
Income tax benefit (expense) | — | 37 | (36 | ) | — | 1 | |||||||||||||
Net income (loss) | (249 | ) | 67 | (220 | ) | 153 | (249 | ) | |||||||||||
Less: Net loss attributable to noncontrolling interest | — | — | — | — | — | ||||||||||||||
Net income (loss) attributable to Dynegy Inc. | $ | (249 | ) | $ | 67 | $ | (220 | ) | $ | 153 | $ | (249 | ) |
Parent | Guarantor Subsidiaries | Non-Guarantor Subsidiaries | Eliminations | Consolidated | |||||||||||||||
Revenues | $ | — | $ | 2,517 | $ | 696 | $ | (2 | ) | $ | 3,211 | ||||||||
Cost of sales, excluding depreciation expense | — | (1,295 | ) | (405 | ) | 2 | (1,698 | ) | |||||||||||
Gross margin | — | 1,222 | 291 | — | 1,513 | ||||||||||||||
Operating and maintenance expense | — | (503 | ) | (192 | ) | — | (695 | ) | |||||||||||
Depreciation expense | — | (433 | ) | (61 | ) | — | (494 | ) | |||||||||||
Impairments | — | (709 | ) | (148 | ) | — | (857 | ) | |||||||||||
General and administrative expense | (5 | ) | (87 | ) | (25 | ) | — | (117 | ) | ||||||||||
Acquisition and integration costs | (8 | ) | (3 | ) | 3 | — | (8 | ) | |||||||||||
Other | — | (1 | ) | (15 | ) | — | (16 | ) | |||||||||||
Operating loss | (13 | ) | (514 | ) | (147 | ) | — | (674 | ) | ||||||||||
Earnings from unconsolidated investment | — | 7 | — | — | 7 | ||||||||||||||
Equity in losses from investments in affiliates | (718 | ) | — | — | 718 | — | |||||||||||||
Interest expense | (355 | ) | (9 | ) | (87 | ) | 2 | (449 | ) | ||||||||||
Other income and expense, net | 26 | 20 | 16 | (2 | ) | 60 | |||||||||||||
Loss before income taxes | (1,060 | ) | (496 | ) | (218 | ) | 718 | (1,056 | ) | ||||||||||
Income tax benefit (expense) | — | 30 | (36 | ) | — | (6 | ) | ||||||||||||
Net loss | (1,060 | ) | (466 | ) | (254 | ) | 718 | (1,062 | ) | ||||||||||
Less: Net loss attributable to noncontrolling interest | — | — | (2 | ) | — | (2 | ) | ||||||||||||
Net loss attributable to Dynegy Inc. | $ | (1,060 | ) | $ | (466 | ) | $ | (252 | ) | $ | 718 | $ | (1,060 | ) |
Parent | Guarantor Subsidiaries | Non-Guarantor Subsidiaries | Eliminations | Consolidated | |||||||||||||||
Revenues | $ | — | $ | 878 | $ | 249 | $ | 105 | $ | 1,232 | |||||||||
Cost of sales, excluding depreciation expense | — | (369 | ) | (147 | ) | (105 | ) | (621 | ) | ||||||||||
Gross margin | — | 509 | 102 | — | 611 | ||||||||||||||
Operating and maintenance expense | — | (154 | ) | (65 | ) | — | (219 | ) | |||||||||||
Depreciation expense | — | (149 | ) | (25 | ) | — | (174 | ) | |||||||||||
Impairments | — | (74 | ) | — | — | (74 | ) | ||||||||||||
General and administrative expense | 3 | (26 | ) | (6 | ) | — | (29 | ) | |||||||||||
Acquisition and integration costs | — | (8 | ) | — | — | (8 | ) | ||||||||||||
Operating income | 3 | 98 | 6 | — | 107 | ||||||||||||||
Losses from unconsolidated investment | — | (4 | ) | — | — | (4 | ) | ||||||||||||
Equity in earnings from investments in affiliates | 53 | — | — | (53 | ) | — | |||||||||||||
Interest expense | (127 | ) | — | (18 | ) | — | (145 | ) | |||||||||||
Other income and expense, net | 47 | (1 | ) | — | — | 46 | |||||||||||||
Income (loss) before income taxes | (24 | ) | 93 | (12 | ) | (53 | ) | 4 | |||||||||||
Income tax benefit (expense) | — | (45 | ) | 17 | — | (28 | ) | ||||||||||||
Net income (loss) | (24 | ) | 48 | 5 | (53 | ) | (24 | ) | |||||||||||
Less: Net loss attributable to noncontrolling interest | — | — | — | — | — | ||||||||||||||
Net income (loss) attributable to Dynegy Inc. | $ | (24 | ) | $ | 48 | $ | 5 | $ | (53 | ) | $ | (24 | ) |
Parent | Guarantor Subsidiaries | Non-Guarantor Subsidiaries | Eliminations | Consolidated | |||||||||||||||
Revenues | $ | — | $ | 2,186 | $ | 672 | $ | (4 | ) | $ | 2,854 | ||||||||
Cost of sales, excluding depreciation expense | — | (1,080 | ) | (418 | ) | 4 | (1,494 | ) | |||||||||||
Gross margin | — | 1,106 | 254 | — | 1,360 | ||||||||||||||
Operating and maintenance expense | — | (385 | ) | (195 | ) | — | (580 | ) | |||||||||||
Depreciation expense | — | (352 | ) | (61 | ) | — | (413 | ) | |||||||||||
Impairments | — | (74 | ) | — | — | (74 | ) | ||||||||||||
General and administrative expense | — | (69 | ) | (25 | ) | — | (94 | ) | |||||||||||
Acquisition and integration costs | — | (121 | ) | — | — | (121 | ) | ||||||||||||
Other | — | (1 | ) | — | — | (1 | ) | ||||||||||||
Operating income (loss) | — | 104 | (27 | ) | — | 77 | |||||||||||||
Losses from unconsolidated investment | — | (1 | ) | — | — | (1 | ) | ||||||||||||
Equity in earnings from investments in affiliates | 500 | — | — | (500 | ) | — | |||||||||||||
Interest expense | (361 | ) | — | (52 | ) | — | (413 | ) | |||||||||||
Other income and expense, net | 45 | — | — | — | 45 | ||||||||||||||
Income (loss) before income taxes | 184 | 103 | (79 | ) | (500 | ) | (292 | ) | |||||||||||
Income tax benefit | — | 473 | — | — | 473 | ||||||||||||||
Net income (loss) | 184 | 576 | (79 | ) | (500 | ) | 181 | ||||||||||||
Less: Net loss attributable to noncontrolling interest | — | — | (3 | ) | — | (3 | ) | ||||||||||||
Net income (loss) attributable to Dynegy Inc. | $ | 184 | $ | 576 | $ | (76 | ) | $ | (500 | ) | $ | 184 |
Parent | Guarantor Subsidiaries | Non-Guarantor Subsidiaries | Eliminations | Consolidated | |||||||||||||||
Net income (loss) | $ | (249 | ) | $ | 67 | $ | (220 | ) | $ | 153 | $ | (249 | ) | ||||||
Amounts reclassified from accumulated other comprehensive income: | |||||||||||||||||||
Amortization of unrecognized prior service credit, net of tax of zero | (1 | ) | — | (1 | ) | — | (2 | ) | |||||||||||
Other comprehensive loss from investment in affiliates | (1 | ) | — | — | 1 | — | |||||||||||||
Other comprehensive loss, net of tax | (2 | ) | — | (1 | ) | 1 | (2 | ) | |||||||||||
Comprehensive income (loss) | (251 | ) | 67 | (221 | ) | 154 | (251 | ) | |||||||||||
Less: Comprehensive income (loss) attributable to noncontrolling interest | — | — | — | — | — | ||||||||||||||
Total comprehensive income (loss) attributable to Dynegy Inc. | $ | (251 | ) | $ | 67 | $ | (221 | ) | $ | 154 | $ | (251 | ) |
Parent | Guarantor Subsidiaries | Non-Guarantor Subsidiaries | Eliminations | Consolidated | |||||||||||||||
Net loss | $ | (1,060 | ) | $ | (466 | ) | $ | (254 | ) | $ | 718 | $ | (1,062 | ) | |||||
Amounts reclassified from accumulated other comprehensive income: | |||||||||||||||||||
Amortization of unrecognized prior service credit, net of tax of zero | (3 | ) | — | (1 | ) | — | (4 | ) | |||||||||||
Other comprehensive loss from investment in affiliates | (1 | ) | — | — | 1 | — | |||||||||||||
Other comprehensive loss, net of tax | (4 | ) | — | (1 | ) | 1 | (4 | ) | |||||||||||
Comprehensive loss | (1,064 | ) | (466 | ) | (255 | ) | 719 | (1,066 | ) | ||||||||||
Less: Comprehensive loss attributable to noncontrolling interest | — | — | (2 | ) | — | (2 | ) | ||||||||||||
Total comprehensive loss attributable to Dynegy Inc. | $ | (1,064 | ) | $ | (466 | ) | $ | (253 | ) | $ | 719 | $ | (1,064 | ) |
Parent | Guarantor Subsidiaries | Non-Guarantor Subsidiaries | Eliminations | Consolidated | |||||||||||||||
Net income (loss) | $ | (24 | ) | $ | 48 | $ | 5 | $ | (53 | ) | $ | (24 | ) | ||||||
Other comprehensive income before reclassifications: | |||||||||||||||||||
Actuarial gain and plan amendments, net of tax of $2 | 6 | — | 7 | — | 13 | ||||||||||||||
Amounts reclassified from accumulated other comprehensive income: | |||||||||||||||||||
Amortization of unrecognized prior service credit and actuarial gain, net of tax of zero | (1 | ) | — | — | — | (1 | ) | ||||||||||||
Other comprehensive income from investment in affiliates | 7 | — | — | (7 | ) | — | |||||||||||||
Other comprehensive income, net of tax | 12 | — | 7 | (7 | ) | 12 | |||||||||||||
Comprehensive income (loss) | (12 | ) | 48 | 12 | (60 | ) | (12 | ) | |||||||||||
Less: Comprehensive income attributable to noncontrolling interest | 1 | — | 1 | (1 | ) | 1 | |||||||||||||
Total comprehensive income (loss) attributable to Dynegy Inc. | $ | (13 | ) | $ | 48 | $ | 11 | $ | (59 | ) | $ | (13 | ) |
Parent | Guarantor Subsidiaries | Non-Guarantor Subsidiaries | Eliminations | Consolidated | |||||||||||||||
Net income (loss) | $ | 184 | $ | 576 | $ | (79 | ) | $ | (500 | ) | $ | 181 | |||||||
Other comprehensive income before reclassifications: | |||||||||||||||||||
Actuarial gain and plan amendments, net of tax of $2 | 1 | — | 7 | — | 8 | ||||||||||||||
Amounts reclassified from accumulated other comprehensive income: | |||||||||||||||||||
Amortization of unrecognized prior service credit and actuarial gain, net of tax of zero | (3 | ) | — | — | — | (3 | ) | ||||||||||||
Other comprehensive income from investment in affiliates | 7 | — | — | (7 | ) | — | |||||||||||||
Other comprehensive income, net of tax | 5 | — | 7 | (7 | ) | 5 | |||||||||||||
Comprehensive income (loss) | 189 | 576 | (72 | ) | (507 | ) | 186 | ||||||||||||
Less: Comprehensive income (loss) attributable to noncontrolling interest | 1 | — | (2 | ) | (1 | ) | (2 | ) | |||||||||||
Total comprehensive income (loss) attributable to Dynegy Inc. | $ | 188 | $ | 576 | $ | (70 | ) | $ | (506 | ) | $ | 188 |
Parent | Guarantor Subsidiaries | Non-Guarantor Subsidiaries | Eliminations | Consolidated | |||||||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES: | |||||||||||||||||||
Net cash provided by (used in) operating activities | $ | (155 | ) | $ | 780 | $ | 24 | $ | — | $ | 649 | ||||||||
CASH FLOWS FROM INVESTING ACTIVITIES: | |||||||||||||||||||
Capital expenditures | — | (227 | ) | (32 | ) | — | (259 | ) | |||||||||||
Increase in restricted cash | — | — | (2,045 | ) | — | (2,045 | ) | ||||||||||||
Net intercompany transfers | 670 | — | — | (670 | ) | — | |||||||||||||
Distributions from unconsolidated affiliate | — | 14 | — | — | 14 | ||||||||||||||
Other investing | — | 10 | — | — | 10 | ||||||||||||||
Net cash provided by (used in) investing activities | 670 | (203 | ) | (2,077 | ) | (670 | ) | (2,280 | ) | ||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES: | |||||||||||||||||||
Proceeds from long-term borrowings, net of debt issuance costs | 84 | 198 | 1,995 | — | 2,277 | ||||||||||||||
Repayments of borrowings | (6 | ) | (15 | ) | — | — | (21 | ) | |||||||||||
Proceeds from issuance of equity, net of issuance costs | 359 | — | — | — | 359 | ||||||||||||||
Preferred stock dividends paid | (16 | ) | — | — | — | (16 | ) | ||||||||||||
Interest rate swap settlement payments | (13 | ) | — | — | — | (13 | ) | ||||||||||||
Net intercompany transfers | — | (785 | ) | 115 | 670 | — | |||||||||||||
Other financing | (2 | ) | — | — | — | (2 | ) | ||||||||||||
Net cash provided by (used in) financing activities | 406 | (602 | ) | 2,110 | 670 | 2,584 | |||||||||||||
Net increase (decrease) in cash and cash equivalents | 921 | (25 | ) | 57 | — | 953 | |||||||||||||
Cash and cash equivalents, beginning of period | 327 | 94 | 84 | — | 505 | ||||||||||||||
Cash and cash equivalents, end of period | $ | 1,248 | $ | 69 | $ | 141 | $ | — | $ | 1,458 |
Parent | Guarantor Subsidiaries | Non-Guarantor Subsidiaries | Eliminations | Consolidated | |||||||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES: | |||||||||||||||||||
Net cash provided by (used in) operating activities | $ | (141 | ) | $ | 502 | $ | (59 | ) | $ | — | $ | 302 | |||||||
CASH FLOWS FROM INVESTING ACTIVITIES: | |||||||||||||||||||
Capital expenditures | (8 | ) | (122 | ) | (41 | ) | — | (171 | ) | ||||||||||
Acquisition, net of cash acquired | (6,207 | ) | 29 | 100 | — | (6,078 | ) | ||||||||||||
Decrease in restricted cash | 5,148 | — | — | — | 5,148 | ||||||||||||||
Net intercompany transfers | 349 | — | — | (349 | ) | — | |||||||||||||
Distributions from unconsolidated affiliate | — | 8 | — | — | 8 | ||||||||||||||
Other investing | — | (6 | ) | — | — | (6 | ) | ||||||||||||
Net cash provided by (used in) investing activities | (718 | ) | (91 | ) | 59 | (349 | ) | (1,099 | ) | ||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES: | |||||||||||||||||||
Proceeds from long-term borrowings, net of debt issuance costs | (31 | ) | 78 | 10 | — | 57 | |||||||||||||
Repayments of borrowings | (6 | ) | (23 | ) | — | — | (29 | ) | |||||||||||
Proceeds from issuance of equity, net of issuance costs | (6 | ) | — | — | — | (6 | ) | ||||||||||||
Preferred stock dividends paid | (17 | ) | — | — | — | (17 | ) | ||||||||||||
Interest rate swap settlement payments | (13 | ) | — | — | — | (13 | ) | ||||||||||||
Net intercompany transfers | — | (344 | ) | (5 | ) | 349 | — | ||||||||||||
Repurchase of common stock | (127 | ) | — | — | — | (127 | ) | ||||||||||||
Other financing | (4 | ) | — | — | — | (4 | ) | ||||||||||||
Net cash provided by (used in) financing activities | (204 | ) | (289 | ) | 5 | 349 | (139 | ) | |||||||||||
Net increase (decrease) in cash and cash equivalents | (1,063 | ) | 122 | 5 | — | (936 | ) | ||||||||||||
Cash and cash equivalents, beginning of period | 1,642 | 54 | 174 | — | 1,870 | ||||||||||||||
Cash and cash equivalents, end of period | $ | 579 | $ | 176 | $ | 179 | $ | — | $ | 934 |
(amounts in millions) | Coal | IPH | Gas | Other and Eliminations | Total | |||||||||||||||
Domestic: | ||||||||||||||||||||
Unaffiliated revenues | $ | 388 | $ | 241 | $ | 539 | $ | — | $ | 1,168 | ||||||||||
Intercompany and affiliate revenues | — | 1 | 15 | — | 16 | |||||||||||||||
Total revenues | $ | 388 | $ | 242 | $ | 554 | $ | — | $ | 1,184 | ||||||||||
Depreciation expense | $ | (27 | ) | $ | (7 | ) | $ | (128 | ) | $ | (1 | ) | $ | (163 | ) | |||||
Impairments | (55 | ) | (148 | ) | (9 | ) | — | (212 | ) | |||||||||||
General and administrative expense | — | — | — | (41 | ) | (41 | ) | |||||||||||||
Acquisition and integration costs | — | — | — | (7 | ) | (7 | ) | |||||||||||||
Operating income (loss) | $ | (33 | ) | $ | (104 | ) | $ | 69 | $ | (49 | ) | $ | (117 | ) | ||||||
Earnings from unconsolidated investment | — | — | 4 | — | 4 | |||||||||||||||
Interest expense | — | — | — | (166 | ) | (166 | ) | |||||||||||||
Other income and expense, net | 3 | 1 | — | 25 | 29 | |||||||||||||||
Loss before income taxes | (250 | ) | ||||||||||||||||||
Income tax benefit | — | — | — | 1 | 1 | |||||||||||||||
Net loss | (249 | ) | ||||||||||||||||||
Less: Net income attributable to noncontrolling interest | — | |||||||||||||||||||
Net loss attributable to Dynegy Inc. | $ | (249 | ) | |||||||||||||||||
Total assets—domestic | $ | 1,432 | $ | 746 | $ | 7,498 | $ | 3,348 | $ | 13,024 | ||||||||||
Investment in unconsolidated affiliate | $ | — | $ | — | $ | 173 | $ | — | $ | 173 | ||||||||||
Capital expenditures | $ | (8 | ) | $ | (11 | ) | $ | (15 | ) | $ | (1 | ) | $ | (35 | ) |
(amounts in millions) | Coal | IPH | Gas | Other and Eliminations | Total | |||||||||||||||
Domestic: | ||||||||||||||||||||
Unaffiliated revenues | $ | 1,022 | $ | 575 | $ | 1,587 | $ | — | $ | 3,184 | ||||||||||
Intercompany and affiliate revenues | (24 | ) | (1 | ) | 52 | — | 27 | |||||||||||||
Total revenues | $ | 998 | $ | 574 | $ | 1,639 | $ | — | $ | 3,211 | ||||||||||
Depreciation expense | $ | (99 | ) | $ | (21 | ) | $ | (370 | ) | $ | (4 | ) | $ | (494 | ) | |||||
Impairments | (700 | ) | (148 | ) | (9 | ) | — | (857 | ) | |||||||||||
General and administrative expense | — | — | — | (117 | ) | (117 | ) | |||||||||||||
Acquisition and integration costs | — | 8 | — | (16 | ) | (8 | ) | |||||||||||||
Operating income (loss) | $ | (728 | ) | $ | (87 | ) | $ | 279 | $ | (138 | ) | $ | (674 | ) | ||||||
Earnings from unconsolidated investment | — | — | 7 | — | 7 | |||||||||||||||
Interest expense | — | — | — | (449 | ) | (449 | ) | |||||||||||||
Other income and expense, net | 9 | 15 | 12 | 24 | 60 | |||||||||||||||
Loss before income taxes | (1,056 | ) | ||||||||||||||||||
Income tax expense | — | — | — | (6 | ) | (6 | ) | |||||||||||||
Net loss | (1,062 | ) | ||||||||||||||||||
Less: Net loss attributable to noncontrolling interest | (2 | ) | ||||||||||||||||||
Net loss attributable to Dynegy Inc. | $ | (1,060 | ) | |||||||||||||||||
Total assets—domestic | $ | 1,432 | $ | 746 | $ | 7,498 | $ | 3,348 | $ | 13,024 | ||||||||||
Investment in unconsolidated affiliate | $ | — | $ | — | $ | 173 | $ | — | $ | 173 | ||||||||||
Capital expenditures | $ | (47 | ) | $ | (32 | ) | $ | (171 | ) | $ | (9 | ) | $ | (259 | ) |
(amounts in millions) | Coal | IPH | Gas | Other and Eliminations | Total | |||||||||||||||
Domestic: | ||||||||||||||||||||
Unaffiliated revenues | $ | 410 | $ | 221 | $ | 605 | $ | (4 | ) | $ | 1,232 | |||||||||
Intercompany revenues | (14 | ) | — | 10 | 4 | — | ||||||||||||||
Total revenues | $ | 396 | $ | 221 | $ | 615 | $ | — | $ | 1,232 | ||||||||||
Depreciation expense | $ | (39 | ) | $ | (8 | ) | $ | (126 | ) | $ | (1 | ) | $ | (174 | ) | |||||
Impairments | (74 | ) | — | — | — | (74 | ) | |||||||||||||
General and administrative expense | — | — | — | (29 | ) | (29 | ) | |||||||||||||
Acquisition and integration costs | — | — | — | (8 | ) | (8 | ) | |||||||||||||
Operating income (loss) | $ | (36 | ) | $ | 31 | $ | 152 | $ | (40 | ) | $ | 107 | ||||||||
Losses from unconsolidated investment | — | — | (4 | ) | — | (4 | ) | |||||||||||||
Interest expense | — | — | — | (145 | ) | (145 | ) | |||||||||||||
Other income and expense, net | — | — | — | 46 | 46 | |||||||||||||||
Income before income taxes | 4 | |||||||||||||||||||
Income tax expense | — | — | — | (28 | ) | (28 | ) | |||||||||||||
Net loss | (24 | ) | ||||||||||||||||||
Less: Net income attributable to noncontrolling interest | — | |||||||||||||||||||
Net loss attributable to Dynegy Inc. | $ | (24 | ) | |||||||||||||||||
Total assets—domestic | $ | 2,426 | $ | 993 | $ | 7,948 | $ | 790 | $ | 12,157 | ||||||||||
Investment in unconsolidated affiliate | $ | — | $ | — | $ | 189 | $ | — | $ | 189 | ||||||||||
Capital expenditures | $ | (25 | ) | $ | (12 | ) | $ | (29 | ) | $ | (3 | ) | $ | (69 | ) |
(amounts in millions) | Coal | IPH | Gas | Other and Eliminations | Total | |||||||||||||||
Domestic: | ||||||||||||||||||||
Unaffiliated revenues | $ | 976 | $ | 629 | $ | 1,254 | $ | (5 | ) | $ | 2,854 | |||||||||
Intercompany revenues | (131 | ) | (4 | ) | 130 | 5 | — | |||||||||||||
Total revenues | $ | 845 | $ | 625 | $ | 1,384 | $ | — | $ | 2,854 | ||||||||||
Depreciation expense | $ | (96 | ) | $ | (24 | ) | $ | (290 | ) | $ | (3 | ) | $ | (413 | ) | |||||
Impairments | (74 | ) | — | — | — | (74 | ) | |||||||||||||
General and administrative expense | — | — | — | (94 | ) | (94 | ) | |||||||||||||
Acquisition and integration costs | — | — | — | (121 | ) | (121 | ) | |||||||||||||
Operating income (loss) | $ | (34 | ) | $ | 39 | $ | 290 | $ | (218 | ) | $ | 77 | ||||||||
Losses from unconsolidated investment | — | — | (1 | ) | — | (1 | ) | |||||||||||||
Interest expense | — | — | — | (413 | ) | (413 | ) | |||||||||||||
Other income and expense, net | — | — | — | 45 | 45 | |||||||||||||||
Loss before income taxes | (292 | ) | ||||||||||||||||||
Income tax benefit | — | — | — | 473 | 473 | |||||||||||||||
Net income | 181 | |||||||||||||||||||
Less: Net loss attributable to noncontrolling interest | (3 | ) | ||||||||||||||||||
Net income attributable to Dynegy Inc. | $ | 184 | ||||||||||||||||||
Total assets—domestic | $ | 2,426 | $ | 993 | $ | 7,948 | $ | 790 | $ | 12,157 | ||||||||||
Investment in unconsolidated affiliate | $ | — | $ | — | $ | 189 | $ | — | $ | 189 | ||||||||||
Capital expenditures | $ | (44 | ) | $ | (41 | ) | $ | (78 | ) | $ | (8 | ) | $ | (171 | ) |
September 30, 2016 | ||||||||||||
(amounts in millions) | Dynegy Inc. | IPH (1) (2) | Total | |||||||||
Revolving facilities and LC capacity (3) | $ | 1,480 | $ | 44 | $ | 1,524 | ||||||
Less: Outstanding LCs | (382 | ) | (30 | ) | (412 | ) | ||||||
Revolving facilities and LC availability | 1,098 | 14 | 1,112 | |||||||||
Cash and cash equivalents | 1,351 | 107 | 1,458 | |||||||||
Total available liquidity (4) | $ | 2,449 | $ | 121 | $ | 2,570 |
(1) | Includes Cash and cash equivalents of $84 million related to Genco. |
(2) | As previously discussed, due to the ring-fenced nature of IPH, cash at the IPH and Genco entities may not be moved out of these entities without meeting certain criteria. However, cash at these entities is available to support current operations of these entities. |
(3) | Dynegy includes (i) $950 million of aggregate available capacity related to our incremental revolving credit facilities, (ii) $475 million of available capacity related to the five-year senior secured revolving credit facility, and (iii) $55 million related to an LC. IPH consists of $44 million related to IPM LCs. One of the IPM LCs is fully collateralized by cash, and as of September 30, 2016, IPM had $19 million deposited with the issuing bank. Please read Note 13—Debt—Letter of Credit Facilities for further discussion. |
(4) | On December 2, 2013, Dynegy and Illinois Power Resources, LLC entered into an intercompany revolving promissory note of $25 million. At September 30, 2016, there was approximately $5 million outstanding on the note, which is not reflected in the table above. |
Nine Months Ended September 30, | ||||||||
(amounts in millions) | 2016 | 2015 | ||||||
Net cash provided by operating activities | $ | 649 | $ | 302 | ||||
Net cash used in investing activities | $ | (2,280 | ) | $ | (1,099 | ) | ||
Net cash provided by (used in) financing activities | $ | 2,584 | $ | (139 | ) |
(amounts in millions) | September 30, 2016 | December 31, 2015 | ||||||
Dynegy Inc.: | ||||||||
Cash (1) | $ | 108 | $ | 159 | ||||
LCs | 382 | 475 | ||||||
Total Dynegy Inc. | 490 | 634 | ||||||
IPH: | ||||||||
Cash (1) (2) | 12 | 11 | ||||||
LCs (3) (4) | 30 | 45 | ||||||
Total IPH | 42 | 56 | ||||||
Total | $ | 532 | $ | 690 |
(1) | Includes broker margin as well as other collateral postings included in Prepayments and other current assets in our unaudited consolidated balance sheets. At September 30, 2016 and December 31, 2015, $73 million and $106 million, respectively, of cash posted as collateral were netted against Liabilities from risk management activities in our unaudited consolidated balance sheets. |
(2) | Includes cash of approximately zero and $1 million related to Genco at September 30, 2016 and December 31, 2015, respectively. |
(3) | Includes LCs of approximately $18 million and $20 million outstanding as of September 30, 2016 and December 31, 2015, respectively, related to the cash-backed LC facility at IPM. Please read Note 13—Debt—Letter of Credit Facilities for further discussion. |
(4) | Includes LCs of approximately $12 million related to the two-year secured LC entered into by IPM and collateralized by IPRG receivables. |
Nine Months Ended September 30, | ||||||||
(amounts in millions) | 2016 | 2015 | ||||||
Coal | $ | 47 | $ | 44 | ||||
IPH | 32 | 41 | ||||||
Gas | 171 | 78 | ||||||
Other | 9 | 8 | ||||||
Total (1) | $ | 259 | $ | 171 |
(1) | Includes capitalized interest of $9 million for the nine months ended September 30, 2016 and 2015. |
Compliance Period | Consolidated Senior Secured Net Debt to Consolidated Adjusted EBITDA (1) | |
September 30, 2013 through December 31, 2013 | 5.00: 1.00 | |
March 31, 2014 through December 31, 2014 | 4.00: 1.00 | |
March 31, 2015 through December 31, 2015 | 4.75: 1.00 | |
March 31, 2016 through December 31, 2016 | 3.75: 1.00 | |
March 31, 2017 and Thereafter | 3.00: 1.00 |
(1) | For purposes of calculating Net Debt, as defined within the Credit Agreement, we may only apply a maximum of $150 million in cash to our outstanding secured debt. |
Required Ratio | ||
Restricted payment interest coverage ratio (1) | ≥1.75 | |
Additional indebtedness interest coverage ratio (2) | ≥2.50 | |
Additional indebtedness debt-to-capital ratio (2) | ≤60% |
(1) | As of the date of a restricted payment, as defined, the minimum ratio must have been achieved for the most recently ended four fiscal quarters and projected by management to be achieved for each of the subsequent four six-month periods. |
(2) | Ratios must be computed on a pro forma basis considering the additional indebtedness to be incurred and the related interest expense. Other borrowings from external, third-party sources are included in the definition of indebtedness and are subject to these incurrence tests. |
Moody’s | S&P | |||
Dynegy Inc.: | ||||
Corporate Family Rating | B2 | B+ | ||
Senior Secured | Ba3 | BB | ||
Senior Unsecured | B3 | B+ | ||
Genco: | ||||
Senior Unsecured | Ca | CCC+ |
Three Months Ended September 30, | Favorable (Unfavorable) $ Change | Favorable (Unfavorable) % Change | |||||||||||||
(amounts in millions) | 2016 | 2015 | |||||||||||||
Revenues | |||||||||||||||
Energy | $ | 1,030 | $ | 982 | $ | 48 | 5 | % | |||||||
Capacity | 154 | 183 | (29 | ) | (16 | )% | |||||||||
Mark-to-market income, net | (18 | ) | 56 | (74 | ) | (132 | )% | ||||||||
Contract amortization | (23 | ) | (25 | ) | 2 | 8 | % | ||||||||
Other | 41 | 36 | 5 | 14 | % | ||||||||||
Total revenues | 1,184 | 1,232 | (48 | ) | (4 | )% | |||||||||
Cost of sales, excluding depreciation expense | (660 | ) | (621 | ) | (39 | ) | (6 | )% | |||||||
Gross margin | 524 | 611 | (87 | ) | (14 | )% | |||||||||
Operating and maintenance expense | (218 | ) | (219 | ) | 1 | — | % | ||||||||
Depreciation expense | (163 | ) | (174 | ) | 11 | 6 | % | ||||||||
Impairments | (212 | ) | (74 | ) | (138 | ) | (186 | )% | |||||||
General and administrative expense | (41 | ) | (29 | ) | (12 | ) | (41 | )% | |||||||
Acquisition and integration costs | (7 | ) | (8 | ) | 1 | 13 | % | ||||||||
Operating income (loss) | (117 | ) | 107 | (224 | ) | (209 | )% | ||||||||
Earnings (losses) from unconsolidated investment | 4 | (4 | ) | 8 | 200 | % | |||||||||
Interest expense | (166 | ) | (145 | ) | (21 | ) | (14 | )% | |||||||
Other income and expense, net | 29 | 46 | (17 | ) | (37 | )% | |||||||||
Income (loss) before income taxes | (250 | ) | 4 | (254 | ) | NM | |||||||||
Income tax benefit (expense) | 1 | (28 | ) | 29 | 104 | % | |||||||||
Net loss attributable to Dynegy Inc. | $ | (249 | ) | $ | (24 | ) | $ | (225 | ) | NM |
Three Months Ended September 30, 2016 | ||||||||||||||||||||
(amounts in millions) | Coal | IPH | Gas | Other | Total | |||||||||||||||
Revenues | $ | 388 | $ | 242 | $ | 554 | $ | — | $ | 1,184 | ||||||||||
Cost of sales, excluding depreciation expense | (231 | ) | (142 | ) | (287 | ) | — | (660 | ) | |||||||||||
Gross margin | 157 | 100 | 267 | — | 524 | |||||||||||||||
Operating and maintenance expense | (108 | ) | (50 | ) | (60 | ) | — | (218 | ) | |||||||||||
Depreciation expense | (27 | ) | (7 | ) | (128 | ) | (1 | ) | (163 | ) | ||||||||||
Impairments | (55 | ) | (148 | ) | (9 | ) | — | (212 | ) | |||||||||||
General and administrative expense | — | — | — | (41 | ) | (41 | ) | |||||||||||||
Acquisition and integration costs | — | — | — | (7 | ) | (7 | ) | |||||||||||||
Other | — | 1 | (1 | ) | — | — | ||||||||||||||
Operating income (loss) | $ | (33 | ) | $ | (104 | ) | $ | 69 | $ | (49 | ) | $ | (117 | ) |
Three Months Ended September 30, 2015 | ||||||||||||||||||||
(amounts in millions) | Coal | IPH | Gas | Other | Total | |||||||||||||||
Revenues | $ | 396 | $ | 221 | $ | 615 | $ | — | $ | 1,232 | ||||||||||
Cost of sales, excluding depreciation expense | (201 | ) | (133 | ) | (287 | ) | — | (621 | ) | |||||||||||
Gross margin | 195 | 88 | 328 | — | 611 | |||||||||||||||
Operating and maintenance expense | (118 | ) | (49 | ) | (50 | ) | (2 | ) | (219 | ) | ||||||||||
Depreciation expense | (39 | ) | (8 | ) | (126 | ) | (1 | ) | (174 | ) | ||||||||||
Impairments | (74 | ) | — | — | — | (74 | ) | |||||||||||||
General and administrative expense | — | — | — | (29 | ) | (29 | ) | |||||||||||||
Acquisition and integration costs | — | — | — | (8 | ) | (8 | ) | |||||||||||||
Operating income (loss) | $ | (36 | ) | $ | 31 | $ | 152 | $ | (40 | ) | $ | 107 |
(amounts in millions) | Coal | IPH | Gas | Total | ||||||||||||
Higher (lower) prices | $ | (33 | ) | $ | 13 | $ | 35 | $ | 15 | |||||||
Higher (lower) generation volumes | 26 | 1 | (15 | ) | 12 | |||||||||||
Higher (lower) capacity revenues | (8 | ) | 3 | (24 | ) | (29 | ) | |||||||||
Mark-to-market gains (losses) on hedging transactions | 6 | (3 | ) | (77 | ) | (74 | ) | |||||||||
Lower (higher) contract amortization | (6 | ) | 2 | 6 | 2 | |||||||||||
Other | 7 | 5 | 14 | 26 | ||||||||||||
Total change in revenues | $ | (8 | ) | $ | 21 | $ | (61 | ) | $ | (48 | ) |
(amounts in millions) | Coal | IPH | Gas | Total | ||||||||||||
Higher (lower) prices | $ | 9 | $ | (6 | ) | $ | (3 | ) | $ | — | ||||||
Higher (lower) generation volumes | 7 | (2 | ) | (4 | ) | 1 | ||||||||||
Lower transportation costs due to favorable contract rates | — | — | (4 | ) | (4 | ) | ||||||||||
Lower contract amortization | 8 | 5 | 2 | 15 | ||||||||||||
Other | 6 | 12 | 9 | 27 | ||||||||||||
Total change in cost of sales | $ | 30 | $ | 9 | $ | — | $ | 39 |
Three Months Ended September 30, 2016 | ||||||||||||||||||||
(amounts in millions) | Coal | IPH | Gas | Other | Total | |||||||||||||||
Net loss attributable to Dynegy Inc. | $ | (249 | ) | |||||||||||||||||
Income tax benefit | (1 | ) | ||||||||||||||||||
Other income and expense, net | (29 | ) | ||||||||||||||||||
Interest expense | 166 | |||||||||||||||||||
Earnings from unconsolidated investment | (4 | ) | ||||||||||||||||||
Operating income (loss) | $ | (33 | ) | $ | (104 | ) | $ | 69 | $ | (49 | ) | $ | (117 | ) | ||||||
Depreciation and amortization expense | 30 | 7 | 137 | 1 | 175 | |||||||||||||||
Earnings from unconsolidated investment | — | — | 4 | — | 4 | |||||||||||||||
Other income and expense, net | 3 | 1 | — | 25 | 29 | |||||||||||||||
EBITDA | — | (96 | ) | 210 | (23 | ) | 91 | |||||||||||||
Adjustments to reflect Adjusted EBITDA from unconsolidated investment and exclude noncontrolling interest | — | (1 | ) | (4 | ) | — | (5 | ) | ||||||||||||
Acquisition, integration and restructuring costs | — | — | — | 12 | 12 | |||||||||||||||
Mark-to-market adjustments, including warrants | (20 | ) | 2 | 53 | (4 | ) | 31 | |||||||||||||
Impairments | 55 | 148 | 9 | — | 212 | |||||||||||||||
Wood River energy margin and O&M | 3 | — | — | — | 3 | |||||||||||||||
Non-cash compensation expense | — | — | 1 | 5 | 6 | |||||||||||||||
Other | 1 | (3 | ) | 2 | — | — | ||||||||||||||
Adjusted EBITDA | $ | 39 | $ | 50 | $ | 271 | $ | (10 | ) | $ | 350 |
Three Months Ended September 30, 2015 | ||||||||||||||||||||
(amounts in millions) | Coal | IPH | Gas | Other | Total | |||||||||||||||
Net loss attributable to Dynegy Inc. | $ | (24 | ) | |||||||||||||||||
Income tax expense | 28 | |||||||||||||||||||
Other income and expense, net | (46 | ) | ||||||||||||||||||
Interest expense | 145 | |||||||||||||||||||
Losses from unconsolidated investment | 4 | |||||||||||||||||||
Operating income (loss) | $ | (36 | ) | $ | 31 | $ | 152 | $ | (40 | ) | $ | 107 | ||||||||
Depreciation and amortization expense | 30 | 6 | 139 | 1 | 176 | |||||||||||||||
Losses from unconsolidated investment | — | — | (4 | ) | — | (4 | ) | |||||||||||||
Other income and expense, net | — | — | — | 46 | 46 | |||||||||||||||
EBITDA | (6 | ) | 37 | 287 | 7 | 325 | ||||||||||||||
Adjustment to reflect Adjusted EBITDA from unconsolidated investment | — | — | 8 | — | 8 | |||||||||||||||
Acquisition and integration costs | — | — | — | 8 | 8 | |||||||||||||||
Mark-to-market adjustments, including warrants | (14 | ) | (3 | ) | (6 | ) | (45 | ) | (68 | ) | ||||||||||
Impairments | 74 | — | — | — | 74 | |||||||||||||||
Other | — | — | 2 | 1 | 3 | |||||||||||||||
Adjusted EBITDA (1) | $ | 54 | $ | 34 | $ | 291 | $ | (29 | ) | $ | 350 |
(1) | Not adjusted for the following items which are excluded in 2016: (i) non-cash compensation expense of $6 million, and (ii) Wood River’s energy margin and O&M costs of $1 million. |
Three Months Ended September 30, | Favorable (Unfavorable) $ Change | Favorable (Unfavorable) % Change | |||||||||||||
(dollars in millions, except for price information) | 2016 | 2015 | |||||||||||||
Operating Revenues | |||||||||||||||
Energy | $ | 348 | $ | 351 | $ | (3 | ) | (1 | )% | ||||||
Capacity | 21 | 29 | (8 | ) | (28 | )% | |||||||||
Mark-to-market income (loss), net | 27 | 21 | 6 | 29 | % | ||||||||||
Contract amortization | (13 | ) | (7 | ) | (6 | ) | (86 | )% | |||||||
Other | 5 | 2 | 3 | 150 | % | ||||||||||
Total operating revenues | 388 | 396 | (8 | ) | (2 | )% | |||||||||
Operating Costs | |||||||||||||||
Cost of sales | (243 | ) | (221 | ) | (22 | ) | (10 | )% | |||||||
Contract amortization | 12 | 20 | (8 | ) | (40 | )% | |||||||||
Total operating costs | (231 | ) | (201 | ) | (30 | ) | (15 | )% | |||||||
Gross margin | 157 | 195 | (38 | ) | (19 | )% | |||||||||
Operating and maintenance expense | (108 | ) | (118 | ) | 10 | 8 | % | ||||||||
Depreciation expense | (27 | ) | (39 | ) | 12 | 31 | % | ||||||||
Impairments | (55 | ) | (74 | ) | 19 | 26 | % | ||||||||
Operating loss | (33 | ) | (36 | ) | 3 | 8 | % | ||||||||
Depreciation and amortization expense | 30 | 30 | — | — | % | ||||||||||
Other income and expense, net | 3 | — | 3 | NM | |||||||||||
EBITDA | — | (6 | ) | 6 | 100 | % | |||||||||
Mark-to-market adjustments | (20 | ) | (14 | ) | (6 | ) | (43 | )% | |||||||
Impairments | 55 | 74 | (19 | ) | (26 | )% | |||||||||
Wood River energy margin and O&M | 3 | — | 3 | NM | |||||||||||
Other | 1 | — | 1 | NM | |||||||||||
Adjusted EBITDA (1) | $ | 39 | $ | 54 | $ | (15 | ) | (28 | )% | ||||||
Million Megawatt Hours Generated | 10.0 | 9.5 | 0.5 | 5 | % | ||||||||||
IMA for Coal-Fired Facilities (2) | 86 | % | 82 | % | |||||||||||
Average Capacity Factor for Coal-Fired Facilities (3) | 69 | % | 62 | % | |||||||||||
Average Quoted Market On-Peak Power Prices ($/MWh) (4): | |||||||||||||||
Indiana (Indy Hub) | $ | 40.19 | $ | 33.09 | $ | 7.10 | 21 | % | |||||||
Commonwealth Edison (NI Hub) | $ | 38.41 | $ | 34.03 | $ | 4.38 | 13 | % | |||||||
Mass Hub | $ | 41.31 | $ | 35.52 | $ | 5.79 | 16 | % | |||||||
AD Hub | $ | 38.75 | $ | 35.87 | $ | 2.88 | 8 | % | |||||||
Average Quoted Market Off-Peak Power Prices ($/MWh) (4): | |||||||||||||||
Indiana (Indy Hub) | $ | 24.38 | $ | 23.37 | $ | 1.01 | 4 | % | |||||||
Commonwealth Edison (NI Hub) | $ | 22.57 | $ | 22.93 | $ | (0.36 | ) | (2 | )% | ||||||
Mass Hub | $ | 23.57 | $ | 21.02 | $ | 2.55 | 12 | % | |||||||
AD Hub | $ | 23.53 | $ | 24.21 | $ | (0.68 | ) | (3 | )% |
(1) | 2015 is not adjusted for Wood River’s energy margin and O&M costs of $1 million which are excluded in 2016. |
(2) | IMA is an internal measurement calculation that reflects the percentage of generation available during periods when market prices are such that these units could be profitably dispatched. This calculation excludes certain events outside of management control such as weather related issues. The calculation excludes our Brayton Point facility and CTs. The IMA for our facilities within MISO and PJM (excluding CTs) was 90 percent and 83 percent, respectively, for the three months ended September 30, 2016 and 91 percent and 77 percent, respectively, for the three months ended September 30, 2015. |
(3) | Reflects actual production as a percentage of available capacity. The calculation excludes our Brayton Point facility and CTs. The average capacity factors for our facilities within MISO and PJM (excluding CTs) were 76 percent and 65 percent, respectively, for the three months ended September 30, 2016 and 68 percent and 57 percent, respectively, for the three months ended September 30, 2015. |
(4) | Reflects the average of day-ahead quoted prices for the periods presented and does not necessarily reflect prices we realized. |
Three Months Ended September 30, | Favorable (Unfavorable) $ Change | Favorable (Unfavorable) % Change | |||||||||||||
(dollars in millions, except for price information) | 2016 | 2015 | |||||||||||||
Operating Revenues | |||||||||||||||
Energy | $ | 219 | $ | 202 | $ | 17 | 8 | % | |||||||
Capacity | 21 | 18 | 3 | 17 | % | ||||||||||
Mark-to-market income (loss), net | — | 3 | (3 | ) | (100 | )% | |||||||||
Contract amortization | (2 | ) | (4 | ) | 2 | 50 | % | ||||||||
Other | 4 | 2 | 2 | 100 | % | ||||||||||
Total operating revenues | 242 | 221 | 21 | 10 | % | ||||||||||
Operating Costs | |||||||||||||||
Cost of sales | (146 | ) | (142 | ) | (4 | ) | (3 | )% | |||||||
Contract amortization | 4 | 9 | (5 | ) | (56 | )% | |||||||||
Total operating costs | (142 | ) | (133 | ) | (9 | ) | (7 | )% | |||||||
Gross margin | 100 | 88 | 12 | 14 | % | ||||||||||
Operating and maintenance expense | (50 | ) | (49 | ) | (1 | ) | (2 | )% | |||||||
Depreciation expense | (7 | ) | (8 | ) | 1 | 13 | % | ||||||||
Impairments | (148 | ) | — | (148 | ) | NM | |||||||||
Other | 1 | — | 1 | NM | |||||||||||
Operating income (loss) | (104 | ) | 31 | (135 | ) | NM | |||||||||
Depreciation and amortization expense | 7 | 6 | 1 | 17 | % | ||||||||||
Other income and expense, net | 1 | — | 1 | NM | |||||||||||
