Document and Entity Information
Document and Entity Information - USD ($) | 12 Months Ended | ||
Dec. 31, 2016 | Jan. 20, 2017 | Jun. 30, 2016 | |
Document Information [Abstract] | |||
Document Type | 10-K | ||
Amendment Flag | false | ||
Document Period End Date | Dec. 31, 2016 | ||
Document Fiscal Year Focus | 2,016 | ||
Document Fiscal Period Focus | FY | ||
Entity Registrant Name | CONSOL Energy Inc | ||
Entity Central Index Key | 1,070,412 | ||
Current Fiscal Year End Date | --12-31 | ||
Entity Filer Category | Large Accelerated Filer | ||
Entity Common Stock, Shares Outstanding | 229,443,008 | ||
Entity Well-known Seasoned Issuer | Yes | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Public Float | $ 1,829,987,445 |
Consolidated Statements of Inco
Consolidated Statements of Income - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Income Statement [Abstract] | |||
Oil and Gas Sales Revenue | $ 793,248 | $ 726,921 | $ 1,004,924 |
Gain (Loss) on Hedging Activity | (141,021) | 392,942 | 23,193 |
Coal Products and Services Revenue | 1,065,582 | 1,289,036 | 1,616,874 |
Other Revenue, Net | 32,038 | 30,967 | 276,242 |
Gas Royalty Interests and Purchased Gas Sales | 43,256 | 14,450 | 8,999 |
Freight-Outside | 46,468 | 20,499 | 23,133 |
Other Income | 167,306 | 144,351 | 207,460 |
Gain (Loss) on Disposition of Assets | 19,498 | 74,173 | 43,198 |
Total Revenue and Other Income | 2,026,375 | 2,693,339 | 3,204,023 |
Oil and Gas Property, Lease Operating Expense | 96,434 | 121,847 | 139,242 |
Gas Gathering, Transportation, Marketing and Processing Costs | 374,350 | 343,403 | 239,579 |
Production Tax Expense | 31,049 | 30,438 | 39,418 |
E&P Depreciation, Depletion, and Amortization | 417,853 | 370,374 | 323,600 |
Exploration and Production Costs | 14,519 | 10,120 | 23,355 |
Production Royalty Interests and Purchased Gas Costs | 42,717 | 10,721 | 7,251 |
Other Expenses | 87,913 | 65,939 | 46,838 |
Impairment of Oil and Gas Properties | 0 | 828,905 | 0 |
Results of Operations, General and Administrative Related to Oil and Gas Producing Activities | 102,503 | 102,229 | 128,731 |
Oil and Gas Production Expense | 1,167,338 | 1,883,976 | 948,014 |
Operating Expenses | 733,300 | 666,302 | 982,749 |
Coal Depreciation, Depletion, Amortization | 168,195 | 176,864 | 173,316 |
Freight Expense | 46,468 | 20,499 | 23,133 |
General and Administrative Expense | 37,512 | 40,843 | 68,597 |
Cost of Coal Products and Services | 985,475 | 904,508 | 1,247,795 |
Other Nonoperating Expense | 182,869 | 78,743 | 460,429 |
Other General and Administrative Expense | 12,717 | 14,918 | 13,307 |
Depreciation, Depletion and Amortization, Nonproduction | 12,455 | 19,882 | 35,727 |
Gains (Losses) on Extinguishment of Debt | 0 | 67,751 | 95,267 |
Interest Expense | 191,476 | 199,266 | 223,333 |
Other General Expense | 399,517 | 380,560 | 828,063 |
Total Costs | 2,552,330 | 3,169,044 | 3,023,872 |
Earnings Before Income Taxes | (525,955) | (475,705) | 180,151 |
Income Taxes | 10,010 | (125,439) | 15,204 |
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest | (535,965) | (350,266) | 164,947 |
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent | (303,183) | (14,209) | (1,857) |
Net Income (Loss) | (839,148) | (364,475) | 163,090 |
Less: Net Loss (Income) Attributable to Noncontrolling Interest | (8,954) | (10,410) | 0 |
Net Income Attributable to CONSOL Energy Inc Shareholders | $ (848,102) | $ (374,885) | $ 163,090 |
Earnings per share: | |||
Income (Loss) from Continuing Operations, Per Basic Share | $ (2.38) | $ (1.57) | $ 0.72 |
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Basic Share | (1.32) | (0.07) | (0.01) |
Basic | (3.70) | (1.64) | 0.71 |
Income (Loss) from Continuing Operations, Per Diluted Share | (2.38) | (1.57) | 0.71 |
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Diluted Share | (1.32) | (0.07) | (0.01) |
Dilutive | (3.70) | (1.64) | 0.70 |
Dividends Paid Per Share | $ 0.01 | $ 0.15 | $ 0.25 |
Consolidated Statement of Compr
Consolidated Statement of Comprehensive Income - USD ($) $ in Thousands | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2016 | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Net Income (Loss) | $ (839,148) | $ (839,148) | $ (364,475) | $ 163,090 |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax | 33,226 | 86,447 | (94,989) | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 0 | 97,316 | ||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | (43,470) | (18,288) | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | (78,051) | |||
Other Comprehensive Income (Loss), Net of Tax | (76,696) | (164,498) | 174,017 | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | (915,844) | (528,973) | 337,107 | |
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 9,216 | 10,410 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | (925,060) | (539,383) | 337,107 | |
Parent Company [Member] | ||||
Net Income (Loss) | (848,102) | (374,885) | 163,090 | |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax | 33,226 | 86,447 | (94,989) | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 0 | 97,316 | ||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | (43,470) | (18,288) | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | (78,051) | |||
Other Comprehensive Income (Loss), Net of Tax | (76,696) | (164,498) | 174,017 | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | (924,798) | (539,383) | ||
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 0 | 0 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | (924,798) | (539,383) | 337,107 | |
Cnx Gas Guarantor [Member] | ||||
Net Income (Loss) | (228,289) | (421,803) | 123,273 | |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax | 0 | 0 | 0 | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 97,316 | |||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | (43,470) | (18,288) | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | (78,051) | |||
Other Comprehensive Income (Loss), Net of Tax | (43,470) | (78,051) | 79,028 | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | (271,759) | (499,854) | ||
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 0 | 0 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | (271,759) | (499,854) | 202,301 | |
Other Guarantors Subsidiaries [Member] | ||||
Net Income (Loss) | (197,898) | 205,640 | 182,624 | |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax | 34,044 | 84,607 | (53,190) | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 0 | |||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | 0 | 0 | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | 0 | |||
Other Comprehensive Income (Loss), Net of Tax | (34,044) | (84,607) | 53,190 | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | (231,942) | 121,033 | ||
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 0 | 0 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | (231,942) | 121,033 | 235,814 | |
CNX Coal Resources LP [Member] | ||||
Net Income (Loss) | 25,851 | 64,538 | 104,875 | |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax | (818) | 1,840 | (41,799) | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 0 | |||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | 0 | 0 | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | 0 | |||
Other Comprehensive Income (Loss), Net of Tax | 818 | (1,840) | 41,799 | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | 26,669 | 62,698 | ||
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 0 | 0 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | 26,669 | 62,698 | 146,674 | |
Non-Guarantor Subsidiaries [Member] | ||||
Net Income (Loss) | (303,212) | (12,026) | 5,131 | |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax | 0 | 0 | 0 | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 0 | |||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | 0 | 0 | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | 0 | |||
Other Comprehensive Income (Loss), Net of Tax | 0 | 0 | 0 | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | (303,212) | (12,026) | ||
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 0 | 0 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | (303,212) | (12,026) | 5,131 | |
Consolidation, Eliminations [Member] | ||||
Net Income (Loss) | 712,502 | 174,061 | (415,903) | |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax | (33,226) | (86,447) | 94,989 | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | (97,316) | |||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | 43,470 | 18,288 | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | 78,051 | |||
Other Comprehensive Income (Loss), Net of Tax | 76,696 | 164,498 | (174,017) | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | 789,198 | 338,559 | ||
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 9,216 | 10,410 | 0 | |
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | $ 779,982 | $ 328,149 | $ (589,920) |
Consolidated Statement of Comp4
Consolidated Statement of Comprehensive Income Parentheticals - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax | $ 33,226 | $ 86,447 | $ (94,989) |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 0 | 97,316 | |
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | (78,051) | ||
Cash Flow Hedging [Member] | |||
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 0 | 0 | (55,767) |
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | 25,011 | 45,054 | 10,465 |
Adjustment For Actuarially Determined Liabilities [Member] | |||
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax | $ 16,281 | $ 53,252 | $ (56,304) |
Consolidated Balance Sheets
Consolidated Balance Sheets - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Current Assets: | ||
Cash and Cash Equivalents | $ 60,475 | $ 72,574 |
Accounts and Notes Receivable: | ||
Trade | 220,222 | 151,383 |
Other Receivables, Net, Current | 69,901 | 121,735 |
Inventories | 65,461 | 66,792 |
Income Taxes Receivable, Current | 116,851 | 13,887 |
Prepaid Expenses | 93,146 | 297,287 |
Disposal Group, Including Discontinued Operation, Assets, Current | 83 | 81,105 |
Total Current Assets | 626,139 | 804,763 |
Property, Plant and Equipment: | ||
Property, Plant and Equipment, Gross | 13,771,388 | 13,794,907 |
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | 5,630,949 | 5,062,201 |
Disposal Group, Including Discontinued Operation, Property, Plant and Equipment | 0 | 936,671 |
Total Property, Plant and Equipment-Net | 8,140,439 | 9,669,377 |
Other Assets: | ||
Deferred Tax Assets, Net of Valuation Allowance, Noncurrent | 4,290 | 0 |
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures | 190,964 | 237,330 |
Other | 222,149 | 214,388 |
Disposal Group, Including Discontinued Operation, Other Assets | 0 | 4,044 |
Other Assets | 417,403 | 455,762 |
Total Assets | 9,183,981 | 10,929,902 |
Current Liabilities: | ||
Accounts Payable | 241,616 | 250,609 |
Long-term Debt and Capital Lease Obligations, Current | 12,000 | 9,409 |
Short-Term Notes Payable (Note 12) | 0 | 952,000 |
Other Accrued Liabilities, Current | 680,348 | 421,827 |
Disposal Group, Including Discontinued Operation, Liabilities, Current | 6,050 | 51,514 |
Total Current Liabilities | 940,014 | 1,685,359 |
Long-Term Debt: | ||
Long-term Debt, Excluding Current Maturities | 2,722,995 | 2,703,899 |
Capital Lease Obligations | 39,074 | 34,884 |
Disposal Group, Including Discontinued Operation, Liabilities | 0 | 5,001 |
Total Long-Term Debt | 2,762,069 | 2,743,784 |
Deferred Credits and Other Liabilities | ||
Deferred Tax Liabilities, Net, Noncurrent | 0 | 74,629 |
Postretirement Benefits Other Than Pensions | 659,474 | 630,892 |
Pneumoconiosis Benefits | 108,073 | 111,903 |
Mine Closing | 218,631 | 227,339 |
Gas Well Closing | 223,352 | 163,842 |
Workers' Compensation | 67,277 | 69,812 |
Salary Retirement | 112,543 | 91,596 |
Reclamation | 0 | 25 |
Other | 151,660 | 166,957 |
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent | 0 | 107,988 |
Total Deferred Credits and Other Liabilities | 1,541,010 | 1,644,983 |
TOTAL LIABILITIES | 5,243,093 | 6,074,126 |
Stockholders' Equity: | ||
Common Stock, $.01 Par Value; 500,000,000 Shares Authorized, 229,443,008 Issued and Outstanding at December 31, 2016; 229,054,236 Issued and Outstanding at December 31, 2015 | 2,298 | 2,294 |
Capital in Excess of Par Value | 2,460,864 | 2,435,497 |
Preferred Stock, 15,000,000 shares authorized, None issued and outstanding | 0 | 0 |
Retained Earnings | 1,727,789 | 2,579,834 |
Accumulated Other Comprehensive Loss | (392,556) | (315,598) |
Common Stock in Treasury, at Cost- No Shares at December 31, 2016 and 2015 | 0 | 0 |
Total CONSOL Energy Inc. Stockholders' Equity | 3,798,395 | 4,702,027 |
Noncontrolling Interest in Limited Partnerships | 142,493 | 153,749 |
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest | 3,940,888 | 4,855,776 |
TOTAL LIABILITIES AND EQUITY | $ 9,183,981 | $ 10,929,902 |
Consolidated Balance Sheets Par
Consolidated Balance Sheets Parentheticals - $ / shares | Dec. 31, 2016 | Dec. 31, 2015 |
Common Stock, Shares, Outstanding | 229,443,008 | 229,054,236 |
Common Stock [Member] | ||
Common Stock, Par or Stated Value Per Share | $ 0.01 | $ 0.01 |
Common Stock, Shares Authorized | 500,000,000 | 500,000,000 |
Common Stock, Shares, Issued | 229,443,008 | 229,054,236 |
Common Stock, Shares, Outstanding | 229,443,008 | 229,054,236 |
Treasury Stock, Shares | 0 | 0 |
Preferred Stock [Member] | ||
Preferred Stock, Shares Authorized | 15,000,000 | 15,000,000 |
Preferred Stock, Shares Issued | 0 | 0 |
Preferred Stock, Shares Outstanding | 0 | 0 |
Consolidated Statements of Stoc
Consolidated Statements of Stockholders' Equity - USD ($) $ in Thousands | Total | Common Stock [Member] | Capital in Excess of Par Value | Retained Earnings (Deficit) | Accumulated Other Comprehensive Income (Loss) | Common Stock in Treasury | Total CONSOL Energy Inc. Stockholders' Equity | Non-Controlling Interest |
Balance, Beginning of Period at Dec. 31, 2013 | $ 5,006,289 | $ 2,294 | $ 2,364,592 | $ 2,964,520 | $ (325,117) | $ 0 | $ 5,006,289 | $ 0 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||
Net Income (Loss) | 163,090 | 0 | 0 | 163,090 | 0 | 0 | 163,090 | 0 |
Gas Cash Flow Hedge | (79,028) | 0 | 0 | 0 | (79,028) | 0 | (79,028) | 0 |
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent | 94,989 | 0 | 0 | 0 | 94,989 | 0 | 94,989 | 0 |
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | 337,107 | 0 | 0 | 163,090 | 174,017 | 0 | 337,107 | 0 |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | 337,107 | |||||||
Issuance of Treasury Stock | (15,954) | 0 | 0 | (15,954) | 0 | 0 | (15,954) | 0 |
Proceeds from Issuance of Common Stock | 15,016 | 12 | 15,004 | 0 | 0 | 0 | 15,016 | 0 |
Amortization of Stock-Based Compensation Awards | 41,877 | 0 | 41,877 | 0 | 0 | 0 | 41,877 | 0 |
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | 0 | |||||||
Dividends | 57,506 | 0 | 0 | 57,506 | 0 | 0 | 57,506 | 0 |
Balance, End of Period at Dec. 31, 2014 | 5,329,458 | 2,306 | 2,424,102 | 3,054,150 | (151,100) | 0 | 5,329,458 | 0 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||
Other Comprehensive Income (Loss), Net of Tax | 174,017 | |||||||
Adjustments to Additional Paid in Capital, Income Tax Benefit from Share-based Compensation | 2,629 | 0 | 2,629 | 0 | 0 | 0 | 2,629 | 0 |
Net Income (Loss) | (364,475) | 0 | 0 | (374,885) | 0 | 0 | (374,885) | 10,410 |
Gas Cash Flow Hedge | 78,051 | 0 | 0 | 0 | 78,051 | 0 | 78,051 | 0 |
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent | (86,447) | 0 | 0 | 0 | (86,447) | 0 | (86,447) | 0 |
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | (539,383) | 0 | 0 | (374,885) | (164,498) | 0 | (539,383) | 10,410 |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | (528,973) | |||||||
Issuance of Treasury Stock | (12,181) | 0 | 0 | (12,181) | 0 | 0 | (12,181) | 0 |
Proceeds from Issuance of Common Stock | 8,288 | 10 | 8,278 | 0 | 0 | 0 | 8,288 | 0 |
Stock Repurchased During Period, Value | (71,674) | (22) | (17,683) | (53,969) | 0 | 0 | (71,674) | 0 |
Adjustments to Additional Paid in Capital, Income Tax Deficiency from Share-based Compensation | (3,706) | 0 | (3,706) | 0 | 0 | 0 | (3,706) | 0 |
Amortization of Stock-Based Compensation Awards | 24,506 | 0 | 24,506 | 0 | 0 | 0 | 24,506 | 0 |
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | (5,060) | 0 | 0 | 0 | 0 | 0 | 0 | (5,060) |
Net Change in Noncontrolling Interest | 148,399 | 0 | 0 | 0 | 0 | 0 | 0 | 148,399 |
Dividends | 33,281 | 0 | 0 | 33,281 | 0 | 0 | 33,281 | 0 |
Balance, End of Period at Dec. 31, 2015 | 4,855,776 | 2,294 | 2,435,497 | 2,579,834 | (315,598) | 0 | 4,702,027 | 153,749 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||
Other Comprehensive Income (Loss), Net of Tax | (164,498) | |||||||
Net Income (Loss) | (839,148) | |||||||
Gas Cash Flow Hedge | 43,470 | 0 | 0 | 0 | 43,470 | 0 | 43,470 | 0 |
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent | (33,226) | 0 | 0 | 0 | (33,488) | 0 | (33,488) | (262) |
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | (925,060) | |||||||
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | (915,844) | 0 | 0 | (848,102) | (76,958) | 0 | (925,060) | 9,216 |
Stock Granted, Value, Share-based Compensation, Forfeited | (1,649) | 0 | 0 | (1,649) | 0 | 0 | (1,649) | 0 |
Proceeds from Issuance of Common Stock | 4 | 4 | 0 | 0 | 0 | 0 | 4 | 0 |
Adjustments to Additional Paid in Capital, Income Tax Deficiency from Share-based Compensation | (4,931) | 0 | (4,931) | 0 | 0 | 0 | (4,931) | 0 |
Amortization of Stock-Based Compensation Awards | 31,483 | 0 | 30,298 | 0 | 0 | 0 | 30,298 | 1,185 |
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | (21,657) | |||||||
Net Change in Noncontrolling Interest | (21,657) | 0 | 0 | 0 | 0 | 0 | 0 | (21,657) |
Dividends | 2,294 | 0 | 0 | (2,294) | 0 | 0 | (2,294) | 0 |
Balance, End of Period at Dec. 31, 2016 | 3,940,888 | $ 2,298 | $ 2,460,864 | $ 1,727,789 | $ (392,556) | $ 0 | $ 3,798,395 | $ 142,493 |
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||
Other Comprehensive Income (Loss), Net of Tax | $ (76,696) |
Consolidated Statements of Cash
Consolidated Statements of Cash Flows - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Operating Activities: | |||
Net Income (Loss) | $ (839,148) | $ (364,475) | $ 163,090 |
Adjustments to Reconcile Net Income to Net Cash Provided By Operating Activities: | |||
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax | 303,183 | 14,209 | 1,857 |
Depreciation, Depletion and Amortization | 598,503 | 567,120 | 532,643 |
Gain (Loss) on Hedging Activity | 141,021 | (392,942) | (23,193) |
Derivative, Cash Received on Hedge | 245,212 | 196,348 | 19,025 |
Impairment of Long-Lived Assets to be Disposed of | 0 | 828,905 | 0 |
Non-Cash Other Post-Employment Benefits | 0 | (261,750) | (45,749) |
Share-based Compensation | 31,483 | 24,513 | 41,877 |
(Gain) Loss on Sale of Assets | (19,498) | (74,173) | (43,198) |
Gains (Losses) on Extinguishment of Debt | 0 | 67,751 | 95,267 |
Deferred Income Tax Expense (Benefit) | 120,305 | (140,472) | (7,319) |
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital | 22,268 | 35,466 | 102,174 |
Equity in Earnings of Affiliates | (53,078) | (54,897) | (49,791) |
Changes in Operating Assets: | |||
Accounts and Notes Receivable | (48,014) | 160,370 | (89,928) |
Inventories | 1,330 | 5,573 | 49,443 |
Prepaid Expenses | 84,026 | 128,405 | 4,788 |
Changes in Other Assets | (98,572) | 3,311 | (16,242) |
Changes in Operating Liabilities: | |||
Accounts Payable | (27,371) | (145,875) | 3,974 |
Increase (Decrease) in Interest Payable, Net | (1,040) | 26,649 | (9,868) |