EBITDA | (96 | ) | 37 | (133 | ) | NM | |||||||||
Adjustment to exclude noncontrolling interest | (1 | ) | — | (1 | ) | NM | |||||||||
Mark-to-market adjustments | 2 | (3 | ) | 5 | 167 | % | |||||||||
Impairments | 148 | — | 148 | NM | |||||||||||
Other | (3 | ) | — | (3 | ) | NM | |||||||||
Adjusted EBITDA | $ | 50 | $ | 34 | $ | 16 | 47 | % | |||||||
Million Megawatt Hours Generated | 5.0 | 4.8 | 0.2 | 4 | % | ||||||||||
IMA for IPH Facilities (1) | 88 | % | 84 | % | |||||||||||
Average Capacity Factor for IPH Facilities (2) | 59 | % | 54 | % | |||||||||||
Average Quoted Market Power Prices ($/MWh) (3): | |||||||||||||||
On-Peak: Indiana (Indy Hub) | $ | 40.19 | $ | 33.09 | $ | 7.10 | 21 | % | |||||||
Off-Peak: Indiana (Indy Hub) | $ | 24.38 | $ | 23.37 | $ | 1.01 | 4 | % |
(1) | IMA is an internal measurement calculation that reflects the percentage of generation available during periods when market prices are such that these units could be profitably dispatched. This calculation excludes certain events outside of management control such as weather related issues. |
(2) | Reflects actual production as a percentage of available capacity. |
(3) | Reflects the average of day-ahead quoted prices for the periods presented and does not necessarily reflect prices we realized. |
Three Months Ended September 30, | Favorable (Unfavorable) $ Change | Favorable (Unfavorable) % Change | |||||||||||||
(dollars in millions, except for price information) | 2016 | 2015 | |||||||||||||
Operating Revenues | |||||||||||||||
Energy | $ | 463 | $ | 429 | $ | 34 | 8 | % | |||||||
Capacity | 112 | 136 | (24 | ) | (18 | )% | |||||||||
Mark-to-market income (loss), net | (45 | ) | 32 | (77 | ) | (241 | )% | ||||||||
Contract amortization | (8 | ) | (14 | ) | 6 | 43 | % | ||||||||
Other | 32 | 32 | — | — | % | ||||||||||
Total operating revenues | 554 | 615 | (61 | ) | (10 | )% | |||||||||
Operating Costs | |||||||||||||||
Cost of sales | (286 | ) | (288 | ) | 2 | 1 | % | ||||||||
Contract amortization | (1 | ) | 1 | (2 | ) | (200 | )% | ||||||||
Total operating costs | (287 | ) | (287 | ) | — | — | % | ||||||||
Gross margin | 267 | 328 | (61 | ) | (19 | )% | |||||||||
Operating and maintenance expense | (60 | ) | (50 | ) | (10 | ) | (20 | )% | |||||||
Depreciation expense | (128 | ) | (126 | ) | (2 | ) | (2 | )% | |||||||
Impairments | (9 | ) | — | (9 | ) | NM | |||||||||
Other | (1 | ) | — | (1 | ) | NM | |||||||||
Operating income | 69 | 152 | (83 | ) | (55 | )% | |||||||||
Depreciation and amortization expense | 137 | 139 | (2 | ) | (1 | )% | |||||||||
Earnings from unconsolidated investment | 4 | (4 | ) | 8 | 200 | % | |||||||||
EBITDA | 210 | 287 | (77 | ) | (27 | )% | |||||||||
Mark-to-market adjustments | 53 | (6 | ) | 59 | NM | ||||||||||
Adjustment to reflect Adjusted EBITDA from unconsolidated investment | (4 | ) | 8 | (12 | ) | (150 | )% | ||||||||
Impairments | 9 | — | 9 | NM | |||||||||||
Non-cash compensation expense | 1 | — | 1 | NM | |||||||||||
Other | 2 | 2 | — | — | % | ||||||||||
Adjusted EBITDA | $ | 271 | $ | 291 | $ | (20 | ) | (7 | )% | ||||||
Million Megawatt Hours Generated | 15.2 | 15.5 | (0.3 | ) | (2 | )% | |||||||||
IMA for Combined Cycle Facilities (1) | 97 | % | 99 | % | |||||||||||
Average Capacity Factor for Combined Cycle Facilities (2): | 67 | % | 72 | % | |||||||||||
Average Market On-Peak Spark Spreads ($/MWh) (3): | |||||||||||||||
Commonwealth Edison (NI Hub) | $ | 18.93 | $ | 14.49 | $ | 4.44 | 31 | % | |||||||
PJM West | $ | 31.48 | $ | 29.82 | $ | 1.66 | 6 | % | |||||||
North of Path 15 (NP 15) | $ | 15.44 | $ | 16.25 | $ | (0.81 | ) | (5 | )% | ||||||
New York—Zone A | $ | 39.27 | $ | 26.32 | $ | 12.95 | 49 | % | |||||||
Mass Hub | $ | 21.58 | $ | 18.90 | $ | 2.68 | 14 | % | |||||||
AD Hub | $ | 27.27 | $ | 23.17 | $ | 4.10 | 18 | % | |||||||
Average Market Off-Peak Spark Spreads ($/MWh) (3): | |||||||||||||||
Commonwealth Edison (NI Hub) | $ | 3.09 | $ | 3.39 | $ | (0.30 | ) | (9 | )% | ||||||
PJM West | $ | 15.10 | $ | 15.50 | $ | (0.40 | ) | (3 | )% | ||||||
North of Path 15 (NP 15) | $ | 7.31 | $ | 8.22 | $ | (0.91 | ) | (11 | )% | ||||||
New York—Zone A | $ | 13.24 | $ | 10.49 | $ | 2.75 | 26 | % | |||||||
Mass Hub | $ | 3.85 | $ | 4.39 | $ | (0.54 | ) | (12 | )% | ||||||
AD Hub | $ | 14.78 | $ | 15.62 | $ | (0.84 | ) | (5 | )% | ||||||
Average natural gas price—Henry Hub ($/MMBtu) (4) | $ | 2.84 | $ | 2.74 | $ | 0.10 | 4 | % |
(1) | IMA is an internal measurement calculation that reflects the percentage of generation available when market prices are such that these units could be profitably dispatched. This calculation excludes certain events outside of management control such as weather related issues. |
(2) | Reflects actual production as a percentage of available capacity. |
(3) | Reflects the simple average of the on- and off-peak spark spreads available to a 7.0 MMBtu/MWh heat rate generator selling power at day-ahead prices and buying delivered natural gas at a daily cash market price and does not reflect spark spreads available to us. |
(4) | Reflects the average of daily quoted prices for the periods presented and does not reflect costs incurred by us. |
Nine Months Ended September 30, | Favorable (Unfavorable) $ Change | Favorable (Unfavorable) % Change | |||||||||||||
(amounts in millions) | 2016 | 2015 | |||||||||||||
Revenues | |||||||||||||||
Energy | $ | 2,648 | $ | 2,350 | $ | 298 | 13 | % | |||||||
Capacity | 459 | 369 | 90 | 24 | % | ||||||||||
Mark-to-market income, net | 73 | 120 | (47 | ) | (39 | )% | |||||||||
Contract amortization | (58 | ) | (58 | ) | — | — | % | ||||||||
Other | 89 | 73 | 16 | 22 | % | ||||||||||
Total revenues | 3,211 | 2,854 | 357 | 13 | % | ||||||||||
Cost of sales, excluding depreciation expense | (1,698 | ) | (1,494 | ) | (204 | ) | (14 | )% | |||||||
Gross margin | 1,513 | 1,360 | 153 | 11 | % | ||||||||||
Operating and maintenance expense | (695 | ) | (580 | ) | (115 | ) | (20 | )% | |||||||
Depreciation expense | (494 | ) | (413 | ) | (81 | ) | (20 | )% | |||||||
Impairments | (857 | ) | (74 | ) | (783 | ) | NM | ||||||||
General and administrative expense | (117 | ) | (94 | ) | (23 | ) | (24 | )% | |||||||
Acquisition and integration costs | (8 | ) | (121 | ) | 113 | 93 | % | ||||||||
Other | (16 | ) | (1 | ) | (15 | ) | (100 | )% | |||||||
Operating income (loss) | (674 | ) | 77 | (751 | ) | NM | |||||||||
Earnings (losses) from unconsolidated investment | 7 | (1 | ) | 8 | NM | ||||||||||
Interest expense | (449 | ) | (413 | ) | (36 | ) | (9 | )% | |||||||
Other income and expense, net | 60 | 45 | 15 | 33 | % | ||||||||||
Loss before income taxes | (1,056 | ) | (292 | ) | (764 | ) | NM | ||||||||
Income tax benefit (expense) | (6 | ) | 473 | (479 | ) | (101 | )% | ||||||||
Net income (loss) | (1,062 | ) | 181 | (1,243 | ) | NM | |||||||||
Less: Net loss attributable to noncontrolling interest | (2 | ) | (3 | ) | 1 | 33 | % | ||||||||
Net income (loss) attributable to Dynegy Inc. | $ | (1,060 | ) | $ | 184 | $ | (1,244 | ) | NM |
Nine Months Ended September 30, 2016 | ||||||||||||||||||||
(amounts in millions) | Coal | IPH | Gas | Other | Total | |||||||||||||||
Revenues | $ | 998 | $ | 574 | $ | 1,639 | $ | — | $ | 3,211 | ||||||||||
Cost of sales, excluding depreciation expense | (590 | ) | (342 | ) | (766 | ) | — | (1,698 | ) | |||||||||||
Gross margin | 408 | 232 | 873 | — | 1,513 | |||||||||||||||
Operating and maintenance expense | (337 | ) | (143 | ) | (214 | ) | (1 | ) | (695 | ) | ||||||||||
Depreciation expense | (99 | ) | (21 | ) | (370 | ) | (4 | ) | (494 | ) | ||||||||||
Impairments | (700 | ) | (148 | ) | (9 | ) | — | (857 | ) | |||||||||||
General and administrative expense | — | — | — | (117 | ) | (117 | ) | |||||||||||||
Acquisition and integration costs | — | 8 | — | (16 | ) | (8 | ) | |||||||||||||
Other | — | (15 | ) | (1 | ) | — | (16 | ) | ||||||||||||
Operating income (loss) | $ | (728 | ) | $ | (87 | ) | $ | 279 | $ | (138 | ) | $ | (674 | ) |
Nine Months Ended September 30, 2015 | ||||||||||||||||||||
(amounts in millions) | Coal | IPH | Gas | Other | Total | |||||||||||||||
Revenues | $ | 845 | $ | 625 | $ | 1,384 | $ | — | $ | 2,854 | ||||||||||
Cost of sales, excluding depreciation expense | (423 | ) | (402 | ) | (669 | ) | — | (1,494 | ) | |||||||||||
Gross margin | 422 | 223 | 715 | — | 1,360 | |||||||||||||||
Operating and maintenance expense | (286 | ) | (160 | ) | (134 | ) | — | (580 | ) | |||||||||||
Depreciation expense | (96 | ) | (24 | ) | (290 | ) | (3 | ) | (413 | ) | ||||||||||
Impairments | (74 | ) | — | — | — | (74 | ) | |||||||||||||
General and administrative expense | — | — | — | (94 | ) | (94 | ) | |||||||||||||
Acquisition and integration costs | — | — | — | (121 | ) | (121 | ) | |||||||||||||
Other | — | — | (1 | ) | — | (1 | ) | |||||||||||||
Operating income (loss) | $ | (34 | ) | $ | 39 | $ | 290 | $ | (218 | ) | $ | 77 |
(amounts in millions) | Coal | IPH | Gas | Total | ||||||||||||
Revenues, net of hedges, attributable to newly acquired Duke Midwest and EquiPower plants for the first quarter of 2016 | $ | 269 | $ | — | $ | 392 | $ | 661 | ||||||||
Lower revenues attributable to our legacy plants, including IPH: | ||||||||||||||||
Higher (lower) prices | (31 | ) | 38 | (49 | ) | (42 | ) | |||||||||
Lower generation volumes | (4 | ) | (100 | ) | (56 | ) | (160 | ) | ||||||||
Higher (lower) capacity revenues | (5 | ) | 9 | (8 | ) | (4 | ) | |||||||||
Mark-to-market losses on hedging transactions | (84 | ) | (5 | ) | (53 | ) | (142 | ) | ||||||||
Lower contract amortization | 1 | 8 | 2 | 11 | ||||||||||||
Other | 7 | (1 | ) | 27 | 33 | |||||||||||
Total change in revenues | $ | 153 | $ | (51 | ) | $ | 255 | $ | 357 |
(amounts in millions) | Coal | IPH | Gas | Total | ||||||||||||
Cost of sales attributable to newly acquired Duke Midwest and EquiPower plants for the first quarter of 2016 | $ | 105 | $ | — | $ | 180 | $ | 285 | ||||||||
Lower cost of sales attributable to our legacy plants, including IPH: | ||||||||||||||||
Higher (lower) prices | 22 | (7 | ) | (68 | ) | (53 | ) | |||||||||
Lower generation volumes | (15 | ) | (81 | ) | (24 | ) | (120 | ) | ||||||||
Lower transportation costs | — | — | (14 | ) | (14 | ) | ||||||||||
Lower contract amortization | 18 | 6 | 7 | 31 | ||||||||||||
Other | 37 | 22 | 16 | 75 | ||||||||||||
Total change in cost of sales | $ | 167 | $ | (60 | ) | $ | 97 | $ | 204 |
Nine Months Ended September 30, 2016 | ||||||||||||||||||||
(amounts in millions) | Coal | IPH | Gas | Other | Total | |||||||||||||||
Net loss attributable to Dynegy Inc. | $ | (1,060 | ) | |||||||||||||||||
Loss attributable to noncontrolling interest | (2 | ) | ||||||||||||||||||
Income tax expense | 6 | |||||||||||||||||||
Other income and expense, net | (60 | ) | ||||||||||||||||||
Interest expense | 449 | |||||||||||||||||||
Earnings from unconsolidated investment | (7 | ) | ||||||||||||||||||
Operating income (loss) | $ | (728 | ) | $ | (87 | ) | $ | 279 | $ | (138 | ) | $ | (674 | ) | ||||||
Depreciation and amortization expense | 87 | 20 | 418 | 4 | 529 | |||||||||||||||
Earnings from unconsolidated investment | — | — | 7 | — | 7 | |||||||||||||||
Other income and expense, net | 9 | 15 | 12 | 24 | 60 | |||||||||||||||
EBITDA | (632 | ) | (52 | ) | 716 | (110 | ) | (78 | ) | |||||||||||
Adjustments to reflect Adjusted EBITDA from unconsolidated investment and exclude noncontrolling interest | — | — | — | — | — | |||||||||||||||
Acquisition, integration and restructuring costs | — | (8 | ) | — | 21 | 13 | ||||||||||||||
Mark-to-market adjustments, including warrants | 23 | (3 | ) | (61 | ) | (5 | ) | (46 | ) | |||||||||||
Impairments | 700 | 148 | 9 | — | 857 | |||||||||||||||
Wood River energy margin and O&M | 23 | — | — | — | 23 | |||||||||||||||
Non-cash compensation expense | — | — | 2 | 16 | 18 | |||||||||||||||
Other | 1 | (3 | ) | 1 | 2 | 1 | ||||||||||||||
Adjusted EBITDA | $ | 115 | $ | 82 | $ | 667 | $ | (76 | ) | $ | 788 |
Nine Months Ended September 30, 2015 | ||||||||||||||||||||
(amounts in millions) | Coal | IPH | Gas | Other | Total | |||||||||||||||
Net income attributable to Dynegy Inc. | $ | 184 | ||||||||||||||||||
Loss attributable to noncontrolling interest | (3 | ) | ||||||||||||||||||
Income tax benefit | (473 | ) | ||||||||||||||||||
Other income and expense, net | (45 | ) | ||||||||||||||||||
Interest expense | 413 | |||||||||||||||||||
Losses from unconsolidated investment | 1 | |||||||||||||||||||
Operating income (loss) | $ | (34 | ) | $ | 39 | $ | 290 | $ | (218 | ) | $ | 77 | ||||||||
Depreciation and amortization expense | 78 | 27 | 306 | 3 | 414 | |||||||||||||||
Losses from unconsolidated investment | — | — | (1 | ) | — | (1 | ) | |||||||||||||
Other income and expense, net | — | — | — | 45 | 45 | |||||||||||||||
EBITDA | 44 | 66 | 595 | (170 | ) | 535 | ||||||||||||||
Adjustments to reflect Adjusted EBITDA from unconsolidated investment and exclude noncontrolling interest | — | 3 | 8 | — | 11 | |||||||||||||||
Acquisition and integration costs | — | — | — | 121 | 121 | |||||||||||||||
Mark-to-market adjustments, including warrants | (35 | ) | (8 | ) | (29 | ) | (43 | ) | (115 | ) | ||||||||||
Impairments | 74 | — | — | — | 74 | |||||||||||||||
Other | — | — | 1 | 1 | 2 | |||||||||||||||
Adjusted EBITDA (1) | $ | 83 | $ | 61 | $ | 575 | $ | (91 | ) | $ | 628 |
(1) | Not adjusted for the following items which are excluded in 2016: (i) non-cash compensation expense of $20 million, and (ii) Wood River’s energy margin and O&M costs of $9 million. |
Nine Months Ended September 30, | Favorable (Unfavorable) $ Change | Favorable (Unfavorable) % Change | |||||||||||||
(dollars in millions, except for price information) | 2016 | 2015 | |||||||||||||
Operating revenues | |||||||||||||||
Energy | $ | 942 | $ | 766 | $ | 176 | 23 | % | |||||||
Capacity | 74 | 59 | 15 | 25 | % | ||||||||||
Mark-to-market income (loss), net | (7 | ) | 38 | (45 | ) | (118 | )% | ||||||||
Contract amortization | (19 | ) | (19 | ) | — | — | % | ||||||||
Other | 8 | 1 | 7 | NM | |||||||||||
Total operating revenues | 998 | 845 | 153 | 18 | % | ||||||||||
Operating costs | |||||||||||||||
Cost of sales | (628 | ) | (466 | ) | (162 | ) | (35 | )% | |||||||
Contract amortization | 38 | 43 | (5 | ) | (12 | )% | |||||||||
Total operating costs | (590 | ) | (423 | ) | (167 | ) | (39 | )% | |||||||
Gross margin | 408 | 422 | (14 | ) | (3 | )% | |||||||||
Operating and maintenance expense | (337 | ) | (286 | ) | (51 | ) | (18 | )% | |||||||
Depreciation expense | (99 | ) | (96 | ) | (3 | ) | (3 | )% | |||||||
Impairments | (700 | ) | (74 | ) | (626 | ) | NM | ||||||||
Operating loss | (728 | ) | (34 | ) | (694 | ) | NM | ||||||||
Depreciation and amortization expense | 87 | 78 | 9 | 12 | % | ||||||||||
Other income and expense, net | 9 | — | 9 | NM | |||||||||||
EBITDA | (632 | ) | 44 | (676 | ) | NM | |||||||||
Mark-to-market adjustments | 23 | (35 | ) | 58 | 166 | % | |||||||||
Impairments | 700 | 74 | 626 | NM | |||||||||||
Wood River energy margin and O&M | 23 | — | 23 | NM | |||||||||||
Other | 1 | — | 1 | NM | |||||||||||
Adjusted EBITDA (1) | $ | 115 | $ | 83 | $ | 32 | 39 | % | |||||||
Million Megawatt Hours Generated (5) | 25.3 | 21.7 | 3.6 | 17 | % | ||||||||||
IMA for Coal-Fired Facilities (2)(5) | 84 | % | 80 | % | |||||||||||
Average Capacity Factor for Coal-Fired Facilities (3)(5) | 55 | % | 59 | % | |||||||||||
Average Quoted Market On-Peak Power Prices ($/MWh) (4): | |||||||||||||||
Indiana (Indy Hub) | $ | 32.32 | $ | 35.17 | $ | (2.85 | ) | (8 | )% | ||||||
Commonwealth Edison (NI Hub) | $ | 31.54 | $ | 35.44 | $ | (3.90 | ) | (11 | )% | ||||||
Mass Hub | $ | 34.44 | $ | 53.62 | $ | (19.18 | ) | (36 | )% | ||||||
AD Hub | $ | 32.66 | $ | 39.86 | $ | (7.20 | ) | (18 | )% | ||||||
Average Quoted Market Off-Peak Power Prices ($/MWh) (4): | |||||||||||||||
Indiana (Indy Hub) | $ | 22.31 | $ | 25.41 | $ | (3.10 | ) | (12 | )% | ||||||
Commonwealth Edison (NI Hub) | $ | 20.81 | $ | 23.49 | $ | (2.68 | ) | (11 | )% | ||||||
Mass Hub | $ | 23.40 | $ | 38.90 | $ | (15.50 | ) | (40 | )% | ||||||
AD Hub | $ | 22.72 | $ | 27.20 | $ | (4.48 | ) | (16 | )% |
(1) | 2015 is not adjusted for Wood River’s energy margin and O&M costs of $9 million which are excluded in 2016. |
(2) | IMA is an internal measurement calculation that reflects the percentage of generation available during periods when market prices are such that these units could be profitably dispatched. This calculation excludes certain events outside of management control such as weather related issues. The calculation excludes our Brayton Point facility and CTs. The IMA for our facilities within MISO and PJM (excluding CTs) was 89 percent and 81 percent, respectively, for the nine months ended September 30, 2016 and 87 percent and 73 percent, respectively, for the nine months ended September 30, 2015. |
(3) | Reflects actual production as a percentage of available capacity. The calculation excludes our Brayton Point facility and CTs. The average capacity factors for our facilities within MISO and PJM (excluding CTs) were 61 percent and 51 percent, respectively, for the nine months ended September 30, 2016 and 66 percent and 51 percent, respectively, for the nine months ended September 30, 2015. |
(4) | Reflects the average of day-ahead quoted prices for the periods presented and does not necessarily reflect prices we realized. |
(5) | Reflects the activity for the period in which the Acquisitions were included in our consolidated results. |
Nine Months Ended September 30, | Favorable (Unfavorable) $ Change | Favorable (Unfavorable) % Change | |||||||||||||
(dollars in millions, except for price information) | 2016 | 2015 | |||||||||||||
Operating revenues | |||||||||||||||
Energy | $ | 527 | $ | 589 | $ | (62 | ) | (11 | )% | ||||||
Capacity | 49 | 40 | 9 | 23 | % | ||||||||||
Mark-to-market income, net | 3 | 8 | (5 | ) | (63 | )% | |||||||||
Contract amortization | (10 | ) | (18 | ) | 8 | 44 | % | ||||||||
Other | 5 | 6 | (1 | ) | (17 | )% | |||||||||
Total operating revenues | 574 | 625 | (51 | ) | (8 | )% | |||||||||
Operating costs | |||||||||||||||
Cost of sales | (360 | ) | (426 | ) | 66 | 15 | % | ||||||||
Contract amortization | 18 | 24 | (6 | ) | (25 | )% | |||||||||
Total operating costs | (342 | ) | (402 | ) | 60 | 15 | % | ||||||||
Gross margin | 232 | 223 | 9 | 4 | % | ||||||||||
Operating and maintenance expense | (143 | ) | (160 | ) | 17 | 11 | % | ||||||||
Depreciation expense | (21 | ) | (24 | ) | 3 | 13 | % | ||||||||
Impairments | (148 | ) | — | (148 | ) | NM | |||||||||
Acquisition and integration costs | 8 | — | 8 | NM | |||||||||||
Other | (15 | ) | — | (15 | ) | NM | |||||||||
Operating income (loss) | (87 | ) | 39 | (126 | ) | NM | |||||||||
Depreciation and amortization expense | 20 | 27 | (7 | ) | (26 | )% | |||||||||
Other income and expense, net | 15 | — | 15 | NM | |||||||||||
EBITDA | (52 | ) | 66 | (118 | ) | (179 | )% | ||||||||
Acquisition and integration costs | (8 | ) | — | (8 | ) | NM | |||||||||
Adjustment to exclude noncontrolling interest | — | 3 | (3 | ) | (100 | )% | |||||||||
Mark-to-market adjustments | (3 | ) | (8 | ) | 5 | 63 | % | ||||||||
Impairments | 148 | — | 148 | NM | |||||||||||
Other | (3 | ) | — | (3 | ) | NM | |||||||||
Adjusted EBITDA | $ | 82 | $ | 61 | $ | 21 | 34 | % | |||||||
Million Megawatt Hours Generated | 11.6 | 14.7 | (3.1 | ) | (21 | )% | |||||||||
IMA for IPH Facilities (1) | 88 | % | 89 | % | |||||||||||
Average Capacity Factor for IPH Facilities (2) | 45 | % | 55 | % | |||||||||||
Average Quoted Market Power Prices ($/MWh) (3): | |||||||||||||||
On-Peak: Indiana (Indy Hub) | $ | 32.32 | $ | 35.17 | $ | (2.85 | ) | (8 | )% | ||||||
Off-Peak: Indiana (Indy Hub) | $ | 22.31 | $ | 25.41 | $ | (3.10 | ) | (12 | )% |
(1) | IMA is an internal measurement calculation that reflects the percentage of generation available during periods when market prices are such that these units could be profitably dispatched. This calculation excludes certain events outside of management control such as weather related issues. |
(2) | Reflects actual production as a percentage of available capacity. |
(3) | Reflects the average of day-ahead quoted prices for the periods presented and does not necessarily reflect prices we realized. |
Nine Months Ended September 30, | Favorable (Unfavorable) $ Change | Favorable (Unfavorable) % Change | |||||||||||||
(dollars in millions, except for price information) | 2016 | 2015 | |||||||||||||
Operating Revenues | |||||||||||||||
Energy | $ | 1,179 | $ | 995 | $ | 184 | 18 | % | |||||||
Capacity | 336 | 270 | 66 | 24 | % | ||||||||||
Mark-to-market income, net | 77 | 74 | 3 | 4 | % | ||||||||||
Contract amortization | (29 | ) | (21 | ) | (8 | ) | (38 | )% | |||||||
Other | 76 | 66 | 10 | 15 | % | ||||||||||
Total operating revenues | 1,639 | 1,384 | 255 | 18 | % | ||||||||||
Operating Costs | |||||||||||||||
Cost of sales | (748 | ) | (674 | ) | (74 | ) | (11 | )% | |||||||
Contract amortization | (18 | ) | 5 | (23 | ) | NM | |||||||||
Total operating costs | (766 | ) | (669 | ) | (97 | ) | (14 | )% | |||||||
Gross margin | 873 | 715 | 158 | 22 | % | ||||||||||
Operating and maintenance expense | (214 | ) | (134 | ) | (80 | ) | (60 | )% | |||||||
Depreciation expense | (370 | ) | (290 | ) | (80 | ) | (28 | )% | |||||||
Impairments | (9 | ) | — | (9 | ) | NM | |||||||||
Other | (1 | ) | (1 | ) | — | — | % | ||||||||
Operating income | 279 | 290 | (11 | ) | (4 | )% | |||||||||
Depreciation and amortization expense | 418 | 306 | 112 | 37 | % | ||||||||||
Earnings (losses) from unconsolidated investment | 7 | (1 | ) | 8 | NM | ||||||||||
Other income and expense, net | 12 | — | 12 | NM | |||||||||||
EBITDA | 716 | 595 | 121 | 20 | % | ||||||||||
Adjustment to reflect Adjusted EBITDA from unconsolidated investment | — | 8 | (8 | ) | (100 | )% | |||||||||
Mark-to-market adjustments | (61 | ) | (29 | ) | (32 | ) | (110 | )% | |||||||
Impairments | 9 | — | 9 | NM | |||||||||||
Non-cash compensation expense | 2 | — | 2 | NM | |||||||||||
Other | 1 | 1 | — | — | % | ||||||||||
Adjusted EBITDA | $ | 667 | $ | 575 | $ | 92 | 16 | % | |||||||
Million Megawatt Hours Generated (5) | 40.4 | 33.2 | 7.2 | 22 | % | ||||||||||
IMA for Combined Cycle Facilities (1)(5) | 97 | % | 98 | % | |||||||||||
Average Capacity Factor for Combined Cycle Facilities (2)(5) | 61 | % | 63 | % | |||||||||||
Average Market On-Peak Spark Spreads ($/MWh) (3): | |||||||||||||||
Commonwealth Edison (NI Hub) | $ | 15.41 | $ | 14.91 | $ | 0.50 | 3 | % | |||||||
PJM West | $ | 23.79 | $ | 25.58 | $ | (1.79 | ) | (7 | )% | ||||||
North of Path 15 (NP 15) | $ | 12.32 | $ | 14.63 | $ | (2.31 | ) | (16 | )% | ||||||
New York—Zone A | $ | 26.66 | $ | 29.49 | $ | (2.83 | ) | (10 | )% | ||||||
Mass Hub | $ | 14.49 | $ | 15.77 | $ | (1.28 | ) | (8 | )% | ||||||
AD Hub | $ | 28.88 | $ | 34.41 | $ | (5.53 | ) | (16 | )% | ||||||
Average Market Off-Peak Spark Spreads ($/MWh) (3): | |||||||||||||||
Commonwealth Edison (NI Hub) | $ | 4.68 | $ | 2.97 | $ | 1.71 | 58 | % | |||||||
PJM West | $ | 13.10 | $ | 10.71 | $ | 2.39 | 22 | % | |||||||
North of Path 15 (NP 15) | $ | 6.03 | $ | 7.75 | $ | (1.72 | ) | (22 | )% | ||||||
New York—Zone A | $ | 8.32 | $ | 14.12 | $ | (5.80 | ) | (41 | )% | ||||||
Mass Hub | $ | 3.46 | $ | 1.05 | $ | 2.41 | 230 | % | |||||||
AD Hub | $ | 13.36 | $ | 16.22 | $ | (2.86 | ) | (18 | )% | ||||||
Average natural gas price—Henry Hub ($/MMBtu) (4) | $ | 2.31 | $ | 2.78 | $ | (0.47 | ) | (17 | )% |
(1) | IMA is an internal measurement calculation that reflects the percentage of generation available when market prices are such that these units could be profitably dispatched. This calculation excludes certain events outside of management control such as weather related issues. |
(2) | Reflects actual production as a percentage of available capacity. |
(3) | Reflects the simple average of the on- and off-peak spark spreads available to a 7.0 MMBtu/MWh heat rate generator selling power at day-ahead prices and buying delivered natural gas at a daily cash market price and does not reflect spark spreads available to us. |
(4) | Reflects the average of daily quoted prices for the periods presented and does not reflect costs incurred by us. |
(5) | Reflects the activity for the period in which the Acquisitions were included in our consolidated results. |
2014-2015 | 2015-2016 | 2016-2017 | ||||
Price per MW-day | $16.75 | $150.00 | $72.00 |
2016-2017 | 2017-2018 | 2018-2019 | 2019-2020 | |||||
Coal Segment: | ||||||||
Capacity sold (MW) | 1,011 | 1,075 | 242 | 185 | ||||
Average price per kW-month | $2.75 | $3.39 | $2.68 | $2.60 | ||||
IPH Segment: | ||||||||
Capacity sold (MW) | 2,246 | 1,899 | 1,518 | 570 | ||||
Average price per kW-month | $4.30 | $4.63 | $5.12 | $5.20 |
2014-2015 | 2015-2016 | 2016-2017 | 2017-2018 | 2018-2019 | 2019-2020 | |||||||
Price per kW-month | $3.21 | $3.43 | $3.15 | $7.03 | $9.55 | $7.03 |
2016-2017 | 2017-2018 | 2018-2019 | 2019-2020 | |||||
Capacity sold (MW) | 3,683 | 2,186 | 2,195 | 2,240 | ||||
Average price per kW-month | $3.24 | $6.99 | $9.64 | $7.03 |
2014-2015 | 2015-2016 | 2016-2017 | 2017-2018 | 2018-2019 | 2019-2020 | |||||||||||||||||||||||||||||||||||
Legacy Capacity | Legacy Capacity | Legacy Capacity | CP | Legacy Capacity | CP | Base | CP | Base | CP | |||||||||||||||||||||||||||||||
RTO zone, price per MW-day | $ | 125.99 | $ | 136.00 | $ | 59.37 | $ | 134.00 | $ | 120.00 | $ | 151.50 | $ | 149.98 | $ | 164.77 | $ | 80.00 | $ | 100.00 | ||||||||||||||||||||
MAAC zone, price per MW-day | $ | 136.50 | $ | 167.46 | $ | 119.13 | $ | 134.00 | $ | 120.00 | $ | 151.50 | $ | 149.98 | $ | 164.77 | $ | 80.00 | $ | 100.00 | ||||||||||||||||||||
EMAAC zone, price per MW-day | $ | 136.50 | $ | 167.46 | $ | 119.13 | $ | 134.00 | $ | 120.00 | $ | 151.50 | $ | 210.63 | $ | 225.42 | $ | 99.77 | $ | 119.77 | ||||||||||||||||||||
COMED zone, price per MW-day | $ | 125.99 | $ | 136.00 | $ | 59.37 | $ | 134.00 | $ | 120.00 | $ | 151.50 | $ | 200.21 | $ | 215.00 | $ | 182.77 | $ | 202.77 | ||||||||||||||||||||
ATSI zone, price per MW-day | $ | 125.99 | $ | 357.00 | $ | 114.23 | $ | 134.00 | $ | 120.00 | $ | 151.50 | $ | 149.98 | $ | 164.77 | $ | 80.00 | $ | 100.00 |
2016-2017 | 2017-2018 | 2018-2019 | 2019-2020 | |||||
Capacity sold (MW) | 9,762 | 10,837 | 9,911 | 9,803 | ||||
Average price per MW-day | $120.53 | $137.27 | $182.46 | $135.49 |
Winter 2014-2015 | Summer 2015 | Winter 2015-2016 | Summer 2016 | Winter 2016-2017 | ||||||
Price per kW-month | $2.90 | $3.50 | $1.25 | $3.62 | $0.75 |
Summer 2016 | Winter 2016-2017 | Summer 2017 | Winter 2017-2018 | Summer 2018 | Winter 2018-2019 | Summer 2019 | ||||||||
Capacity sold (MW) | 927 | 839 | 868 | 580 | 565 | 330 | 255 | |||||||
Average price per kW-month | $3.36 | $2.47 | $3.44 | $3.14 | $3.66 | $3.32 | $3.39 |
Remainder of 2016 | 2017 | 2018 | 2019 | |||||
Capacity sold (Avg MW) | 230 | 725 | 400 | 850 |
(amounts in millions) | Less than 1 Year | 1 - 3 Years | 3 - 5 Years | More than 5 Years | Total | |||||||||||||||
Coal segment | $ | 1 | $ | 98 | $ | 56 | $ | 60 | $ | 215 | ||||||||||
IPH segment | 1 | 86 | 10 | — | 97 | |||||||||||||||
Total Consolidated ELGs | $ | 2 | $ | 184 | $ | 66 | $ | 60 | $ | 312 |
Projected Obligation by Period | ||||||||||||||||||||||||
(amounts in millions) | NPV | Less than 1 Year | 1 - 3 Years | 3 - 5 Years | More than 5 Years | Total | ||||||||||||||||||
Coal | ||||||||||||||||||||||||
CCR | $ | 121 | $ | — | $ | 28 | $ | 41 | $ | 72 | $ | 141 | ||||||||||||
Non-CCR | 58 | 1 | 15 | 5 | 113 | 134 | ||||||||||||||||||
Total Coal segment | 179 | 1 | 43 | 46 | 185 | 275 | ||||||||||||||||||
Gas | ||||||||||||||||||||||||
Non-CCR | 22 | — | 11 | — | 45 | 56 | ||||||||||||||||||
Total Gas segment | 22 | — | 11 | — | 45 | 56 | ||||||||||||||||||
IPH | ||||||||||||||||||||||||
CCR | 70 | — | 6 | 42 | 63 | 111 | ||||||||||||||||||
Non-CCR | 12 | — | 7 | 10 | 91 | 108 | ||||||||||||||||||
Total IPH segment | 82 | — | 13 | 52 | 154 | 219 | ||||||||||||||||||
Total Consolidated AROs | $ | 283 | $ | 1 | $ | 67 | $ | 98 | $ | 384 | $ | 550 |
(amounts in millions) | As of and for the Nine Months Ended September 30, 2016 | |||
Fair value of portfolio at December 31, 2015 | $ | (90 | ) | |
Risk management losses recognized through the statement of operations in the period, net | (3 | ) | ||
Contracts realized or otherwise settled during the period | 78 | |||
Changes in collateral/margin netting | (33 | ) | ||
Fair value of portfolio at September 30, 2016 | $ | (48 | ) |
(amounts in millions) | Total | 2016 | 2017 | 2018 | 2019 | 2020 | Thereafter | |||||||||||||||||||||
Market quotations (1)(2) | $ | (98 | ) | $ | (1 | ) | $ | (77 | ) | $ | (14 | ) | $ | (6 | ) | $ | — | $ | — | |||||||||
Prices based on models (2) | (23 | ) | (6 | ) | (14 | ) | (6 | ) | 1 | 2 | — | |||||||||||||||||
Total (3) | $ | (121 | ) | $ | (7 | ) | $ | (91 | ) | $ | (20 | ) | $ | (5 | ) | $ | 2 | $ | — |
(3) | Excludes $73 million of broker margin and collateral that has been netted against Risk management liabilities in our unaudited consolidated balance sheets. Please read Note 5—Risk Management Activities, Derivatives, and Financial Instruments for further discussion. |
• | beliefs and assumptions about weather and general economic conditions; |
• | beliefs, assumptions, and projections regarding the demand for power, generation volumes, and commodity pricing, including natural gas prices and the timing of a recovery in power market prices, if any; |
• | beliefs and assumptions about market competition, generation capacity, and regional supply and demand characteristics of the wholesale and retail power markets, including the anticipation of plant retirements and higher market pricing over the longer term; |
• | sufficiency of, access to, and costs associated with coal, fuel oil, and natural gas inventories and transportation thereof; |
• | the effects of, or changes to, MISO, PJM, CAISO, NYISO, or ISO-NE power and capacity procurement processes; |
• | expectations regarding, or impacts of, environmental matters, including costs of compliance, availability and adequacy of emission credits, and the impact of ongoing proceedings and potential regulations or changes to current regulations, including those relating to climate change, air emissions, cooling water intake structures, coal combustion byproducts, and other laws and regulations that we are, or could become, subject to, which could increase our costs, result in an impairment of our assets, cause us to limit or terminate the operation of certain of our facilities, or otherwise have a negative financial effect; |
• | beliefs about the outcome of legal, administrative, legislative, and regulatory matters; |
• | projected operating or financial results, including anticipated cash flows from operations, revenues, and profitability; |
• | our focus on safety and our ability to efficiently operate our assets so as to capture revenue generating opportunities and operating margins; |
• | our ability to mitigate forced outage risk, including managing risk associated with CP in PJM and performance incentives in ISO-NE; |
• | our ability to optimize our assets through targeted investment in cost effective technology enhancements; |
• | the effectiveness of our strategies to capture opportunities presented by changes in commodity prices and to manage our exposure to energy price volatility; |
• | efforts to secure retail sales and the ability to grow the retail business; |
• | efforts to identify opportunities to reduce congestion and improve busbar power prices; |
• | ability to mitigate impacts associated with expiring RMR and/or capacity contracts; |
• | expectations regarding our compliance with the Credit Agreement, including collateral demands, interest expense, any applicable financial ratios, and other payments; |
• | expectations regarding performance standards and capital and maintenance expenditures; |
• | beliefs concerning the restructuring of Genco, including the RSA; |
• | the timing and anticipated benefits to be achieved through our company-wide improvement programs, including our PRIDE initiative; |
• | anticipated timing, outcome, and impact of the expected retirement of Brayton Point and the shutdown of Baldwin Units 1 and 3, and Moss Landing 6 and 7; |
• | beliefs about the costs and scope of the ongoing demolition and site remediation efforts at the Vermilion and Wood River facilities and any potential future remediation obligations at the South Bay facility; |
• | expectations regarding the synergies, completion, timing and anticipated benefits of the Delta Transaction; |
• | expectations regarding the completion and timing of the Elwood Energy facility sale, and anticipated use of proceeds from such sale; and |
• | beliefs regarding redevelopment efforts for the Morro Bay facility. |
(amounts in millions) | September 30, 2016 | December 31, 2015 | ||||||
One day VaR—95 percent confidence level | $ | 8 | $ | 20 | ||||
One day VaR—99 percent confidence level | $ | 11 | $ | 29 | ||||
Average VaR—95 percent confidence level for the rolling twelve months ended | $ | 12 | $ | 8 |
(amounts in millions) | Investment Grade Quality | |||
Type of Business: | ||||
Financial institutions | $ | 33 | ||
Utility and power generators | 16 | |||
Total | $ | 49 |
September 30, 2016 | December 31, 2015 | |||||||
Interest rate swaps (in millions of U.S. dollars) | $ | 771 | $ | 777 | ||||
Fixed interest rate paid (percent) | 3.19 | % | 3.19 | % |
Exhibit Number | Description | ||
2.1 | Membership Interest Purchase Agreement, dated as of August 3, 2016, by and among Elwood Expansion Holdings, LLC, Elwood Energy Holdings, LLC, Tomcat Power, LLC, Elwood Energy Holdings II, LLC and J-POWER USA Development Co., Ltd. *(incorporated by reference to Exhibit 2.1 to the Current Report on Form 8-K of Dynegy Inc. filed on August 4, 2016 File No. 001-33443). | ||
4.1 | 2025 Notes Indenture, dated October 11, 2016, between Dynegy Inc. and Wilmington Trust, National Association (incorporated by reference to Exhibit 4.1 to the Current Report on Form 8-K of Dynegy Inc. filed on October 11, 2016 File No. 001-33443). | ||
**10.1 | First Amendment to the Letter of Credit Reimbursement Agreement, dated August 10, 2016 among Dynegy Inc., Macquarie Bank Limited and Macquarie Energy LLC. | ||
10.2 | Guaranty, dated as of August 3, 2016, by Dynegy Inc., for the benefit of J-POWER USA Development Co., Ltd. (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K of Dynegy Inc. filed on August 4, 2016 File No. 001-33443). | ||
10.3 | Restructuring Support Agreement dated October 14, 2016 (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K of Dynegy Inc. filed on October 14, 2016 File No. 001-33443). | ||
**10.4 | Amendment to Restructuring Support Agreement dated October 21, 2016. | ||
**10.5 | Amendment to Executive Participation Agreement by and between Dynegy Inc. and Mario E. Alonso effective October 24, 2016 | ||
**31.1 | Chief Executive Officer Certification Pursuant to Rule 13a-14(a) and 15d-14(a), As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. | ||
**31.2 | Chief Financial Officer Certification Pursuant to Rule 13a-14(a) and 15d-14(a), As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. | ||
†32.1 | Chief Executive Officer Certification Pursuant to 18 United States Code Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. | ||
†32.2 | Chief Financial Officer Certification Pursuant to 18 United States Code Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. | ||
**101.INS | XBRL Instance Document | ||
**101.SCH | XBRL Taxonomy Extension Schema Document | ||
**101.CAL | XBRL Taxonomy Extension Calculation Linkbase Document | ||
**101.DEF | XBRL Taxonomy Extension Definition Linkbase Document | ||
**101.LAB | XBRL Taxonomy Extension Label Linkbase Document | ||
**101.PRE | XBRL Taxonomy Extension Presentation Linkbase Document |
* | Schedules and exhibits to the Membership Interest Purchase Agreement have been omitted pursuant to Item 601(b)(2) of Regulation S-K. Dynegy will furnish the omitted schedules and exhibits to the Securities and Exchange Commission upon request by the Commission. |
DYNEGY INC. | |||
Date: | November 2, 2016 | By: | /s/ CLINT C. FREELAND |
Clint C. Freeland Executive Vice President and Chief Financial Officer |
Americas 91190406 (2K) |
Americas 91190406 (2K) |
Attention: | Executive Director, Legal Risk Management Division, Commodities and Financial Markets |
Americas 91190406 (2K) |
Americas 91190406 (2K) |
i. | The reference to the phrase “Effective Date” in clause (e) and clause (f) of such Article shall mean the “First Amendment Effective Date”; |
ii. | The reference to “December 31, 2013” in clause (f) of such Article shall mean “December 31, 2015” and the reference to “March 31, 2014” in such clause (f) shall mean “March 31, 2016”; and |