Other Operating Liabilities | (20,356) | (147,110) | 227,467 |
Changes in Other Liabilities | (9,724) | (9,916) | (161,024) |
Other | 28,820 | 32,667 | 45,093 |
Net Cash Provided by (Used in) Operating Activities, Continuing Operations | 459,350 | 499,677 | 840,386 |
Cash Provided by (Used in) Operating Activities, Discontinued Operations | 9,935 | 6,172 | 96,390 |
Net Cash Provided by Operating Activities | 469,285 | 505,849 | 936,776 |
Investing Activities: | |||
Capital Expenditures | (226,820) | (982,934) | (1,459,452) |
Proceeds from Divestiture of Interest in Joint Venture | 213,295 | 0 | 0 |
Proceeds from Sales of Assets | 59,902 | 110,571 | 356,836 |
Net Investment in Equity Affiliates | 73,743 | (84,221) | 95,207 |
Cash Provided by (Used in) Investing Activities, Discontinued Operations | 367,251 | (39,633) | (33,973) |
Net Cash Used in Investing Activities | 487,371 | (996,217) | (1,041,382) |
Net Cash Provided by (Used in) Investing Activities, Continuing Operations | 120,120 | (956,584) | (1,007,409) |
Financing Activities: | |||
(Payments on) Proceeds from Short-Term Borrowings | (952,000) | 952,000 | (11,736) |
Payments on Miscellaneous Borrowings | (8,312) | (4,282) | (10,286) |
Payments On Long Term Notes Including Redemption Premium | 0 | (1,263,719) | (1,819,005) |
Net Proceeds from Revolver - MLP | 16,000 | 185,000 | 0 |
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | (21,657) | (5,060) | 0 |
Proceeds from Noncontrolling Interests | 0 | 148,359 | 0 |
Proceeds from Issuance of Long-Term Notes | 0 | 492,760 | 1,859,920 |
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities | 0 | 208 | 2,629 |
Dividends Paid | (2,294) | (33,281) | (57,506) |
Proceeds from Issuance of Common Stock | 4 | 8,288 | 15,016 |
Treasury Stock, Value, Acquired, Cost Method | 0 | (71,674) | 0 |
Payments of Debt Issuance Costs | (482) | (22,586) | (24,861) |
Cash Provided by (Used in) Financing Activities, Discontinued Operations | (14) | (56) | 0 |
Net Cash (Used in) Provided by Financing Activities | (968,755) | 385,957 | (45,829) |
Net Cash Provided by (Used in) Financing Activities, Continuing Operations | (968,741) | 386,013 | (45,829) |
Net Increase in Cash and Cash Equivalents | (12,099) | (104,411) | (150,435) |
Cash and Cash Equivalents at Beginning of Period | 72,574 | 176,985 | 327,420 |
Cash and Cash Equivalents at End of Period | $ 60,475 | $ 72,574 | $ 176,985 |
Discontinued Operations (Notes)
Discontinued Operations (Notes) | 12 Months Ended |
Dec. 31, 2016 | |
Discontinued Operations and Disposal Groups [Abstract] | |
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block] | NOTE 2—DISCONTINUED OPERATIONS: In August 2016, CONSOL Energy completed the sale of its Miller Creek Mining Complex and Fola Mining Complex subsidiaries. In the transaction, the buyer acquired the Miller Creek and Fola assets and assumed the Miller Creek and Fola mine closing and reclamation liabilities; in order to equalize the value exchange, CONSOL Energy paid $ 28,271 cash at closing, which included property taxes associated with the properties sold and other closing costs (a portion of which will be held in escrow for purposes of obtaining the surety bonds required for the the permits to transfer). These amounts were included in Net Cash Provided by Discontinued Investing Activities on the Consolidated Statements of Cash Flow. In addition, CONSOL Energy will pay a total of $ 17,200 in installments over the next four years. The net loss on sale of $ 53,130 , excluding the related impairment charge discussed below, was included in Loss from Discontinued Operations, net on the Consolidated Statements of Income. Prior to the closing, the Miller Creek and Fola Mining Complexes were classified as held for sale in discontinued operations and in accordance with the accounting guidance for Property, Plant and Equipment, assets held for sale are required to be measured at the lower of the carrying value or fair value less costs to sell. Upon meeting the assets held for sale criteria, the Company determined the carrying value of the Miller Creek and Fola Mining Complexes exceeded the fair value less costs to sell. As a result, an impairment charge of $ 355,681 was recorded during the year ended December 31, 2016. This impairment is included in the Loss from Discontinued Operations, net on the Consolidated Statements of Income. In March 2016, CONSOL Energy completed the sale of its membership interests in CONSOL Buchanan Mining Company, LLC (BMC), which owned and operated the Buchanan Mine located in Mavisdale, Virginia; various assets relating to the Amonate Mining Complex located in Amonate, Virginia; Russell County, Virginia coal reserves and Pangburn Shaner Fallowfield coal reserves located in Southwestern, Pennsylvania to Coronado IV LLC ("Coronado"). Various CONSOL Energy assets were excluded from the sale including coalbed methane, natural gas and minerals other than coal, current assets of BMC, certain coal seams, certain surface rights, and the Amonate Preparation Plant. Coronado assumed only specified liabilities and various CONSOL Energy liabilities were excluded and not assumed. The excluded liabilities included BMC’s indebtedness, trade payables and liabilities arising prior to closing, as well as the liabilities of the subsidiaries other than BMC which are parties to the sale. In addition, the buyer agreed to pay CONSOL Energy for Buchanan Mine coal sold outside the U.S. and Canada during the five years following closing a royalty of 20% of any excess of the gross sales price per ton over the following amounts: (1) year one, $ 75.00 per ton; (2) year two, $ 78.75 per ton; (3) year three, $ 82.69 per ton; (4) year four, $ 86.82 per ton; (5) year five, $ 91.16 per ton. At closing, the parties entered into several agreements including, among others, agreements relating to the coordination and conduct of gas operations at the mines, an option to purchase the Amonate Preparation Plant and transition services. Cash proceeds of $ 402,799 were received at closing and are included in Net Cash Provided by Discontinued Investing Activities on the Consolidated Statements of Cash Flow. The net loss on the sale was $ 38,364 and was included in Loss from Discontinued Operations, net on the Consolidated Statements of Income. For all periods presented in the accompanying Consolidated Statements of Income, BMC along with the various other assets and the Miller Creek and Fola Mining Complexes are classified as discontinued operations. The following table details selected financial information for the divested business included within discontinued operations: For the Years Ended December 31, 2016 2015 2014 Coal Sales $ 102,904 $ 367,234 $ 426,263 Freight-Outside Coal 1,322 5,098 5,015 Miscellaneous Other Income 740 51 2,635 (Loss) Gain on Sale of Assets (91,785 ) 336 (6,640 ) Total Revenue and Other Income $ 13,181 $ 372,719 $ 427,273 Total Costs 134,248 395,913 431,344 Loss From Operations Before Income Taxes $ (121,067 ) $ (23,194 ) $ (4,071 ) Impairment on Assets Held for Sale 355,681 — — Income Tax Benefit (173,565 ) (8,985 ) (2,214 ) Loss From Discontinued Operations, net $ (303,183 ) $ (14,209 ) $ (1,857 ) The major classes of assets and liabilities of discontinued operations: December 31, December 31, Assets: Accounts Receivable - Trade $ 83 $ 49,125 Inventories — 30,646 Prepaid Expense — 970 Other Current Assets — 364 Total Current Assets $ 83 $ 81,105 Property, Plant and Equipment, Net — 936,671 Other Assets — 4,044 Total Assets of Discontinued Operations $ 83 $ 1,021,820 Liabilities: Accounts Payable $ 36 $ 20,786 Other Current Liabilities 6,014 30,728 Total Current Liabilities $ 6,050 $ 51,514 Long Term Debt — 5,001 Pneumoconiosis Benefits — 1,129 Mine Closing — 71,941 Reclamation — 34,126 Other liabilities — 792 Total Liabilities of Discontinued Operations $ 6,050 $ 164,503 |
Acquisitions and Dispositions
Acquisitions and Dispositions | 12 Months Ended |
Dec. 31, 2016 | |
ACQUISITIONS AND DISPOSITIONS: [Abstract] | |
Acquisitions and Dispositions: | ACQUISITIONS AND DISPOSITIONS: In September 2015, CONSOL Energy sold its 49% interest in Western Allegheny Energy (WAE), a joint venture with Rosebud Mining Company engaged in coal mining activities in Pennsylvania. At closing, CONSOL Energy received $76,297 in cash and a $2,136 reduction in certain liabilities. During the third quarter of 2015, CONSOL Energy also received a cash distribution of $10,780 from WAE. The net gain on the sale was $48,468 and was included in the Gain on Sale of Assets in the Consolidated Statements of Income. In December 2014, CNX Gas Company LLC (CNX Gas Company), wholly-owned subsidiary of CONSOL Energy, finalized an agreement with Columbia Energy Ventures (CEVCO) to sublease from CEVCO approximately 20,000 acres of Utica Shale and Upper Devonian gas rights in Greene and Washington Counties in Pennsylvania and Marshall and Ohio Counties in West Virginia. Up-front bonus consideration of up to $96,106 was to be paid by CONSOL Energy over a five year period, as drilling occurs, in addition to royalties. CONSOL Energy made payments of $9,000 to CEVCO in the year ended December 31, 2016 , while $ 50,969 of payments were made in the year ended December 31, 2015 . At December 31, 2016 , the amounts recorded in Other Current Liabilities and Other Long-Term Liabilities both on a discounted basis were $ 3,947 and $ 26,461 , respectively. At December 31, 2015 , the amounts recorded in Other Current Liabilities and Other Long-Term Liabilities on a discounted basis were $ 8,349 and $29,333 , respectively. In December 2014, CONSOL Energy completed the sale of its industrial supplies subsidiary to an unrelated third party for expected net proceeds of approximately $ 51,000 , of which $ 44,035 was received and included in cash flows from investing activities during the year ended December 31, 2014. In connection with the sale, CONSOL Energy signed a supply agreement under which, among other things, it will continue to purchase certain goods exclusively from the new entity for a period of at least three years. CONSOL Energy recorded a net loss on the sale of $ 30,845 , which was included in Gain on Sale of Assets in the Consolidated Statements of Income. In December 2015, there was $ 6,258 of expense related to the settlement of working capital adjustments and other matters in conjunction with the sale, which was included in Other Costs - Miscellaneous Operating Costs in the Consolidated Statements of Income. |
Other Income
Other Income | 12 Months Ended |
Dec. 31, 2016 | |
Component of Operating Income [Abstract] | |
Other Income and Other Expense Disclosure [Text Block] | NOTE 4—MISCELLANEOUS OTHER INCOME: For the Years Ended December 31, 2016 2015 2014 Equity in Earnings of Affiliates - CONE $ 48,260 $ 43,799 $ 29,807 Rental Income 36,059 37,984 45,059 Right of Way Issuance 27,343 13,289 7,333 Royalty Income - Non-Operated Coal 20,083 15,402 19,653 Gathering Revenue 10,834 9,530 23,520 Coal Contract Buyout 6,288 — 30,000 Purchased Coal Sales 5,757 1,596 9,029 Equity in Earnings of Affiliates - Other 4,818 11,098 19,984 Interest Income 1,507 2,299 2,303 Other 6,357 9,354 20,772 Miscellaneous Other Income $ 167,306 $ 144,351 $ 207,460 |
Income Taxes
Income Taxes | 12 Months Ended |
Dec. 31, 2016 | |
Income Tax Disclosure [Abstract] | |
Income Taxes | INCOME TAXES: Income tax expense (benefit) provided on earnings from continuing operations consisted of: For The Years Ended December 31, 2016 2015 2014 Current: U.S. Federal $ (103,562 ) $ 19,726 $ 18,388 U.S. State (8,699 ) (5,657 ) 2,724 Non-U.S. 1,966 964 1,411 (110,295 ) 15,033 22,523 Deferred: U.S. Federal 124,766 (181,859 ) (12,581 ) U.S. State (4,461 ) 41,387 5,262 120,305 (140,472 ) (7,319 ) Total Income Tax Expense (Benefit) $ 10,010 $ (125,439 ) $ 15,204 The components of the net deferred taxes are as follows: December 31, 2016 2015 Deferred Tax Assets: Postretirement benefits other than pensions $ 260,959 $ 257,604 Alternative minimum tax 219,872 143,122 Net operating loss - Federal 144,450 165,951 Net operating loss - State 74,310 76,171 Gas derivatives 72,105 — Gas well closing 68,585 79,246 Pneumoconiosis benefits 43,997 44,830 Salary retirement 42,393 30,177 Mine closing 39,860 63,399 Foreign tax credit 39,850 39,850 Workers' compensation 30,758 31,544 Mine subsidence 29,532 44,317 Capital lease 2,925 4,404 Equity Partnerships — 45,746 Reclamation — 14,122 Other 66,724 65,427 Total Deferred Tax Assets 1,136,320 1,105,910 Valuation Allowance (282,778 ) (78,306 ) Net Deferred Tax Assets 853,542 1,027,604 Deferred Tax Liabilities: Property, plant and equipment (782,710 ) (946,778 ) Equity Partnerships (40,200 ) — Advance mining royalties (22,326 ) (44,921 ) Gas derivatives — (105,864 ) Other (4,016 ) (4,670 ) Total Deferred Tax Liabilities (849,252 ) (1,102,233 ) Net Deferred Tax Asset (Liability) $ 4,290 $ (74,629 ) A valuation allowance is required when it is more likely than not that all or a portion of a deferred tax asset will not be realized. All available evidence, both positive and negative, must be considered in determining the need for a valuation allowance. For the years ended December 31, 2016 and 2015 , positive evidence considered included financial earnings generated over the past three years for certain subsidiaries, reversals of financial to tax temporary differences and the implementation of and/or ability to employ various tax planning strategies. Negative evidence included financial and tax losses generated in prior periods, the inability to achieve forecasted results for those periods and the expectation that future financial results from normal operations would not be sufficient to support full utilization of certain tax credits within the foreseeable future. CONSOL Energy continues to report, on an after federal tax basis, a deferred tax asset related to state operating losses of $74,310 with a related valuation allowance of $60,488 at December 31, 2016 . The deferred tax asset related to state operating losses, on an after tax adjusted basis, was $76,171 with a related valuation allowance of $42,983 at December 31, 2015 . A review of positive and negative evidence regarding these tax benefits concluded that the valuation allowances for various CONSOL Energy subsidiaries was warranted. The net operating losses expire at various times between 2017 and 2036. A valuation allowance on foreign tax credits of $39,850 and $25,903 has been recorded at December 31, 2016 and 2015 , respectively. The foreign tax credits expire at various times between 2021 and 2023. A valuation allowance on charitable contribution carry-forwards of $5,051 has been recorded for 2016 . The charitable contributions carry-forwards expire at various times between 2018 and 2021. No such valuation allowance was recorded for 2015 . The deferred tax assets attributable to the state tax effect of future deductible temporary differences for certain CONSOL Energy subsidiaries with histories of financial and tax losses were also reviewed for positive and negative evidence regarding the realization of the deferred tax assets. A valuation allowance of $10,591 and $ 9,420 on an after federal tax adjusted basis has also been recorded for 2016 and 2015 , respectively. During 2016 , the deferred tax asset relating to federal alternative minimum tax credits increased $ 76,750 , to $219,872 at December 31, 2016 from $143,122 at December 31, 2015 . This increase was primarily attributable to restoring previously monetized alternative minimum tax credits. This restoration was created by an agreement reached with the IRS to accelerate certain tax depreciation deductions in exchange for forgoing previously claimed alternative minimum tax credit monetization. At December 31, 2016 , a valuation allowance of $166,798 was recorded against these alternative minimum tax credits, based on management's view that negative evidence with respect to their realizability outweighed positive evidence. There was no such valuation allowance at December 31, 2015 . These credits do not expire and will be able to be fully utilized when sufficient operating income is generated by the Company. Management will continue to assess the potential for realized deferred tax assets based upon income forecast data and the feasibility of future tax planning strategies and may record adjustments to valuation allowances against deferred tax assets in future periods, as appropriate, that could materially impact net income. The following is a reconciliation, stated as a percentage of pretax income, of the United States statutory federal income tax rate to CONSOL Energy's effective tax rate: For the Years Ended December 31, 2016 2015 2014 Amount Percent Amount Percent Amount Percent Statutory U.S. federal income tax rate $ (187,218 ) 35.0 % $ (166,497 ) 35.0 % $ 63,053 35.0 % Excess tax depletion (18,960 ) 3.5 (29,526 ) 6.2 (42,302 ) (23.5 ) Effect of domestic production activities — — — — (1,235 ) (0.7 ) Federal tax accrual to tax return reconciliation (6,789 ) 1.3 13,576 (2.9 ) (8,331 ) (4.6 ) IRS and state tax examination settlements 36,619 (6.8 ) (36 ) — (5,248 ) (2.9 ) Net effect of state income taxes (25,629 ) 4.8 (10,109 ) 2.1 5,235 2.9 Effect of change in federal valuation allowance 187,759 (35.1 ) 25,903 (5.4 ) — — Effect of change in state valuation allowance 20,047 (3.7 ) 39,492 (8.3 ) (1,436 ) (0.8 ) Effect of foreign tax 1,966 (0.4 ) 964 (0.2 ) 1,411 0.8 Other 2,215 (0.5 ) 794 (0.2 ) 4,057 2.1 Income Tax Expense (Benefit) / Effective Rate $ 10,010 (1.9 )% $ (125,439 ) 26.3 % $ 15,204 8.3 % As part of CONSOL Energy's IRS examination of the tax years 2010-2013, bonus depreciation was claimed resulting in a net cash refund of $92,000 . The bonus depreciation deduction adversely impacts earnings by reducing the Company's percentage depletion adjustment on its mining operations and reducing the Section 199 manufacturing deduction in the years 2008-2012. This resulted in a net non-cash charge to earnings of $36,619 . A reconciliation of the beginning and ending gross amounts of unrecognized tax benefits is as follows: For the Years Ended December 31, 2016 2015 Balance at beginning of period $ 12,702 $ 4,265 Increase in unrecognized tax benefits resulting from tax positions taken during current period 666 — Increase in unrecognized tax benefits resulting from tax positions taken during prior periods — 8,437 Reduction of unrecognized tax benefits as a result of a settlement with taxing authorities (4,265 ) — Balance at end of period $ 9,103 $ 12,702 If these unrecognized tax benefits were recognized, $666 and $4,265 would affect CONSOL Energy's effective income tax rate for 2016 and 2015 , respectively. CONSOL Energy and its subsidiaries file income tax returns in the United States and returns within various states and Canadian jurisdictions. With few exceptions, the Company is no longer subject to United States federal, state, local or non-U.S. income tax examinations by tax authorities for the years before 2010. CONSOL Energy recognizes interest accrued related to unrecognized tax benefits in its interest expense. As of December 31, 2016 and 2015 , the Company had an accrued liability of $305 and $53 , respectively, for interest related to uncertain tax positions. Interest expense of $252 and $53 was recorded in the Company's Consolidated Statements of Income for the years ended December 31, 2016 and 2015 , respectively. During the years ended December 31, 2016 and 2015 , CONSOL Energy paid no interest related to income tax deficiencies. CONSOL Energy recognizes penalties accrued related to uncertain tax positions in its income tax expense. As of December 31, 2016 and 2015 , CONSOL Energy had no accrued liabilities for tax penalties. |