iii. | The reference to “December 31, 2013” in clause (g) of such Article shall mean “December 31, 2015.” |
Americas 91190406 (2K) |
Americas 91190406 (2K) |
By: | /s/ Siddharth Manjeshwar Name: Siddharth Manjeshwar Title: Vice President and Treasurer |
Americas 91190406 (2K) |
By: | /s/ Byron den Hertog Name: Byron den Hertog Title: Division Director |
By: | /s/ Fiona Smith Name: Fiona Smith Title: Division Director |
By: | /s/ Sherri Brudner Name: Sherri Brudner Title: Division Director |
Americas 91190406 (2K) |
1. | Section 5 of the Agreement is amended, to be and to read as follows: |
2. | The Agreement is amended to add a new Section 11, to be and to read as follows: |
3. | This Amendment is hereby deemed to be an amendment to each currently outstanding Company equity award held by the Executive on the date hereof to the extent necessary to cause the underlying award agreement to reflect the terms of this Amendment. |
1. | I have reviewed this report on Form 10-Q of Dynegy Inc.; |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
(a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
(b) | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
(c) | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
(d) | Disclosed in this quarterly report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5. | The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
(a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
(b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
Date: | November 2, 2016 | By: | /s/ ROBERT C. FLEXON |
Robert C. Flexon President and Chief Executive Officer |
1. | I have reviewed this report on Form 10-Q of Dynegy Inc.; |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
(a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
(b) | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
(c) | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
(d) | Disclosed in this quarterly report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5. | The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
(a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
(b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
Date: | November 2, 2016 | By: | /s/ CLINT C. FREELAND |
Clint C. Freeland Executive Vice President and Chief Financial Officer |
(1) | the Report fully complies with the requirements of Section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934, and |
(2) | the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company at the dates and for the periods indicated. |
Date: | November 2, 2016 | By: | /s/ ROBERT C. FLEXON |
Robert C. Flexon President and Chief Executive Officer |
(1) | the Report fully complies with the requirements of Section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934, and |
(2) | the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company at the dates and for the periods indicated. |
Date: | November 2, 2016 | By: | /s/ CLINT C. FREELAND |
Clint C. Freeland Executive Vice President and Chief Financial Officer |
Document and Entity Information - shares |
9 Months Ended | |
---|---|---|
Sep. 30, 2016 |
Oct. 12, 2016 |
|
Document and Entity Information [Abstract] | ||
Entity Registrant Name | DYNEGY INC. | |
Entity Central Index Key | 0001379895 | |
Document Type | 10-Q | |
Document Period End Date | Sep. 30, 2016 | |
Amendment Flag | false | |
Current Fiscal Year End Date | --12-31 | |
Entity Current Reporting Status | Yes | |
Entity Filer Category | Large Accelerated Filer | |
Entity Common Stock, Shares Outstanding | 117,293,478 | |
Document Fiscal Year Focus | 2016 | |
Document Fiscal Period Focus | Q3 |
CONSOLIDATED BALANCE SHEETS (PARENTHETICAL) - USD ($) $ in Millions |
9 Months Ended | 12 Months Ended |
---|---|---|
Sep. 30, 2016 |
Dec. 31, 2015 |
|
Allowance for doubtful accounts | $ 1 | $ 1 |
Common stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Common stock, shares authorized | 420,000,000 | 420,000,000 |
Common stock, shares issued | 128,619,600 | 128,228,477 |
Common stock, shares outstanding | 117,293,478 | 116,902,355 |
Series A 5.375% mandatory convertible preferred stock | ||
Preferred stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Preferred stock, series A 5.375% | 5.375% | 5.375% |
Preferred stock, shares authorized | 20,000,000 | 20,000,000 |
Preferred stock, shares issues | 4,000,000 | 4,000,000 |
Preferred stock, shares outstanding | 4,000,000 | 4,000,000 |
CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Millions, $ in Millions |
3 Months Ended | 9 Months Ended | |||||||
---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
||||||
Income Statement [Abstract] | |||||||||
Revenues | $ 1,184 | $ 1,232 | $ 3,211 | $ 2,854 | |||||
Cost of sales, excluding depreciation expense | (660) | (621) | (1,698) | (1,494) | |||||
Gross margin | 524 | 611 | 1,513 | 1,360 | |||||
Operating and maintenance expense | (218) | (219) | (695) | (580) | |||||
Depreciation expense | (163) | (174) | (494) | (413) | |||||
Impairments | (212) | (74) | (857) | (74) | |||||
General and administrative expense | (41) | (29) | (117) | (94) | |||||
Acquisition and integration costs | (7) | (8) | (8) | (121) | |||||
Other | 0 | 0 | (16) | (1) | |||||
Operating income (loss) | (117) | 107 | (674) | 77 | |||||
Earnings (losses) from unconsolidated investment | 4 | (4) | 7 | (1) | |||||
Interest expense | (166) | (145) | (449) | (413) | |||||
Other income and expense, net | 29 | 46 | 60 | 45 | |||||
Income (loss) before income taxes | (250) | 4 | (1,056) | (292) | |||||
Income tax benefit (expense) (Note 15) | 1 | (28) | (6) | 473 | |||||
Net income (loss) | (249) | (24) | (1,062) | 181 | |||||
Less: Net loss attributable to noncontrolling interest | 0 | 0 | (2) | (3) | |||||
Net income (loss) attributable to Dynegy Inc. | (249) | (24) | (1,060) | 184 | |||||
Less: Dividends on preferred stock | 5 | 5 | 16 | 16 | |||||
Income (loss) from continuing operations attributable to Dynegy Inc. common stockholders for basic earnings (loss) per share | $ (254) | $ (29) | $ (1,076) | $ 168 | |||||
Earnings (Loss) Per Share (Note 18): | |||||||||
Basic earnings (loss) per share attributable to Dynegy Inc. common stockholders (in dollars per share) | [1] | $ (1.81) | $ (0.23) | $ (8.54) | $ 1.33 | ||||
Diluted earnings (loss) per share attributable to Dynegy Inc. common stockholders (in dollars per share) | [2] | $ (1.81) | $ (0.23) | $ (8.54) | $ 1.31 | ||||
Basic shares outstanding (shares) | [1] | 140 | 126 | 126 | 126 | ||||
Diluted shares outstanding (shares) | 140 | 126 | 126 | 140 | |||||
|
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
|
Statement of Comprehensive Income [Abstract] | ||||
Net income (loss) | $ (249) | $ (24) | $ (1,062) | $ 181 |
Other comprehensive income (loss) before reclassifications: | ||||
Actuarial gain and plan amendments (net of tax of zero, $2, zero, and $2 for each respective period) | 0 | 13 | 0 | 8 |
Amounts reclassified from accumulated other comprehensive income: | ||||
Amortization of unrecognized prior service credit (net of tax of zero for each respective period) | (2) | (1) | (4) | (3) |
Other comprehensive income (loss), net of tax | (2) | 12 | (4) | 5 |
Comprehensive income (loss) | (251) | (12) | (1,066) | 186 |
Comprehensive income (loss) attributable to noncontrolling interest | 0 | 1 | (2) | (2) |
Total comprehensive income (loss) attributable to Dynegy Inc. | $ (251) | $ (13) | $ (1,064) | $ 188 |
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (PARENTHETICAL) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
|
Statement of Comprehensive Income [Abstract] | ||||
Tax on actuarial loss | $ 0 | $ 2 | $ 0 | $ 2 |
Tax on amortization of unrecognized prior service cost (credit) and actuarial loss (gain) | $ 0 | $ 0 | $ 0 | $ 0 |
Basis of Presentation and Organization |
9 Months Ended |
---|---|
Sep. 30, 2016 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Basis of Presentation and Organization | Note 1—Basis of Presentation and Organization The accompanying unaudited consolidated financial statements have been prepared in accordance with the instructions to interim financial reporting as prescribed by the SEC. The year-end consolidated balance sheet data was derived from audited consolidated financial statements, but does not include all disclosures required by the Generally Accepted Accounting Principles of the United States of America (“GAAP”). The unaudited consolidated financial statements contained in this report include all material adjustments of a normal recurring nature that, in the opinion of management, are necessary for a fair presentation of the results for the interim periods. Certain prior period amounts in our unaudited consolidated financial statements have been reclassified to conform to current year presentation. These interim financial statements should be read together with the consolidated financial statements and notes thereto included in our annual report on Form 10-K for the year ended December 31, 2015, filed with the SEC on February 25, 2016, which we refer to as our “Form 10-K.” Unless the context indicates otherwise, throughout this report, the terms “Dynegy,” “the Company,” “we,” “us,” “our,” and “ours” are used to refer to Dynegy Inc. and its direct and indirect subsidiaries. Our current business operations are focused primarily on the unregulated power generation sector of the energy industry. We report the results of our power generation business as three segments in our unaudited consolidated financial statements: (i) the Coal segment (“Coal”), (ii) the IPH segment (“IPH”), and (iii) the Gas segment (“Gas”). Our consolidated financial results also reflect corporate-level expenses such as general and administrative expense, interest expense, and income tax benefit (expense). All significant intercompany transactions have been eliminated. Please read Note 20—Segment Information for further discussion. IPH and its direct and indirect subsidiaries are organized into ring-fenced groups in order to maintain corporate separateness from Dynegy and its other subsidiaries. Certain of the entities in the IPH segment, including Illinois Power Generating Company (“Genco”), have an independent director whose consent is required for certain corporate actions, including material transactions with affiliates. Further, entities within the IPH segment present themselves to the public as separate entities. They maintain separate books, records and bank accounts, and separately appoint officers. Furthermore, they pay liabilities from their own funds, conduct business in their own names, and have restrictions on pledging their assets for the benefit of certain other persons. These provisions restrict our ability to move cash out of these entities without meeting certain requirements as set forth in the governing documents. Genco’s $825 million Senior Notes are non-recourse to Dynegy. |
Accounting Policies |
9 Months Ended |
---|---|
Sep. 30, 2016 | |
Accounting Policies [Abstract] | |
Accounting Policies | Note 2—Accounting Policies The accounting policies followed by the Company are set forth in Note 2—Summary of Significant Accounting Policies in our Form 10-K. The accompanying unaudited consolidated financial statements include our accounts and the accounts of our majority-owned or controlled subsidiaries. Accounting policies for all of our operations are in accordance with GAAP. There have been no significant changes to our accounting policies during the nine months ended September 30, 2016. Use of Estimates. The preparation of unaudited consolidated financial statements in conformity with GAAP requires management to make informed estimates and judgments that affect our reported financial position and results of operations based on currently available information. Actual results could differ materially from our estimates. The results of operations for the interim periods presented in this Form 10-Q are not necessarily indicative of the results to be expected for the full year or any other interim period due to seasonal fluctuations in demand for our energy products and services, changes in commodity prices, timing of maintenance and other expenditures, and other factors. Accounting Standards Adopted During the Current Period Hybrid Financial Instruments. In November 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-16-Derivatives and Hedging (Topic 815): Determining Whether the Host Contract in a Hybrid Financial Instrument Issued in the Form of a Share Is More Akin to Debt or Equity. The amendments in this ASU clarify how current GAAP should be interpreted in evaluating the economic characteristics and risks of a host contract in a hybrid financial instrument that is issued in the form of a share. Specifically, the amendments clarify that an entity should consider all relevant terms and features, including the embedded derivative feature being evaluated for bifurcation, in evaluating the nature of the host contract. Furthermore, the amendments clarify that no single term or feature would necessarily determine the economic characteristics and risks of the host contract. Rather, the nature of the host contract depends upon the economic characteristics and risks of the entire hybrid financial instrument. The amendments in this ASU also clarify that, in evaluating the nature of a host contract, an entity should assess the substance of the relevant terms and features (i.e., the relative strength of the debt-like or equity-like terms and features given the facts and circumstances) when considering how to weight those terms and features. The adoption of this ASU on January 1, 2016, did not have an impact on our unaudited consolidated financial statements. Debt Issuance Costs. In April 2015, the FASB issued ASU 2015-03-Interest-Imputation of Interest (Subtopic 835-30). The amendments in this ASU require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for our debt issuance costs are not affected by the amendments in this update. In August 2015, the FASB issued ASU 2015-15-Interest-Imputation of Interest (Subtopic 835-30). The amendments in this ASU further clarify the guidance provided in ASU 2015-03 to include the presentation of debt issuance costs in relation to line-of-credit arrangements. The amendments state these costs may be presented as an asset and subsequently amortized ratably over the term of the arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. We adopted these ASUs on January 1, 2016, on a retrospective basis affecting presentation on the unaudited consolidated balance sheets for all periods presented. Accordingly, we reclassified unamortized debt issuance costs of $3 million from Prepayments and other current assets to Debt, current portion, net and $77 million from Other long-term assets to Debt, long-term portion, net within our unaudited consolidated balance sheet as of December 31, 2015. Consolidation. In February 2015, the FASB issued ASU 2015-02-Consolidation (Topic 810). The amendments in this ASU respond to concerns about the current accounting for consolidation of certain legal entities, in particular: (i) consolidation of limited partnerships and similar legal entities, (ii) evaluating fees paid to a decision maker or a service provider as a variable interest, (iii) the effect of fee arrangements on the primary beneficiary determination, (iv) the effect of related parties on the primary beneficiary determination, and (v) consolidation of certain investment funds. The adoption of this ASU on January 1, 2016, did not have an impact on our unaudited consolidated financial statements. Extraordinary and Unusual Items. In January 2015, the FASB issued ASU 2015-01-Income Statement-Extraordinary and Unusual Items (Subtopic 225-20). The amendments in this ASU eliminate from GAAP the concept of extraordinary items and will no longer require separate classification of these items within the statement of operations. Presentation and disclosure guidance for items that are unusual in nature or occur infrequently will be retained and will be expanded to include items that are both unusual in nature and infrequently occurring. The guidance in this ASU is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. The adoption of this ASU on January 1, 2016, did not have an impact on our unaudited consolidated financial statements. Accounting Standards Not Yet Adopted Statement of Cash Flows. In August 2016, the FASB issued ASU 2016-15-Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. To reduce current and future diversity in practice, the amendments in this ASU provide guidance for several cash flow classification issues identified where current GAAP is either unclear or does not include specific guidance. The guidance in this ASU is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2017, with early adoption permitted. We are currently evaluating this ASU and any potential impacts the adoption of this ASU will have on our unaudited consolidated financial statements. Credit Losses. In June 2016, the FASB issued ASU 2016-13-Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments. The amendments in this ASU require the measurement of all expected credit losses for financial assets, which include trade receivables, held at the reporting date based on historical experience, current conditions, and reasonable and supportable forecasts. The guidance in this ASU is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019, with early adoption permitted for interim and annual periods beginning after December 15, 2018. We are currently evaluating this ASU and any potential impacts the adoption of this ASU will have on our unaudited consolidated financial statements. Compensation. In March 2016, the FASB issued ASU 2016-09-Compensation-Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. The amendments in this ASU simplify several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities and classification on the statement of cash flows. The guidance in this ASU is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2016, with early adoption permitted. We are currently evaluating this ASU and any potential impacts the adoption of this ASU will have on our unaudited consolidated financial statements. Debt Instruments. In March 2016, the FASB issued ASU 2016-06-Derivative and Hedging: Contingent Put and Call Options in Debt Instruments. The amendments in this ASU clarify what steps are required when assessing whether the economic characteristics and risks of call (put) options are clearly and closely related to the economic characteristics and risks of their debt hosts, which is one of the criteria for bifurcating an embedded derivative. An entity performing the assessment under the amendments in this ASU is required to assess the embedded call (put) options solely in accordance with the four-step decision sequence. The amendments are effective for public business entities for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years. All entities have the option of adopting the new requirements early, including adoption in an interim period. If an entity early adopts the new requirements in an interim period, it must reflect any adjustments as of the beginning of the fiscal year that includes that interim period. We are currently evaluating this ASU; however, we do not anticipate the adoption of this ASU will have a material impact on our unaudited consolidated financial statements. Leases. In February 2016, the FASB issued ASU 2016-02-Leases (Topic 842). The amendments in this ASU will mainly require lessees to recognize lease assets and lease liabilities, for those leases classified as operating leases under GAAP, in their balance sheet. The lease assets recognized in the balance sheet will represent a right-of-use asset, which is an asset that represents the lessee’s right to use, or control the use of, a specified asset for the lease term. The lease liability recognized in the balance sheet will represent the lessee’s obligation to make lease payments arising from a lease, measured on a discounted basis. The guidance in this ASU is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019, with early adoption permitted. We are currently evaluating this ASU and any potential impacts the adoption of this ASU will have on our unaudited consolidated financial statements. Going Concern. In August 2014, the FASB issued ASU 2014-15-Presentation of Financial Statements-Going Concern (Subtopic 205-40). The amendments in this ASU require management, in connection with preparing financial statements for each annual and interim reporting period, to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date that the financial statements are issued (or within one year after the date that the financial statements are available to be issued, when applicable). Currently, there is no guidance in GAAP about management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern or to provide related footnote disclosures. The amendments in this ASU provide that guidance. In doing so, the amendments should reduce diversity in the timing and content of footnote disclosures. The guidance in this ASU is effective for fiscal years ending after December 15, 2016, and interim periods within those fiscal years, beginning after December 15, 2016, with early adoption permitted. We are currently evaluating this ASU; however, we do not anticipate the adoption of this ASU will have a material impact on our unaudited consolidated financial statements. Revenue from Contracts with Customers. In May 2014, the FASB and International Accounting Standards Board jointly issued ASU 2014-09-Revenue from Contracts with Customers (Topic 606). This ASU, and subsequently issued amendments to the standard, develop a common revenue standard for GAAP and International Financial Reporting Standards by removing inconsistencies and weaknesses in revenue requirements, providing a more robust framework for addressing revenue issues, improving comparability of revenue recognition practices, providing more useful information to users of financial statements, and simplifying the preparation of financial statements. The guidance in this ASU and its amendments is effective for interim and annual periods beginning after December 15, 2017, with early adoption permitted for interim and annual periods beginning after December 15, 2016. We are currently evaluating this ASU; however, we do not anticipate the adoption of this ASU will have a material impact on our unaudited consolidated financial statements. |
Acquisitions |
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Acquisitions | Note 3—Acquisitions Delta Transaction. On February 24, 2016, Atlas Power Finance, LLC (“Atlas” or the “Purchaser”), a wholly owned subsidiary of Atlas Power, LLC (“Atlas Power”), entered into a Stock Purchase Agreement, as amended and restated on June 27, 2016, (the “Delta Stock Purchase Agreement”) with GDF SUEZ Energy North America, Inc. (“GSENA”) and International Power, S.A. (the “Seller”), indirect subsidiaries of Engie S.A. Pursuant to the Delta Stock Purchase Agreement, the Purchaser will acquire approximately 9,058 MW of generation, including (i) 15 natural gas-fired facilities located in Illinois, Massachusetts, New Jersey, Ohio, Pennsylvania, Texas, Virginia, and West Virginia, (ii) one coal-fired facility in Texas, and (iii) one waste coal-fired facility in Pennsylvania for a base purchase price of approximately $3.3 billion in cash, subject to certain adjustments (the “Delta Transaction”). On June 27, 2016, a wholly owned subsidiary of Dynegy acquired the 35 percent interest in Atlas Power (the “ECP Buyout”) held by certain affiliated investment funds of Energy Capital Partners III, LLC (the “ECP Funds”). As a result, Atlas Power became an indirect wholly owned subsidiary of Dynegy. In accordance with the agreement with Energy Capital Partners (“ECP”), Dynegy will pay ECP $375 million (the “ECP Buyout Price”) on the later of December 31, 2016, or three months after the closing of the Delta Transaction (the “First Payment Date”). Alternatively, Dynegy may pay the ECP Buyout Price after the First Payment Date, but in such case, the ECP Buyout Price would be subject to quarterly escalation up to a maximum of $468.5 million. Dynegy intends to pay the buyout price at or prior to the First Payment Date. The Purchaser and the Seller have agreed to indemnify the other for breaches of representations, warranties and covenants, and for certain other matters, subject to certain exceptions and limitations. The Delta Stock Purchase Agreement contains certain termination rights for both the Purchaser and the Seller, including if the closing does not occur within 12 months following the date of the Delta Stock Purchase Agreement. In the event the Delta Stock Purchase Agreement is terminated under certain circumstances, including the failure to obtain certain regulatory approvals, the Purchaser must pay GSENA the reverse termination fee of $132 million discussed below. Dynegy also entered into an amended and restated limited guarantee in favor of GSENA, pursuant to which Dynegy guarantees 100 percent of the Purchaser’s obligation to pay the reverse termination fee of $132 million if such fee becomes payable. Please read Note 14—Commitments and Contingencies—Indemnifications and Guarantees for further discussion. The Delta Stock Purchase Agreement includes customary representations, warranties and covenants by the parties. The Delta Transaction is subject to various closing conditions, including (i) expiration of the applicable waiting period, which was received on April 1, 2016, under the Hart-Scott-Rodino Act; (ii) obtaining required approvals from the FERC and the Public Utility Commission of Texas, the latter of which was received on July 20, 2016; (iii) no injunction or other orders preventing the consummation of the transactions contemplated under the Delta Stock Purchase Agreement; (iv) the completion of GSENA’s internal reorganization in all material respects in accordance with an exhibit attached to the Delta Stock Purchase Agreement; (v) the continuing accuracy of each party’s representations and warranties, and (vi) the satisfaction of other customary conditions. On June 8, 2016, we received a letter from FERC requesting additional information, to which we have responded. We expect the Delta Transaction to close in the fourth quarter of 2016 after satisfaction or waiver of these closing conditions. Delta Transaction Financing. On February 24, 2016, Dynegy entered into a Stock Purchase Agreement with Terawatt Holdings, LP (“Terawatt”), an affiliate of the ECP Funds (the “PIPE Stock Purchase Agreement”), pursuant to which Dynegy will sell and issue to Terawatt at the closing of the Delta Transaction 13,711,152 shares of Dynegy common stock for $150 million (the “PIPE Transaction”). The closing of the PIPE Transaction is contingent on the closing of the Delta Transaction. In addition, Dynegy has agreed to enter into an Investor Rights Agreement, in the form attached to the PIPE Stock Purchase Agreement (the “Investor Rights Agreement”), with Terawatt at the closing of the PIPE Transaction. Under the Investor Rights Agreement, Terawatt will be entitled to certain rights, including certain registration rights, rights of first refusal with respect to issuances of our common stock and the designation of one individual to serve on our Board of Directors as long as Terawatt and its affiliates own at least 10 percent of our common stock. Further, the Investor Rights Agreement subjects Terawatt to certain obligations, including certain voting obligations and customary standstill and lock-up periods. On June 21, 2016, pursuant to a registered public offering, Dynegy issued 4.6 million tangible equity units (“TEUs”) for proceeds of $446 million, net of issuance costs of $14 million. Please read Note 12—Tangible Equity Units for further discussion. On June 27, 2016, Dynegy Finance IV, Inc. (“Finance IV”), a direct wholly-owned subsidiary of Dynegy, entered into a term loan credit agreement with certain lenders providing for a $2.0 billion, seven-year senior secured term loan facility (the “Tranche C Term Loan”), the net proceeds of which were placed into escrow pending the closing of the Delta Transaction. Under the escrow agreement, the applicable borrowings are subject to full liquidation and release to the lenders if the Delta Transaction is terminated or not consummated by February 24, 2017. Also, on June 27, 2016, Dynegy entered into a Third Amendment to the Credit Agreement (the “Third Amendment”), which, upon the release of funds from escrow, provides for (i) a $75 million revolving loan commitment increase to the incremental tranche B revolving loan commitments (the “Incremental Tranche B Revolver”), which has terms substantially the same as the terms of the existing incremental tranche B revolving loan commitments under the Credit Agreement, and (ii) conversion of the Tranche C Term Loan to an incremental $2.0 billion senior secured tranche C term loan. Please read Note 13—Debt—Credit Agreement and Finance IV Credit Agreement for further discussion. Dynegy intends to use the net proceeds associated with the PIPE Transaction, the TEUs, the Tranche C Term Loan, borrowings under its revolving credit facilities, and cash-on-hand to fund the Delta Transaction and pay related fees and expenses. EquiPower Acquisition. On April 1, 2015 (the “EquiPower Closing Date”), pursuant to the terms of a stock purchase agreement dated August 21, 2014, as amended, our wholly-owned subsidiary, Dynegy Resource II, LLC purchased 100 percent of the equity interests in EquiPower Resources Corp. (“ERC”) from certain affiliates of ECP (collectively, the “ERC Sellers”) thereby acquiring (i) five combined cycle natural gas-fired facilities in Connecticut, Massachusetts, and Pennsylvania, (ii) a partial interest in one natural gas-fired peaking facility in Illinois, (iii) two gas and oil-fired peaking facilities in Ohio, and (iv) one coal-fired facility in Illinois (the “ERC Acquisition”). On the EquiPower Closing Date, in a related transaction, pursuant to a stock purchase agreement and plan of merger dated August 21, 2014, as amended, our wholly-owned subsidiary Dynegy Resource III, LLC purchased 100 percent of the equity interests in Brayton Point Holdings, LLC (“Brayton”) from certain affiliates of ECP (collectively, the “Brayton Sellers” and together with the ERC Sellers, the “ECP Sellers”), thereby acquiring a coal-fired facility in Massachusetts (the “Brayton Acquisition”). The ERC Acquisition and the Brayton Acquisition (collectively, the “EquiPower Acquisition”) added approximately 6,300 MW of generation in Connecticut, Illinois, Massachusetts, Ohio, and Pennsylvania for an aggregate base purchase price of approximately $3.35 billion in cash plus approximately $105 million in common stock of Dynegy, subject to certain adjustments. In aggregate, the resulting operations from the two coal-fired facilities acquired from the ECP Sellers are reported within our Coal segment, while related operations from the six natural gas-fired and two gas and oil-fired facilities are reported within our Gas segment. Duke Midwest Acquisition. On April 2, 2015, pursuant to the terms of the purchase and sale agreement dated August 21, 2014, as amended, our wholly-owned subsidiary Dynegy Resource I, LLC purchased 100 percent of the membership interests in Duke Energy Commercial Asset Management, LLC and Duke Energy Retail Sales, LLC, from two affiliates of Duke Energy Corporation (collectively, “Duke Energy”), thereby acquiring approximately 6,200 MW of generation in (i) three combined cycle natural gas-fired facilities located in Ohio and Pennsylvania, (ii) two natural gas-fired peaking facilities located in Ohio and Illinois, (iii) one oil-fired peaking facility located in Ohio, (iv) partial interests in five coal-fired facilities located in Ohio, and (v) a retail energy business for a base purchase price of approximately $2.8 billion in cash (the “Duke Midwest Acquisition”), subject to certain adjustments. We operate two of the five coal-fired facilities, the Miami Fort and Zimmer facilities, with other owners operating the three remaining facilities. The operations from the retail energy business, the five coal-fired and the one oil-fired facilities acquired from Duke Energy are reported within our Coal segment, while related operations from the five natural gas-fired facilities are reported within our Gas segment. Business Combination Accounting. The EquiPower Acquisition and the Duke Midwest Acquisition (collectively, the “Acquisitions”) have been accounted for in accordance with Accounting Standards Codification (“ASC”) 805, Business Combinations, with identifiable assets acquired and liabilities assumed recorded at their estimated fair values on the acquisition dates, April 1, 2015 and April 2, 2015, respectively. The valuation of these assets and liabilities is classified as Level 3 within the fair value hierarchy. To fair value working capital, we used available market information. Asset retirement obligations (“AROs”) were recorded in accordance with ASC 410, Asset Retirement and Environmental Obligations. To fair value the acquired property, plant and equipment (“PP&E”), we used a discounted cash flow (“DCF”) analysis based upon a debt-free, free cash flow model. The DCF model was created for each power generation facility based on its remaining useful life, and included gross margin forecasts for each facility using forward commodity market prices obtained from third party quotations for the years 2015 and 2016. For the years 2017 through 2024, we used gross margin forecasts based upon commodity and capacity price curves developed internally using forward New York Mercantile Exchange natural gas prices and supply and demand factors. For periods beyond 2024, we assumed a 2.5 percent growth rate. We also used management’s forecasts of operations and maintenance expense, general and administrative expense, and capital expenditures for the years 2015 through 2019 and assumed a 2.5 percent growth rate, based upon management’s view of future conditions, thereafter. The resulting cash flows were then discounted using plant specific discount rates of approximately 8 percent to 10 percent for gas-fired generation facilities and approximately 9 percent to 13 percent for coal-fired generation facilities, based upon the asset’s age, efficiency, region, and years until retirement. Contracts with terms that were not at current market prices were also valued using a DCF analysis. The cash flows generated by the contracts were compared with their cash flows based on current market prices with the resulting difference recorded as either an intangible asset or liability. The 3,460,053 shares of common stock of Dynegy, issued as part of the consideration for the EquiPower Acquisition, were valued at approximately $105 million based on the closing price of Dynegy’s common stock on the EquiPower Closing Date. As of June 30, 2016, we completed our valuation of the assets acquired and liabilities assumed in connection with the Acquisitions. The following table summarizes the consideration paid and the fair value amounts recognized for the assets acquired and liabilities assumed related to the EquiPower Acquisition and Duke Midwest Acquisition, as of the respective acquisition dates, April 1, 2015 and April 2, 2015:
No acquisition costs related to the Acquisitions were incurred during the three and nine months ended September 30, 2016. We incurred acquisition costs of $1 million and $86 million related to the Acquisitions for the three and nine months ended September 30, 2015, respectively. These acquisition costs are included in Acquisition and integration costs in our unaudited consolidated statements of operations. Revenues of $543 million and $1,675 million and operating loss of $34 million and income of $146 million, attributable to the Acquisitions, are included in our unaudited consolidated statements of operations for the three and nine months ended September 30, 2016, respectively. Revenues of $626 million and $1,128 million and operating income of $120 million and $190 million, attributable to the Acquisitions, are included in our unaudited consolidated statements of operations for the three and nine months ended September 30, 2015, respectively. Pro Forma Results. The unaudited pro forma financial results for the nine months ended September 30, 2015 assume the EquiPower Acquisition and the Duke Midwest Acquisition occurred on January 1, 2014. The unaudited pro forma financial results may not be indicative of the results that would have occurred had the acquisitions been completed as of January 1, 2014, nor are they indicative of future results of operations.