Stock Repurchase (Notes)
Stock Repurchase (Notes) | 12 Months Ended |
Dec. 31, 2016 | |
Stock Repurchase [Abstract] | |
Repurchase Agreements, Valuation, Policy [Policy Text Block] | NOTE 5— STOCK REPURCHASE: In December 2014, CONSOL Energy’s Board of Directors approved a stock repurchase program under which CONSOL Energy could have purchased up to $ 250,000 of its common stock over a two year period. Under the terms of the program, CONSOL Energy was permitted to make repurchases in the open market, in privately negotiated transactions, accelerated repurchase programs or in structured share repurchase programs. Any repurchases of common stock were to be funded from available cash on hand or short-term borrowings. The program did not obligate CONSOL Energy to acquire any particular amount of common stock, and could have been modified or suspended at any time at the Company’s discretion. The program was conducted in compliance with applicable legal requirements and within the limits imposed by any credit agreement, receivables purchase agreement or indenture and was subject to market conditions and other factors. No shares were repurchased under this program during the year ended December 31, 2016 . During the year ended December 31, 2015 , 2,213,100 shares were repurchased and retired at an average price of $ 32.37 per share. |
Inventories
Inventories | 12 Months Ended |
Dec. 31, 2016 | |
Inventory Disclosure [Abstract] | |
Inventories | INVENTORIES: December 31, 2016 2015 Coal $ 7,800 $ 4,660 Supplies 57,661 62,132 Total Inventories $ 65,461 $ 66,792 |
Property, Plant and Equipment
Property, Plant and Equipment | 12 Months Ended |
Dec. 31, 2016 | |
Property, Plant and Equipment [Abstract] | |
Property, Plant and Equipment | PROPERTY, PLANT AND EQUIPMENT: December 31, E&P Property, Plant and Equipment 2016 2015 Intangible drilling cost $ 3,583,565 $ 3,452,989 Proved gas properties 2,016,916 1,922,602 Unproved gas properties 1,116,282 1,421,083 Gas gathering equipment 1,138,299 1,147,173 Gas wells and related equipment 791,996 785,744 Other gas assets 190,406 125,691 Gas advance royalties 13,762 19,745 Total E&P Property, Plant and Equipment $ 8,851,226 $ 8,875,027 Less: Accumulated Depreciation, Depletion and Amortization 3,106,296 2,695,674 Total E&P Property, Plant and Equipment - Net $ 5,744,930 $ 6,179,353 PA Mining Operations Property, Plant and Equipment Coal and other plant and equipment $ 2,307,668 $ 2,284,103 Coal properties and surface lands 458,398 456,044 Airshafts 371,752 351,870 Mine development 326,152 326,225 Coal advance mining royalties 16,224 16,263 Leased coal lands 26,566 26,402 Total PA Mining Operations Property, Plant and Equipment $ 3,506,760 $ 3,460,907 Less: Accumulated Depreciation, Depletion and Amortization 1,768,712 1,603,642 Total PA Mining Operations Property, Plant and Equipment - Net $ 1,738,048 $ 1,857,265 Other Property, Plant and Equipment Coal and other plant and equipment $ 532,919 $ 569,333 Coal properties and surface lands 481,126 484,348 Airshafts 10,003 10,002 Mine development 17,988 18,073 Coal advance mining royalties 310,530 312,452 Leased coal lands 60,836 64,765 Total Other Property, Plant and Equipment $ 1,413,402 $ 1,458,973 Less: Accumulated Depreciation, Depletion and Amortization 755,941 762,885 Total Other Property, Plant and Equipment - Net $ 657,461 $ 696,088 Total Company Property, Plant and Equipment $ 13,771,388 $ 13,794,907 Less - Total Company Accumulated Depreciation, Depletion and Amortization 5,630,949 5,062,201 Total Company Property, Plant and Equipment - Net $ 8,140,439 $ 8,732,706 The following assets are amortized using the units-of-production method. Amounts reflect properties where mining or drilling operations have not yet commenced and therefore, are not being amortized for the years ended December 31, 2016 and 2015 , respectively. December 31, 2016 2015 Unproved gas properties $ 1,116,282 $ 1,421,083 Coal properties 195,354 258,099 Leased coal lands 36,788 44,805 Airshafts 19,693 24,674 Coal advance mining royalties 16,270 21,544 Gas advance royalties 13,762 19,745 Mine development 7,771 7,930 Total $ 1,405,920 $ 1,797,880 As of December 31, 2016 and 2015 , plant and equipment includes gross assets under capital lease of $ 77,438 and $ 79,551 , respectively. Included in Gas gathering equipment under the E&P division is a capital lease for the Jewell Ridge Pipeline of $ 66,919 at December 31, 2016 and 2015 . The E&P division also maintains a capital lease for vehicles of $ 6,015 and $ 7,474 at December 31, 2016 and 2015 , respectively, which is included in Other gas assets. At December 31, 2016 and 2015 , the PA Mining segment maintains capital leases for vehicles of $2,525 and $1,923 , respectively, which are included in Coal and other plant and equipment. At December 31, 2016 and 2015 , the Other segment maintains capital leases for vehicles and computer equipment of $ 1,979 and $ 3,235 , respectively, which are included in Coal and other plant and equipment. Accumulated amortization for capital leases was $ 51,213 and $ 46,503 at December 31, 2016 and 2015 , respectively. Amortization expense for capital leases is included in Depreciation, Depletion and Amortization in the Consolidated Statements of Income. See Note 13–Leases for further discussion of capital leases. Industry Participation Agreements CONSOL Energy had two significant industry participation agreements (referred to as "joint ventures" or "JVs") that provided drilling and completion carries for the Company's retained interests. CNX Gas Company is party to a joint development agreement with Hess Ohio Developments, LLC (Hess) with respect to approximately 155 thousand net Utica Shale acres in Ohio in which each party has a 50% undivided interest. Under the agreement, as amended, Hess was obligated to pay a total of approximately $335,000 in the form of a 50% drilling carry of certain CONSOL Energy working interest obligations as the acreage is developed. As of December 31, 2016 , Hess' entire carry obligation has been met. CNX Gas Company was party to a joint development agreement with Noble Energy, Inc. (Noble) with respect to approximately 700 thousand net Marcellus Shale oil and gas acres in West Virginia and Pennsylvania, in which each party owned a 50% undivided interest. On October 29, 2016, CNX Gas entered into an Exchange Agreement with Noble Energy, which terminated the joint development agreement related to the jointly owned gas assets held in connection with the joint venture with Noble and divided such jointly owned gas assets among CNX Gas and Noble Energy. The transactions contemplated by the Exchange Agreement was closed on December 1, 2016 with an effective date of October 1, 2016. As part of the exchange: each party will own and operate a 100% interest in its properties and wells in two separate operating areas; each party will have independent control and flexibility with respect to the scope and timing of future development over its operating area; and all acreage operated by CONSOL Energy and Noble Energy, Inc. in their respective operating areas will remain fully dedicated to CONE Midstream Partners LP. Cash proceeds of approximately $213,295 were received at closing and are included in cash flows from investing activities in the Consolidated Statements of Cash Flows. The exchange was accounted for as a mineral conveyance, thus no gain or loss was recorded in connection with the transaction. |
Short-Term Notes Payable
Short-Term Notes Payable | 12 Months Ended |
Dec. 31, 2016 | |
Short-term Debt [Abstract] | |
Short-Term Notes Payable: | SHORT-TERM NOTES PAYABLE: CONSOL Energy's current senior secured credit agreement expires on June 18, 2019. The credit facility allows for up to $2,000,000 of borrowings, which includes a $ 750,000 letters of credit sub-limit. CONSOL Energy can also request an additional $ 500,000 increase in the aggregate borrowing limit amount. The current facility is secured by substantially all of the assets of CONSOL Energy and certain of its subsidiaries. Fees and interest rate spreads are based on the percentage of facility utilization, measured quarterly. Availability under the facility is limited to a borrowing base, which is determined by the lenders syndication agent and approved by the required number of lenders in good faith by calculating a value of CONSOL Energy's proved natural gas reserves. The current facility contains a number of affirmative and negative covenants that limit the Company's ability to dispose of assets, make investments, purchase or redeem CONSOL Energy common stock, pay dividends, merge with another corporation and amend, modify or restate the senior unsecured notes. In April 2016, the facility was amended to require that the Company must: (i) prepay outstanding loans under the revolving credit facility to the extent that cash on hand exceeds $150,000 for two consecutive business days; (ii) mortgage 85% of its proved reserves and 80% of its proved developed producing reserves, in each case, which are included in the borrowing base; (iii) maintain applicable deposit, securities and commodities accounts with the lenders or affiliates thereof; and (iv) enter into control agreements with respect to such applicable accounts. In addition, the Company pledged the equity interest it holds in CONE Gathering, LLC and CONE Midstream Partners, LP as collateral to secure loans under the credit agreement. The facility also requires that CONSOL Energy maintains a minimum interest coverage ratio of no less than 2.50 to 1.00, which is calculated as the ratio of Adjusted EBITDA to cash interest expense of CONSOL Energy and certain of its subsidiaries, measured quarterly. CONSOL Energy must also maintain a minimum current ratio of no less than 1.00 to 1.00, which is calculated as the ratio of current assets, plus revolver availability, to current liabilities, excluding borrowings under the revolver, measured quarterly. At December 31, 2016 , the interest coverage ratio was 3.49 to 1.00 and the current ratio was 2.59 to 1.00. Further, the credit facility allows unlimited investments in joint ventures for the development and operation of natural gas gathering systems and permits CONSOL Energy to separate its E&P and coal businesses if the leverage ratio (which is, essentially, the ratio of debt to EBITDA) of the E&P business immediately after the separation would not be greater than 2.75 to 1.00. The calculation of all of the ratios exclude CNX Coal Resources LP (CNXC). At December 31, 2016 , the $2,000,000 facility had no borrowings outstanding and $ 325,676 of letters of credit outstanding, leaving $ 1,674,324 of unused capacity. At December 31, 2015 , the $2,000,000 facility had $952,000 of borrowings outstanding and $258,177 of letters of credit outstanding, leaving $789,823 of unused capacity. |