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Unconsolidated Investments | Note 4—Unconsolidated Investment Equity Method Investment In connection with the EquiPower Acquisition, we acquired a 50 percent interest in Elwood Energy LLC, a limited liability company (“Elwood Energy”) and Elwood Expansion LLC, a limited liability company (“Elwood Expansion” and, together with Elwood Energy, “Elwood”). Elwood Energy owns a 1,580 MW natural gas-fired facility located in Elwood, Illinois. At September 30, 2016 and December 31, 2015, our equity method investment included in our unaudited consolidated balance sheets was $173 million and $190 million, respectively. Upon the acquisition of our Elwood investment, we recognized basis differences in the net assets of approximately $89 million related to working capital, PP&E, debt, and intangibles. These basis differences are being amortized over their respective useful lives. Our risk of loss related to our equity method investment is limited to our investment balance. Holders of the debt of our unconsolidated investment do not have recourse to us and our other subsidiaries. For the three and nine months ended September 30, 2016, we recorded $4 million and $7 million in equity earnings related to our investment in Elwood, respectively. For the three and nine months ended September 30, 2015, we recorded $4 million and $1 million in equity losses related to our investment in Elwood, respectively. These equity earnings (losses) are included in Earnings (losses) from unconsolidated investment in our unaudited consolidated statements of operations. For the nine months ended September 30, 2016, we received a distribution of $15 million, of which $14 million was considered a return of investment. For the nine months ended September 30, 2015, we received a distribution of $11 million, of which $8 million was considered a return of investment. At September 30, 2016 and December 31, 2015, we have $10 million and $3 million in accounts receivable due from Elwood, respectively, which is included in Accounts receivable, net in our unaudited consolidated balance sheets. On March 28, 2016, Dynegy Marketing and Trade, LLC (“DMT”), a subsidiary of Dynegy, entered into (i) an Asset Management Agreement and (ii) a Fuel Supply and Fuel Management Services Agreement with Elwood Energy. Under these agreements, DMT provides gas supply and management services to meet Elwood Energy’s fuel supply requirements. For the three and nine months ended September 30, 2016, we recorded $15 million and $27 million in revenues related to these agreements, respectively, which is reflected in Revenues in our unaudited consolidated statements of operations. On August 3, 2016, Dynegy announced that it has entered into an agreement to sell its 50 percent equity interest in the Elwood Energy facility in Elwood, IL, to J-Power USA Development Co. Ltd. for approximately $173 million (“the Elwood Sale”). Under the agreement, Elwood will not make distributions to its members prior to the closing of the Elwood Sale. As a result, we recorded an impairment charge of $9 million to Impairments in our unaudited consolidated statements of operations for the three and nine months ended September 30, 2016, to write down our investment in Elwood to the sales price. Additionally, approximately $35 million of previously posted collateral will be returned to Dynegy at closing. Upon approval from the FERC, the sale is expected to close in the fourth quarter of 2016. Note 10—Joint Ownership of Generating Facilities We hold ownership interests in certain jointly owned generating facilities. We are entitled to the proportional share of the generating capacity and the output of each unit equal to our ownership interests. We pay our share of capital expenditures, fuel inventory purchases, and operating expenses, except in certain instances where agreements have been executed to limit certain joint owners’ maximum exposure to additional costs. Our share of revenues and operating costs of the jointly owned generating facilities is included within the corresponding financial statement line items in our unaudited consolidated statements of operations. The following tables present the ownership interests of the jointly owned facilities as of September 30, 2016 and December 31, 2015 included in our unaudited consolidated balance sheets. Each facility is co-owned with one or more other generation companies.
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In the third quarter 2016, we impaired the book value of the jointly owned Stuart facility and recorded a charge of $55 million to Impairments in our unaudited consolidated statements of operations for the three and nine months ended September 30, 2016. Please read Note 9—Property, Plant and Equipment for further discussion. |
Risk Management Activities, Derivatives and Financial Instruments |
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Derivative Instruments and Hedging Activities Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Risk Management Activities, Derivatives and Financial Instruments | Note 5—Risk Management Activities, Derivatives, and Financial Instruments The nature of our business necessarily involves commodity market and financial risks. Specifically, we are exposed to commodity price variability related to our power generation business. Our commercial team manages these commodity price risks with financially and physically settled contracts consistent with our commodity risk management policy. Our treasury team manages our interest rate risk. Our commodity risk management policy gives us the flexibility to sell energy and capacity and purchase fuel through a combination of spot market sales and near-term contractual arrangements (generally over a rolling one- to three-year time frame). Our commodity risk management goal is to protect cash flow in the near-term while keeping the ability to capture value longer-term. Many of our contractual arrangements are derivative instruments and are accounted for at fair value as part of Revenues in our unaudited consolidated statements of operations. We have other contractual arrangements such as capacity forward sales arrangements, tolling arrangements, fixed price coal purchases, and retail power sales which do not receive recurring fair value accounting treatment because these arrangements do not meet the definition of a derivative or are designated as “normal purchase, normal sale,” in accordance with ASC 815, Derivatives and Hedging. As a result, the gains and losses with respect to these arrangements are not reflected in our unaudited consolidated financial statements until the delivery occurs. Quantitative Disclosures Related to Financial Instruments and Derivatives As of September 30, 2016, we had net purchases and sales of derivative contracts outstanding in the following quantities:
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Derivatives on the Balance Sheet. The following tables present the fair value and balance sheet classification of derivatives in our unaudited consolidated balance sheets as of September 30, 2016 and December 31, 2015. As of September 30, 2016 and December 31, 2015, there were no gross amounts available to be offset that were not offset in our unaudited consolidated balance sheets.
Certain of our derivative instruments have credit limits that require us to post collateral. The amount of collateral required to be posted is a function of the net liability position of the derivative as well as our established credit limit with the respective counterparty. If our credit rating were to worsen, the counterparties could require us to post additional collateral. The amount of additional collateral that would be required to be posted would vary depending on the extent of change in our credit rating as well as the requirements of the individual counterparty. As of September 30, 2016, the aggregate fair value of all commodity derivative instruments containing credit-risk-related contingent features which are in a liability position and not fully collateralized is $26 million for which we have posted $12 million in collateral. Transactions with our clearing brokers are excluded as they are fully collateralized. Our remaining derivative instruments do not have credit-related collateral contingencies as they are included within our first-lien collateral program. The following table summarizes our cash collateral posted as of September 30, 2016 and December 31, 2015, within Prepayments and other current assets in our unaudited consolidated balance sheets and the amount applied against short-term risk management activities:
Impact of Derivatives on the Unaudited Consolidated Statements of Operations The following discussion and table present the location and amount of gains and losses on derivative instruments in our unaudited consolidated statements of operations. Financial Instruments Not Designated as Hedges. We elect not to designate derivatives related to our power generation business and interest rate instruments as cash flow or fair value hedges. Thus, we account for changes in the fair value of these derivatives within our unaudited consolidated statements of operations. Our unaudited consolidated statements of operations for the three and nine months ended September 30, 2016 and 2015 include the impact of derivative financial instruments as presented below:
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Fair Value Measurements |
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Fair Value Disclosures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Measurements | Note 6—Fair Value Measurements We apply the market approach for recurring fair value measurements, employing valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. We have consistently used the same valuation techniques for all periods presented. Please read Note 2—Summary of Significant Accounting Policies—Fair Value Measurements in our Form 10-K for further discussion. The following tables set forth, by level within the fair value hierarchy, our financial assets and liabilities that were accounted for at fair value on a recurring basis as of September 30, 2016 and December 31, 2015, and are presented on a gross basis before consideration of amounts netted under master netting agreements and the application of collateral and margin paid:
Level 3 Valuation Methods. The electricity derivatives classified within Level 3 include financial swaps executed in illiquid trading locations or on long dated contracts, capacity contracts, and FTRs. The curves used to generate the fair value of the financial swaps are based on basis adjustments applied to forward curves for liquid trading points, while the curves for the capacity deals are based upon auction results in the marketplace, which are infrequently executed. The forward market price of FTRs is derived using historical congestion patterns within the marketplace and heat rate derivative valuations are derived using a Black-Scholes spread model, which uses forward natural gas and power prices, market implied volatilities, and modeled correlation values. The natural gas derivatives classified within Level 3 include financial swaps, basis swaps, and physical purchases executed in illiquid trading locations or on long dated contracts. The coal derivatives classified within Level 3 include financial swaps executed in illiquid trading locations. Sensitivity to Changes in Significant Unobservable Inputs for Level 3 Valuations. The significant unobservable inputs used in the fair value measurement of our commodity instruments categorized within Level 3 of the fair value hierarchy include estimates of forward congestion, power price spreads, natural gas and coal pricing, and the difference between our plant locational prices to liquid hub prices. Power price spreads, natural gas and coal pricing, and the difference between our plant locational prices to liquid hub prices are generally based on observable markets where available, or derived from historical prices and forward market prices from similar observable markets when not available. Increases in the price of the spread on a buy or sell position in isolation would result in a higher/lower fair value measurement. The significant unobservable inputs used in the valuation of Dynegy’s contracts classified as Level 3 as of September 30, 2016 are as follows:
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The following tables set forth a reconciliation of changes in the fair value of financial instruments classified as Level 3 in the fair value hierarchy:
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Gains and losses recognized for Level 3 recurring items are included in Revenues in our unaudited consolidated statements of operations for commodity derivatives. We believe an analysis of commodity instruments classified as Level 3 should be undertaken with the understanding that these items generally serve as economic hedges of our power generation portfolio. We did not have any transfers between Level 1, Level 2, and Level 3 for the three and nine months ended September 30, 2016 and 2015. Nonfinancial Assets and Liabilities. Nonfinancial assets and liabilities that are measured at fair value on a nonrecurring basis are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of such assets and liabilities and their placement within the fair value hierarchy. During the nine months ended September 30, 2016, as a result of impairment testing, we measured our Baldwin and Stuart facilities at fair value. See Note 9—Property, Plant and Equipment for further discussion. During the three and nine months ended September 30, 2015, we fair valued the EquiPower and Duke Midwest acquisitions. See Note 3—Acquisitions for further discussion. Each of these valuations is classified as Level 3 within the fair value hierarchy. Fair Value of Financial Instruments. The following table discloses the fair value of financial instruments recognized in our unaudited consolidated balance sheets. Unless otherwise noted, the fair value of debt as reflected in the table has been calculated based on the average of certain available broker quotes as of September 30, 2016 and December 31, 2015, respectively.
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Accumulated Other Comprehensive Income |
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Accumulated Other Comprehensive Income | Note 7—Accumulated Other Comprehensive Income Changes in accumulated other comprehensive income, net of tax, by component, are as follows:
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Inventory |
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Inventory | Note 8—Inventory A summary of our inventories is as follows:
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Property, Plant and Equipment |
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Property, Plant and Equipment | Note 9—Property, Plant and Equipment A summary of our property, plant and equipment is as follows:
Impairments Stuart. In the third quarter 2016, we held strategic discussions with our partners, including the operator, concerning changes to our long term views of required maintenance and environmental capital expenditures, as well as discussing the profitability of the facility. As a result of these discussions, combined with consistently poor reliability and a determination that the facility would experience recurring negative cash flows, we concluded the facility will not recover its book value, thereby failing the recoverability step of an impairment analysis. Due to the recurring nature of the forecasted negative cash flows, we fair valued the asset at zero, resulting in an impairment charge of $55 million recorded to Impairments in our unaudited consolidated statements of operations for the three and nine months ended September 30, 2016. The valuation is classified as Level 3 within the fair value hierarchy. Newton. On September 2, 2016, IPH and Ameren Energy Medina Valley Cogen, LLC filed a motion with the IPCB to terminate the variance from the SO2 annual emission rate limits provided in the Illinois Multi-Pollutant Standards (“MPS”). IPH retired Newton Unit 2 on September 15, 2016. This retirement, along with the use of dispatch management, will allow IPH to continue to comply with the MPS SO2 limits, thereby eliminating the need for the variance. As a result, the FGD systems construction project at our Newton generation facility was terminated. On October 27, 2016, the IPCB granted the motion to terminate the variance. Capitalized costs not yet placed into service related to the project of $148 million were written-off and recorded to Impairments in our unaudited consolidated statements of operations for the three and nine months ended September 30, 2016. Baldwin. On May 3, 2016, Dynegy announced the shutdown of Units 1 and 3 at its Baldwin power generation facility in Baldwin, Illinois over the next year. This decision was made after the units failed to recover their basic operating costs in the most recent MISO auction. On October 17, 2016, we shut down Baldwin Unit 3. Due to bilateral sales of incremental capacity for Planning Year 2017-2018, we will continue to operate Baldwin Unit 1 through the next Planning Year. As a result of these shutdowns, we performed an impairment analysis on all our MISO plants. We performed step one of the impairment analysis using undiscounted cash flows for the estimated useful lives of the facilities and determined the book value of the Baldwin facility would not be recovered. We performed step two of the impairment analysis using a DCF model, utilizing a 13 percent discount rate, and assuming normal operations for the estimated useful lives of the facilities. For the model, gross margin was based on forward commodity market prices obtained from third party quotations for the years 2016 through 2018. For the years 2019 through 2025, we used commodity and capacity price curves developed internally utilizing supply and demand factors. We also used management’s forecasts of operations and maintenance expense, general and administrative expense, and capital expenditures for the years 2016 through 2025 and assumed a 2.5 percent growth rate thereafter, based upon management’s view of future conditions. The model resulted in a fair value of the Baldwin facility of $97 million, resulting in an impairment charge of $645 million recorded to Impairments in our unaudited consolidated statements of operations for the nine months ended September 30, 2016. The valuation is classified as Level 3 within the fair value hierarchy. Wood River. In the third quarter 2015, we impaired the book value of our Wood River facility and recorded a charge of $74 million to Impairments in our unaudited consolidated statements of operations for the three and nine months ended September 30, 2015. Please read Note 9—Property, Plant and Equipment in our Form 10-K for further discussion. |
Joint Ownership of Generating Facilities |
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Equity Method Investments and Joint Ventures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Joint Ownership of Generating Facilities | Note 4—Unconsolidated Investment Equity Method Investment In connection with the EquiPower Acquisition, we acquired a 50 percent interest in Elwood Energy LLC, a limited liability company (“Elwood Energy”) and Elwood Expansion LLC, a limited liability company (“Elwood Expansion” and, together with Elwood Energy, “Elwood”). Elwood Energy owns a 1,580 MW natural gas-fired facility located in Elwood, Illinois. At September 30, 2016 and December 31, 2015, our equity method investment included in our unaudited consolidated balance sheets was $173 million and $190 million, respectively. Upon the acquisition of our Elwood investment, we recognized basis differences in the net assets of approximately $89 million related to working capital, PP&E, debt, and intangibles. These basis differences are being amortized over their respective useful lives. Our risk of loss related to our equity method investment is limited to our investment balance. Holders of the debt of our unconsolidated investment do not have recourse to us and our other subsidiaries. For the three and nine months ended September 30, 2016, we recorded $4 million and $7 million in equity earnings related to our investment in Elwood, respectively. For the three and nine months ended September 30, 2015, we recorded $4 million and $1 million in equity losses related to our investment in Elwood, respectively. These equity earnings (losses) are included in Earnings (losses) from unconsolidated investment in our unaudited consolidated statements of operations. For the nine months ended September 30, 2016, we received a distribution of $15 million, of which $14 million was considered a return of investment. For the nine months ended September 30, 2015, we received a distribution of $11 million, of which $8 million was considered a return of investment. At September 30, 2016 and December 31, 2015, we have $10 million and $3 million in accounts receivable due from Elwood, respectively, which is included in Accounts receivable, net in our unaudited consolidated balance sheets. On March 28, 2016, Dynegy Marketing and Trade, LLC (“DMT”), a subsidiary of Dynegy, entered into (i) an Asset Management Agreement and (ii) a Fuel Supply and Fuel Management Services Agreement with Elwood Energy. Under these agreements, DMT provides gas supply and management services to meet Elwood Energy’s fuel supply requirements. For the three and nine months ended September 30, 2016, we recorded $15 million and $27 million in revenues related to these agreements, respectively, which is reflected in Revenues in our unaudited consolidated statements of operations. On August 3, 2016, Dynegy announced that it has entered into an agreement to sell its 50 percent equity interest in the Elwood Energy facility in Elwood, IL, to J-Power USA Development Co. Ltd. for approximately $173 million (“the Elwood Sale”). Under the agreement, Elwood will not make distributions to its members prior to the closing of the Elwood Sale. As a result, we recorded an impairment charge of $9 million to Impairments in our unaudited consolidated statements of operations for the three and nine months ended September 30, 2016, to write down our investment in Elwood to the sales price. Additionally, approximately $35 million of previously posted collateral will be returned to Dynegy at closing. Upon approval from the FERC, the sale is expected to close in the fourth quarter of 2016. Note 10—Joint Ownership of Generating Facilities We hold ownership interests in certain jointly owned generating facilities. We are entitled to the proportional share of the generating capacity and the output of each unit equal to our ownership interests. We pay our share of capital expenditures, fuel inventory purchases, and operating expenses, except in certain instances where agreements have been executed to limit certain joint owners’ maximum exposure to additional costs. Our share of revenues and operating costs of the jointly owned generating facilities is included within the corresponding financial statement line items in our unaudited consolidated statements of operations. The following tables present the ownership interests of the jointly owned facilities as of September 30, 2016 and December 31, 2015 included in our unaudited consolidated balance sheets. Each facility is co-owned with one or more other generation companies.
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In the third quarter 2016, we impaired the book value of the jointly owned Stuart facility and recorded a charge of $55 million to Impairments in our unaudited consolidated statements of operations for the three and nine months ended September 30, 2016. Please read Note 9—Property, Plant and Equipment for further discussion. |
Intangible Assets and Liabilities |
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Intangible Assets, Net (Excluding Goodwill) [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Intangible Assets and Liabilities | Note 11—Intangible Assets and Liabilities The following table summarizes the components of our intangible assets and liabilities as of September 30, 2016 and December 31, 2015:
The following table presents our amortization expense (revenue) of intangible assets and liabilities for the three and nine months ended September 30, 2016 and 2015:
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Tangible Equity Units |
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Tangible Equity Units | Note 12—Tangible Equity Units On June 21, 2016, we issued 4.6 million, 7 percent TEUs at $100 per unit and received proceeds of $446 million, net of issuance costs of $14 million. During the third quarter of 2016, we incurred an additional $3 million in issuance costs. Each TEU is comprised of: (i) a prepaid stock purchase contract (“SPC”) issued by Dynegy, and (ii) an amortizing note (“Amortizing Note”), with an initial principal amount of $18.95 that pays an equal quarterly cash installment of $1.75 per Amortizing Note on January 1, April 1, July 1, and October 1 of each year, with the exception of the first installment payment of $1.94 due on October 1, 2016. In the aggregate, the annual quarterly cash installments will be equivalent to a 7 percent cash payment per year. Each installment cash payment constitutes a payment of interest and a partial repayment of principal. Each TEU may be separated by a holder into its constituent SPC and Amortizing Note after the initial issuance date of the TEUs, and the separate components may be combined to create a TEU after the initial issuance date, in accordance with the terms of the SPC. The TEUs are listed on the New York Stock Exchange under the symbol “DYNC”. We allocated the proceeds from the issuance of the TEUs, including other fees and expenses, to equity and debt based on the relative fair value of the respective components of each TEU as follows:
The fair value of the SPCs was recorded as additional paid in capital, net of issuance costs. The fair value of the Amortizing Notes was recorded as debt, with deferred financing costs recorded as a reduction of the carrying amount of the debt in our unaudited consolidated balance sheet. Deferred financing costs related to the Amortizing Notes will be amortized through the maturity date using the effective interest rate method. Unless settled early at the holder’s or Dynegy’s election or redeemed by Dynegy in connection with an acquisition termination redemption, on July 1, 2019, Dynegy will deliver to the SPC holders a number of shares of common stock based on the 20 day volume-weighted average price (“VWAP”) of our common stock as follows:
In addition, on any business day during the period beginning on, and including, the business day immediately following the date of initial issuance of the TEUs to, but excluding, the third business day immediately preceding the mandatory settlement date, any holder of an SPC may settle any or all of its SPCs early, and Dynegy will deliver a number of shares of Common Stock equal to the minimum settlement rate. Additionally, the SPCs may be redeemed in the event of a fundamental change or under an acquisition termination event, both as defined in the SPC. |
Debt |
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Debt | Note 13—Debt A summary of our long-term debt is as follows:
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Credit Agreement and Finance IV Credit Agreement As of September 30, 2016, we had a $2.225 billion credit agreement, as amended, that consisted of (i) an $800 million seven-year senior secured term loan facility (the “Tranche B-2 Term Loan”) and (ii) $1.425 billion in senior secured revolving credit facilities (the “Revolving Facility,” and collectively with the Tranche B-2 Term Loan the “Credit Agreement”). Additionally, we had a $2.0 billion, seven-year senior Tranche C Term Loan, under the Finance IV Credit Agreement, as defined below. At September 30, 2016, there were no amounts drawn on the Revolving Facility; however, we had outstanding letters of credit (“LCs”) of approximately $327 million, which reduce the amount available under the Revolving Facility. The Credit Agreement contains customary events of default and affirmative and negative covenants, subject to certain specified exceptions, including a Senior Secured Leverage Ratio (as defined in the Credit Agreement) calculated on a rolling four quarters basis. Based on the calculation outlined in the Credit Agreement, we are in compliance as of September 30, 2016. Finance IV Credit Agreement. On June 27, 2016 (the “Term Loan Closing Date”), Finance IV entered into a term loan credit agreement which provides for a $2.0 billion, seven-year Tranche C Term Loan, and matures on June 27, 2023. The Tranche C Term Loan bears interest at either (i) 4 percent per annum plus LIBOR, subject to a floor of one percent with respect to any LIBOR Loan or (ii) 3 percent per annum plus the Base Rate with respect to any Base Rate Loan. Amounts available under the Tranche C Term Loan were fully drawn on the Term Loan Closing Date, and the net proceeds were placed into escrow (see “Escrow Agreement” described below) pending the consummation of the Delta Transaction. The Finance IV Credit Agreement contains limited events of default and affirmative covenants and one negative covenant, which restricts the activities of Finance IV to those primarily relating to the Delta Transaction and financing. The obligations of Finance IV under the Finance IV Credit Agreement are secured by the related amounts placed in escrow from time to time. Escrow Agreement. On the Term Loan Closing Date, Finance IV borrowed the full amount of the Tranche C Term Loan and placed the net proceeds into an escrow account (the “Escrow Account”). Additionally, Dynegy initially contributed $70 million into escrow so that the aggregate funds in the Escrow Account would be sufficient to repay the Tranche C Term Loan plus any interest that may accrue for a period of six months from the Term Loan Closing Date. Pursuant to the Escrow Agreement, interest payments on the Tranche C Term Loan will be paid from the amounts in the escrow account until the release of funds on the Escrow Release Date. To date, $26 million has been released from escrow for interest payments. As of September 30, 2016, we had $2.0 billion classified as long-term Restricted cash and $45 million classified as short-term Restricted cash in our unaudited consolidated balance sheet related to the Escrow Agreement. The $45 million includes a payment to the escrow account of (i) $25 million of remaining pre-funded interest and interest income earned, and (ii) $20 million of pre-funded original issue discount which is contingent upon the closing of the Delta Transaction. Upon the release of funds from escrow upon the satisfaction of the Delta Transaction Escrow Conditions, as defined in the Finance IV Credit Agreement (the “Escrow Release Date”), Finance IV will merge with and into Dynegy, with Dynegy as the surviving entity, and Dynegy will use the amounts released from escrow to fund a portion of the Delta Transaction. The Finance IV Credit Agreement provides that, upon the effectiveness of the Conversion and Deemed Issuance, as defined in the Finance IV Credit Agreement, the latter will (a) cease to be of force or effect and (b) be superseded by the provisions of the Credit Agreement, as amended by the Third Amendment. If the Delta Transaction Escrow Conditions are not satisfied on or prior to February 24, 2017 (the “Delta Transaction Deadline”) or if the Delta Stock Purchase Agreement is terminated or Finance IV has determined that the Delta Transaction will not be consummated on or before the Delta Transaction Deadline, the escrow agent will, within one business day, liquidate all escrowed property held in escrow and release all amounts to the lenders under the Finance IV Credit Agreement. Credit Agreement Third Amendment. The Third Amendment provides, upon the Escrow Release Date, for (i) a $75 million Incremental Tranche B Revolver to the Revolving Facility, which has terms substantially the same as the terms of the Revolving Facility and will mature on April 2, 2020 and (ii) an incremental $2.0 billion, seven-year senior secured Tranche C Term Loan which has terms substantially the same as the Finance IV Credit Agreement discussed above. In addition, as requested by the Seller in the Delta Transaction, on June 27, 2016, Dynegy, the guarantors, the lenders and other parties thereto entered into a waiver to the Credit Agreement (the “Waiver”), providing a waiver from the lenders party thereto of the Incremental Ratio Tests (as defined in the Credit Agreement) and confirmation that notwithstanding the terms of the Credit Agreement or other related Credit Document (as defined in the Credit Agreement), Dynegy may incur the Tranche C Term Loan and the Incremental Tranche B Revolver without regard to the satisfaction of the Incremental Ratio Tests and no default or event of default will occur as a result of any breach of the Incremental Ratio Tests. Upon the Escrow Release Date, the Credit Agreement will be comprised of (i) an $800 million, seven-year Tranche B-2 Term Loan, (ii) a $2.0 billion, seven-year Tranche C Term Loan, and (iii) a $1.5 billion Revolving Facility consisting of three tranches of revolving commitments including: (a) a $475 million tranche which will mature on April 23, 2018, (b) a $350 million tranche which will mature April 1, 2020, and (c) a $675 million tranche, which includes the Incremental Tranche B Revolver and will mature on April 2, 2020. Interest Rate Swaps. During 2013, we amended our interest rate swaps to more closely match the terms of our Tranche B-2 Term Loan. The swaps have an aggregate notional value of approximately $771 million at an average fixed rate of 3.19 percent with a floor of one percent, and expire during the second quarter of 2020. In lieu of paying the breakage fees related to terminating the old swaps and issuing the new swaps, the costs were incorporated into the terms of the new swaps. As a result, any cash flows related to the settlement of the swaps are reflected as a financing activity in our unaudited consolidated statements of cash flows. Letter of Credit Facilities Dynegy has an LC Reimbursement Agreement with an issuing bank, and its affiliate (the “Lender”), for an LC in an amount not to exceed $55 million. The facility expires in September 2017. At September 30, 2016, there was $55 million outstanding under this LC. Illinois Power Marketing Company (“IPM”) has LC and reimbursement agreements with issuing banks in which the issuing banks agree to issue standby LCs in stated amounts not to exceed $50 million, in aggregate, to support performance obligations and other general corporate activities of IPM and IPRG. As of September 30, 2016, there were $30 million in LCs outstanding under these facilities. One of the IPM LC facilities is fully collateralized by cash, and as of September 30, 2016, IPM had $19 million deposited with the issuing bank. On February 24, 2016, Dynegy entered into a bilateral letter of credit facility commitment letter with an issuing bank for $50 million, which is contingent upon the closing of the Delta Transaction. Forward Capacity Agreement On March 18, 2016, we entered into a bilateral contract with a financial institution to sell a portion of our forward cleared PJM capacity auction volumes. In exchange, we received $198 million in cash proceeds during the first quarter of 2016. The buyer in this transaction will receive capacity payments from PJM during the Planning Years 2017-2018 and 2018-2019 in the amounts of $110 million and $109 million, respectively. Dynegy will continue to be subject to the performance obligations as well as any associated performance penalties and bonus payments for those planning years. The transaction is accounted for as a debt issuance of $219 million with an implied interest rate of 4.45 percent. Inventory Financing Agreements Brayton Point Inventory Financing. In connection with the EquiPower Acquisition, we assumed an inventory financing agreement (the “Inventory Financing Agreement”) for coal and fuel oil inventories at our Brayton Point facility, consisting of a debt obligation for existing and subsequent inventories, as well as a $15 million line of credit. Balances in excess of the $15 million line of credit are cash collateralized. As the materials are purchased and delivered to our facilities, our debt obligation and line of credit increase based on the then market rate of the materials, transportation costs, and other expenses. The debt obligation increases for 85 percent of the total cost of the coal and for 90 percent of the total cost of the fuel oil. The line of credit increases for the remaining 15 percent and 10 percent for coal and oil costs, respectively. We repay the debt obligation and line of credit from revenues received, at the then market price, for the amount of the materials consumed, on a weekly basis. As of September 30, 2016, there was $58 million outstanding under this agreement. Both the debt obligation related to coal and the base level of fuel oil, as well as the line of credit, bear interest at an annual interest rate of the 3-month LIBOR plus 5.6 percent. An availability fee is calculated on a per annum rate of 0.25 percent. Additionally, we had collateral postings of approximately $3 million. The Inventory Financing Agreement terminates, and the remaining obligation, if any, becomes due and payable, on May 31, 2017. Emissions Repurchase Agreements. In August 2015, we entered into two repurchase transactions with a third party in which we sold approximately $78 million of RGGI inventory and received cash. We are obligated to repurchase a portion of the inventory in February 2017 and the remaining inventory in February 2018 at a specified price with an annualized carry cost of approximately 3.49 percent. As of September 30, 2016, there was $78 million, in aggregate, outstanding under these agreements. Amortizing Notes On June 21, 2016, in connection with the issuance of the TEUs, Dynegy issued the Amortizing Notes with a principal amount of approximately $87 million. The Amortizing Notes mature on July 1, 2019. Each installment payment of $1.75 (or, in the case of the installment payment due on October 1, 2016, $1.94) per Amortizing Note will be paid in cash and will constitute a partial repayment of principal and a payment of interest, computed at an annual rate of 7 percent. Interest will be calculated on the basis of a 360 day year consisting of twelve 30 day months. Payments will be 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. Please read Note 12—Tangible Equity Units for further discussion. The Indenture limits, among other things, the ability of Dynegy to consolidate, merge, sell, or dispose all or substantially all of its assets. If a fundamental change occurs, or if Dynegy elects to settle the SPCs early or to redeem the SPCs in connection with a termination of the Delta Stock Purchase Agreement, then the holders of the Amortizing Notes will have the right to require Dynegy to repurchase the Amortizing Notes at a repurchase price equal to the principal amount of the Amortizing Notes as of the repurchase date (as described in the supplemental indenture) plus accrued and unpaid interest. The Indenture also contains customary events of default which would permit the holders of the Amortizing Notes to declare those Amortizing Notes to be immediately due and payable if not cured within applicable grace periods, including the failure to make timely installment payments on the Amortizing Notes or other material indebtedness, the failure to satisfy covenants, and specified events of bankruptcy and insolvency. Dynegy Senior Notes As of September 30, 2016, we had $5.6 billion in senior notes that consisted of (i) $2.1 billion, 6.75 percent senior notes, due 2019, (ii) $1.75 billion, 7.375 percent senior notes, due 2022, (iii) $500 million, 5.875 percent senior notes, due 2023, and (iv) $1.25 billion, 7.625 percent senior notes, due 2024 (collectively, the “Senior Notes”). On October 11, 2016, Dynegy issued in a private placement transaction $750 million of 8 percent unsecured senior notes due 2025. See Note 21—Subsequent Events—2025 Senior Notes for further discussion. 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 2017 to 2025. 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 unaudited consolidated statements of cash flows. The related assets were recorded at the net present value of the payments of $75 million. The $25 million discount is currently amortized as interest expense over the life of the payments. Genco Senior Notes Genco’s approximately $825 million in aggregate principal amount of unsecured senior notes (the “Genco Senior Notes”) are an obligation of Genco, a subsidiary of IPH. IPH and its direct and indirect subsidiaries are organized into ring-fenced groups in order to maintain corporate separateness from Dynegy and its other subsidiaries. The Genco Senior Notes are non-recourse to Dynegy. Please read Note 1—Basis of Presentation and Organization for further discussion. Genco’s indenture includes provisions that require Genco to maintain certain interest coverage and debt-to-capital ratios in order for Genco to pay dividends, to make principal or interest payments on subordinated borrowings, to make loans to or investments in affiliates, or to incur additional external, third-party indebtedness. Genco’s debt incurrence-related ratio restrictions under the indenture may be disregarded if both Moody’s and S&P reaffirm the ratings in place at the time of the debt incurrence after considering the additional indebtedness. The following table summarizes these required ratios:
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Based on September 30, 2016 calculations, Genco did not meet the ratios required for Genco to pay dividends and borrow additional funds from external, third-party sources. On October 14, 2016, we entered into an RSA with Genco and the Ad Hoc Group to restructure the Genco Senior Notes. See Note 21—Subsequent Events—Genco Debt Restructure for further discussion. As a result of this restructure, Moody’s downgraded Genco’s Senior Unsecured credit rating from Caa3 to Ca. |
Commitments and Contingencies |
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Sep. 30, 2016 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies | Note 14—Commitments and Contingencies Legal Proceedings Set forth below is a summary of our material ongoing legal proceedings. We record accruals for estimated losses from contingencies when available information indicates that a loss is probable and the amount of the loss, or range of loss, can be reasonably estimated. In addition, we disclose matters for which management believes a material loss is reasonably possible. In all instances, management has assessed the matters below based on current information and made judgments concerning their potential outcome, giving consideration to the nature of the claim, the amount, if any, the nature of damages sought, and the probability of success. Management regularly reviews all new information with respect to such contingencies and adjusts its assessments and estimates of such contingencies accordingly. Because litigation is subject to inherent uncertainties including unfavorable rulings or developments, it is possible that the ultimate resolution of our legal proceedings could involve amounts that are different from our currently recorded accruals, and that such differences could be material. In addition to the matters discussed below, we are party to other routine proceedings arising in the ordinary course of business. Any accruals or estimated losses related to these matters are not material. In management’s judgment, the ultimate resolution of these matters will not have a material effect on our financial condition, results of operations, or cash flows. 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 and false reporting of natural gas prices to various index publications 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. The cases are consolidated in a multi-district litigation proceeding pending in the United States District Court for Nevada. At this time we cannot reasonably estimate a potential loss. Illinova Generating Company Arbitration. In May 2007, our subsidiary Illinova Generating Company (“IGC”) received an adverse award in an arbitration brought by Ponderosa Pine Energy, LLC (“PPE”). The award required IGC to pay PPE $17 million, which IGC paid in June 2007 under protest while simultaneously seeking to vacate the award. On May 23, 2014, the Texas Supreme Court vacated the arbitration award based upon the evident partiality of one of the arbitrators. On November 20, 2014, PPE initiated a new arbitration against IGC and its co-respondents, but the Dallas District Court enjoined the arbitration from proceeding against IGC while any dispute over IGC’s $17 million payment remains pending. On December 16, 2014, the Dallas District Court entered a judgment requiring the return of the $17 million to IGC and an additional $2.5 million payment to IGC for interest. PPE paid the $17 million principal and the $2.5 million in interest to IGC. On July 14, 2016, the Dallas Court of Appeals affirmed the judgment. PPE’s deadline to appeal the judgment to the Texas Supreme Court has expired. We recognized a gain of $20 million which is included in Other income and expense, net in our unaudited consolidated statements of operations for the three and nine months ended September 30, 2016. Other Contingencies 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., have challenged the results of the PRA as unjust and unreasonable, requested rate relief/refunds, and requested changes to the MISO PRA structure going forward. Complainants have also alleged that Dynegy may have engaged in economic or physical withholding in Zone 4 constituting market manipulation in the 2015-2016 PRA. The Independent Market Monitor for MISO (“MISO IMM”), which was responsible for monitoring the MISO 2015-2016 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 proposed remedies. We filed our Answer to these complaints and believe that we complied fully with the terms of the MISO tariff in connection with the 2015-2016 PRA, disputed the allegations, and will defend our actions vigorously. In addition, the Illinois Industrial Energy Consumers filed a complaint at FERC against MISO on June 30, 2015 requesting prospective changes to the MISO tariff. Dynegy also responded to this complaint. On October 1, 2015, FERC issued an order of non-public, formal investigation, stating that shortly after the conclusion of the 2015-2016 PRA, FERC’s Office of Enforcement began a non-public informal investigation into whether market manipulation or other potential violations of FERC orders, rules, and regulations occurred before or during the PRA (the “Order”). The Order noted that the investigation is ongoing, and that the order converting the informal, non-public investigation to a formal, non-public investigation does not indicate that FERC has determined that any entity has engaged in market manipulation or otherwise violated any FERC order, rule, or regulation. Further, FERC held a Staff-led technical conference on October 20, 2015 to obtain further information concerning potential changes to the MISO PRA structure going forward, including proposals made by complainants. The technical conference did not address the ongoing Office of Enforcement investigation. On December 31, 2015, FERC issued an order on the complaints requiring a number of prospective changes to the MISO tariff provisions associated with calculating Initial Reference Levels and Local Clearing Requirements, effective as of the 2016-2017 PRA. Under the order, FERC found that the existing tariff provision which bases Initial Reference Levels for capacity supply offers on the estimated opportunity cost of exporting capacity to a neighboring region (for example, PJM) are no longer just and reasonable. Accordingly, FERC required MISO to set the Initial Reference Level for capacity at $0 per MW-day for the 2016-2017 PRA. Capacity suppliers may also request a facility-specific reference level from the MISO IMM. The order did not address the arguments of the complainants regarding the 2015-2016 PRA, and stated that those issues remain under consideration and will be addressed in a future order. New Source Review and CAA Matters. New Source Review. Since 1999, the EPA has been engaged in a nationwide enforcement initiative to determine whether coal-fired power plants failed to comply with the requirements of the New Source Review and New Source Performance Standard provisions under the CAA when the plants implemented modifications. The EPA’s initiative focuses on whether projects performed at power plants triggered various permitting requirements, including the need to install pollution control equipment. In August 2012, the EPA issued a Notice of Violation (“NOV”) alleging that projects performed in 1997, 2006, and 2007 at the Newton facility violated Prevention of Significant Deterioration, Title V permitting, and other requirements. The NOV remains unresolved. We believe our defenses to the allegations described in the NOV are meritorious. A decision by the U.S. Court of Appeals for the Seventh Circuit in 2013 held that similar claims older than five years were barred by the statute of limitations. This decision may provide an additional defense to the allegations in the Newton facility NOV. Wood River CAA Section 114 Information Request. In 2014, we received an information request from the EPA concerning our Wood River facility’s compliance with the Illinois State Implementation Plan (“SIP”) and associated permits. We responded to the EPA’s request and believe that there are no issues with Wood River’s compliance, but we are unable to predict the EPA’s response, if any. As of June 1, 2016, our Wood River facility has been retired. CAA Notices of Violation. In December 2014, the EPA issued an NOV alleging violation of opacity standards at the Zimmer facility, which we co-own and operate. The EPA previously had issued NOVs to Zimmer in 2008 and 2010 alleging violations of the CAA, the Ohio SIP, and the station’s air permits involving standards applicable to opacity, sulfur dioxide, sulfuric acid mist, and heat input. The NOVs remain unresolved. In December 2014, the EPA also issued NOVs alleging violations of opacity standards at the Stuart and Killen facilities, which we jointly own but do not operate. 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 IPH segment’s Edwards facility. In August 2016, the District Court granted the plaintiffs’ motion for summary judgment on certain liability issues. We have filed a motion seeking interlocutory appeal of the court’s summary judgment ruling. The District Court has not yet scheduled the remedy phase of the case. 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. At this time we are unable to make a reasonable estimate of the possible costs, or range of costs, that might be incurred to resolve these matters. Stuart National Pollutant Discharge Elimination System (“NPDES”) Permit Appeal. In January 2013, the Ohio EPA reissued the NPDES permit for the jointly owned Stuart facility. The operator of Stuart, The Dayton Power and Light Company, appealed various aspects of the permit, including provisions regarding thermal discharge limitations, to the Ohio Environmental Review Appeals Commission. Depending on the outcome of the appeal, the effects on Stuart’s operations could be material. At this time we are unable to make a reasonable estimate of the possible costs, or range of costs, that might be incurred to resolve this matter. Coal Segment Groundwater. In 2012, the Illinois EPA (“IEPA”) issued violation notices alleging violations of groundwater standards onsite at our Baldwin and Vermilion facilities. At Baldwin, with approval of the IEPA, we performed a comprehensive evaluation of the Baldwin Coal Combustion Residuals (“CCR”) surface impoundment system beginning in 2013. Based on the results of that evaluation, we recommended to the IEPA in 2014 that the closure process for the inactive east CCR surface impoundment begin and that a geotechnical investigation of the existing soil cap on the inactive old east CCR surface impoundment be undertaken. We also submitted a supplemental groundwater modeling report that indicates no known offsite water supply wells will be impacted under the various Baldwin CCR surface impoundment closure scenarios modeled. In April 2016, we submitted closure and post-closure care plans to the IEPA for the Baldwin old east, east, and west fly ash CCR surface impoundments. The IEPA has approved our plans. We initiated an investigation at Baldwin in 2011 at the request of the IEPA to determine if the facility’s CCR surface impoundment system impacts offsite groundwater. Results of the offsite groundwater quality investigation, as submitted to the IEPA in 2012, indicate two localized areas where Class I groundwater standards were exceeded. Based on the data and groundwater flows, we do not believe that the exceedances are attributable to the Baldwin CCR surface impoundment system. At our retired Vermilion facility, which is not subject to the CCR rule, we submitted proposed corrective action plans for two CCR surface impoundments (i.e., the old east and the north CCR surface impoundments) to the IEPA in 2012. Our hydrogeologic investigation indicates that these two CCR surface impoundments impact groundwater quality onsite and that such groundwater migrate offsite to the north of the property and to the adjacent Middle Fork of the Vermilion River. The proposed corrective action plans recommend closure in place of both CCR surface impoundments and include an application to the IEPA to establish a groundwater management zone while impacts from the facility are mitigated. In 2014, we submitted a revised corrective action plan for the old east CCR surface impoundment. We await IEPA action on our proposed corrective action plans. Our estimated cost of the recommended closure alternative for both the Vermilion old east and north CCR surface impoundments, including post-closure care, is approximately $10 million. If remediation measures concerning groundwater are necessary in the future at either Baldwin or Vermilion, 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 we cannot reasonably estimate the costs, or range of costs, of remediation, if any, that ultimately may be required. IPH Segment Groundwater. Groundwater monitoring results indicate that the CCR surface impoundments at each of the IPH segment facilities potentially impact onsite groundwater. In 2012, the IEPA issued violation notices alleging violations of groundwater standards at the Newton and Coffeen facilities’ CCR surface impoundments. In April 2015, we submitted an assessment monitoring report to the IEPA concerning previously reported groundwater quality standard exceedances at the Newton facility’s active CCR landfill. The report identifies the Newton facility’s inactive unlined landfill as the likely source of the exceedances and recommends various measures to minimize the effects of that source on the groundwater monitoring results of the active landfill. In August 2016, IEPA approved the report. If remediation measures concerning groundwater are necessary at any of our IPH facilities, IPH may incur significant costs that could have a material adverse effect on its financial condition, results of operations, and cash flows. At this time we cannot reasonably estimate the costs, or range of costs, of remediation, if any, that ultimately may be required. Dam Safety Assessment Reports. In response to the failure at the Tennessee Valley Authority’s Kingston plant, the EPA initiated a nationwide investigation of the structural integrity of CCR surface impoundments in 2009. The EPA assessments found all of our surface impoundments to be in satisfactory or fair condition, with the exception of the surface impoundments at the Baldwin and Hennepin facilities. In response to the Hennepin report, we made capital improvements to the Hennepin east CCR surface impoundment berms and notified the EPA of our intent to close the Hennepin west CCR surface impoundment. The preliminary estimated cost for closure of the west CCR surface impoundment, including post-closure monitoring, is approximately $5 million, which is reflected in our AROs. We performed further studies needed to support closure of the west CCR surface impoundment, submitted those studies to the IEPA in 2014, and await IEPA action. In response to the Baldwin report, we notified the EPA in 2013 of our action plan, which included implementation of recommended operating practices and certain recommended studies. In 2014, we updated the EPA on the status of our Baldwin action plan, including the completion of certain studies and implementation of remedial measures and our ongoing evaluation of potential long-term measures in the context of our concurrent evaluation at Baldwin of groundwater corrective actions. At this time, to resolve the concerns raised in the EPA’s assessment report and as a result of the CCR rule, we plan to initiate closure of the Baldwin west fly ash CCR surface impoundment in 2017, which is reflected in our AROs. Other Commitments In conducting our operations, we have routinely entered into long-term commodity purchase and sale commitments, as well as agreements that commit future cash flow to the lease or acquisition of assets used in our businesses. These commitments have been typically associated with commodity supply arrangements, capital projects, reservation charges associated with firm transmission, transportation, storage and leases for office space, equipment, design and construction, plant sites, and power generation assets. Environmental Compliance Obligations. On September 2, 2016, IPH and Ameren Energy Medina Valley Cogen, LLC filed a motion with the IPCB to terminate the variance from the SO2 annual emission rate limits provided in the MPS. IPH retired Newton Unit 2 on September 15, 2016. This retirement, along with the use of dispatch management, will allow IPH to continue to comply with the MPS SO2 limits, thereby eliminating the need for the variance. As a result, the FGD systems construction project at our Newton generation facility was terminated. On October 27, 2016, the IPCB granted the motion to terminate the variance. Indemnifications and Guarantees In the ordinary course of business, we routinely enter into contractual agreements that contain various representations, warranties, indemnifications, and guarantees. Examples of such agreements include, but are not limited to, service agreements, equipment purchase agreements, engineering and technical service agreements, asset sales agreements, and procurement and construction contracts. Some agreements contain indemnities that cover the other party’s negligence or limit the other party’s liability with respect to third party claims, in which event we will effectively be indemnifying the other party. Virtually all such agreements contain representations or warranties that are covered by indemnifications against the losses incurred by the other parties in the event such representations and warranties are false. While there is always the possibility of a loss related to such representations, warranties, indemnifications, and guarantees in our contractual agreements, and such loss could be significant, in most cases management considers the probability of loss to be remote. We have accrued no amounts with respect to the indemnifications as of September 30, 2016 because none were probable of occurring, nor could they be reasonably estimated. Delta Transaction Guarantee. In connection with the Delta Stock Purchase Agreement executed on June 27, 2016, Dynegy entered into a guarantee agreement under which Dynegy has agreed to guarantee 100 percent of the Purchaser’s obligation to pay the reverse termination fee of $132 million if such fee becomes payable under the terms and conditions of the Delta Stock Purchase Agreement. |
Income Taxes |
9 Months Ended |
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Sep. 30, 2016 | |
Income Tax Disclosure [Abstract] | |
Income Taxes | Note 15—Income Taxes We compute our quarterly taxes under the effective tax rate method based on applying an anticipated annual effective rate to our year-to-date income or loss, except for significant, unusual, or extraordinary transactions. Income taxes for significant, unusual, or extraordinary transactions are computed and recorded in the period that the specific transaction occurs. For the three and nine months ended September 30, 2016, we recorded a tax benefit of $1 million and expense of $6 million, respectively for the application of our effective state tax rates for jurisdictions for which we do not record a valuation allowance. In addition, for the nine months ended September 30, 2016, we recorded a tax benefit of $3 million for the additional release of our valuation allowance as a result of increased net deferred tax liabilities related to the final purchase price allocation for the EquiPower Acquisition and a $14 million state tax expense as a result of a change to our corporate tax structure. For the three and nine months ended September 30, 2015, we recognized a tax charge of $21 million and a tax benefit of $459 million, respectively. This charge and benefit were related to the release of our deferred tax valuation allowance caused by the initial, and subsequent adjustment to, allocation of part of the EquiPower Acquisition purchase price to deferred tax liabilities. In addition, for the three and nine months ended September 30, 2015, we recorded a tax charge of $7 million and tax benefit of $14 million respectively for discreet items, including a state law change in Connecticut and the application of our effective state tax rates for jurisdictions for which we do not record a valuation allowance. As of September 30, 2016, we continued to maintain a valuation allowance against our net deferred tax assets in each jurisdiction as they arise as there was not sufficient evidence to overcome our historical cumulative losses to conclude that it is more-likely-than-not our net deferred tax assets can be realized in the future. |
Pension and Other Post-Employment Benefit Plans |
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Pension and Other Post-Employment Benefit Plans | Note 16—Pension and Other Post-Employment Benefit Plans We sponsor and administer defined benefit plans and defined contribution plans for the benefit of our employees and also provide other post-employment benefits to retirees who meet age and service requirements, which are further described in Note 18—Employee Compensation, Savings, Pension and Other Post-Employment Benefit Plans in our Form 10-K. In August 2015, we finalized certain new collective bargaining agreements that resulted in amendments to certain pension and other post-employment benefit plans. As a result of these amendments, we remeasured our benefit obligations and the funded status of the affected plans using inputs as of July 31, 2015. We recorded a gain through other comprehensive income and decreased our net liability by approximately $15 million during the third quarter of 2015. Components of Net Periodic Benefit Cost (Gain). The components of net periodic benefit cost (gain) were as follows:
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Capital Stock |
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Sep. 30, 2016 | |
Equity [Abstract] | |
Capital Stock | Note 17—Capital Stock Dividends We pay quarterly dividends on our mandatory convertible preferred stock on February 1, May 1, August 1, and November 1 of each year, if declared by our Board of Directors. For the three months ended September 30, 2016 and 2015, we paid $5 million in dividends on August 1, 2016 and August 3, 2015, respectively. For the nine months ended September 30, 2016 and 2015, we paid an aggregate of $16 million and $17 million in dividends, respectively. On September 30, 2016, our Board of Directors declared a dividend on our mandatory convertible preferred stock of $1.34 per share, or approximately $5 million in the aggregate. The dividend is for the period beginning on August 1, 2016 and ending on October 31, 2016. Such dividends were paid on November 1, 2016 to stockholders of record as of October 15, 2016. TEUs On June 21, 2016, pursuant to a registered public offering, we issued 4.6 million, 7 percent TEUs at $100 per unit. Each TEU was comprised of a prepaid stock purchase contract and an amortizing note which were accounted for as separate instruments. Please read Note 12—Tangible Equity Units for further discussion. Share Repurchase Program On August 3, 2015, our Board of Directors authorized a share repurchase program for up to $250 million, which was initiated in the third quarter of 2015 and completed in the fourth quarter of 2015. The shares were purchased in the open market or in privately negotiated transactions at prevailing market prices. As of September 30, 2015, we had repurchased 4,996,299 shares at an aggregate cost of $127 million. Please read Note 17—Capital Stock—Common Stock in our Form 10-K for further discussion. |
Earnings (Loss) Per Share |
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Earnings Per Share [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earnings (Loss) Per Share | Note 18—Earnings (Loss) Per Share Basic earnings (loss) per share is based on the weighted average number of common shares outstanding during the period. Diluted earnings (loss) is based on the weighted average number of common shares used for the basic earnings (loss) per share computation, adjusted for the incremental issuance of shares of common stock assuming (i) our stock options and warrants are exercised, (ii) our restricted stock units and performance stock units are fully vested under the treasury stock method, and (iii) our mandatory convertible preferred stock and the SPCs are converted into common stock under the if-converted method. Please read Note 17—Capital Stock in our Form 10-K and Note 12—Tangible Equity Units for further discussion. The basic and diluted earnings (loss) per share from continuing operations attributable to our common stockholders during the three and nine months ended September 30, 2016 and 2015 is shown in the following table:
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For the three and nine months ended September 30, 2016 and 2015, the following potentially dilutive securities were not included in the computation of diluted per share amounts because the effect would be anti-dilutive:
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Condensed Consolidating Financial Information |
9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Organization, Consolidation and Presentation of Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Condensed Consolidating Financial Information | Note 19—Condensed Consolidating Financial Information The following condensed consolidating financial statements present the financial information of (i) Dynegy (“Parent”), which is the parent and issuer of the $5.6 billion Senior Notes, on a stand-alone, unconsolidated basis, (ii) the guarantor subsidiaries of Dynegy, (iii) the non-guarantor subsidiaries of Dynegy, and (iv) the eliminations necessary to arrive at the information for Dynegy on a consolidated basis. The 100 percent owned subsidiary guarantors, jointly, severally, fully, and unconditionally, guarantee the payment obligations under the Senior Notes. Not all of Dynegy’s subsidiaries guarantee the Senior Notes including Dynegy’s indirect, wholly-owned subsidiary, IPH. Please read Note 13—Debt for further discussion. These statements should be read in conjunction with the unaudited consolidated financial statements and notes thereto of Dynegy. 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. For purposes of the unaudited condensed consolidating financial statements, a portion of our intercompany receivable, which we do not consider to be likely of settlement, has been classified as equity as of September 30, 2016 and December 31, 2015. Condensed Consolidating Balance Sheet as of September 30, 2016 (amounts in millions)
Condensed Consolidating Balance Sheet as of December 31, 2015 (amounts in millions)
Condensed Consolidating Statements of Operations for the Three Months Ended September 30, 2016 (amounts in millions)
Condensed Consolidating Statements of Operations for the Nine Months Ended September 30, 2016 (amounts in millions)
Condensed Consolidating Statements of Operations for the Three Months Ended September 30, 2015 (amounts in millions)
Condensed Consolidating Statements of Operations for the Nine Months Ended September 30, 2015 (amounts in millions)
Condensed Consolidating Statements of Comprehensive Income (Loss) for the Three Months Ended September 30, 2016 (amounts in millions)
Condensed Consolidating Statements of Comprehensive Income (Loss) for the Nine Months Ended September 30, 2016 (amounts in millions)
Condensed Consolidating Statements of Comprehensive Income (Loss) for the Three Months Ended September 30, 2015 (amounts in millions)
Condensed Consolidating Statements of Comprehensive Income (Loss) for the Nine Months Ended September 30, 2015 (amounts in millions)
Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2016 (amounts in millions)
Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2015 (amounts in millions)
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Segment Information |
9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Segment Reporting [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Segment Information | Note 20—Segment Information We report the results of our operations in three segments: (i) Coal, (ii) IPH, and (iii) Gas. The Coal segment includes certain of our coal-fired power generation facilities and our Dynegy Energy Services retail business. The IPH segment includes Genco, and IPRG, which also own, directly and indirectly, certain of our coal-fired power generation facilities. IPH also includes our Homefield Energy retail business in Illinois. IPH and its direct and indirect subsidiaries, and Genco and its direct and indirect subsidiaries, are each organized into ring-fenced groups in order to maintain corporate separateness. The Gas segment includes substantially all of our natural gas-fired power generation facilities. Our consolidated financial results also reflect corporate-level expenses such as general and administrative expense, interest expense, and income tax benefit (expense). Reportable segment information, including intercompany transactions accounted for at prevailing market rates, for the three and nine months ended September 30, 2016 and 2015 is presented below: Segment Data as of and for the Three Months Ended September 30, 2016
Segment Data as of and for the Nine Months Ended September 30, 2016
Segment Data as of and for the Three Months Ended September 30, 2015
Segment Data as of and for the Nine Months Ended September 30, 2015
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Subsequent Events |
9 Months Ended |
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Sep. 30, 2016 | |
Subsequent Events [Abstract] | |
Subsequent Events | Note 21—Subsequent Events Genco Debt Restructure On October 14, 2016, we entered into an RSA with Genco and the Ad Hoc Group to restructure Genco’s Senior Notes either through (a) out-of-court exchanges (the “Exchange Offers”) or (b) if the Exchange Offers are not successful (as discussed below), a pre-packaged plan of reorganization for Genco (the “Plan”). Under the RSA, the $825 million of existing Genco Senior Notes will be exchanged for up to $210 million in new seven-year Dynegy unsecured notes, up to $139 million of cash consideration (including a $9 million RSA payment discussed below) funded with existing IPH cash balances and an expected return of collateral of approximately $61 million, and up to 10 million Dynegy warrants with a seven-year term for an exercise price of $35 per share. If the restructuring is consummated pursuant to the Plan, it is expected that participating non-accredited investors will be entitled to a cash payment in lieu of their pro rata allocation of the notes and warrants described above. Solicitation with respect to the Exchange Offers will occur simultaneously with solicitation of the Plan. Genco will continue making interest payments on the Genco Senior Notes, with payments after September 30, 2016 netted against the proposed cash consideration. Dynegy, Genco, and the Ad Hoc Group agreed that holders of the Genco Senior Notes who entered into the RSA on or before October 21, 2016, will be paid their pro rata share of $9 million in cash upon consummation of a restructuring, with such pro rata share determined as the proportion that the amount of Genco Senior Notes held by each such holder bears to the aggregate amount of Genco Senior Notes held by all holders entitled to receive a share of the $9 million. If holders of 97 percent or more of the aggregate principal amount of Genco Senior Notes participate in the Exchange Offers and the other conditions thereto are satisfied, we intend to consummate the restructuring out of court. If holders of less than 97 percent of the aggregate principal amount of Genco Senior Notes participate in the Exchange Offers, but a majority in number of the holders who have voted on the Plan and who hold at least 66.7 percent in the aggregate amount of Genco Senior Notes held by holders voting on the Plan vote to accept the plan, the parties to the RSA intend to consummate the restructuring through a prepackaged Chapter 11 filing of Genco. As of October 24, 2016, the Ad Hoc Group of Genco bondholders represents approximately 70 percent in amount of the $825 million Genco Senior Notes. 2025 Senior Notes On October 11, 2016, Dynegy issued in a private placement transaction $750 million of 8 percent unsecured senior notes due 2025 (the “2025 Senior Notes”). The 2025 Senior Notes do not provide registration rights but otherwise have terms and provisions similar to the Dynegy Senior Notes. |
Accounting Policies (Policies) |
9 Months Ended |
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Sep. 30, 2016 | |
Accounting Policies [Abstract] | |
Basis of Presentation | The accompanying unaudited consolidated financial statements have been prepared in accordance with the instructions to interim financial reporting as prescribed by the SEC. The year-end consolidated balance sheet data was derived from audited consolidated financial statements, but does not include all disclosures required by the Generally Accepted Accounting Principles of the United States of America (“GAAP”). The unaudited consolidated financial statements contained in this report include all material adjustments of a normal recurring nature that, in the opinion of management, are necessary for a fair presentation of the results for the interim periods. Certain prior period amounts in our unaudited consolidated financial statements have been reclassified to conform to current year presentation. These interim financial statements should be read together with the consolidated financial statements and notes thereto included in our annual report on Form 10-K for the year ended December 31, 2015, filed with the SEC on February 25, 2016, which we refer to as our “Form 10-K.” Unless the context indicates otherwise, throughout this report, the terms “Dynegy,” “the Company,” “we,” “us,” “our,” and “ours” are used to refer to Dynegy Inc. and its direct and indirect subsidiaries. Our current business operations are focused primarily on the unregulated power generation sector of the energy industry. We report the results of our power generation business as three segments in our unaudited consolidated financial statements: (i) the Coal segment (“Coal”), (ii) the IPH segment (“IPH”), and (iii) the Gas segment (“Gas”). Our consolidated financial results also reflect corporate-level expenses such as general and administrative expense, interest expense, and income tax benefit (expense). All significant intercompany transactions have been eliminated. Please read Note 20—Segment Information for further discussion. IPH and its direct and indirect subsidiaries are organized into ring-fenced groups in order to maintain corporate separateness from Dynegy and its other subsidiaries. Certain of the entities in the IPH segment, including Illinois Power Generating Company (“Genco”), have an independent director whose consent is required for certain corporate actions, including material transactions with affiliates. Further, entities within the IPH segment present themselves to the public as separate entities. They maintain separate books, records and bank accounts, and separately appoint officers. Furthermore, they pay liabilities from their own funds, conduct business in their own names, and have restrictions on pledging their assets for the benefit of certain other persons. These provisions restrict our ability to move cash out of these entities without meeting certain requirements as set forth in the governing documents. |
Use of Estimates | Use of Estimates. The preparation of unaudited consolidated financial statements in conformity with GAAP requires management to make informed estimates and judgments that affect our reported financial position and results of operations based on currently available information. Actual results could differ materially from our estimates. The results of operations for the interim periods presented in this Form 10-Q are not necessarily indicative of the results to be expected for the full year or any other interim period due to seasonal fluctuations in demand for our energy products and services, changes in commodity prices, timing of maintenance and other expenditures, and other factors. |
Accounting Standards Adopted During the Current Period | Accounting Standards Adopted During the Current Period Hybrid Financial Instruments. In November 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-16-Derivatives and Hedging (Topic 815): Determining Whether the Host Contract in a Hybrid Financial Instrument Issued in the Form of a Share Is More Akin to Debt or Equity. The amendments in this ASU clarify how current GAAP should be interpreted in evaluating the economic characteristics and risks of a host contract in a hybrid financial instrument that is issued in the form of a share. Specifically, the amendments clarify that an entity should consider all relevant terms and features, including the embedded derivative feature being evaluated for bifurcation, in evaluating the nature of the host contract. Furthermore, the amendments clarify that no single term or feature would necessarily determine the economic characteristics and risks of the host contract. Rather, the nature of the host contract depends upon the economic characteristics and risks of the entire hybrid financial instrument. The amendments in this ASU also clarify that, in evaluating the nature of a host contract, an entity should assess the substance of the relevant terms and features (i.e., the relative strength of the debt-like or equity-like terms and features given the facts and circumstances) when considering how to weight those terms and features. The adoption of this ASU on January 1, 2016, did not have an impact on our unaudited consolidated financial statements. Debt Issuance Costs. In April 2015, the FASB issued ASU 2015-03-Interest-Imputation of Interest (Subtopic 835-30). The amendments in this ASU require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for our debt issuance costs are not affected by the amendments in this update. In August 2015, the FASB issued ASU 2015-15-Interest-Imputation of Interest (Subtopic 835-30). The amendments in this ASU further clarify the guidance provided in ASU 2015-03 to include the presentation of debt issuance costs in relation to line-of-credit arrangements. The amendments state these costs may be presented as an asset and subsequently amortized ratably over the term of the arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. We adopted these ASUs on January 1, 2016, on a retrospective basis affecting presentation on the unaudited consolidated balance sheets for all periods presented. Accordingly, we reclassified unamortized debt issuance costs of $3 million from Prepayments and other current assets to Debt, current portion, net and $77 million from Other long-term assets to Debt, long-term portion, net within our unaudited consolidated balance sheet as of December 31, 2015. Consolidation. In February 2015, the FASB issued ASU 2015-02-Consolidation (Topic 810). The amendments in this ASU respond to concerns about the current accounting for consolidation of certain legal entities, in particular: (i) consolidation of limited partnerships and similar legal entities, (ii) evaluating fees paid to a decision maker or a service provider as a variable interest, (iii) the effect of fee arrangements on the primary beneficiary determination, (iv) the effect of related parties on the primary beneficiary determination, and (v) consolidation of certain investment funds. The adoption of this ASU on January 1, 2016, did not have an impact on our unaudited consolidated financial statements. Extraordinary and Unusual Items. In January 2015, the FASB issued ASU 2015-01-Income Statement-Extraordinary and Unusual Items (Subtopic 225-20). The amendments in this ASU eliminate from GAAP the concept of extraordinary items and will no longer require separate classification of these items within the statement of operations. Presentation and disclosure guidance for items that are unusual in nature or occur infrequently will be retained and will be expanded to include items that are both unusual in nature and infrequently occurring. The guidance in this ASU is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. The adoption of this ASU on January 1, 2016, did not have an impact on our unaudited consolidated financial statements. |
Accounting Standards Not Yet Adopted | Accounting Standards Not Yet Adopted Statement of Cash Flows. In August 2016, the FASB issued ASU 2016-15-Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments. To reduce current and future diversity in practice, the amendments in this ASU provide guidance for several cash flow classification issues identified where current GAAP is either unclear or does not include specific guidance. The guidance in this ASU is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2017, with early adoption permitted. We are currently evaluating this ASU and any potential impacts the adoption of this ASU will have on our unaudited consolidated financial statements. Credit Losses. In June 2016, the FASB issued ASU 2016-13-Financial Instruments-Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments. The amendments in this ASU require the measurement of all expected credit losses for financial assets, which include trade receivables, held at the reporting date based on historical experience, current conditions, and reasonable and supportable forecasts. The guidance in this ASU is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019, with early adoption permitted for interim and annual periods beginning after December 15, 2018. We are currently evaluating this ASU and any potential impacts the adoption of this ASU will have on our unaudited consolidated financial statements. Compensation. In March 2016, the FASB issued ASU 2016-09-Compensation-Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. The amendments in this ASU simplify several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities and classification on the statement of cash flows. The guidance in this ASU is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2016, with early adoption permitted. We are currently evaluating this ASU and any potential impacts the adoption of this ASU will have on our unaudited consolidated financial statements. Debt Instruments. In March 2016, the FASB issued ASU 2016-06-Derivative and Hedging: Contingent Put and Call Options in Debt Instruments. The amendments in this ASU clarify what steps are required when assessing whether the economic characteristics and risks of call (put) options are clearly and closely related to the economic characteristics and risks of their debt hosts, which is one of the criteria for bifurcating an embedded derivative. An entity performing the assessment under the amendments in this ASU is required to assess the embedded call (put) options solely in accordance with the four-step decision sequence. The amendments are effective for public business entities for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years. All entities have the option of adopting the new requirements early, including adoption in an interim period. If an entity early adopts the new requirements in an interim period, it must reflect any adjustments as of the beginning of the fiscal year that includes that interim period. We are currently evaluating this ASU; however, we do not anticipate the adoption of this ASU will have a material impact on our unaudited consolidated financial statements. Leases. In February 2016, the FASB issued ASU 2016-02-Leases (Topic 842). The amendments in this ASU will mainly require lessees to recognize lease assets and lease liabilities, for those leases classified as operating leases under GAAP, in their balance sheet. The lease assets recognized in the balance sheet will represent a right-of-use asset, which is an asset that represents the lessee’s right to use, or control the use of, a specified asset for the lease term. The lease liability recognized in the balance sheet will represent the lessee’s obligation to make lease payments arising from a lease, measured on a discounted basis. The guidance in this ASU is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019, with early adoption permitted. We are currently evaluating this ASU and any potential impacts the adoption of this ASU will have on our unaudited consolidated financial statements. Going Concern. In August 2014, the FASB issued ASU 2014-15-Presentation of Financial Statements-Going Concern (Subtopic 205-40). The amendments in this ASU require management, in connection with preparing financial statements for each annual and interim reporting period, to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern within one year after the date that the financial statements are issued (or within one year after the date that the financial statements are available to be issued, when applicable). Currently, there is no guidance in GAAP about management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern or to provide related footnote disclosures. The amendments in this ASU provide that guidance. In doing so, the amendments should reduce diversity in the timing and content of footnote disclosures. The guidance in this ASU is effective for fiscal years ending after December 15, 2016, and interim periods within those fiscal years, beginning after December 15, 2016, with early adoption permitted. We are currently evaluating this ASU; however, we do not anticipate the adoption of this ASU will have a material impact on our unaudited consolidated financial statements. Revenue from Contracts with Customers. In May 2014, the FASB and International Accounting Standards Board jointly issued ASU 2014-09-Revenue from Contracts with Customers (Topic 606). This ASU, and subsequently issued amendments to the standard, develop a common revenue standard for GAAP and International Financial Reporting Standards by removing inconsistencies and weaknesses in revenue requirements, providing a more robust framework for addressing revenue issues, improving comparability of revenue recognition practices, providing more useful information to users of financial statements, and simplifying the preparation of financial statements. The guidance in this ASU and its amendments is effective for interim and annual periods beginning after December 15, 2017, with early adoption permitted for interim and annual periods beginning after December 15, 2016. We are currently evaluating this ASU; however, we do not anticipate the adoption of this ASU will have a material impact on our unaudited consolidated financial statements. |
Acquisitions (Tables) |
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Schedule of Recognized Identified Assets Acquired and Liabilities Assumed | The following table summarizes the consideration paid and the fair value amounts recognized for the assets acquired and liabilities assumed related to the EquiPower Acquisition and Duke Midwest Acquisition, as of the respective acquisition dates, April 1, 2015 and April 2, 2015:
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Business Acquisition, Pro Forma Information | The unaudited pro forma financial results for the nine months ended September 30, 2015 assume the EquiPower Acquisition and the Duke Midwest Acquisition occurred on January 1, 2014. The unaudited pro forma financial results may not be indicative of the results that would have occurred had the acquisitions been completed as of January 1, 2014, nor are they indicative of future results of operations.
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Risk Management Activities, Derivatives and Financial Instruments (Tables) |
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Derivative Instruments and Hedging Activities Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Derivative Contracts and Interest Rate Swaps | As of September 30, 2016, we had net purchases and sales of derivative contracts outstanding in the following quantities:
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Schedule of Derivative Instruments in the Balance Sheet, Fair Value | The following tables present the fair value and balance sheet classification of derivatives in our unaudited consolidated balance sheets as of September 30, 2016 and December 31, 2015. As of September 30, 2016 and December 31, 2015, there were no gross amounts available to be offset that were not offset in our unaudited consolidated balance sheets.
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Schedule of Derivative Collateral Posted and Location on Balance Sheet | The following table summarizes our cash collateral posted as of September 30, 2016 and December 31, 2015, within Prepayments and other current assets in our unaudited consolidated balance sheets and the amount applied against short-term risk management activities:
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Schedule of Derivative Instruments, Gain (Loss) in the Statement of Operations | Our unaudited consolidated statements of operations for the three and nine months ended September 30, 2016 and 2015 include the impact of derivative financial instruments as presented below:
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Fair Value Measurements (Tables) |
9 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2016 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Disclosures [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis | The following tables set forth, by level within the fair value hierarchy, our financial assets and liabilities that were accounted for at fair value on a recurring basis as of September 30, 2016 and December 31, 2015, and are presented on a gross basis before consideration of amounts netted under master netting agreements and the application of collateral and margin paid:
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Sensitivity to Changes in Significant Unobservable Inputs for Level 3 Valuations | The significant unobservable inputs used in the valuation of Dynegy’s contracts classified as Level 3 as of September 30, 2016 are as follows:
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Schedule of Changes in Fair Value of Financial Instruments | The following tables set forth a reconciliation of changes in the fair value of financial instruments classified as Level 3 in the fair value hierarchy:
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Fair Value of Financial Assets and Liabilities | Unless otherwise noted, the fair value of debt as reflected in the table has been calculated based on the average of certain available broker quotes as of September 30, 2016 and December 31, 2015, respectively.
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Accumulated Other Comprehensive Income (Tables) |
9 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2016 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Accumulated Other Comprehensive Income (Loss) | Changes in accumulated other comprehensive income, net of tax, by component, are as follows:
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Inventory (Tables) |
9 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2016 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventory Disclosure [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Summary of Inventories | A summary of our inventories is as follows:
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Property, Plant and Equipment (Tables) |
9 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2016 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment | A summary of our property, plant and equipment is as follows:
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Joint Ownership of Generating Facilities (Tables) |
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Equity Method Investments and Joint Ventures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Equity Method Investments | The following tables present the ownership interests of the jointly owned facilities as of September 30, 2016 and December 31, 2015 included in our unaudited consolidated balance sheets. Each facility is co-owned with one or more other generation companies.