Other Accrued Liabilities
Other Accrued Liabilities | 12 Months Ended |
Dec. 31, 2016 | |
Other Liabilities Disclosure [Abstract] | |
Accounts Payable and Accrued Liabilities Disclosure [Text Block] | NOTE 11—OTHER ACCRUED LIABILITIES: December 31, 2016 2015 Gas derivatives $ 231,573 $ 12,206 Subsidence liability 104,437 86,860 Royalties 44,657 38,707 Accrued interest 37,366 38,406 Accrued payroll & benefits 24,649 24,952 Accrued other taxes 20,679 10,927 Short-term incentive compensation 19,497 6,802 Deferred Revenue 18,211 11,557 Equipment leases 15,286 15,286 Other 59,025 60,052 Current portion of long-term liabilities: Postretirement benefits other than pensions 42,001 46,105 Gas well closing 17,285 15,648 Mine closing 14,276 22,599 Workers' compensation 13,874 14,803 Pneumoconiosis benefits 10,763 9,382 Long-term disability 3,865 4,248 Salary retirement 2,904 2,772 Reclamation — 515 Total Other Accrued Liabilities $ 680,348 $ 421,827 |
Long-Term Debt
Long-Term Debt | 12 Months Ended |
Dec. 31, 2016 | |
Long-term Debt, Unclassified [Abstract] | |
Long-term Debt | LONG-TERM DEBT: December 31, 2016 2015 Debt: Senior Notes due April 2022 at 5.875% (Principal of $1,850,000 plus Unamortized Premium of $4,731 and $5,617, respectively) $ 1,854,731 $ 1,855,617 Senior Notes due April 2023 at 8.00% (Principal of $500,000 less Unamortized Discount of $5,656 and $6,561, respectively) 494,344 493,439 Revolving Credit Facility - CNX Coal Resources LP 201,000 185,000 MEDCO Revenue Bonds in Series due September 2025 at 5.75% 102,865 102,865 Senior Notes due April 2020 at 8.25%, Issued at Par Value 74,470 74,470 Senior Notes due March 2021 at 6.375%, Issued at Par Value 20,611 20,611 Advance Royalty Commitments (7.73% and 16.35% Weighted Average Interest Rate, respectively) 2,678 3,964 Other Long-Term Note Maturing in 2018 (Principal of $1,789 and $3,096 less Unamortized Discount of $117 and $327, respectively) 1,672 2,769 Less: Unamortized Debt Issuance Costs 27,699 33,017 2,724,672 2,705,718 Less: Amounts Due in One Year* 1,677 1,819 Long-Term Debt $ 2,722,995 $ 2,703,899 *Excludes current portion of Capital Lease Obligations of $10,323 and $7,590 at December 31, 2016 and 2015 , respectively. Annual undiscounted maturities on long-term debt during the next five years and thereafter are as follows: Year ended December 31, Amount 2017 $ 1,804 2018 672 2019 292 2020 275,740 2021 20,861 Thereafter 2,454,043 Total Long-Term Debt Maturities $ 2,753,412 |
Leases
Leases | 12 Months Ended |
Dec. 31, 2016 | |
Leases [Abstract] | |
Leases of Lessee Disclosure [Text Block] | NOTE 13—LEASES: CONSOL Energy uses various leased facilities and equipment in its operations. Future minimum lease payments under capital and operating leases, together with the present value of the net minimum capital lease payments, at December 31, 2016 are as follows: Capital Operating Leases Leases Year Ended December 31, 2017 $ 13,237 $ 103,325 2018 12,442 64,520 2019 11,977 37,272 2020 11,007 27,722 2021 8,959 26,816 Thereafter — 80,692 Total minimum lease payments $ 57,622 $ 340,347 Less amount representing interest (2.00% – 7.36%) 8,225 Present value of minimum lease payments 49,397 Less amount due in one year 10,323 Total Long-Term Capital Lease Obligation $ 39,074 Rental expense under operating leases was $108,698 , $109,789 , and $111,257 for the years ended December 31, 2016 , 2015 and 2014 , respectively. At December 31, 2016 , certain of the above capital leases for mining equipment are subleased to a third-party. The following represents the minimum payments including interest for those capital subleases: 2017 2018 2019 2020 2021 Thereafter Total $ 3,699 $ 3,699 $ 3,699 $ 3,699 $ 2,157 $ — $ 16,953 At December 31, 2016 , certain of the above operating leases for mining equipment are subleased to third-parties. The following represents the minimum rental payments for those operating subleases: 2017 2018 2019 2020 2021 Thereafter Total $ 40,299 $ 13,819 $ 6,909 $ — $ — $ — $ 61,027 CONSOL Energy leases certain owned mining equipment to a third-party under operating leases. The owned equipment included in gross property, plant and equipment was $ 26,005 , with $ 15,603 accumulated depreciation at December 31, 2016 . At December 31, 2016 , scheduled minimum rental payments for operating leases related to this equipment were as follows: 2017 2018 2019 2020 2021 Thereafter Total $ 4,496 $ 2,992 $ 1,701 $ 627 $ — $ — $ 9,816 |
Pension and OPEB
Pension and OPEB | 12 Months Ended |
Dec. 31, 2016 | |
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract] | |
Components of Pension and Other Postretirement Benefit Plans: | NOTE 14—PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS: Pension: CONSOL Energy has non-contributory defined benefit retirement plans. Effective December 31, 2015, CONSOL Energy's qualified defined benefit retirement plan was frozen. The benefits for these plans are based primarily on years of service and employees' pay. CONSOL Energy's qualified pension plan allows for lump-sum distributions of benefits earned up until December 31, 2005, at the employees' election. On September 30, 2014, the qualified pension plan was remeasured to reflect an announced plan amendment that reduced future accruals of pension benefits as of January 1, 2015. The plan amendment called for a hard freeze of the qualified defined benefit pension plan on January 1, 2015 for employees who were under age 40 or had less than 10 years of service as of September 30, 2014. Employees who were age 40 or over and had at least 10 years of service continued in the defined benefit pension plan unchanged. The modifications to the pension plan resulted in a $21,624 reduction in the pension liability. On August 31, 2015, the qualified pension plan was remeasured to reflect an announced plan amendment that reduced accruals of pension benefits as of January 1, 2016. The plan amendment called for a hard freeze of the qualified defined benefit pension plan on January 1, 2016 for all remaining participants in the plan. The modifications to the pension plan resulted in a $26,352 reduction in the pension liability. The amendment resulted in a remeasurement of the qualified pension plan at August 31, 2015, which increased the pension liability by $17,793 . In the third quarter of 2015, CONSOL Energy remeasured its pension plan as a result of the previously discussed plan amendment. In conjunction with this remeasurement, the method used to estimate the service and interest components of net periodic benefit cost for pension was changed. This change was also made to other postretirement benefits in the fourth quarter during the annual remeasurement of that plan. This change, compared to the previous method, resulted in a decrease in the service and interest components for pension cost in the third quarter. Historically, CONSOL Energy estimated these service and interest cost components utilizing a single weighted-average discount rate derived from the yield curve used to measure the benefit obligation at the beginning of the period. CONSOL Energy has elected to utilize a full yield curve approach in the estimation of these components by applying the specific spot rates along the yield curve used in the determination of the benefit obligation to the relevant projected cash flows. This change was made to provide a more precise measurement of service and interest costs by improving the correlation between projected benefit cash flows to the corresponding spot yield curve rates. This change is immaterial to CONSOL's financial statements. CONSOL Energy has accounted for this change as a change in accounting estimate that is inseparable from a change in accounting principle and, accordingly, accounted for it prospectively. According to the Defined Benefit Plans Topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification, if the lump sum distributions made during a plan year, which for CONSOL Energy is January 1 to December 31, exceed the total of the projected service cost and interest cost for the plan year, settlement accounting is required. Lump sum payments exceeded this threshold during the years ended December 31, 2016 , 2015 , and 2014 . Accordingly, CONSOL Energy recognized settlement expense of $22,196 , $19,053 , and $29,095 for the years ended December 31, 2016 , 2015 and 2014 respectively, in Other Costs - Miscellaneous Operating Expense in the Consolidated Statements of Income. The settlement charges resulted in remeasurements of the pension plan during 2016 , 2015 and 2014 . Other Postretirement Benefit Plans: Certain subsidiaries of CONSOL Energy provide medical and prescription drug benefits to retired employees covered