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Intangible Assets and Liabilities (Tables) |
9 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2016 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Intangible Assets, Net (Excluding Goodwill) [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Intangible Assets and Liabilities | The following table summarizes the components of our intangible assets and liabilities as of September 30, 2016 and December 31, 2015:
The following table presents our amortization expense (revenue) of intangible assets and liabilities for the three and nine months ended September 30, 2016 and 2015:
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Tangible Equity Units (Tables) |
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Equity [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Tangible Equity Units | We allocated the proceeds from the issuance of the TEUs, including other fees and expenses, to equity and debt based on the relative fair value of the respective components of each TEU as follows:
Unless settled early at the holder’s or Dynegy’s election or redeemed by Dynegy in connection with an acquisition termination redemption, on July 1, 2019, Dynegy will deliver to the SPC holders a number of shares of common stock based on the 20 day volume-weighted average price (“VWAP”) of our common stock as follows:
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Debt (Tables) |
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Debt Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Long-term Debt Instruments | A summary of our long-term debt is as follows:
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Credit Agreement Compliance Ratios | The following table summarizes these required ratios:
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Pension and Other Post-Employment Benefit Plans (Tables) |
9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Compensation and Retirement Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Net Benefit Costs | The components of net periodic benefit cost (gain) were as follows:
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Earnings (Loss) Per Share (Tables) |
9 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2016 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earnings Per Share [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Earnings (Loss) Per Share, Basic and Diluted | The basic and diluted earnings (loss) per share from continuing operations attributable to our common stockholders during the three and nine months ended September 30, 2016 and 2015 is shown in the following table:
__________________________________________
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Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share | For the three and nine months ended September 30, 2016 and 2015, the following potentially dilutive securities were not included in the computation of diluted per share amounts because the effect would be anti-dilutive:
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Condensed Consolidating Financial Information (Tables) |
9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Condensed Consolidating Balance Sheets | Condensed Consolidating Balance Sheet as of September 30, 2016 (amounts in millions)
Condensed Consolidating Balance Sheet as of December 31, 2015 (amounts in millions)
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Condensed Consolidating Statements of Operations | Condensed Consolidating Statements of Operations for the Three Months Ended September 30, 2016 (amounts in millions)
Condensed Consolidating Statements of Operations for the Nine Months Ended September 30, 2016 (amounts in millions)
Condensed Consolidating Statements of Operations for the Three Months Ended September 30, 2015 (amounts in millions)
Condensed Consolidating Statements of Operations for the Nine Months Ended September 30, 2015 (amounts in millions)
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Condensed Consolidating Statements of Comprehensive Income (Loss) | Condensed Consolidating Statements of Comprehensive Income (Loss) for the Three Months Ended September 30, 2016 (amounts in millions)
Condensed Consolidating Statements of Comprehensive Income (Loss) for the Nine Months Ended September 30, 2016 (amounts in millions)
Condensed Consolidating Statements of Comprehensive Income (Loss) for the Three Months Ended September 30, 2015 (amounts in millions)
Condensed Consolidating Statements of Comprehensive Income (Loss) for the Nine Months Ended September 30, 2015 (amounts in millions)
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Condensed Consolidating Statements of Cash Flow | Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2016 (amounts in millions)
Condensed Consolidating Statements of Cash Flows for the Nine Months Ended September 30, 2015 (amounts in millions)
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Segment Information (Tables) |
9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Segment Reporting [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Segment Reporting Information, by Segment | Reportable segment information, including intercompany transactions accounted for at prevailing market rates, for the three and nine months ended September 30, 2016 and 2015 is presented below: Segment Data as of and for the Three Months Ended September 30, 2016
Segment Data as of and for the Nine Months Ended September 30, 2016
Segment Data as of and for the Three Months Ended September 30, 2015
Segment Data as of and for the Nine Months Ended September 30, 2015
|
Basis of Presentation and Organization (Details) $ in Millions |
9 Months Ended | |
---|---|---|
Sep. 30, 2016
USD ($)
segment
|
Dec. 31, 2015
USD ($)
|
|
Debt Instrument [Line Items] | ||
Number of reportable segments | segment | 3 | |
Carrying amount | $ 9,741 | $ 7,416 |
Genco | ||
Debt Instrument [Line Items] | ||
Carrying amount | $ 825 |
Accounting Policies (Details) - Accounting Standards Update 2015-03 $ in Millions |
Dec. 31, 2015
USD ($)
|
---|---|
Prepayments and Other Current Assets | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
Deferred finance costs, net | $ 3.0 |
Other long-term assets | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
Deferred finance costs, net | 77.0 |
Debt, current portion, net | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
Deferred finance costs, net | (3.0) |
Debt, long-term portion | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
Deferred finance costs, net | $ (77.0) |
Acquisitions (ECP Purchase Agreements) (Details) $ in Millions |
6 Months Ended | |
---|---|---|
Apr. 01, 2015
USD ($)
facility
MW
|
Jun. 30, 2016
USD ($)
|
|
Business Acquisition [Line Items] | ||
Cash | $ | $ 6,150 | |
Equity interests issued and issuable | $ | $ 105 | |
ERC Purchase Agreement | ||
Business Acquisition [Line Items] | ||
Percent of voting interests acquired (as a percentage) | 100.00% | |
Combined cycle gas facilities acquired | 5 | |
Natural gas power facilities acquired | 1 | |
Coal-Fired power facilities | 1 | |
EquiPower Resources Corp. and Brayton Point Holdings, LLC | Brayton Point Holdings, LLC | ||
Business Acquisition [Line Items] | ||
Percent of voting interests acquired (as a percentage) | 100.00% | |
EquiPower Acquisition | ||
Business Acquisition [Line Items] | ||
Natural gas power facilities acquired | 6 | |
Gas and oil power facilities acquired | 2 | |
Coal-Fired power facilities | 2 | |
Capacity of power facilities acquired | MW | 6,300 | |
Cash | $ | $ 3,350 | |
Equity interests issued and issuable | $ | $ 105 |
Acquisitions (Duke Midwest Purchase Agreement) (Details) $ in Millions |
6 Months Ended | |
---|---|---|
Apr. 02, 2015
USD ($)
facility
Affiliate
MW
|
Jun. 30, 2016
USD ($)
|
|
Business Acquisition [Line Items] | ||
Cash | $ | $ 6,150 | |
Duke Midwest Purchase Agreement | ||
Business Acquisition [Line Items] | ||
Retail Energy Business acquired | 1 | |
Percent of voting interests acquired (as a percentage) | 100.00% | |
Number of affiliates | Affiliate | 2 | |
Capacity of power facilities acquired | MW | 6,200 | |
Combined cycle gas facilities acquired | 3 | |
Natural gas power facilities acquired | 2 | |
Cash | $ | $ 2,800 | |
Duke Midwest Purchase Agreement | Gas | ||
Business Acquisition [Line Items] | ||
Natural gas power facilities acquired | 5 | |
Duke Midwest Purchase Agreement | Coal | ||
Business Acquisition [Line Items] | ||
Oil-Fired power facilities | 1 | |
Coal-Fired power facilities | 5 | |
Duke Midwest Purchase Agreement | Parent | Coal | ||
Business Acquisition [Line Items] | ||
Coal-Fired power facilities | 2 | |
Duke Midwest Purchase Agreement | Third Parties | Coal | ||
Business Acquisition [Line Items] | ||
Coal-Fired power facilities | 3 |
Acquisitions (Business Combination Accounting) (Details) - EquiPower and Duke Midwest Acquisitions - USD ($) |
3 Months Ended | 9 Months Ended | 12 Months Ended | 60 Months Ended | ||
---|---|---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
Dec. 31, 2025 |
Dec. 31, 2019 |
|
Business Acquisition [Line Items] | ||||||
Acquisition and integration costs | $ 0 | $ 1,000,000 | $ 0 | $ 86,000,000 | ||
Revenues and gains recognized | 543,000,000 | 626,000,000 | 1,675,000,000 | 1,128,000,000 | ||
Operating gains (losses) | $ (34,000,000) | $ 120,000,000 | $ 146,000,000 | $ 190,000,000 | ||
Forecasted | ||||||
Business Acquisition [Line Items] | ||||||
Long-term growth rate (as a percentage) | 2.50% | |||||
Operations, maintenance and capital expenditures, growth rate after year five (as a percentage) | 2.50% | |||||
Minimum | Gas | ||||||
Business Acquisition [Line Items] | ||||||
Discount rate (as a percentage) | 8.00% | |||||
Minimum | Coal | ||||||
Business Acquisition [Line Items] | ||||||
Discount rate (as a percentage) | 9.00% | |||||
Maximum | Gas | ||||||
Business Acquisition [Line Items] | ||||||
Discount rate (as a percentage) | 10.00% | |||||
Maximum | Coal | ||||||
Business Acquisition [Line Items] | ||||||
Discount rate (as a percentage) | 13.00% |
Acquisitions (Schedule of Assets Acquired and Liabilities Assumed) (Details) - USD ($) $ in Millions |
6 Months Ended | ||||
---|---|---|---|---|---|
Apr. 02, 2015 |
Apr. 01, 2015 |
Jun. 30, 2016 |
Sep. 30, 2016 |
Dec. 31, 2015 |
|
Business Acquisition [Line Items] | |||||
Cash | $ 6,150 | ||||
Equity instruments (3,460,053 common shares of Dynegy) | 105 | ||||
Net working capital adjustment | 197 | ||||
Fair value of total consideration transferred | 6,452 | ||||
Cash | 267 | ||||
Accounts receivable | 175 | ||||
Inventory | 272 | ||||
Assets from risk management activities (including current portion of $4 million and $30 million, respectively) | 37 | ||||
Prepayments and other current assets | 101 | ||||
Property, plant and equipment | 5,507 | ||||
Investment in unconsolidated affiliate | 200 | ||||
Intangible assets (including current portion of $67 million and $36 million, respectively) | 195 | ||||
Other long-term assets | 63 | ||||
Total assets acquired | 6,817 | ||||
Accounts payable | 123 | ||||
Accrued liabilities and other current liabilities | 31 | ||||
Debt, current portion | 39 | ||||
Liabilities from risk management activities (including current portion of $41 million and zero, respectively) | 164 | ||||
Asset retirement obligations | 92 | ||||
Intangible liabilities (including current portion of $24 million and $58 million, respectively) | 166 | ||||
Deferred income taxes, net | 509 | ||||
Other long-term liabilities | 40 | ||||
Total liabilities assumed | 1,164 | ||||
Identifiable net assets acquired | 5,653 | ||||
Goodwill | 799 | $ 799 | $ 797 | ||
Net assets acquired | $ 6,452 | ||||
EquiPower Acquisition | |||||
Business Acquisition [Line Items] | |||||
Cash | $ 3,350 | ||||
Equity instruments (3,460,053 common shares of Dynegy) | 105 | ||||
Net working capital adjustment | 206 | ||||
Fair value of total consideration transferred | 3,661 | ||||
Cash | 267 | ||||
Accounts receivable | 49 | ||||
Inventory | 167 | ||||
Assets from risk management activities (including current portion of $4 million and $30 million, respectively) | 4 | ||||
Prepayments and other current assets | 32 | ||||
Property, plant and equipment | 2,773 | ||||
Investment in unconsolidated affiliate | 200 | ||||
Intangible assets (including current portion of $67 million and $36 million, respectively) | 111 | ||||
Other long-term assets | 28 | ||||
Total assets acquired | 3,631 | ||||
Accounts payable | 27 | ||||
Accrued liabilities and other current liabilities | 21 | ||||
Debt, current portion | 39 | ||||
Liabilities from risk management activities (including current portion of $41 million and zero, respectively) | 57 | ||||
Asset retirement obligations | 43 | ||||
Intangible liabilities (including current portion of $24 million and $58 million, respectively) | 73 | ||||
Deferred income taxes, net | 509 | ||||
Other long-term liabilities | 0 | ||||
Total liabilities assumed | 769 | ||||
Identifiable net assets acquired | 2,862 | ||||
Goodwill | 799 | ||||
Net assets acquired | $ 3,661 | ||||
Duke Midwest Acquisition | |||||
Business Acquisition [Line Items] | |||||
Cash | $ 2,800 | ||||
Equity instruments (3,460,053 common shares of Dynegy) | 0 | ||||
Net working capital adjustment | (9) | ||||
Fair value of total consideration transferred | 2,791 | ||||
Cash | 0 | ||||
Accounts receivable | 126 | ||||
Inventory | 105 | ||||
Assets from risk management activities (including current portion of $4 million and $30 million, respectively) | 33 | ||||
Prepayments and other current assets | 69 | ||||
Property, plant and equipment | 2,734 | ||||
Investment in unconsolidated affiliate | 0 | ||||
Intangible assets (including current portion of $67 million and $36 million, respectively) | 84 | ||||
Other long-term assets | 35 | ||||
Total assets acquired | 3,186 | ||||
Accounts payable | 96 | ||||
Accrued liabilities and other current liabilities | 10 | ||||
Debt, current portion | 0 | ||||
Liabilities from risk management activities (including current portion of $41 million and zero, respectively) | 107 | ||||
Asset retirement obligations | 49 | ||||
Intangible liabilities (including current portion of $24 million and $58 million, respectively) | 93 | ||||
Deferred income taxes, net | 0 | ||||
Other long-term liabilities | 40 | ||||
Total liabilities assumed | 395 | ||||
Identifiable net assets acquired | 2,791 | ||||
Goodwill | 0 | ||||
Net assets acquired | $ 2,791 |
Acquisitions (Schedule of Assets Acquired and Liabilities Assumed - Phantom) (Details) - USD ($) $ in Millions |
Apr. 01, 2015 |
Apr. 02, 2015 |
---|---|---|
EquiPower Acquisition | ||
Business Acquisition [Line Items] | ||
Number of shares issued | 3,460,053 | |
Current assets from risk management activities | $ 4 | |
Intangible assets, current | 67 | |
Current liabilities from risk management activities | 41 | |
Intangible liabilities, current | $ 24 | |
Duke Midwest Acquisition | ||
Business Acquisition [Line Items] | ||
Current assets from risk management activities | $ 30 | |
Intangible assets, current | 36 | |
Current liabilities from risk management activities | 0 | |
Intangible liabilities, current | $ 58 |
Acquisitions (Pro Forma Results) (Details) - EquiPower and Duke Midwest Acquisitions $ in Millions |
9 Months Ended |
---|---|
Sep. 30, 2015
USD ($)
| |
Business Acquisition [Line Items] | |
Revenues | $ 3,844 |
Net income | 442 |
Noncontrolling Interest | |
Business Acquisition [Line Items] | |
Net income | (3) |
Parent | |
Business Acquisition [Line Items] | |
Net income | $ 445 |
Unconsolidated Investments (Details) $ in Millions |
3 Months Ended | 9 Months Ended | ||||||
---|---|---|---|---|---|---|---|---|
Aug. 03, 2016
USD ($)
|
Sep. 30, 2016
USD ($)
|
Sep. 30, 2015
USD ($)
|
Sep. 30, 2016
USD ($)
|
Sep. 30, 2015
USD ($)
|
Jun. 30, 2016
USD ($)
|
Dec. 31, 2015
USD ($)
|
Apr. 01, 2015
MW
|
|
Schedule of Equity Method Investments [Line Items] | ||||||||
Investment in unconsolidated affiliate | $ 173 | $ 173 | $ 190 | |||||
Identifiable net assets acquired | $ 5,653 | |||||||
Income from unconsolidated investments | 4 | $ (4) | 7 | $ (1) | ||||
Distributions from unconsolidated investment | 1 | 3 | ||||||
Return of investment | 14 | 8 | ||||||
Accounts receivable, net | 374 | 374 | 402 | |||||
Revenues | 1,184 | 1,232 | 3,211 | 2,854 | ||||
Impairments | 212 | $ 74 | 857 | 74 | ||||
Elwood | ||||||||
Schedule of Equity Method Investments [Line Items] | ||||||||
Percent of voting interests acquired (as a percentage) | 50.00% | |||||||
Capacity of power facilities acquired | MW | 1,580 | |||||||
Investment in unconsolidated affiliate | 173 | 173 | 190 | |||||
Identifiable net assets acquired | 89 | 89 | ||||||
Distributions from unconsolidated investment | 15 | 11 | ||||||
Return of investment | 14 | $ 8 | ||||||
Accounts receivable, net | 10 | 10 | $ 3 | |||||
Collateral posted, expected to be released on closing | $ 35 | |||||||
Dynegy Marketing And Trade, LLC | Fuel Supply and Fuel Management Services Agreement | Elwood | ||||||||
Schedule of Equity Method Investments [Line Items] | ||||||||
Revenues | 15 | 27 | ||||||
J-Power USA Development Co. Ltd | Elwood | ||||||||
Schedule of Equity Method Investments [Line Items] | ||||||||
Ownership interest, percentage | 50.00% | |||||||
Proceeds from Sale of Equity Method Investments | $ 173 | |||||||
Impairments | $ 9 | $ 9 |
Risk Management Activities, Derivatives and Financial Instruments (Narratives) (Details) $ in Millions |
9 Months Ended |
---|---|
Sep. 30, 2016
USD ($)
| |
Minimum | |
Derivative [Line Items] | |
Rolling time period over which the entity can sell energy and capacity through near-term contractual arrangements | 1 year |
Maximum | |
Derivative [Line Items] | |
Rolling time period over which the entity can sell energy and capacity through near-term contractual arrangements | 3 years |
Commodity Contract | |
Derivative [Line Items] | |
Credit risk derivative liabilities at fair value | $ 26 |
Fair value of collateral | $ 12 |
Risk Management Activities, Derivatives and Financial Instruments (Schedule of Derivative Contracts and Interest Rate Swaps) (Details) $ in Millions |
Sep. 30, 2016
USD ($)
dollars
warrant
t
BTU
MWh
shares
|
Dec. 31, 2015
USD ($)
|
|||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Derivative [Line Items] | |||||||||||||
Number of securities called by each warrant or right | shares | 1 | ||||||||||||
Not Designated as Hedging Instrument | |||||||||||||
Derivative [Line Items] | |||||||||||||
Margin and collateral netting | $ 73 | $ 106 | |||||||||||
Not Designated as Hedging Instrument | Common stock warrants | Long | |||||||||||||
Derivative [Line Items] | |||||||||||||
Number of instruments held | warrant | [1] | 16,000,000 | |||||||||||
Derivative Fair Value, Liability | [1],[2] | $ (2) | |||||||||||
Not Designated as Hedging Instrument | Commodity Contract | Electricity derivatives | Short | |||||||||||||
Derivative [Line Items] | |||||||||||||
Number of instruments held | MWh | [3] | 58,000,000 | |||||||||||
Derivative Fair Value, Liability | [2],[3] | $ 25 | |||||||||||
Not Designated as Hedging Instrument | Commodity Contract | Electricity basis derivatives | Short | |||||||||||||
Derivative [Line Items] | |||||||||||||
Number of instruments held | MWh | [4] | 30,000,000 | |||||||||||
Derivative Fair Value, Liability | [2],[4] | $ (8) | |||||||||||
Not Designated as Hedging Instrument | Commodity Contract | Natural gas derivatives | Long | |||||||||||||
Derivative [Line Items] | |||||||||||||
Number of instruments held | BTU | [3] | 362,000,000 | |||||||||||
Derivative Fair Value, Liability | [2],[3] | $ (64) | |||||||||||
Not Designated as Hedging Instrument | Commodity Contract | Natural gas basis derivatives | Long | |||||||||||||
Derivative [Line Items] | |||||||||||||
Number of instruments held | BTU | 64,000,000 | ||||||||||||
Derivative Fair Value, Liability | [2] | $ (22) | |||||||||||
Not Designated as Hedging Instrument | Commodity Contract | Coal derivatives | |||||||||||||
Derivative [Line Items] | |||||||||||||
Number of instruments held | t | [5] | 1,000,000 | |||||||||||
Not Designated as Hedging Instrument | Commodity Contract | Coal derivatives | Long | |||||||||||||
Derivative [Line Items] | |||||||||||||
Number of instruments held | t | [5] | 0 | |||||||||||
Derivative Fair Value, Liability | [2],[5] | $ (7) | |||||||||||
Not Designated as Hedging Instrument | Commodity Contract | Emissions derivatives | Long | |||||||||||||
Derivative [Line Items] | |||||||||||||
Number of instruments held | t | 5,000,000 | ||||||||||||
Derivative Fair Value, Liability | [2] | $ (5) | |||||||||||
Not Designated as Hedging Instrument | Interest rate swaps | Long | |||||||||||||
Derivative [Line Items] | |||||||||||||
Number of instruments held | dollars | 771,000,000 | ||||||||||||
Derivative Fair Value, Liability | [2] | $ (40) | |||||||||||
|
Risk Management Activities, Derivatives and Financial Instruments (Schedule of Derivative Instruments in the Balance Sheet) (Details) - Not Designated as Hedging Instrument - USD ($) $ in Millions |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Risk Management Activities, Derivatives and Financial Instruments | ||
Derivative Asset, Gross Fair Value | $ 351 | $ 403 |
Derivative Asset, Contract Netting | (238) | (285) |
Derivative Asset, Collateral, Obligation to Return Cash, Offset | 0 | 0 |
Derivative Assets, Net Fair Value | 113 | 118 |
Derivative Liabilities, Gross Fair Value | (474) | (606) |
Derivative Liability, Contract Netting | (238) | (285) |
Margin and collateral netting | 73 | 106 |
Derivative Liabilities, Net Fair Value | (163) | (215) |
Derivative Assets (Liabilities), Gross Fair Value | (123) | (203) |
Derivative Asset and Liability Contract Netting | 0 | 0 |
Derivative Asset And Liability, Collateral, Obligation to Return Cash, Offset | 73 | 106 |
Derivative Assets (Liabilities), Net Fair Value | (50) | (97) |
Commodity Contract | Assets from Risk Management Activities | ||
Risk Management Activities, Derivatives and Financial Instruments | ||
Derivative Asset, Gross Fair Value | 351 | 403 |
Derivative Asset, Contract Netting | (238) | (285) |
Derivative Asset, Collateral, Obligation to Return Cash, Offset | 0 | 0 |
Derivative Assets, Net Fair Value | 113 | 118 |
Commodity Contract | Liabilities from Risk Management Activities | ||
Risk Management Activities, Derivatives and Financial Instruments | ||
Derivative Liabilities, Gross Fair Value | (432) | (557) |
Derivative Liability, Contract Netting | (238) | (285) |
Margin and collateral netting | 73 | 106 |
Derivative Liabilities, Net Fair Value | (121) | (166) |
Interest rate contracts | Liabilities from Risk Management Activities | ||
Risk Management Activities, Derivatives and Financial Instruments | ||
Derivative Liabilities, Gross Fair Value | (40) | (42) |
Derivative Liability, Contract Netting | 0 | 0 |
Margin and collateral netting | 0 | 0 |
Derivative Liabilities, Net Fair Value | (40) | (42) |
Common stock warrants | Other Liabilities | ||
Risk Management Activities, Derivatives and Financial Instruments | ||
Derivative Liabilities, Gross Fair Value | (2) | (7) |
Derivative Liability, Contract Netting | 0 | 0 |
Margin and collateral netting | 0 | 0 |
Derivative Liabilities, Net Fair Value | $ (2) | $ (7) |
Risk Management Activities, Derivatives and Financial Instruments (Schedule of Collateral Posted and Balance Sheet Location) (Details) - Commodity Contract - Prepayments and Other Current Assets - USD ($) $ in Millions |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Derivative [Line Items] | ||
Gross collateral posted with counterparties | $ 119 | $ 162 |
Less: Collateral netted against risk management liabilities | 73 | 106 |
Net collateral within Prepayments and other current assets | $ 46 | $ 56 |
Risk Management Activities, Derivatives and Financial Instruments (Schedule of Derivative Instruments, Gain (Loss) in the Statement of Operations) (Details) - Not Designated as Hedging Instrument - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
|
Commodity Contract | Revenues | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Recognized gain (loss) on derivatives | $ (27) | $ 48 | $ 188 | $ 120 |
Interest rate contracts | Interest expense | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Recognized gain (loss) on derivatives | 1 | (9) | (11) | (17) |
Common stock warrants | Other income and (expense), net | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Recognized gain (loss) on derivatives | $ 4 | $ 45 | $ 5 | $ 43 |
Fair Value Measurements (Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis) (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Millions |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Assets: | ||
Total assets from commodity risk management activities | $ 351 | $ 403 |
Liabilities: | ||
Liabilities from commodity risk management activities: | (432) | (557) |
Liabilities from interest rate contracts | (40) | (42) |
Total liabilities | (474) | (606) |
Electricity contracts | ||
Assets: | ||
Assets from commodity risk management activities: | 286 | 348 |
Liabilities: | ||
Liabilities from commodity risk management activities: | (269) | (325) |
Natural gas derivatives | ||
Assets: | ||
Assets from commodity risk management activities: | 61 | 42 |
Liabilities: | ||
Liabilities from commodity risk management activities: | (147) | (192) |
Emissions derivatives | ||
Assets: | ||
Assets from commodity risk management activities: | 3 | |
Liabilities: | ||
Liabilities from commodity risk management activities: | (8) | |
Diesel derivatives | ||
Liabilities: | ||
Liabilities from commodity risk management activities: | (4) | |
Coal derivatives | ||
Assets: | ||
Assets from commodity risk management activities: | 1 | 13 |
Liabilities: | ||
Liabilities from commodity risk management activities: | (8) | (36) |
Liabilities from outstanding common stock warrants | ||
Liabilities: | ||
Liabilities from outstanding common stock warrants | (2) | (7) |
Level 1 | ||
Assets: | ||
Total assets from commodity risk management activities | 0 | 0 |
Liabilities: | ||
Liabilities from commodity risk management activities: | 0 | 0 |
Liabilities from interest rate contracts | 0 | 0 |
Total liabilities | (2) | (7) |
Level 1 | Electricity contracts | ||
Assets: | ||
Assets from commodity risk management activities: | 0 | 0 |
Liabilities: | ||
Liabilities from commodity risk management activities: | 0 | 0 |
Level 1 | Natural gas derivatives | ||
Assets: | ||
Assets from commodity risk management activities: | 0 | 0 |
Liabilities: | ||
Liabilities from commodity risk management activities: | 0 | 0 |
Level 1 | Emissions derivatives | ||
Assets: | ||
Assets from commodity risk management activities: | 0 | |
Liabilities: | ||
Liabilities from commodity risk management activities: | 0 | |
Level 1 | Diesel derivatives | ||
Liabilities: | ||
Liabilities from commodity risk management activities: | 0 | |
Level 1 | Coal derivatives | ||
Assets: | ||
Assets from commodity risk management activities: | 0 | 0 |
Liabilities: | ||
Liabilities from commodity risk management activities: | 0 | 0 |
Level 1 | Liabilities from outstanding common stock warrants | ||
Liabilities: | ||
Liabilities from outstanding common stock warrants | (2) | (7) |
Level 2 | ||
Assets: | ||
Total assets from commodity risk management activities | 302 | 358 |
Liabilities: | ||
Liabilities from commodity risk management activities: | (360) | (464) |
Liabilities from interest rate contracts | (40) | (42) |
Total liabilities | (400) | (506) |
Level 2 | Electricity contracts | ||
Assets: | ||
Assets from commodity risk management activities: | 248 | 308 |
Liabilities: | ||
Liabilities from commodity risk management activities: | (221) | (267) |
Level 2 | Natural gas derivatives | ||
Assets: | ||
Assets from commodity risk management activities: | 51 | 40 |
Liabilities: | ||
Liabilities from commodity risk management activities: | (123) | (158) |
Level 2 | Emissions derivatives | ||
Assets: | ||
Assets from commodity risk management activities: | 3 | |
Liabilities: | ||
Liabilities from commodity risk management activities: | (8) | |
Level 2 | Diesel derivatives | ||
Liabilities: | ||
Liabilities from commodity risk management activities: | (4) | |
Level 2 | Coal derivatives | ||
Assets: | ||
Assets from commodity risk management activities: | 0 | 10 |
Liabilities: | ||
Liabilities from commodity risk management activities: | (8) | (35) |
Level 2 | Liabilities from outstanding common stock warrants | ||
Liabilities: | ||
Liabilities from outstanding common stock warrants | 0 | 0 |
Level 3 | ||
Assets: | ||
Total assets from commodity risk management activities | 49 | 45 |
Liabilities: | ||
Liabilities from commodity risk management activities: | (72) | (93) |
Liabilities from interest rate contracts | 0 | 0 |
Total liabilities | (72) | (93) |
Level 3 | Electricity contracts | ||
Assets: | ||
Assets from commodity risk management activities: | 38 | 40 |
Liabilities: | ||
Liabilities from commodity risk management activities: | (48) | (58) |
Level 3 | Natural gas derivatives | ||
Assets: | ||
Assets from commodity risk management activities: | 10 | 2 |
Liabilities: | ||
Liabilities from commodity risk management activities: | (24) | (34) |
Level 3 | Emissions derivatives | ||
Assets: | ||
Assets from commodity risk management activities: | 0 | |
Liabilities: | ||
Liabilities from commodity risk management activities: | 0 | |
Level 3 | Diesel derivatives | ||
Liabilities: | ||
Liabilities from commodity risk management activities: | 0 | |
Level 3 | Coal derivatives | ||
Assets: | ||
Assets from commodity risk management activities: | 1 | 3 |
Liabilities: | ||
Liabilities from commodity risk management activities: | 0 | (1) |
Level 3 | Liabilities from outstanding common stock warrants | ||
Liabilities: | ||
Liabilities from outstanding common stock warrants | $ 0 | $ 0 |
Fair Value Measurements (Sensitivity to Changes in Significant Unobservable Inputs for Level 3 Valuations) (Details) - Market Approach Valuation Technique - Level 3 - Fair Value, Measurements, Recurring T in Millions, MWh in Millions, BTU in Millions |
9 Months Ended | |||
---|---|---|---|---|
Sep. 30, 2016
USD ($)
BTU
T
MWh
| ||||
Forward contracts - power | ||||
Fair Value Inputs, Equity, Quantitative Information [Line Items] | ||||
Number of instruments held | MWh | 10 | [1] | ||
Fair value of derivatives held | $ (7,000,000) | [1] | ||
Forward contracts - power | Minimum | ||||
Fair Value Inputs, Equity, Quantitative Information [Line Items] | ||||
Basis spread | 5.00 | |||
Forward contracts - power | Maximum | ||||
Fair Value Inputs, Equity, Quantitative Information [Line Items] | ||||
Basis spread | $ 7.00 | |||
FTRs | ||||
Fair Value Inputs, Equity, Quantitative Information [Line Items] | ||||
Number of instruments held | MWh | 26 | |||
Fair value of derivatives held | $ (3,000,000) | |||
FTRs | Minimum | ||||
Fair Value Inputs, Equity, Quantitative Information [Line Items] | ||||
Forward price | 0.00 | |||
FTRs | Maximum | ||||
Fair Value Inputs, Equity, Quantitative Information [Line Items] | ||||
Forward price | $ 6.00 | |||
Natural gas derivatives | ||||
Fair Value Inputs, Equity, Quantitative Information [Line Items] | ||||
Number of instruments held | BTU | 78 | [1] | ||
Fair value of derivatives held | $ (14,000,000) | [1] | ||
Natural gas derivatives | Minimum | ||||
Fair Value Inputs, Equity, Quantitative Information [Line Items] | ||||
Forward price | 1.05 | |||
Natural gas derivatives | Maximum | ||||
Fair Value Inputs, Equity, Quantitative Information [Line Items] | ||||
Forward price | $ 1.35 | |||
Forward contracts - coal | ||||
Fair Value Inputs, Equity, Quantitative Information [Line Items] | ||||
Number of instruments held | T | 0 | [1] | ||
Fair value of derivatives held | $ 1,000,000 | [1] | ||
Forward contracts - coal | Minimum | ||||
Fair Value Inputs, Equity, Quantitative Information [Line Items] | ||||
Forward price | 6.10 | |||
Forward contracts - coal | Maximum | ||||
Fair Value Inputs, Equity, Quantitative Information [Line Items] | ||||
Forward price | $ 7.45 | |||
|
Fair Value Measurements (Schedule of Changes in Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | |||||
---|---|---|---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | |||||||
Unrealized gain (loss) relating to instruments held at the end of the period | $ 75 | $ 117 | |||||
Level 3 | |||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | |||||||
Balance at the beginning of the period | $ (38) | $ (68) | (48) | (4) | |||
Acquisitions | (72) | ||||||
Total gains (losses) included in earnings | 6 | (1) | 4 | 7 | |||
Settlements | [1] | 9 | 7 | 21 | 7 | ||
Balance at the end of the period | (23) | (62) | (23) | (62) | |||
Unrealized gain (loss) relating to instruments held at the end of the period | 6 | (1) | 4 | 7 | |||
Level 3 | Electricity Derivatives | |||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | |||||||
Balance at the beginning of the period | (24) | (54) | (18) | (4) | |||
Acquisitions | (54) | ||||||
Total gains (losses) included in earnings | 9 | 2 | 4 | 7 | |||
Settlements | [1] | 5 | 3 | 4 | 2 | ||
Balance at the end of the period | (10) | (49) | (10) | (49) | |||
Unrealized gain (loss) relating to instruments held at the end of the period | 9 | 2 | 4 | 7 | |||
Level 3 | Natural gas derivatives | |||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | |||||||
Balance at the beginning of the period | (15) | (11) | (32) | 0 | |||
Acquisitions | (14) | ||||||
Total gains (losses) included in earnings | (4) | (3) | 0 | 0 | |||
Settlements | [1] | 5 | 0 | 18 | 0 | ||
Balance at the end of the period | (14) | (14) | (14) | (14) | |||
Unrealized gain (loss) relating to instruments held at the end of the period | (4) | (3) | 0 | 0 | |||
Level 3 | Heat Rate Derivatives | |||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | |||||||
Balance at the beginning of the period | (7) | 0 | |||||
Acquisitions | (9) | ||||||
Total gains (losses) included in earnings | 0 | 0 | |||||
Settlements | [1] | 5 | 7 | ||||
Balance at the end of the period | (2) | (2) | |||||
Unrealized gain (loss) relating to instruments held at the end of the period | 0 | 0 | |||||
Level 3 | Coal derivatives | |||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | |||||||
Balance at the beginning of the period | 1 | 4 | 2 | 0 | |||
Acquisitions | 5 | ||||||
Total gains (losses) included in earnings | 1 | 0 | 0 | 0 | |||
Settlements | [1] | (1) | (1) | (1) | (2) | ||
Balance at the end of the period | 1 | 3 | 1 | 3 | |||
Unrealized gain (loss) relating to instruments held at the end of the period | $ 1 | $ 0 | $ 0 | $ 0 | |||
|
Fair Value Measurements (Schedule of Financial Assets and Liabilities) (Details) - USD ($) $ in Millions |
Sep. 30, 2016 |
Dec. 31, 2015 |
|||||
---|---|---|---|---|---|---|---|
Not Designated as Hedging Instrument | |||||||
Fair value of Financial Instruments | |||||||
Margin and collateral netting | $ 73 | $ 106 | |||||
Commodity Contract | Prepayments and Other Current Assets | |||||||
Fair value of Financial Instruments | |||||||
Margin and collateral netting | $ 73 | 106 | |||||
Senior Notes 6.75%, Due 2019 | |||||||
Fair value of Financial Instruments | |||||||
Stated interest rate | 6.75% | ||||||
Senior Notes 7.375%, Due 2022 | |||||||
Fair value of Financial Instruments | |||||||
Stated interest rate | 7.375% | ||||||
5.875% Senior Notes, Due June 2023 | |||||||
Fair value of Financial Instruments | |||||||
Stated interest rate | 5.875% | ||||||
Senior Notes 7.625%, Due 2024 | |||||||
Fair value of Financial Instruments | |||||||
Stated interest rate | 7.625% | ||||||
Dynegy, Inc. | Senior Notes 6.75%, Due 2019 | |||||||
Fair value of Financial Instruments | |||||||
Stated interest rate | 6.75% | ||||||
Dynegy, Inc. | Senior Notes 7.375%, Due 2022 | |||||||
Fair value of Financial Instruments | |||||||
Stated interest rate | 7.375% | ||||||
Dynegy, Inc. | 5.875% Senior Notes, Due June 2023 | |||||||
Fair value of Financial Instruments | |||||||
Stated interest rate | 5.875% | ||||||
Dynegy, Inc. | Senior Notes 7.625%, Due 2024 | |||||||
Fair value of Financial Instruments | |||||||
Stated interest rate | 7.625% | ||||||
Dynegy, Inc. | TEUs - 7.00% Amortizing Notes, due 2019 | |||||||
Fair value of Financial Instruments | |||||||
Stated interest rate | 7.00% | ||||||
Genco | Senior Notes Series H 7.00% Due 2018 | |||||||
Fair value of Financial Instruments | |||||||
Stated interest rate | 7.00% | ||||||
Genco | Senior Notes Series I 6.30% Due 2020 | |||||||
Fair value of Financial Instruments | |||||||
Stated interest rate | 6.30% | ||||||
Genco | Senior Notes Series F 7.95% Due 2032 | |||||||
Fair value of Financial Instruments | |||||||
Stated interest rate | 7.95% | ||||||
Carrying Amount | Dynegy, Inc. | Common stock warrants | |||||||
Fair value of Financial Instruments | |||||||
Common stock warrants | $ (2) | (7) | |||||
Carrying Amount | Dynegy, Inc. | Interest rate contracts | Not Designated as Hedging Instrument | |||||||
Fair value of Financial Instruments | |||||||
Interest rate derivatives | (40) | (42) | |||||
Carrying Amount | Dynegy, Inc. | Commodity Contract | Not Designated as Hedging Instrument | |||||||
Fair value of Financial Instruments | |||||||
Commodity-based derivative contracts | [1] | (81) | (154) | ||||
Carrying Amount | Dynegy, Inc. | Senior Notes 6.75%, Due 2019 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (2,081) | (2,077) | ||||
Carrying Amount | Dynegy, Inc. | Term Facilities Tranche B-2 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (762) | (766) | ||||
Carrying Amount | Dynegy, Inc. | Senior Notes 7.375%, Due 2022 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (1,731) | (1,729) | ||||
Carrying Amount | Dynegy, Inc. | 5.875% Senior Notes, Due June 2023 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (492) | (491) | ||||
Carrying Amount | Dynegy, Inc. | Senior Notes 7.625%, Due 2024 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (1,236) | (1,235) | ||||
Carrying Amount | Dynegy, Inc. | TEUs - 7.00% Amortizing Notes, due 2019 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (84) | 0 | ||||
Carrying Amount | Dynegy, Inc. | Forward capacity agreement | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (203) | 0 | ||||
Carrying Amount | Dynegy, Inc. | Inventory financing agreements | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | (136) | (136) | |||||
Carrying Amount | Dynegy, Inc. | Equipment financing agreements | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (75) | (61) | ||||
Carrying Amount | Dynegy Finance IV, Inc. | Tranche C Term Loan, due 2023 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (1,995) | 0 | ||||
Carrying Amount | Genco | Senior Notes Series H 7.00% Due 2018 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (284) | (276) | ||||
Carrying Amount | Genco | Senior Notes Series I 6.30% Due 2020 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (218) | (213) | ||||
Carrying Amount | Genco | Senior Notes Series F 7.95% Due 2032 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (226) | (225) | ||||
Fair Value | Dynegy, Inc. | Common stock warrants | |||||||
Fair value of Financial Instruments | |||||||
Common stock warrants | (2) | (7) | |||||
Fair Value | Dynegy, Inc. | Interest rate contracts | Not Designated as Hedging Instrument | |||||||
Fair value of Financial Instruments | |||||||
Interest rate derivatives | (40) | (42) | |||||
Fair Value | Dynegy, Inc. | Commodity Contract | Not Designated as Hedging Instrument | |||||||
Fair value of Financial Instruments | |||||||
Commodity-based derivative contracts | [1] | (81) | (154) | ||||
Fair Value | Dynegy, Inc. | Senior Notes 6.75%, Due 2019 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (2,168) | (1,985) | ||||
Fair Value | Dynegy, Inc. | Term Facilities Tranche B-2 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (779) | (754) | ||||
Fair Value | Dynegy, Inc. | Senior Notes 7.375%, Due 2022 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (1,724) | (1,531) | ||||
Fair Value | Dynegy, Inc. | 5.875% Senior Notes, Due June 2023 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (450) | (404) | ||||
Fair Value | Dynegy, Inc. | Senior Notes 7.625%, Due 2024 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (1,225) | (1,078) | ||||
Fair Value | Dynegy, Inc. | TEUs - 7.00% Amortizing Notes, due 2019 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (88) | 0 | ||||
Fair Value | Dynegy, Inc. | Forward capacity agreement | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (203) | 0 | ||||
Fair Value | Dynegy, Inc. | Inventory financing agreements | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | (135) | (137) | |||||
Fair Value | Dynegy, Inc. | Equipment financing agreements | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (75) | (61) | ||||
Fair Value | Dynegy Finance IV, Inc. | Tranche C Term Loan, due 2023 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (2,015) | 0 | ||||
Fair Value | Genco | Senior Notes Series H 7.00% Due 2018 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (119) | (204) | ||||
Fair Value | Genco | Senior Notes Series I 6.30% Due 2020 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | (99) | (148) | ||||
Fair Value | Genco | Senior Notes Series F 7.95% Due 2032 | |||||||
Fair value of Financial Instruments | |||||||
Long-term debt, gross | [2] | $ (107) | $ (162) | ||||
|
Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions |
9 Months Ended | ||||
---|---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
||||
Accumulated Other Comprehensive Income [Roll Forward] | |||||
Beginning of period | $ 19 | $ 20 | |||
Actuarial gain and plan amendments (net of tax of zero and $2, respectively) | 0 | 7 | |||
Amortization of unrecognized prior service credit and actuarial gain (net of tax of zero and zero, respectively) | [1] | (4) | (3) | ||
Net current period other comprehensive income (loss), net of tax | (4) | 4 | |||
End of period | 15 | 24 | |||
Tax on actuarial gain and plan amendments | 0 | 2 | |||
Tax on amortization of unrecognized prior service cost (credit) and actuarial loss (gain) | [1] | $ 0 | $ 0 | ||
|
Inventory (Summary of Inventories) (Details) - USD ($) $ in Millions |
Sep. 30, 2016 |
Dec. 31, 2015 |
|||||
---|---|---|---|---|---|---|---|
Inventory Disclosure [Abstract] | |||||||
Materials and supplies | $ 183 | $ 178 | |||||
Coal | [1] | 233 | 350 | ||||
Fuel oil | [1] | 17 | 17 | ||||
Emissions allowances | [2] | 14 | 51 | ||||
Other | 0 | 1 | |||||
Total | $ 447 | $ 597 | |||||
|
Inventory (Inventory Summary Footnote) (Details) - USD ($) $ in Millions |
Sep. 30, 2016 |
Dec. 31, 2015 |
||||
---|---|---|---|---|---|---|
Inventory [Line Items] | ||||||
Coal | [1] | $ 233 | $ 350 | |||
Fuel oil | [1] | 17 | 17 | |||
Inventory financing agreements | ||||||
Inventory [Line Items] | ||||||
Coal | 47 | [1] | 44 | |||
Fuel oil | $ 16 | [1] | $ 16 | |||
|
Property, Plant and Equipment (Details) - USD ($) $ in Millions |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Property, Plant and Equipment, Net, by Type [Abstract] | ||
Property, plant and equipment | $ 8,522 | $ 9,235 |
Accumulated depreciation | (1,270) | (888) |
Property, Plant and Equipment, Net | 7,252 | 8,347 |
Power generation | ||
Property, Plant and Equipment, Net, by Type [Abstract] | ||
Property, plant and equipment | 7,481 | 8,178 |
Building and Building Improvements | ||
Property, Plant and Equipment, Net, by Type [Abstract] | ||
Property, plant and equipment | 938 | 956 |
Office and miscellaneous Equipment | ||
Property, Plant and Equipment, Net, by Type [Abstract] | ||
Property, plant and equipment | $ 103 | $ 101 |
Property, Plant and Equipment (Narrative) (Details) - USD ($) |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
|
Property, Plant and Equipment [Line Items] | ||||
Impairments of long lived assets held for use | $ 212,000,000 | $ 74,000,000 | $ 857,000,000 | $ 74,000,000 |
Asset impairment charges | 212,000,000 | 74,000,000 | 857,000,000 | 74,000,000 |
Stuart Facility | ||||
Property, Plant and Equipment [Line Items] | ||||
Estimated fair value | 0 | 0 | ||
Impairments of long lived assets held for use | 55,000,000 | $ 55,000,000 | ||
Baldwin Power Generation Facility | Power generation | ||||
Property, Plant and Equipment [Line Items] | ||||
Discount rate (as a percentage) | 13.00% | |||
Long-term growth rate (as a percentage) | 2.50% | |||
Estimated fair value | 97,000,000 | $ 97,000,000 | ||
Asset impairment charges | 645,000,000 | |||
Newton Power Generation Facility | ||||
Property, Plant and Equipment [Line Items] | ||||
Asset impairment charges | $ 148,000,000 | $ 148,000,000 | ||
Wood River Power Station | ||||
Property, Plant and Equipment [Line Items] | ||||
Impairments of long lived assets held for use | $ 74,000,000 | $ 0 |
Joint Ownership of Generating Facilities (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||||||
---|---|---|---|---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
Dec. 31, 2015 |
||||
Schedule of Equity Method Investments [Line Items] | ||||||||
Property, plant and equipment | $ 8,522 | $ 8,522 | $ 9,235 | |||||
Accumulated Depreciation | (1,270) | (1,270) | (888) | |||||
Property, plant and equipment, net | 7,252 | 7,252 | $ 8,347 | |||||
Impairments | $ (212) | $ (74) | $ (857) | $ (74) | ||||
Miami Fort | ||||||||
Schedule of Equity Method Investments [Line Items] | ||||||||
Ownership Interest | 64.00% | 64.00% | 64.00% | |||||
Property, plant and equipment | $ 206 | $ 206 | $ 207 | |||||
Accumulated Depreciation | (33) | (33) | (16) | |||||
Construction Work in Progress | 3 | 3 | 3 | |||||
Property, plant and equipment, net | $ 176 | $ 176 | $ 194 | |||||
J.M. Stuart | ||||||||
Schedule of Equity Method Investments [Line Items] | ||||||||
Ownership Interest | [1] | 39.00% | 39.00% | 39.00% | ||||
Property, plant and equipment | [1] | $ 0 | $ 0 | $ 32 | ||||
Accumulated Depreciation | [1] | 0 | 0 | (4) | ||||
Construction Work in Progress | [1] | 0 | 0 | 20 | ||||
Property, plant and equipment, net | [1] | $ 0 | $ 0 | $ 48 | ||||
Conesville | ||||||||
Schedule of Equity Method Investments [Line Items] | ||||||||
Ownership Interest | [1] | 40.00% | 40.00% | 40.00% | ||||
Property, plant and equipment | [1] | $ 61 | $ 61 | $ 61 | ||||
Accumulated Depreciation | [1] | (2) | (2) | (2) | ||||
Construction Work in Progress | [1] | 5 | 5 | 4 | ||||
Property, plant and equipment, net | [1] | $ 64 | $ 64 | $ 63 | ||||
W.M. Zimmer | ||||||||
Schedule of Equity Method Investments [Line Items] | ||||||||
Ownership Interest | 46.50% | 46.50% | 46.50% | |||||
Property, plant and equipment | $ 116 | $ 116 | $ 99 | |||||
Accumulated Depreciation | (21) | (21) | (10) | |||||
Construction Work in Progress | 4 | 4 | 11 | |||||
Property, plant and equipment, net | $ 99 | $ 99 | $ 100 | |||||
Killen Station | ||||||||
Schedule of Equity Method Investments [Line Items] | ||||||||
Ownership Interest | [1] | 33.00% | 33.00% | 33.00% | ||||
Property, plant and equipment | [1] | $ 18 | $ 18 | $ 17 | ||||
Accumulated Depreciation | [1] | (1) | (1) | (1) | ||||
Construction Work in Progress | [1] | 2 | 2 | 2 | ||||
Property, plant and equipment, net | [1] | 19 | 19 | $ 18 | ||||
Stuart Facility | ||||||||
Schedule of Equity Method Investments [Line Items] | ||||||||
Impairments | $ (55) | $ (55) | ||||||
|
Intangible Assets and Liabilities (Intangible Assets and Liabilities) (Details) - USD ($) $ in Millions |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Intangible Assets and Liabilities [Line Items] | ||
Gross Carrying Amount | $ 306 | $ 306 |
Accumulated Amortization | (224) | (142) |
Net Carrying Amount | 82 | 164 |
Electricity Contract Liability, Gross | (28) | (30) |
Electricity Contract Liability, Accumulated Amortization | 26 | 19 |
Electricity Contract Liability, Net | (2) | (11) |
Coal Contract Liability, Gross | (93) | (134) |
Coal Contract Liability, Accumulated Amortization | 76 | 82 |
Coal Contract Liability, Net | (17) | (52) |
Coal Transport Contract Liability, Gross | (104) | (104) |
Coal Transport Liability, Accumulated Amortization | 85 | 64 |
Coal Transport Liability, Net | (19) | (40) |
Gas Transport Contract Liability, Gross | (41) | (64) |
Gas Transport Liability, Accumulated Amortization | 7 | 27 |
Gas Transport Liability, Net | (34) | (37) |
Intangible Liabilities, Gross | (266) | (332) |
Intangible Liabilities, Accumulated Amortization | 194 | 192 |
Intangible Liabilities, Net | (72) | (140) |
Intangible Assets (Liabilities), Gross | 40 | (26) |
Intangible Assets (Liabilities), Accumulated Amortization | (30) | 50 |
Intangible Assets (Liabilities), Net | 10 | 24 |
Electricity contracts | ||
Intangible Assets and Liabilities [Line Items] | ||
Gross Carrying Amount | 260 | 260 |
Accumulated Amortization | (187) | (126) |
Net Carrying Amount | 73 | 134 |
Gas transport contracts | ||
Intangible Assets and Liabilities [Line Items] | ||
Gross Carrying Amount | 46 | 46 |
Accumulated Amortization | (37) | (16) |
Net Carrying Amount | $ 9 | $ 30 |
Intangible Assets and Liabilities (Amortization of Intangible Assets and Liabilities) (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | |||||||
---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
||||||
Intangible Assets and Liabilities [Line Items] | |||||||||
Amortization of intangibles | $ 4 | $ (9) | $ 17 | $ (18) | |||||
Electricity contracts, net | |||||||||
Intangible Assets and Liabilities [Line Items] | |||||||||
Amortization of intangibles | [1] | 19 | 21 | 52 | 53 | ||||
Coal contracts | |||||||||
Intangible Assets and Liabilities [Line Items] | |||||||||
Amortization of intangibles | [2] | (9) | (19) | (32) | (42) | ||||
Coal transport contracts | |||||||||
Intangible Assets and Liabilities [Line Items] | |||||||||
Amortization of intangibles | [2] | (7) | (9) | (21) | (24) | ||||
Gas transport contracts | |||||||||
Intangible Assets and Liabilities [Line Items] | |||||||||
Amortization of intangibles | [2] | $ 1 | $ (2) | $ 18 | $ (5) | ||||
|
Tangible Equity Units (Details) - Tangible Equity Units - USD ($) $ / shares in Units, $ in Millions |
3 Months Ended | 6 Months Ended | 9 Months Ended |
---|---|---|---|
Sep. 30, 2016 |
Jun. 30, 2016 |
Sep. 30, 2016 |
|
Tangible Equity Units [Line Items] | |||
Number of units issued | 4,600,000 | ||
Stated interest rate | 7.00% | 7.00% | 7.00% |
Unit price (in dollars per unit) | $ 100 | $ 100 | $ 100 |
Less: Issuance costs | $ 3 | $ 14 | $ 17 |
Net proceeds | $ 446 | $ 443 | |
Initial principal amount per unit (in dollars per unit) | $ 18.95 | ||
Observation period, consecutive trading days | 20 days | ||
Threshold appreciation price | $ 19.92 | ||
Initial reference price | $ 16.13 | ||
Minimum | |||
Tangible Equity Units [Line Items] | |||
Settlement rate per unit | 5.0201 | ||
Maximum | |||
Tangible Equity Units [Line Items] | |||
Settlement rate per unit | 6.1996 | ||
Secondary annual installments | |||
Tangible Equity Units [Line Items] | |||
Quarterly cash installment (in dollars per unit) | $ 1.75 | ||
Initial Installment, due October 1, 2016 | |||
Tangible Equity Units [Line Items] | |||
Quarterly cash installment (in dollars per unit) | $ 1.94 |
Tangible Equity Units (Net Proceeds Schedule) (Details) - USD ($) $ / shares in Units, $ in Millions |
3 Months Ended | 6 Months Ended | 9 Months Ended |
---|---|---|---|
Sep. 30, 2016 |
Jun. 30, 2016 |
Sep. 30, 2016 |
|
Total | |||
Tangible Equity Units [Line Items] | |||
Price per TEU (in dollars per unit) | $ 100 | $ 100 | $ 100 |
Gross proceeds | $ 460 | ||
Less: Issuance costs | $ (3) | $ (14) | (17) |
Net proceeds | $ 446 | $ 443 | |
SPC | |||
Tangible Equity Units [Line Items] | |||
Price per TEU (in dollars per unit) | $ 81 | $ 81 | |
Gross proceeds | $ 373 | ||
Less: Issuance costs | (14) | ||
Net proceeds | $ 359 | ||
Amortizing Note | |||
Tangible Equity Units [Line Items] | |||
Price per TEU (in dollars per unit) | $ 19 | $ 19 | |
Gross proceeds | $ 87 | ||
Less: Issuance costs | (3) | ||
Net proceeds | $ 84 |
Debt (Schedule of Long-term Debt) (Details) - USD ($) $ in Millions |
Sep. 30, 2016 |
Mar. 18, 2016 |
Dec. 31, 2015 |
|||||||
---|---|---|---|---|---|---|---|---|---|---|
Debt Instrument [Line Items] | ||||||||||
Carrying amount | $ 9,741 | $ 7,416 | ||||||||
Unamortized debt discounts and issuance costs (2) | [1] | (218) | (207) | |||||||
Total Debt | 9,523 | 7,209 | ||||||||
Less: Current maturities, including unamortized debt discounts and issuance costs, net | 167 | 80 | ||||||||
Debt, long-term portion, net | $ 9,356 | 7,129 | ||||||||
Forward capacity agreement | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | $ 219 | |||||||||
Senior Notes 6.75%, Due 2019 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Stated interest rate | 6.75% | |||||||||
Senior Notes 7.375%, Due 2022 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Stated interest rate | 7.375% | |||||||||
5.875% Senior Notes, Due June 2023 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Stated interest rate | 5.875% | |||||||||
Senior Notes 7.625%, Due 2024 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Stated interest rate | 7.625% | |||||||||
Secured and Unsecured Debt | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | $ 8,916 | 6,591 | ||||||||
Secured Debt | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | $ 3,129 | 916 | ||||||||
Dynegy, Inc. | TEUs - 7.00% Amortizing Notes, due 2019 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Stated interest rate | 7.00% | |||||||||
Dynegy, Inc. | Senior Notes 6.75%, Due 2019 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Stated interest rate | 6.75% | |||||||||
Dynegy, Inc. | Senior Notes 7.375%, Due 2022 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Stated interest rate | 7.375% | |||||||||
Dynegy, Inc. | 5.875% Senior Notes, Due June 2023 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Stated interest rate | 5.875% | |||||||||
Dynegy, Inc. | Senior Notes 7.625%, Due 2024 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Stated interest rate | 7.625% | |||||||||
Dynegy, Inc. | Secured Debt | Tranche B-2 Term Loan, Due 2020 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | $ 774 | 780 | ||||||||
Dynegy, Inc. | Secured Debt | Revolving Facility | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | 0 | 0 | ||||||||
Dynegy, Inc. | Secured Debt | Forward capacity agreement | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | 219 | 0 | ||||||||
Dynegy, Inc. | Secured Debt | Inventory financing agreements | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | 136 | 136 | ||||||||
Dynegy, Inc. | Unsecured Debt | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | 5,787 | 5,675 | ||||||||
Dynegy, Inc. | Unsecured Debt | TEUs - 7.00% Amortizing Notes, due 2019 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | 87 | 0 | ||||||||
Dynegy, Inc. | Unsecured Debt | Senior Notes 6.75%, Due 2019 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | 2,100 | 2,100 | ||||||||
Dynegy, Inc. | Unsecured Debt | Senior Notes 7.375%, Due 2022 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | 1,750 | 1,750 | ||||||||
Dynegy, Inc. | Unsecured Debt | 5.875% Senior Notes, Due June 2023 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | 500 | 500 | ||||||||
Dynegy, Inc. | Unsecured Debt | Senior Notes 7.625%, Due 2024 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | 1,250 | 1,250 | ||||||||
Dynegy, Inc. | Unsecured Debt | Equipment financing agreements | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | 100 | 75 | ||||||||
Dynegy Finance IV, Inc. | Secured Debt | Tranche C Term Loan, due 2023 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | [2] | 2,000 | 0 | |||||||
Genco | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | $ 825 | |||||||||
Genco | Senior Notes Series H 7.00% Due 2018 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Stated interest rate | 7.00% | |||||||||
Genco | Senior Notes Series I 6.30% Due 2020 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Stated interest rate | 6.30% | |||||||||
Genco | Senior Notes Series F 7.95% Due 2032 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Stated interest rate | 7.95% | |||||||||
Genco | Unsecured Debt | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | [3] | $ 825 | 825 | |||||||
Unamortized debt discounts and issuance costs (2) | (97) | (111) | ||||||||
Genco | Unsecured Debt | Senior Notes Series H 7.00% Due 2018 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | 300 | 300 | ||||||||
Genco | Unsecured Debt | Senior Notes Series I 6.30% Due 2020 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | 250 | 250 | ||||||||
Genco | Unsecured Debt | Senior Notes Series F 7.95% Due 2032 | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Carrying amount | $ 275 | $ 275 | ||||||||
|
Debt (Narratives) (Details) |
9 Months Ended | 12 Months Ended | ||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 18, 2016
USD ($)
|
Sep. 30, 2016
USD ($)
tranche
$ / shares
|
Dec. 31, 2018
USD ($)
|
Dec. 31, 2017
USD ($)
|
Oct. 11, 2016
USD ($)
|
Jun. 30, 2016
USD ($)
|
Jun. 27, 2016
USD ($)
|
Dec. 31, 2015
USD ($)
|
Aug. 14, 2015
USD ($)
|
Apr. 02, 2015
USD ($)
|
Apr. 01, 2015
USD ($)
|
Sep. 18, 2014
USD ($)
|
Dec. 02, 2013 |
||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Restricted cash | $ 2,000,000,000 | $ 0 | ||||||||||||||||||||
Long-term Debt | 9,523,000,000 | 7,209,000,000 | ||||||||||||||||||||
Carrying amount | 9,741,000,000 | 7,416,000,000 | ||||||||||||||||||||
Genco restricted payment interest coverage ratio minimum | [1] | 1.75% | ||||||||||||||||||||
Genco additional indebtedness interest coverage ratio minimum | [2] | 2.50% | ||||||||||||||||||||
Genco additional indebtedness debt-to-capital ratio maximum | [2] | 60.00% | ||||||||||||||||||||
Restricted cash | 85,000,000 | 39,000,000 | ||||||||||||||||||||
5.875% Senior Notes, Due June 2023 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Amount of unsecured senior notes | $ 500,000,000 | |||||||||||||||||||||
Stated interest rate | 5.875% | |||||||||||||||||||||
Revolving Facility | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Number of tranches | tranche | 3 | |||||||||||||||||||||
Tranche C Term Loan, due 2023 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Maximum borrowing capacity | $ 2,000,000,000 | |||||||||||||||||||||
Restricted cash | 2,000,000,000 | |||||||||||||||||||||
Escrow Agreement | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Restricted cash | 45,000,000 | $ 70,000,000 | ||||||||||||||||||||
Restricted cash released from escrow for interest payments | 26,000,000 | |||||||||||||||||||||
Letter of Credit | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Maximum borrowing capacity | $ 55,000,000 | |||||||||||||||||||||
Letters of credit outstanding | (55,000,000) | |||||||||||||||||||||
Revolving Credit Facility, Tranche B | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Line of credit facility, amount outstanding | $ 75,000,000 | |||||||||||||||||||||
Forward capacity agreement | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Proceeds from Issuance of Debt | $ 198,000,000 | |||||||||||||||||||||
Carrying amount | $ 219,000,000 | |||||||||||||||||||||
Effective interest rate | 4.45% | |||||||||||||||||||||
Term Facilities Tranche B-2 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Maximum borrowing capacity | $ 800,000,000 | |||||||||||||||||||||
Debt instrument term | 7 years | |||||||||||||||||||||
Senior Notes 6.75%, Due 2019 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Amount of unsecured senior notes | $ 2,100,000,000 | |||||||||||||||||||||
Stated interest rate | 6.75% | |||||||||||||||||||||
Senior Notes 7.375%, Due 2022 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Amount of unsecured senior notes | $ 1,750,000,000 | |||||||||||||||||||||
Stated interest rate | 7.375% | |||||||||||||||||||||
Senior Notes 7.625%, Due 2024 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Amount of unsecured senior notes | $ 1,250,000,000 | |||||||||||||||||||||
Stated interest rate | 7.625% | |||||||||||||||||||||
Term Facilities and Revolving Facility, (The Credit Agreement) | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Maximum borrowing capacity | $ 2,225,000,000.000 | |||||||||||||||||||||
Illinois Power Marketing | Letter of Credit and Reimbursement Agreement | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Savings deposits | 19,000,000 | |||||||||||||||||||||
Illinois Power Marketing | Letter of Credit | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Maximum borrowing capacity | $ 50,000,000 | |||||||||||||||||||||
Letters of credit outstanding | (30,000,000) | |||||||||||||||||||||
Delta Stock Purchase Agreement | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Maximum borrowing capacity | $ 50,000,000 | |||||||||||||||||||||
Dynegy, Inc. | 5.875% Senior Notes, Due June 2023 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Stated interest rate | 5.875% | |||||||||||||||||||||
Dynegy, Inc. | Equipment financing agreements | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Unamortized discount | $ 25,000,000 | |||||||||||||||||||||
Dynegy, Inc. | Senior Notes 6.75%, Due 2019 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Stated interest rate | 6.75% | |||||||||||||||||||||
Dynegy, Inc. | Senior Notes 7.375%, Due 2022 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Stated interest rate | 7.375% | |||||||||||||||||||||
Dynegy, Inc. | Senior Notes 7.625%, Due 2024 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Stated interest rate | 7.625% | |||||||||||||||||||||
Parent | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Restricted cash | $ 0 | |||||||||||||||||||||
Restricted cash | 0 | 0 | ||||||||||||||||||||
Parent | Senior Notes | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Amount of unsecured senior notes | 5,600,000,000.0 | |||||||||||||||||||||
Genco | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | $ 825,000,000 | |||||||||||||||||||||
Genco | Senior Notes Series H 7.00% Due 2018 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Stated interest rate | 7.00% | |||||||||||||||||||||
RGGI Repurchase Agreement | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Assets sold under agreements to repurchase, carrying amount | $ 78,000,000 | $ 78,000,000 | ||||||||||||||||||||
Assets sold under agreements to repurchase, carry rate | 3.49% | |||||||||||||||||||||
Minimum | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Projected interest coverage ratio determination period | 1 year | |||||||||||||||||||||
Maximum | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Projected interest coverage ratio determination period | 2 years | |||||||||||||||||||||
Revolving Facility | Line of Credit | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Maximum borrowing capacity | $ 1,425,000,000.000 | |||||||||||||||||||||
Line of credit facility, amount outstanding | 0 | |||||||||||||||||||||
Revolving Facility | Letter of Credit | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Letters of credit outstanding | (327,000,000) | |||||||||||||||||||||
Interest expense | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Restricted cash | 25,000,000 | |||||||||||||||||||||
Original Issue Discount | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Restricted cash | 20,000,000 | |||||||||||||||||||||
EquiPower and Duke Midwest Acquisitions | Revolving Facility | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Maximum borrowing capacity | 1,500,000,000.0 | |||||||||||||||||||||
Duke Midwest Acquisition | Revolving Facility | Tranche maturing on April 02, 2020 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Maximum borrowing capacity | $ 675,000,000 | |||||||||||||||||||||
EquiPower Acquisition | Inventory financing agreements | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Maximum borrowing capacity | $ 15,000,000 | |||||||||||||||||||||
Letters of credit outstanding | (58,000,000) | |||||||||||||||||||||
Debt Instrument, Collateral Amount | $ 3,000,000 | |||||||||||||||||||||
EquiPower Acquisition | Revolving Facility | Tranche maturing on April 23, 2018 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Maximum borrowing capacity | 475,000,000 | |||||||||||||||||||||
EquiPower Acquisition | Revolving Facility | Tranche maturing on April 01, 2020 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Maximum borrowing capacity | $ 350,000,000 | |||||||||||||||||||||
LIBOR | Inventory financing agreements | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Basis spread on variable rate (as a percentage) | 5.60% | |||||||||||||||||||||
Line of credit facility, commitment fee (as a percentage) | 0.25% | |||||||||||||||||||||
LIBOR | Tranche C Term Loan, due 2023 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Basis spread on variable rate (as a percentage) | 4.00% | |||||||||||||||||||||
LIBOR | Illinois Power Marketing | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Basis spread on variable rate (as a percentage) | 0.50% | |||||||||||||||||||||
LIBOR | Minimum | Tranche C Term Loan, due 2023 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Basis spread on variable rate (as a percentage) | 1.00% | |||||||||||||||||||||
Base Rate | Tranche C Term Loan, due 2023 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Basis spread on variable rate (as a percentage) | 3.00% | |||||||||||||||||||||
Coal contracts | Inventory financing agreements | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Inventory financing, debt obligation increase (as a percentage) | 85.00% | |||||||||||||||||||||
Inventory financing, line of credit increase (as a percentage) | 15.00% | |||||||||||||||||||||
Fuel Oils | Inventory financing agreements | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Inventory financing, debt obligation increase (as a percentage) | 90.00% | |||||||||||||||||||||
Inventory financing, line of credit increase (as a percentage) | 10.00% | |||||||||||||||||||||
Carrying Amount | Dynegy, Inc. | Equipment financing agreements | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Net present value of the payments | $ 75,000,000 | |||||||||||||||||||||
Interest rate swaps | Term Facilities Tranche B-2 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Derivative, notional amount | $ 771,000,000 | |||||||||||||||||||||
Derivative, average fixed interest rate (as a percentage) | 3.19% | |||||||||||||||||||||
Derivative, lower fixed interest rate range (as a percentage) | 1.00% | |||||||||||||||||||||
Unsecured Debt | Dynegy, Inc. | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | $ 5,787,000,000 | 5,675,000,000 | ||||||||||||||||||||
Unsecured Debt | Dynegy, Inc. | 5.875% Senior Notes, Due June 2023 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | 500,000,000 | 500,000,000 | ||||||||||||||||||||
Unsecured Debt | Dynegy, Inc. | Equipment financing agreements | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | 100,000,000 | 75,000,000 | ||||||||||||||||||||
Unsecured Debt | Dynegy, Inc. | Senior Notes 6.75%, Due 2019 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | 2,100,000,000 | 2,100,000,000 | ||||||||||||||||||||
Unsecured Debt | Dynegy, Inc. | Senior Notes 7.375%, Due 2022 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | 1,750,000,000 | 1,750,000,000 | ||||||||||||||||||||
Unsecured Debt | Dynegy, Inc. | Senior Notes 7.625%, Due 2024 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | 1,250,000,000 | 1,250,000,000 | ||||||||||||||||||||
Unsecured Debt | Genco | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | [3] | 825,000,000 | 825,000,000 | |||||||||||||||||||
Unsecured Debt | Genco | Senior Notes Series H 7.00% Due 2018 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | 300,000,000 | 300,000,000 | ||||||||||||||||||||
Secured Debt | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | 3,129,000,000 | 916,000,000 | ||||||||||||||||||||
Secured Debt | Dynegy, Inc. | Inventory financing agreements | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | 136,000,000 | 136,000,000 | ||||||||||||||||||||
Secured Debt | Dynegy, Inc. | Revolving Facility | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | 0 | 0 | ||||||||||||||||||||
Secured Debt | Dynegy, Inc. | Forward capacity agreement | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Carrying amount | $ 219,000,000 | 0 | ||||||||||||||||||||
Secured Debt | Dynegy Finance IV, Inc. | Tranche C Term Loan, due 2023 | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Debt instrument term | 7 years | |||||||||||||||||||||
Carrying amount | [4] | $ 2,000,000,000 | $ 0 | |||||||||||||||||||
Forecasted repayments | Forward capacity agreement | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Repayments of Debt | $ 109,000,000 | $ 110,000,000 | ||||||||||||||||||||
Amortizing Note | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Gross proceeds | $ 87,000,000 | |||||||||||||||||||||
Tangible Equity Units | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Stated interest rate | 7.00% | 7.00% | ||||||||||||||||||||
Gross proceeds | $ 460,000,000 | |||||||||||||||||||||
Secondary annual installments | Tangible Equity Units | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Tangible Equity Units, Quarterly Cash Installment, Per Unit | $ / shares | $ 1.75 | |||||||||||||||||||||
Initial Installment, due October 1, 2016 | Tangible Equity Units | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Tangible Equity Units, Quarterly Cash Installment, Per Unit | $ / shares | $ 1.94 | |||||||||||||||||||||
Subsequent Event | 8.00% Unsecured Senior Notes | ||||||||||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||||||||||
Amount of unsecured senior notes | $ 750,000,000 | |||||||||||||||||||||
Stated interest rate | 8.00% | |||||||||||||||||||||
|
Commitments and Contingencies (Legal Proceedings) (Details) $ in Millions |
1 Months Ended | 3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|---|
Dec. 16, 2014
USD ($)
|
Sep. 30, 2010
USD ($)
|
Jun. 30, 2007
USD ($)
|
Sep. 30, 2016
USD ($)
state
|
Sep. 30, 2016
USD ($)
state
|
|
Gas Index Pricing Litigation | Pending Litigation | |||||
Loss Contingencies [Line Items] | |||||
Number of States with pending litigation | state | 3 | 3 | |||
Illinova Generating Company | Illinova Generating Company Arbitration | Pending Litigation | |||||
Loss Contingencies [Line Items] | |||||
Payments for legal settlements | $ 17.0 | ||||
Illinova Generating Company | Illinova Generating Company Arbitration | Judicial Ruling | |||||
Loss Contingencies [Line Items] | |||||
Value of damages awarded | $ 2.5 | $ 17.0 | |||
Gain litigation settlement | $ 20.0 | $ 20.0 |
Commitments and Contingencies (Other Commitments and Contingencies) (Details) $ in Millions |
1 Months Ended | 12 Months Ended | |||
---|---|---|---|---|---|
Jul. 31, 2013
USD ($)
|
Dec. 31, 2014
USD ($)
|
Dec. 31, 2012
localized_area
surface_impoundment
|
Sep. 30, 2016
$ / MWh
|
May 31, 2015
complaint
|
|
Hennepin, East Dam | |||||
Loss Contingencies [Line Items] | |||||
Post-closure monitoring costs | $ | $ 5 | ||||
Baldwin Groundwater, Environmental Protection Agency Regulations Compliance, Coal Combustion Residues | |||||
Loss Contingencies [Line Items] | |||||
Number of localized areas where groundwater standards were exceeded | localized_area | 2 | ||||
Vermillion Facility, Old East and North Sites | |||||
Loss Contingencies [Line Items] | |||||
Estimated cost for recommended closure alternative for impoundments | $ | $ 10 | ||||
Number of localized areas where groundwater standards were exceeded | surface_impoundment | 2 | ||||
MISO 2015-2016 Planning Resource Auction | |||||
Loss Contingencies [Line Items] | |||||
Number of complaints | complaint | 3 | ||||
Actions taken by FERC, 2016 and 2017 Reference level for capacity per day | $ / MWh | 0 | ||||
Pending Litigation | MISO 2015-2016 Planning Resource Auction | |||||
Loss Contingencies [Line Items] | |||||
Number of complaints | complaint | 1 |
Commitments and Contingencies (Indemnifications and Guarantees) (Details) - USD ($) |
Sep. 30, 2016 |
Jun. 27, 2016 |
---|---|---|
Delta Stock Purchase Agreement | Parent | ||
Loss Contingencies [Line Items] | ||
Ownership interest, percentage | 100.00% | |
LS Power Indemnities | ||
Loss Contingencies [Line Items] | ||
Number of claims and amount of accrued indemnifications, if any | $ 0 | |
Guarantee Obligations | Delta Stock Purchase Agreement | ||
Loss Contingencies [Line Items] | ||
Purchaser's obligation to pay reverse termination fee | $ 132,000,000 |
Income Taxes (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
|
Income Tax Contingency [Line Items] | ||||
Tax benefit (benefit) for application of effective state tax rates, in areas without valuation allowances | $ (1) | $ 7 | $ 6 | $ (14) |
Current state tax expense (benefit) | 14 | |||
EquiPower Acquisition | ||||
Income Tax Contingency [Line Items] | ||||
Increase (decrease) in net deferred tax liabilities | $ (21) | $ 3 | $ (459) |
Pension and Other Post-Employment Benefit Plans (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
|