by the Coal Industry Retiree Health Benefit Act of 1992 (the Coal Act). Represented hourly employees are eligible to participate based upon the terms of the National Bituminous Coal Wage Agreement of 2011. On September 30, 2014, the Salaried OPEB plan and Production and Maintenance (P&M) OPEB plans were remeasured to reflect an announced plan amendment that reduced retiree medical and life insurance benefits as of September 30, 2014. Effective September 30, 2014, no retiree medical, prescription drug or life benefits were to be provided to active employees. Salaried and P&M retirees as of September 30, 2014 were to continue in the OPEB plans for a maximum period up to December 31, 2019 and coverage thereafter was eliminated (see below for information on an additional amendment made to these plans in 2015). The Company elected to make cash transition payments totaling approximately $46,282 to the active employees whose retiree medical, prescription drug and life insurance benefits were eliminated by the changes to the OPEB plans. These cash payments are not considered to be post-retirement benefits, and as such, they are not reflected in the actuarial calculations related to the OPEB plans. The amendment to the OPEB plans resulted in a $315,439 reduction in the OPEB liability and a curtailment gain of $35,633 . On May 31, 2015, the Salaried OPEB and P&M OPEB plans were remeasured to reflect another plan amendment which eliminated Salaried and P&M OPEB benefits at December 31, 2015. The amendment to the OPEB plans resulted in a $43,598 reduction in the OPEB liability. The amendment also resulted in a remeasurement of the OPEB plan at May 31, 2015, which decreased the liability by $1,070 . CONSOL Energy recognized income of $235,541 related to amortization of prior service credit, coupled with recognition of actuarial losses in PA Mining Operations Costs - Operating and Other Costs and Other Costs - Miscellaneous Operating Expense in the Consolidated Statements of Income for the year ended December 31, 2015 as a result of the changes made to the Salaried and P&M OPEB plans. The Company will incur savings from cost containment changes related to pharmacy benefits, which were implemented on January 1, 2017, and increased member responsibility when using out-of-network providers and facilities, which will be implemented on March 27, 2017. These plan amendments resulted in a $28,164 reduction in the OPEB liability during the year ended December 31, 2016. The reconciliation of changes in the benefit obligation, plan assets and funded status of these plans at December 31, 2016 and 2015 is as follows: Pension Benefits Other Postretirement Benefits at December 31, at December 31, 2016 2015 2016 2015 Change in benefit obligation: Benefit obligation at beginning of period $ 763,407 $ 870,471 $ 671,755 $ 760,959 Service cost 1,927 8,653 — — Interest cost 25,491 32,095 24,241 27,238 Actuarial loss (gain) 46,962 (39,563 ) 77,640 (9,224 ) Plan amendments — — (28,164 ) (43,598 ) Plan transfer* — — — (5,242 ) Plan curtailments — (26,352 ) — — Plan settlements (54,197 ) (51,497 ) — — Participant contributions — — — 1,649 Benefits and other payments (35,709 ) (30,400 ) (45,387 ) (60,027 ) Benefit obligation at end of period $ 747,881 $ 763,407 $ 700,085 $ 671,755 Change in plan assets: Fair value of plan assets at beginning of period $ 669,039 $ 751,176 $ — $ — Actual return (loss) on plan assets 50,575 (9,293 ) — — Company contributions 2,726 9,053 45,387 58,378 Participant contributions — — — 1,649 Benefits and other payments (35,709 ) (30,400 ) (45,387 ) (60,027 ) Plan settlements (54,197 ) (51,497 ) — — Fair value of plan assets at end of period $ 632,434 $ 669,039 $ — $ — Funded status: Current liabilities $ (2,904 ) $ (2,772 ) $ (40,611 ) $ (40,863 ) Noncurrent liabilities (112,543 ) (91,596 ) (659,474 ) (630,892 ) Net obligation recognized $ (115,447 ) $ (94,368 ) $ (700,085 ) $ (671,755 ) Amounts recognized in accumulated other comprehensive income consist of: Net actuarial loss $ 299,865 $ 288,695 $ 426,392 $ 367,920 Prior service credit (1,611 ) (2,201 ) (28,164 ) — Net amount recognized (before tax effect) $ 298,254 $ 286,494 $ 398,228 $ 367,920 *The plan transfer relates to the IBNR (incurred but not reported) costs associated with the terminated Salaried and P&M OPEB plans. These costs are now included in Other Accrued Liabilities in the Consolidated Balance Sheets. The components of net periodic benefit costs are as follows: Pension Benefits Other Postretirement Benefits For the Years Ended December 31, For the Years Ended December 31, 2016 2015 2014 2016 2015 2014 Components of net periodic benefit cost: Service cost $ 1,927 $ 8,653 $ 17,187 $ — $ — $ 7,089 Interest cost 25,491 32,095 35,363 24,241 27,238 44,177 Expected return on plan assets (46,674 ) (51,528 ) (51,400 ) — — — Amortization of prior service credits (590 ) (666 ) (1,217 ) — (336,327 ) (21,163 ) Recognized net actuarial loss 9,694 21,519 23,927 19,168 102,875 28,682 Curtailment loss (gain) — 5 (549 ) — — (35,633 ) Settlement loss (gain) 22,196 19,053 29,095 — (8,932 ) — Net periodic benefit cost (credit) $ 12,044 $ 29,131 $ 52,406 $ 43,409 $ (215,146 ) $ 23,152 Amounts included in accumulated other comprehensive loss which are expected to be recognized in 2017 net periodic benefit costs: Other Pension Postretirement Benefits Benefits Prior service credit recognition $ (590 ) $ (2,405 ) Actuarial loss recognition $ 9,403 $ 23,112 CONSOL Energy utilizes a corridor approach to amortize actuarial gains and losses that have been accumulated under the Pension Plan. Cumulative gains and losses that are in excess of 10% of the greater of either the projected benefit obligation (PBO) or the market-related value of plan assets are amortized over the expected remaining future lifetime of all plan participants for the Pension plan. CONSOL Energy also utilizes a corridor approach to amortize actuarial gains and losses that have been accumulated under the OPEB Plan. Cumulative gains and losses that are in excess of 10% of the greater of either the accumulated postretirement benefit obligation (APBO) or the market-related value of plan assets are amortized over the average future remaining lifetime of the current inactive population for the OPEB plan. The following table provides information related to pension plans with an accumulated benefit obligation in excess of plan assets: As of December 31, 2016 2015 Projected benefit obligation $ 747,881 $ 763,407 Accumulated benefit obligation $ 745,793 $ 761,124 Fair value of plan assets $ 632,434 $ 669,039 Assumptions: The weighted-average assumptions used to determine benefit obligations are as follows: Pension Benefits Other Postretirement Benefits For the Year Ended For the Year Ended December 31, December 31, 2016 2015 2016 2015 Discount rate 4.31 % 4.50 % 4.22 % 4.50 % Rate of compensation increase 3.90 % 3.80 % — — The discount rates are determined using a Company-specific yield curve model (above-mean) developed with the assistance of an external actuary. The Company-specific yield curve models (above-mean) use a subset of the expanded bond universe to determine the Company-specific discount rate. Bonds used in the yield curve are rated AA by Moody's or Standard & Poor's as of the measurement date. The yield curve models parallel the plans' projected cash flows, and the underlying cash flows of the bonds included in the models exceed the cash flows needed to satisfy the Company plans. The weighted-average assumptions used to determine net periodic benefit costs are as follows: Pension Benefits at Other Postretirement Benefits at December 31, December 31, 2016 2015 2014 2016 2015 2014 Discount rate 4.52 % 4.07 % 4.87 % 4.50 % 4.03 % 4.88 % Expected long-term return on plan assets 7.25 % 7.75 % 7.75 % — — — Rate of compensation increase 3.80 % 3.80 % 4.21 % — — — The long-term rate of return is the sum of the portion of total assets in each asset class held multiplied by the expected return for that class, adjusted for expected expenses to be paid from the assets. The expected return for each class is determined using the plan asset allocation at the measurement date and a distribution of compound average returns over a twenty year time horizon. The model uses asset class returns, variances and correlation assumptions to produce the expected return for each portfolio. The return assumptions used forward-looking gross returns influenced by the current Treasury yield curve. These returns recognize current bond yields, corporate bond spreads and equity risk premiums based on current market conditions. The assumed health care cost trend rates are as follows: At December 31, 2016 2015 2014 Health care cost trend rate for next year 6.31 % 6.49 % 6.03 % Rate to which the cost trend is assumed to decline (ultimate trend rate) 4.50 % 4.50 % 4.50 % Year that the rate reaches ultimate trend rate 2038 2038 2026 Assumed health care cost trend rates have a significant effect on the amounts reported for the medical plans. A one-percentage point change in assumed health care cost trend rates would have the following effects: 1 Percentage 1 Percentage Point Increase Point Decrease Effect on total of service and interest cost components $ 3,659 $ (3,053 ) Effect on accumulated postretirement benefit obligation $ 84,381 $ (71,751 ) Plan Assets: The Company’s overall investment strategy is to meet current and future benefit payment needs through diversification across asset classes, fund strategies and fund managers to achieve an optimal balance between risk and return and between income and growth of assets through capital appreciation. Consistent with the objectives of the Trust and in consideration of the Trust’s current funded status and the current level of market interest rates, the Retirement Board