Defined Benefit Plan Disclosure [Line Items] | ||||
Gain recognized in OCI from remeasurement | $ 15 | |||
Pension Benefits | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost benefits earned during period | $ 4 | 4 | $ 12 | $ 11 |
Interest cost on projected benefit obligation | 5 | 4 | 15 | 13 |
Expected return on plan assets | (5) | (6) | (17) | (17) |
Amortization of prior service credit | (1) | 0 | (1) | (1) |
Net periodic benefit cost (gain) | 3 | 2 | 9 | 6 |
Other Benefits | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost benefits earned during period | 0 | 1 | 0 | 1 |
Interest cost on projected benefit obligation | 1 | 1 | 3 | 3 |
Expected return on plan assets | (1) | (1) | (3) | (3) |
Amortization of prior service credit | (1) | (1) | (3) | (2) |
Net periodic benefit cost (gain) | $ (1) | $ 0 | $ (3) | $ (1) |
Capital Stock (Details) - USD ($) |
3 Months Ended | 9 Months Ended | |||||
---|---|---|---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
Jun. 30, 2016 |
Aug. 03, 2015 |
|
Class of Stock [Line Items] | |||||||
Stock repurchase program, authorized amount | $ 250,000,000 | ||||||
Treasury stock acquired (shares) | 4,996,299 | ||||||
Stock repurchased during the period, value | $ 127,000,000 | ||||||
Mandatory Convertible Preferred Stock | |||||||
Class of Stock [Line Items] | |||||||
Dividends | $ 5,000,000 | $ 5,000,000 | $ 5,000,000 | $ 16,000,000 | $ 17,000,000 | ||
Dividend declared (in dollars per share) | $ 1.34 | ||||||
Tangible Equity Units | |||||||
Class of Stock [Line Items] | |||||||
Number of units issued | 4,600,000 | ||||||
Stated interest rate | 7.00% | 7.00% | 7.00% | 7.00% | |||
Unit price (in dollars per unit) | $ 100 | $ 100 | $ 100 | $ 100 |
Earnings (Loss) Per Share (Details) - USD ($) $ / shares in Units, $ in Millions |
3 Months Ended | 9 Months Ended | |||||||||
---|---|---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
||||||||
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items] | |||||||||||
Net income (loss) | $ (249) | $ (24) | $ (1,062) | $ 181 | |||||||
Less: Net loss attributable to noncontrolling interest | 0 | 0 | (2) | (3) | |||||||
Income (loss) from continuing operations attributable to Dynegy Inc. | (249) | (24) | (1,060) | 184 | |||||||
Less: Dividends on preferred stock | 5 | 5 | 16 | 16 | |||||||
Income (loss) from continuing operations attributable to Dynegy Inc. common stockholders for basic earnings (loss) per share | (254) | (29) | (1,076) | 168 | |||||||
Add: Dividends on preferred stock | [1] | 0 | 0 | 0 | (16) | ||||||
Adjusted income (loss) from continuing operations attributable to Dynegy Inc. common stockholders for diluted earnings (loss) per share | $ (254) | $ (29) | $ (1,076) | $ 184 | |||||||
Basic shares outstanding (shares) | [2] | 140,000,000 | 126,000,000 | 126,000,000 | 126,000,000 | ||||||
Effect of dilutive securities (shares) | [3] | $ 0 | $ 0 | $ 0 | $ 14 | ||||||
Diluted shares outstanding (shares) | 140,000,000 | 126,000,000 | 126,000,000 | 140,000,000 | |||||||
Basic earnings (loss) per share attributable to Dynegy Inc. common stockholders (in dollars per share) | [2] | $ (1.81) | $ (0.23) | $ (8.54) | $ 1.33 | ||||||
Diluted earnings (loss) per share attributable to Dynegy Inc. common stockholders (in dollars per share) | [3] | $ (1.81) | $ (0.23) | $ (8.54) | $ 1.31 | ||||||
Tangible Equity Units | |||||||||||
Earnings Per Share, Basic, by Common Class, Including Two Class Method [Line Items] | |||||||||||
Basic shares outstanding (shares) | 23,092,460 | 23,092,460 | |||||||||
|
Earnings (Loss) Per Share (Anti-Dilutive Shares - Potentially Dilutive in the Future) (Details) - shares shares in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
|
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||||
Antidilutive securities excluded from computation of earnings per share | 39.2 | 32.4 | 39.2 | 15.6 |
Stock options | ||||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||||
Antidilutive securities excluded from computation of earnings per share | 2.8 | 1.8 | 2.8 | 0.0 |
Restricted stock units | ||||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||||
Antidilutive securities excluded from computation of earnings per share | 1.3 | 1.5 | 1.3 | 0.0 |
Performance stock units | ||||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||||
Antidilutive securities excluded from computation of earnings per share | 1.2 | 0.6 | 1.2 | 0.0 |
Common stock warrants | ||||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||||
Antidilutive securities excluded from computation of earnings per share | 15.6 | 15.6 | 15.6 | 15.6 |
Series A 5.375% mandatory convertible preferred stock | ||||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||||
Antidilutive securities excluded from computation of earnings per share | 12.9 | 12.9 | 12.9 | 0.0 |
Prepaid stock purchase contract (TEUs) | ||||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | ||||
Antidilutive securities excluded from computation of earnings per share | 5.4 | 0.0 | 5.4 | 0.0 |
Condensed Consolidating Financial Information (Narrative) (Details) |
9 Months Ended |
---|---|
Sep. 30, 2016
USD ($)
| |
Condensed Financial Statements, Captions [Line Items] | |
Subsidiary percentage ownership | 100.00% |
Senior Notes | Dynegy, Inc. | |
Condensed Financial Statements, Captions [Line Items] | |
Amount of unsecured senior notes | $ 5,600,000,000.0 |
Condensed Consolidating Financial Information (Balance Sheets) (Details) - USD ($) $ in Millions |
Sep. 30, 2016 |
Jun. 30, 2016 |
Dec. 31, 2015 |
Sep. 30, 2015 |
Dec. 31, 2014 |
---|---|---|---|---|---|
Current Assets | |||||
Cash and cash equivalents | $ 1,458 | $ 505 | $ 934 | $ 1,870 | |
Restricted cash | 85 | 39 | |||
Accounts receivable, net | 374 | 402 | |||
Inventory | 447 | 597 | |||
Other current assets | 275 | 389 | |||
Total Current Assets | 2,639 | 1,932 | |||
Property, plant and equipment, net | 7,252 | 8,347 | |||
Investment in unconsolidated affiliate | 173 | 190 | |||
Restricted cash | 2,000 | 0 | |||
Goodwill | 799 | $ 799 | 797 | ||
Other long-term assets | 161 | 193 | |||
Intercompany note receivable | 0 | 0 | |||
Total Assets | 13,024 | 11,459 | 12,157 | ||
Current Liabilities | |||||
Accounts payable | 263 | 292 | |||
Other current liabilities | 648 | 517 | |||
Total Current Liabilities | 911 | 809 | |||
Debt, long-term portion | 9,356 | 7,129 | |||
Intercompany note payable | 0 | 0 | |||
Other long-term liabilities | 550 | 602 | |||
Total Liabilities | 10,817 | 8,540 | |||
Stockholders’ Equity | |||||
Dynegy Stockholders’ Equity | 2,211 | 2,921 | |||
Intercompany note receivable | 0 | 0 | |||
Total Dynegy Stockholders’ Equity | 2,211 | 2,921 | |||
Noncontrolling interest | (4) | (2) | |||
Total Equity | 2,207 | 2,919 | |||
Total Liabilities and Equity | 13,024 | 11,459 | |||
Eliminations | |||||
Current Assets | |||||
Cash and cash equivalents | 0 | 0 | 0 | 0 | |
Restricted cash | 0 | 0 | |||
Accounts receivable, net | (2,259) | (1,730) | |||
Inventory | 0 | 0 | |||
Other current assets | (2) | (14) | |||
Total Current Assets | (2,261) | (1,744) | |||
Property, plant and equipment, net | 0 | 0 | |||
Investment in unconsolidated affiliate | (12,335) | (13,017) | |||
Restricted cash | 0 | ||||
Goodwill | 0 | 0 | |||
Other long-term assets | 0 | 0 | |||
Intercompany note receivable | (3) | (17) | |||
Total Assets | (14,599) | (14,778) | |||
Current Liabilities | |||||
Accounts payable | (2,259) | (1,730) | |||
Other current liabilities | (2) | (14) | |||
Total Current Liabilities | (2,261) | (1,744) | |||
Debt, long-term portion | 0 | 0 | |||
Intercompany note payable | (3,042) | (3,059) | |||
Other long-term liabilities | (3) | 0 | |||
Total Liabilities | (5,306) | (4,803) | |||
Stockholders’ Equity | |||||
Dynegy Stockholders’ Equity | (12,335) | (13,017) | |||
Intercompany note receivable | 3,042 | 3,042 | |||
Total Dynegy Stockholders’ Equity | (9,293) | (9,975) | |||
Noncontrolling interest | 0 | 0 | |||
Total Equity | (9,293) | (9,975) | |||
Total Liabilities and Equity | (14,599) | (14,778) | |||
Parent | |||||
Current Assets | |||||
Cash and cash equivalents | 1,248 | 327 | 579 | 1,642 | |
Restricted cash | 0 | 0 | |||
Accounts receivable, net | 115 | 499 | |||
Inventory | 0 | 0 | |||
Other current assets | 11 | 13 | |||
Total Current Assets | 1,374 | 839 | |||
Property, plant and equipment, net | 0 | 0 | |||
Investment in unconsolidated affiliate | 12,335 | 13,017 | |||
Restricted cash | 0 | ||||
Goodwill | 0 | 0 | |||
Other long-term assets | 4 | 10 | |||
Intercompany note receivable | 0 | 17 | |||
Total Assets | 13,713 | 13,883 | |||
Current Liabilities | |||||
Accounts payable | 1,745 | 1,388 | |||
Other current liabilities | 224 | 92 | |||
Total Current Liabilities | 1,969 | 1,480 | |||
Debt, long-term portion | 6,355 | 6,293 | |||
Intercompany note payable | 3,042 | 3,042 | |||
Other long-term liabilities | 136 | 147 | |||
Total Liabilities | 11,502 | 10,962 | |||
Stockholders’ Equity | |||||
Dynegy Stockholders’ Equity | 2,211 | 2,921 | |||
Intercompany note receivable | 0 | 0 | |||
Total Dynegy Stockholders’ Equity | 2,211 | 2,921 | |||
Noncontrolling interest | 0 | 0 | |||
Total Equity | 2,211 | 2,921 | |||
Total Liabilities and Equity | 13,713 | 13,883 | |||
Guarantor Subsidiaries | |||||
Current Assets | |||||
Cash and cash equivalents | 69 | 94 | 176 | 54 | |
Restricted cash | 0 | 0 | |||
Accounts receivable, net | 2,383 | 1,503 | |||
Inventory | 234 | 331 | |||
Other current assets | 235 | 335 | |||
Total Current Assets | 2,921 | 2,263 | |||
Property, plant and equipment, net | 6,901 | 7,813 | |||
Investment in unconsolidated affiliate | 173 | 190 | |||
Restricted cash | 0 | ||||
Goodwill | 799 | 797 | |||
Other long-term assets | 112 | 133 | |||
Intercompany note receivable | 0 | 0 | |||
Total Assets | 10,906 | 11,196 | |||
Current Liabilities | |||||
Accounts payable | 226 | 238 | |||
Other current liabilities | 293 | 277 | |||
Total Current Liabilities | 519 | 515 | |||
Debt, long-term portion | 288 | 122 | |||
Intercompany note payable | 0 | 0 | |||
Other long-term liabilities | 287 | 317 | |||
Total Liabilities | 1,094 | 954 | |||
Stockholders’ Equity | |||||
Dynegy Stockholders’ Equity | 12,854 | 13,284 | |||
Intercompany note receivable | (3,042) | (3,042) | |||
Total Dynegy Stockholders’ Equity | 9,812 | 10,242 | |||
Noncontrolling interest | 0 | 0 | |||
Total Equity | 9,812 | 10,242 | |||
Total Liabilities and Equity | 10,906 | 11,196 | |||
Non-Guarantor Subsidiaries | |||||
Current Assets | |||||
Cash and cash equivalents | 141 | 84 | $ 179 | $ 174 | |
Restricted cash | 85 | 39 | |||
Accounts receivable, net | 135 | 130 | |||
Inventory | 213 | 266 | |||
Other current assets | 31 | 55 | |||
Total Current Assets | 605 | 574 | |||
Property, plant and equipment, net | 351 | 534 | |||
Investment in unconsolidated affiliate | 0 | 0 | |||
Restricted cash | 2,000 | ||||
Goodwill | 0 | 0 | |||
Other long-term assets | 45 | 50 | |||
Intercompany note receivable | 3 | 0 | |||
Total Assets | 3,004 | 1,158 | |||
Current Liabilities | |||||
Accounts payable | 551 | 396 | |||
Other current liabilities | 133 | 162 | |||
Total Current Liabilities | 684 | 558 | |||
Debt, long-term portion | 2,713 | 714 | |||
Intercompany note payable | 0 | 17 | |||
Other long-term liabilities | 130 | 138 | |||
Total Liabilities | 3,527 | 1,427 | |||
Stockholders’ Equity | |||||
Dynegy Stockholders’ Equity | (519) | (267) | |||
Intercompany note receivable | 0 | 0 | |||
Total Dynegy Stockholders’ Equity | (519) | (267) | |||
Noncontrolling interest | (4) | (2) | |||
Total Equity | (523) | (269) | |||
Total Liabilities and Equity | $ 3,004 | $ 1,158 |
Condensed Consolidating Financial Information (Operations) (Details) - USD ($) $ in Thousands |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
|
Condensed Financial Statements, Captions [Line Items] | ||||
Revenues | $ 1,184,000 | $ 1,232,000 | $ 3,211,000 | $ 2,854,000 |
Cost of sales, excluding depreciation expense | (660,000) | (621,000) | (1,698,000) | (1,494,000) |
Gross margin | 524,000 | 611,000 | 1,513,000 | 1,360,000 |
Operating and maintenance expense | (218,000) | (219,000) | (695,000) | (580,000) |
Depreciation expense | (163,000) | (174,000) | (494,000) | (413,000) |
Impairments | (212,000) | (74,000) | (857,000) | (74,000) |
General and administrative expense | (41,000) | (29,000) | (117,000) | (94,000) |
Acquisition and integration costs | (7,000) | (8,000) | (8,000) | (121,000) |
Other | 0 | 0 | (16,000) | (1,000) |
Operating income (loss) | (117,000) | 107,000 | (674,000) | 77,000 |
Earnings (losses) from unconsolidated investment | 4,000 | (4,000) | 7,000 | (1,000) |
Equity in earnings from investments in affiliates | 0 | 0 | 0 | 0 |
Interest Expense | (166,000) | (145,000) | (449,000) | (413,000) |
Other income and expense, net | 29,000 | 46,000 | 60,000 | 45,000 |
Income (loss) before income taxes | (250,000) | 4,000 | (1,056,000) | (292,000) |
Income tax benefit (expense) | 1,000 | (28,000) | (6,000) | 473,000 |
Net income (loss) | (249,000) | (24,000) | (1,062,000) | 181,000 |
Less: Comprehensive income (loss) attributable to noncontrolling interest | 0 | 0 | (2,000) | (3,000) |
Net Income (Loss) Attributable to Parent | (249,000) | (24,000) | (1,060,000) | 184,000 |
Eliminations | ||||
Condensed Financial Statements, Captions [Line Items] | ||||
Revenues | (2,000) | 105,000 | (2,000) | (4,000) |
Cost of sales, excluding depreciation expense | 2,000 | (105,000) | 2,000 | 4,000 |
Gross margin | 0 | 0 | 0 | 0 |
Operating and maintenance expense | 0 | 0 | 0 | 0 |
Depreciation expense | 0 | 0 | 0 | 0 |
Impairments | 0 | 0 | 0 | 0 |
General and administrative expense | 0 | 0 | 0 | 0 |
Acquisition and integration costs | 0 | 0 | 0 | 0 |
Other | 0 | 0 | 0 | |
Operating income (loss) | 0 | 0 | 0 | 0 |
Earnings (losses) from unconsolidated investment | 0 | 0 | 0 | 0 |
Equity in earnings from investments in affiliates | 153,000 | (53,000) | 718,000 | (500,000) |
Interest Expense | 1,000 | 0 | 2,000 | 0 |
Other income and expense, net | (1,000) | 0 | (2,000) | 0 |
Income (loss) before income taxes | 153,000 | (53,000) | 718,000 | (500,000) |
Income tax benefit (expense) | 0 | 0 | 0 | 0 |
Net income (loss) | 153,000 | (53,000) | 718,000 | (500,000) |
Less: Comprehensive income (loss) attributable to noncontrolling interest | 0 | 0 | 0 | 0 |
Net Income (Loss) Attributable to Parent | 153,000 | (53,000) | 718,000 | (500,000) |
Parent | ||||
Condensed Financial Statements, Captions [Line Items] | ||||
Revenues | 0 | 0 | 0 | 0 |
Cost of sales, excluding depreciation expense | 0 | 0 | 0 | 0 |
Gross margin | 0 | 0 | 0 | 0 |
Operating and maintenance expense | 0 | 0 | 0 | 0 |
Depreciation expense | 0 | 0 | 0 | 0 |
Impairments | 0 | 0 | 0 | 0 |
General and administrative expense | (2,000) | 3,000 | (5,000) | 0 |
Acquisition and integration costs | (5,000) | 0 | (8,000) | 0 |
Other | 0 | 0 | 0 | |
Operating income (loss) | (7,000) | 3,000 | (13,000) | 0 |
Earnings (losses) from unconsolidated investment | 0 | 0 | 0 | 0 |
Equity in earnings from investments in affiliates | (153,000) | 53,000 | (718,000) | 500,000 |
Interest Expense | (112,000) | (127,000) | (355,000) | (361,000) |
Other income and expense, net | 23,000 | 47,000 | 26,000 | 45,000 |
Income (loss) before income taxes | (249,000) | (24,000) | (1,060,000) | 184,000 |
Income tax benefit (expense) | 0 | 0 | 0 | 0 |
Net income (loss) | (249,000) | (24,000) | (1,060,000) | 184,000 |
Less: Comprehensive income (loss) attributable to noncontrolling interest | 0 | 0 | 0 | 0 |
Net Income (Loss) Attributable to Parent | (249,000) | (24,000) | (1,060,000) | 184,000 |
Guarantor Subsidiaries | ||||
Condensed Financial Statements, Captions [Line Items] | ||||
Revenues | 919,000 | 878,000 | 2,517,000 | 2,186,000 |
Cost of sales, excluding depreciation expense | (501,000) | (369,000) | (1,295,000) | (1,080,000) |
Gross margin | 418,000 | 509,000 | 1,222,000 | 1,106,000 |
Operating and maintenance expense | (152,000) | (154,000) | (503,000) | (385,000) |
Depreciation expense | (147,000) | (149,000) | (433,000) | (352,000) |
Impairments | (64,000) | (74,000) | (709,000) | (74,000) |
General and administrative expense | (28,000) | (26,000) | (87,000) | (69,000) |
Acquisition and integration costs | 0 | (8,000) | (3,000) | (121,000) |
Other | (1,000) | (1,000) | (1,000) | |
Operating income (loss) | 26,000 | 98,000 | (514,000) | 104,000 |
Earnings (losses) from unconsolidated investment | 4,000 | (4,000) | 7,000 | (1,000) |
Equity in earnings from investments in affiliates | 0 | 0 | 0 | 0 |
Interest Expense | (5,000) | 0 | (9,000) | 0 |
Other income and expense, net | 5,000 | (1,000) | 20,000 | 0 |
Income (loss) before income taxes | 30,000 | 93,000 | (496,000) | 103,000 |
Income tax benefit (expense) | 37,000 | (45,000) | 30,000 | 473,000 |
Net income (loss) | 67,000 | 48,000 | (466,000) | 576,000 |
Less: Comprehensive income (loss) attributable to noncontrolling interest | 0 | 0 | 0 | 0 |
Net Income (Loss) Attributable to Parent | 67,000 | 48,000 | (466,000) | 576,000 |
Non-Guarantor Subsidiaries | ||||
Condensed Financial Statements, Captions [Line Items] | ||||
Revenues | 267,000 | 249,000 | 696,000 | 672,000 |
Cost of sales, excluding depreciation expense | (161,000) | (147,000) | (405,000) | (418,000) |
Gross margin | 106,000 | 102,000 | 291,000 | 254,000 |
Operating and maintenance expense | (66,000) | (65,000) | (192,000) | (195,000) |
Depreciation expense | (16,000) | (25,000) | (61,000) | (61,000) |
Impairments | (148,000) | 0 | (148,000) | 0 |
General and administrative expense | (11,000) | (6,000) | (25,000) | (25,000) |
Acquisition and integration costs | (2,000) | 0 | 3,000 | 0 |
Other | 1,000 | (15,000) | 0 | |
Operating income (loss) | (136,000) | 6,000 | (147,000) | (27,000) |
Earnings (losses) from unconsolidated investment | 0 | 0 | 0 | 0 |
Equity in earnings from investments in affiliates | 0 | 0 | 0 | 0 |
Interest Expense | (50,000) | (18,000) | (87,000) | (52,000) |
Other income and expense, net | 2,000 | 0 | 16,000 | 0 |
Income (loss) before income taxes | (184,000) | (12,000) | (218,000) | (79,000) |
Income tax benefit (expense) | (36,000) | 17,000 | (36,000) | 0 |
Net income (loss) | (220,000) | 5,000 | (254,000) | (79,000) |
Less: Comprehensive income (loss) attributable to noncontrolling interest | 0 | 0 | (2,000) | (3,000) |
Net Income (Loss) Attributable to Parent | $ (220,000) | $ 5,000 | $ (252,000) | $ (76,000) |
Condensed Consolidating Financial Information (Comprehensive Income (Loss)) (Details) - USD ($) $ in Millions |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
|
Condensed Financial Statements, Captions [Line Items] | ||||
Net income (loss) | $ (249) | $ (24) | $ (1,062) | $ 181 |
Actuarial gain and plan amendments (net of tax of zero, $2, zero, and $2 for each respective period) | 0 | 13 | 0 | 8 |
Amortization of unrecognized prior service credit (net of tax of zero for each respective period) | (2) | (1) | (4) | (3) |
Other comprehensive income from investment in affiliates | 0 | 0 | 0 | 0 |
Other comprehensive income (loss), net of tax | (2) | 12 | (4) | 5 |
Comprehensive income (loss) | (251) | (12) | (1,066) | 186 |
Comprehensive income (loss) attributable to noncontrolling interest | 0 | 1 | (2) | (2) |
Total comprehensive income (loss) attributable to Dynegy Inc. | (251) | (13) | (1,064) | 188 |
Eliminations | ||||
Condensed Financial Statements, Captions [Line Items] | ||||
Net income (loss) | 153 | (53) | 718 | (500) |
Actuarial gain and plan amendments (net of tax of zero, $2, zero, and $2 for each respective period) | 0 | 0 | ||
Amortization of unrecognized prior service credit (net of tax of zero for each respective period) | 0 | 0 | 0 | 0 |
Other comprehensive income from investment in affiliates | 1 | (7) | 1 | (7) |
Other comprehensive income (loss), net of tax | 1 | (7) | 1 | (7) |
Comprehensive income (loss) | 154 | (60) | 719 | (507) |
Comprehensive income (loss) attributable to noncontrolling interest | 0 | (1) | 0 | (1) |
Total comprehensive income (loss) attributable to Dynegy Inc. | 154 | (59) | 719 | (506) |
Parent | ||||
Condensed Financial Statements, Captions [Line Items] | ||||
Net income (loss) | (249) | (24) | (1,060) | 184 |
Actuarial gain and plan amendments (net of tax of zero, $2, zero, and $2 for each respective period) | 6 | 1 | ||
Amortization of unrecognized prior service credit (net of tax of zero for each respective period) | (1) | (1) | (3) | (3) |
Other comprehensive income from investment in affiliates | (1) | 7 | (1) | 7 |
Other comprehensive income (loss), net of tax | (2) | 12 | (4) | 5 |
Comprehensive income (loss) | (251) | (12) | (1,064) | 189 |
Comprehensive income (loss) attributable to noncontrolling interest | 0 | 1 | 0 | 1 |
Total comprehensive income (loss) attributable to Dynegy Inc. | (251) | (13) | (1,064) | 188 |
Guarantor Subsidiaries | ||||
Condensed Financial Statements, Captions [Line Items] | ||||
Net income (loss) | 67 | 48 | (466) | 576 |
Actuarial gain and plan amendments (net of tax of zero, $2, zero, and $2 for each respective period) | 0 | 0 | ||
Amortization of unrecognized prior service credit (net of tax of zero for each respective period) | 0 | 0 | 0 | 0 |
Other comprehensive income from investment in affiliates | 0 | 0 | 0 | 0 |
Other comprehensive income (loss), net of tax | 0 | 0 | 0 | 0 |
Comprehensive income (loss) | 67 | 48 | (466) | 576 |
Comprehensive income (loss) attributable to noncontrolling interest | 0 | 0 | 0 | 0 |
Total comprehensive income (loss) attributable to Dynegy Inc. | 67 | 48 | (466) | 576 |
Non-Guarantor Subsidiaries | ||||
Condensed Financial Statements, Captions [Line Items] | ||||
Net income (loss) | (220) | 5 | (254) | (79) |
Actuarial gain and plan amendments (net of tax of zero, $2, zero, and $2 for each respective period) | 7 | 7 | ||
Amortization of unrecognized prior service credit (net of tax of zero for each respective period) | (1) | 0 | (1) | 0 |
Other comprehensive income from investment in affiliates | 0 | 0 | 0 | 0 |
Other comprehensive income (loss), net of tax | (1) | 7 | (1) | 7 |
Comprehensive income (loss) | (221) | 12 | (255) | (72) |
Comprehensive income (loss) attributable to noncontrolling interest | 0 | 1 | (2) | (2) |
Total comprehensive income (loss) attributable to Dynegy Inc. | $ (221) | $ 11 | $ (253) | $ (70) |
Condensed Consolidating Financial Information (Cash Flow) (Details) - USD ($) $ in Millions |
9 Months Ended | |
---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
|
CASH FLOWS FROM OPERATING ACTIVITIES: | ||
Net cash provided by (used in) operating activities | $ 649 | $ 302 |
CASH FLOWS FROM INVESTING ACTIVITIES: | ||
Capital expenditures | (259) | (171) |
Acquisitions, net of cash acquired | 0 | (6,078) |
Decrease (increase) in restricted cash | (2,045) | 5,148 |
Net intercompany transfers | 0 | 0 |
Distributions from unconsolidated affiliate | 14 | 8 |
Other investing | 10 | (6) |
Net cash provided by (used in) investing activities | (2,280) | (1,099) |
CASH FLOWS FROM FINANCING ACTIVITIES: | ||
Proceeds from long-term borrowings, net of debt issuance costs | 2,277 | 57 |
Repayments of borrowings | (21) | (29) |
Proceeds from issuance of equity, net of issuance costs | 359 | (6) |
Preferred stock dividends paid | (16) | (17) |
Interest rate swap settlement payments | (13) | (13) |
Net intercompany transfers | 0 | 0 |
Repurchase of common stock | 0 | (127) |
Other financing | (2) | (4) |
Net cash provided by (used in) financing activities | 2,584 | (139) |
Net increase (decrease) in cash and cash equivalents | 953 | (936) |
Cash and cash equivalents, beginning of period | 505 | 1,870 |
Cash and cash equivalents, end of period | 1,458 | 934 |
Eliminations | ||
CASH FLOWS FROM OPERATING ACTIVITIES: | ||
Net cash provided by (used in) operating activities | 0 | 0 |
CASH FLOWS FROM INVESTING ACTIVITIES: | ||
Capital expenditures | 0 | 0 |
Acquisitions, net of cash acquired | 0 | |
Decrease (increase) in restricted cash | 0 | 0 |
Net intercompany transfers | (670) | (349) |
Distributions from unconsolidated affiliate | 0 | 0 |
Other investing | 0 | 0 |
Net cash provided by (used in) investing activities | (670) | (349) |
CASH FLOWS FROM FINANCING ACTIVITIES: | ||
Proceeds from long-term borrowings, net of debt issuance costs | 0 | 0 |
Repayments of borrowings | 0 | 0 |
Proceeds from issuance of equity, net of issuance costs | 0 | 0 |
Preferred stock dividends paid | 0 | 0 |
Interest rate swap settlement payments | 0 | 0 |
Net intercompany transfers | 670 | 349 |
Repurchase of common stock | 0 | |
Other financing | 0 | 0 |
Net cash provided by (used in) financing activities | 670 | 349 |
Net increase (decrease) in cash and cash equivalents | 0 | 0 |
Cash and cash equivalents, beginning of period | 0 | 0 |
Cash and cash equivalents, end of period | 0 | 0 |
Parent | ||
CASH FLOWS FROM OPERATING ACTIVITIES: | ||
Net cash provided by (used in) operating activities | (155) | (141) |
CASH FLOWS FROM INVESTING ACTIVITIES: | ||
Capital expenditures | 0 | (8) |
Acquisitions, net of cash acquired | (6,207) | |
Decrease (increase) in restricted cash | 0 | 5,148 |
Net intercompany transfers | 670 | 349 |
Distributions from unconsolidated affiliate | 0 | 0 |
Other investing | 0 | 0 |
Net cash provided by (used in) investing activities | 670 | (718) |
CASH FLOWS FROM FINANCING ACTIVITIES: | ||
Proceeds from long-term borrowings, net of debt issuance costs | 84 | (31) |
Repayments of borrowings | (6) | (6) |
Proceeds from issuance of equity, net of issuance costs | 359 | (6) |
Preferred stock dividends paid | (16) | (17) |
Interest rate swap settlement payments | (13) | (13) |
Net intercompany transfers | 0 | 0 |
Repurchase of common stock | (127) | |
Other financing | (2) | (4) |
Net cash provided by (used in) financing activities | 406 | (204) |
Net increase (decrease) in cash and cash equivalents | 921 | (1,063) |
Cash and cash equivalents, beginning of period | 327 | 1,642 |
Cash and cash equivalents, end of period | 1,248 | 579 |
Guarantor Subsidiaries | ||
CASH FLOWS FROM OPERATING ACTIVITIES: | ||
Net cash provided by (used in) operating activities | 780 | 502 |
CASH FLOWS FROM INVESTING ACTIVITIES: | ||
Capital expenditures | (227) | (122) |
Acquisitions, net of cash acquired | 29 | |
Decrease (increase) in restricted cash | 0 | 0 |
Net intercompany transfers | 0 | 0 |
Distributions from unconsolidated affiliate | 14 | 8 |
Other investing | 10 | (6) |
Net cash provided by (used in) investing activities | (203) | (91) |
CASH FLOWS FROM FINANCING ACTIVITIES: | ||
Proceeds from long-term borrowings, net of debt issuance costs | 198 | 78 |
Repayments of borrowings | (15) | (23) |
Proceeds from issuance of equity, net of issuance costs | 0 | 0 |
Preferred stock dividends paid | 0 | 0 |
Interest rate swap settlement payments | 0 | 0 |
Net intercompany transfers | (785) | (344) |
Repurchase of common stock | 0 | |
Other financing | 0 | 0 |
Net cash provided by (used in) financing activities | (602) | (289) |
Net increase (decrease) in cash and cash equivalents | (25) | 122 |
Cash and cash equivalents, beginning of period | 94 | 54 |
Cash and cash equivalents, end of period | 69 | 176 |
Non-Guarantor Subsidiaries | ||
CASH FLOWS FROM OPERATING ACTIVITIES: | ||
Net cash provided by (used in) operating activities | 24 | (59) |
CASH FLOWS FROM INVESTING ACTIVITIES: | ||
Capital expenditures | (32) | (41) |
Acquisitions, net of cash acquired | 100 | |
Decrease (increase) in restricted cash | (2,045) | 0 |
Net intercompany transfers | 0 | 0 |
Distributions from unconsolidated affiliate | 0 | 0 |
Other investing | 0 | 0 |
Net cash provided by (used in) investing activities | (2,077) | 59 |
CASH FLOWS FROM FINANCING ACTIVITIES: | ||
Proceeds from long-term borrowings, net of debt issuance costs | 1,995 | 10 |
Repayments of borrowings | 0 | 0 |
Proceeds from issuance of equity, net of issuance costs | 0 | 0 |
Preferred stock dividends paid | 0 | 0 |
Interest rate swap settlement payments | 0 | 0 |
Net intercompany transfers | 115 | (5) |
Repurchase of common stock | 0 | |
Other financing | 0 | 0 |
Net cash provided by (used in) financing activities | 2,110 | 5 |
Net increase (decrease) in cash and cash equivalents | 57 | 5 |
Cash and cash equivalents, beginning of period | 84 | 174 |
Cash and cash equivalents, end of period | $ 141 | $ 179 |
Segment Information (Narrative) (Details) |
9 Months Ended |
---|---|
Sep. 30, 2016
segment
| |
Segment Reporting [Abstract] | |
Number of reportable segments | 3 |
Segment Information (Segment Reporting) (Details) - USD ($) |
3 Months Ended | 9 Months Ended | |||
---|---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
Dec. 31, 2015 |
|
Segment Information | |||||
Unaffiliated revenues | $ 1,168,000,000 | $ 1,232,000,000 | $ 3,184,000,000 | $ 2,854,000,000 | |
Intercompany revenues | 16,000,000 | 0 | 27,000,000 | 0 | |
Revenues | 1,184,000,000 | 1,232,000,000 | 3,211,000,000 | 2,854,000,000 | |
Depreciation expense | (163,000,000) | (174,000,000) | (494,000,000) | (413,000,000) | |
Impairments | (212,000,000) | (74,000,000) | (857,000,000) | (74,000,000) | |
General and administrative expense | (41,000,000) | (29,000,000) | (117,000,000) | (94,000,000) | |
Acquisition and integration costs | (7,000,000) | (8,000,000) | (8,000,000) | (121,000,000) | |
Operating income (loss) | (117,000,000) | 107,000,000 | (674,000,000) | 77,000,000 | |
Earnings (losses) from unconsolidated investment | 4,000,000 | (4,000,000) | 7,000,000 | (1,000,000) | |
Interest expense | (166,000,000) | (145,000,000) | (449,000,000) | (413,000,000) | |
Other items, net | 29,000,000 | 46,000,000 | 60,000,000 | 45,000,000 | |
Income (loss) before income taxes | (250,000,000) | 4,000,000 | (1,056,000,000) | (292,000,000) | |
Income tax benefit (expense) | 1,000,000 | (28,000,000) | (6,000,000) | 473,000,000 | |
Net income (loss) | (249,000,000) | (24,000,000) | (1,062,000,000) | 181,000,000 | |
Less: Net loss attributable to noncontrolling interest | 0 | 0 | (2,000,000) | (3,000,000) | |
Net loss attributable to Dynegy Inc. | (249,000,000) | (24,000,000) | (1,060,000,000) | 184,000,000 | |
Identifiable assets (domestic) | 13,024,000,000 | 12,157,000,000 | 13,024,000,000 | 12,157,000,000 | $ 11,459,000,000 |
Investment in unconsolidated affiliate | 173,000,000 | 189,000,000 | 173,000,000 | 189,000,000 | |
Capital expenditures | (35,000,000) | (69,000,000) | (259,000,000) | (171,000,000) | |
Operating segments | |||||
Segment Information | |||||
Depreciation expense | |||||
Investment in unconsolidated affiliate | 0 | 0 | 0 | 0 | |
Operating segments | Coal | |||||
Segment Information | |||||
Unaffiliated revenues | 388,000,000 | 410,000,000 | 1,022,000,000 | 976,000,000 | |
Intercompany revenues | 0 | (14,000,000) | (24,000,000) | (131,000,000) | |
Revenues | 388,000,000 | 396,000,000 | 998,000,000 | 845,000,000 | |
Depreciation expense | (27,000,000) | (39,000,000) | (99,000,000) | (96,000,000) | |
Impairments | (55,000,000) | (74,000,000) | (700,000,000) | (74,000,000) | |
General and administrative expense | 0 | 0 | 0 | 0 | |
Acquisition and integration costs | 0 | 0 | 0 | 0 | |
Operating income (loss) | (33,000,000) | (36,000,000) | (728,000,000) | (34,000,000) | |
Earnings (losses) from unconsolidated investment | 0 | 0 | 0 | 0 | |
Interest expense | 0 | 0 | 0 | 0 | |
Other items, net | 3,000,000 | 0 | 9,000,000 | 0 | |
Identifiable assets (domestic) | 1,432,000,000 | 2,426,000,000 | 1,432,000,000 | 2,426,000,000 | |
Capital expenditures | (8,000,000) | (25,000,000) | (47,000,000) | (44,000,000) | |
Operating segments | IPH | |||||
Segment Information | |||||
Unaffiliated revenues | 241,000,000 | 221,000,000 | 575,000,000 | 629,000,000 | |
Intercompany revenues | 1,000,000 | 0 | (1,000,000) | (4,000,000) | |
Revenues | 242,000,000 | 221,000,000 | 574,000,000 | 625,000,000 | |
Depreciation expense | (7,000,000) | (8,000,000) | (21,000,000) | (24,000,000) | |
Impairments | (148,000,000) | 0 | (148,000,000) | 0 | |
General and administrative expense | 0 | 0 | 0 | 0 | |
Acquisition and integration costs | 0 | 0 | 8,000,000 | 0 | |
Operating income (loss) | (104,000,000) | 31,000,000 | (87,000,000) | 39,000,000 | |
Earnings (losses) from unconsolidated investment | 0 | 0 | 0 | 0 | |
Interest expense | 0 | 0 | 0 | 0 | |
Other items, net | 1,000,000 | 0 | 15,000,000 | 0 | |
Identifiable assets (domestic) | 746,000,000 | 993,000,000 | 746,000,000 | 993,000,000 | |
Investment in unconsolidated affiliate | 0 | 0 | 0 | 0 | |
Capital expenditures | (11,000,000) | (12,000,000) | (32,000,000) | (41,000,000) | |
Operating segments | Gas | |||||
Segment Information | |||||
Unaffiliated revenues | 539,000,000 | 605,000,000 | 1,587,000,000 | 1,254,000,000 | |
Intercompany revenues | 15,000,000 | 10,000,000 | 52,000,000 | 130,000,000 | |
Revenues | 554,000,000 | 615,000,000 | 1,639,000,000 | 1,384,000,000 | |
Depreciation expense | (128,000,000) | (126,000,000) | (370,000,000) | (290,000,000) | |
Impairments | (9,000,000) | 0 | (9,000,000) | 0 | |
General and administrative expense | 0 | 0 | 0 | 0 | |
Acquisition and integration costs | 0 | 0 | 0 | 0 | |
Operating income (loss) | 69,000,000 | 152,000,000 | 279,000,000 | 290,000,000 | |
Earnings (losses) from unconsolidated investment | 4,000,000 | (4,000,000) | 7,000,000 | (1,000,000) | |
Interest expense | 0 | 0 | 0 | 0 | |
Other items, net | 0 | 0 | 12,000,000 | 0 | |
Identifiable assets (domestic) | 7,498,000,000 | 7,948,000,000 | 7,498,000,000 | 7,948,000,000 | |
Investment in unconsolidated affiliate | 173,000,000 | 189,000,000 | 173,000,000 | 189,000,000 | |
Capital expenditures | (15,000,000) | (29,000,000) | (171,000,000) | (78,000,000) | |
Other and Eliminations | |||||
Segment Information | |||||
Unaffiliated revenues | 0 | (4,000,000) | 0 | (5,000,000) | |
Intercompany revenues | 0 | 4,000,000 | 0 | 5,000,000 | |
Revenues | 0 | 0 | 0 | 0 | |
Depreciation expense | (1,000,000) | (1,000,000) | (4,000,000) | (3,000,000) | |
Impairments | 0 | 0 | 0 | 0 | |
General and administrative expense | (41,000,000) | (29,000,000) | (117,000,000) | (94,000,000) | |
Acquisition and integration costs | (7,000,000) | (8,000,000) | (16,000,000) | (121,000,000) | |
Operating income (loss) | (49,000,000) | (40,000,000) | (138,000,000) | (218,000,000) | |
Earnings (losses) from unconsolidated investment | 0 | 0 | 0 | 0 | |
Interest expense | (166,000,000) | (145,000,000) | (449,000,000) | (413,000,000) | |
Other items, net | 25,000,000 | 46,000,000 | 24,000,000 | 45,000,000 | |
Income tax benefit (expense) | 1,000,000 | (28,000,000) | (6,000,000) | ||
Identifiable assets (domestic) | 3,348,000,000 | 790,000,000 | 3,348,000,000 | 790,000,000 | |
Investment in unconsolidated affiliate | 0 | 0 | 0 | 0 | |
Capital expenditures | $ (1,000,000) | $ (3,000,000) | $ (9,000,000) | $ (8,000,000) |
Subsequent Events (Details) - USD ($) $ / shares in Units, shares in Millions |
9 Months Ended | ||||
---|---|---|---|---|---|
Oct. 14, 2016 |
Sep. 30, 2016 |
Sep. 30, 2015 |
Oct. 24, 2016 |
Oct. 11, 2016 |
|
Subsequent Event [Line Items] | |||||
Distributions from unconsolidated affiliate | $ 14,000,000 | $ 8,000,000 | |||
Subsequent Event | 8.00% Unsecured Senior Notes | |||||
Subsequent Event [Line Items] | |||||
Amount of unsecured senior notes | $ 750,000,000 | ||||
Stated interest rate | 8.00% | ||||
Subsequent Event | Affiliate | Genco and Ad Hock Group of Shareholders | |||||
Subsequent Event [Line Items] | |||||
Payments of debt restructuring costs | $ 139,000,000 | ||||
Subsequent Event | Restructuring Support Agreement | Affiliate | Genco and Ad Hock Group of Shareholders | |||||
Subsequent Event [Line Items] | |||||
Payments of debt restructuring costs | 9,000,000 | ||||
Distributions from unconsolidated affiliate | $ 61,000,000 | ||||
Warrants and rights outstanding | 10 | ||||
Plan of reorganization, term of warrants | 7 years | ||||
Warrants, exercise price (USD per share) | $ 35 | ||||
Aggregate percent of of principal holders acceptance needed for out of court restructuring | 97.00% | ||||
Aggregate percent of principal holders acceptance for pre-packaged Chapter 11 | 66.70% | ||||
Ad Hoc Group of bondholders, Percent | 70.00% | ||||
Subsequent Event | Restructuring Support Agreement | Affiliate | Genco and Ad Hock Group of Shareholders | Genco Senior Notes Series F, H, and I | |||||
Subsequent Event [Line Items] | |||||
Amount of unsecured senior notes | $ 825,000,000 | ||||
Subsequent Event | Restructuring Support Agreement | Affiliate | Genco and Ad Hock Group of Shareholders | Unsecured Debt | |||||
Subsequent Event [Line Items] | |||||
Amount of unsecured senior notes | $ 210,000,000 |
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