has approved an asset allocation strategy that will change over time in response to future improvements in the Trust’s funded status and/or changes in market interest rates. Such changes in asset allocation strategy are intended to allocate additional assets to the fixed income asset class should the Trust’s funded status improve. In this framework, the current target allocation for plan assets are 26% U.S. equity securities, 16.5% non-U.S. equity securities, 7.5% global equity securities and 50% fixed income. Both the equity and fixed income portfolios are comprised of both active and passive investment strategies. The Trust is primarily invested in Mercer Common Collective Trusts. Equity securities consist of investments in large and mid/small cap companies with non-U.S. equities being derived from both developed and emerging markets. Fixed income securities consist of U.S. as well as international instruments, including emerging markets. The core domestic fixed income portfolios invest in government, corporate, asset-backed securities and mortgage-backed obligations. The average quality of the fixed income portfolio must be rated at least “investment grade” by nationally recognized rating agencies. Within the fixed income asset class, investments are invested primarily across various strategies such that its overall profile strongly correlates with the interest rate sensitivity of the Trust’s liabilities in order to reduce the volatility resulting from the risk of changes in interest rates and the impact of such changes on the Trust’s overall financial status. Derivatives, interest rate swaps, options and futures are permitted investments for the purpose of reducing risk and to extend the duration of the overall fixed income portfolio; however, they may not be used for speculative purposes. All or a portion of the assets may be invested in mutual funds or other commingled vehicles so long as the pooled investment funds have an adequate asset base relative to their asset class; are invested in a diversified manner; and have management and/or oversight by an Investment Advisor registered with the SEC. The Retirement Board, as appointed by the CONSOL Energy Board of Directors, reviews the investment program on an ongoing basis including asset performance, current trends and developments in capital markets, changes in Trust liabilities and ongoing appropriateness of the overall investment policy. In May 2015, the FASB issued an Accounting Standards Update that removes the requirement to categorize within the fair value hierarchy investments for which fair values are estimated using the net asset value practical expedient provided by Accounting Standards Codification 820, Fair Value Measurement. This new guidance is effective for public entities for fiscal years beginning after December 15, 2015. In accordance with this Update, certain investments in 2016 and 2015 that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified as Level 1, 2 or 3 in the below fair value hierarchy but are included in the total. The fair values of plan assets at December 31, 2016 and 2015 by asset category are as follows: Fair Value Measurements at December 31, 2016 Fair Value Measurements at December 31, 2015 Quoted Quoted Prices in Prices in Active Active Markets for Significant Significant Markets for Significant Significant Identical Observable Unobservable Identical Observable Unobservable Assets Inputs Inputs Assets Inputs Inputs Total (Level 1) (Level 2) (Level 3) Total (Level 1) (Level 2) (Level 3) Asset Category Cash/Accrued Income $ 639 $ 639 $ — $ — $ 631 $ 631 $ — $ — US Equities (a) 11 11 — — 10 10 — — Mercer Common Collective Trusts (b) 631,784 — — — 668,398 — — — Total $ 632,434 $ 650 $ — $ — $ 669,039 $ 641 $ — $ — __________ (a) This category includes investments in US common stocks and corporate debt. (b) Certain investments that are measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy but are included in the total. There are no investments in CONSOL Energy stock held by these plans at December 31, 2016 or 2015 . There are no assets in the other postretirement benefit plans at December 31, 2016 or 2015 . Cash Flows: If necessary, CONSOL Energy intends to contribute to the pension trust using prudent funding methods. However, the Company does not expect to contribute to the pension plan trust in 2017. Pension benefit payments are primarily funded from the trust. CONSOL Energy expects to pay benefits of $2,904 from the non-qualified pension plan in 2017. CONSOL Energy does not expect to contribute to the other postemployment plan in 2017 and intends to pay benefit claims as they are due. The following benefit payments, reflecting expected future service, are expected to be paid: Other Pension Postretirement Benefits Benefits 2017 $ 47,374 $ 40,611 2018 $ 47,100 $ 43,829 2019 $ 46,211 $ 43,932 2020 $ 45,773 $ 44,136 2021 $ 44,206 $ 44,233 Year 2022-2026 $ 223,745 $ 215,248 |
CWP and Workers Comp
CWP and Workers Comp | 12 Months Ended |
Dec. 31, 2016 | |
Postemployment Benefits [Abstract] | |
Coal Workers' Pneumoconiosis (CWP) and Workers' Compensation: | COAL WORKERS’ PNEUMOCONIOSIS (CWP) AND WORKERS’ COMPENSATION: Under the Federal Coal Mine Health and Safety Act of 1969, as amended, CONSOL Energy is responsible for medical and disability benefits to employees and their dependents resulting from occurrences of coal workers' pneumoconiosis disease. CONSOL Energy is also responsible under various state statutes for pneumoconiosis benefits. CONSOL Energy primarily provides for these claims through a self-insurance program. The calculation of the actuarial present value of the estimated pneumoconiosis obligation is based on an annual actuarial study by independent actuaries and uses assumptions regarding disability incidence, medical costs, indemnity levels, mortality, death benefits, dependents and interest rates which are derived from actual company experience and outside sources. Recent legislative changes have not been favorable for CWP. Although these changes have not had a significant impact on the liability, CONSOL has noticed an increase in claims. Actuarial gains or losses can result from differences in incident rates and severity of claims filed as compared to original assumptions. CONSOL Energy must also compensate individuals who sustain employment-related physical injuries or some types of occupational diseases and, on some occasions, for costs of their rehabilitation. Workers' compensation laws will also compensate survivors of workers who suffer employment-related deaths. Workers' compensation laws are administered by state agencies, and each state has its own set of rules and regulations regarding compensation that is owed to an employee that is injured in the course of employment. CONSOL Energy primarily provides for these claims through a self-insurance program. CONSOL Energy recognizes an actuarial present value of the estimated workers' compensation obligation calculated by independent actuaries. The calculation is based on claims filed and an estimate of claims incurred but not yet reported as well as various assumptions, including discount rate, future healthcare trend rate, benefit duration and recurrence of injuries. Actuarial gains or losses associated with workers' compensation have resulted from discount rate changes and differences in claims experience and incident rates as compared to prior assumptions. CWP Workers' Compensation at December 31, at December 31, 2016 2015 2016 2015 Change in benefit obligation: Benefit obligation at beginning of period $ 122,503 $ 126,098 $ 83,165 $ 89,741 State administrative fees and insurance bond premiums — — 3,265 3,581 Service cost 4,327 6,491 7,618 9,389 Interest cost 4,283 5,116 2,550 3,195 Actuarial loss (gain) 439 (5,089 ) 123 (4,089 ) Benefits paid (11,409 ) (10,113 ) (17,028 ) (18,999 ) Curtailment gain (1,307 ) — — — Settlements — — — 347 Benefit obligation at end of period $ 118,836 $ 122,503 $ 79,693 $ 83,165 Current assets $ — $ — $ 1,458 $ 1,450 Current liabilities (10,763 ) (9,471 ) (13,874 ) (14,803 ) Noncurrent liabilities (108,073 ) (113,032 ) (67,277 ) (69,812 ) Net obligation recognized $ (118,836 ) $ (122,503 ) $ (79,693 ) $ (83,165 ) Amounts recognized in accumulated other comprehensive income consist of: Net actuarial gain $ (62,714 ) $ (68,101 ) $ (12,914 ) $ (13,440 ) Net amount recognized (before tax effect) $ (62,714 ) $ (68,101 ) $ (12,914 ) $ (13,440 ) The components of the net periodic cost are as follows: CWP Workers’ Compensation For the Years Ended For the Years Ended December 31, December 31, 2016 2015 2014 2016 2015 2014 Service cost $ 4,327 $ 6,491 $ 5,674 $ 7,618 $ 9,389 $ 9,781 Interest cost 4,283 5,116 5,537 2,550 3,195 3,577 Recognized net actuarial gain (4,948 ) (5,576 ) (6,196 ) (403 ) (31 ) (382 ) State administrative fees and insurance bond premiums — — — 3,265 3,581 3,352 Curtailment gain (1,307 ) — — — — — Settlement gain — — — — — — Net periodic cost $ 2,355 $ 6,031 $ 5,015 $ 13,030 $ 16,134 $ 16,328 (Income) expense attributable to discontinued operations included in the CWP net periodic cost was $(1,290) , $297 and $87 for the years ended December 31, 2016 , 2015 and 2014 , respectively. On March 31, 2016, CONSOL Energy completed the sale of its membership interests in BMC (see Note 2 - Discontinued Operations). As a result of the sale, certain obligations of the CWP plan were transferred to the buyer. This transfer triggered a curtailment gain of $1,307 . The curtailment resulted in a plan remeasurement increasing plan liabilities by $7,713 at March 31, 2016. The following are amounts included in accumulated other comprehensive income that are expected to be recognized in 2017 net periodic benefit costs: Workers' CWP Compensation Benefits Benefits Actuarial gain recognition $ (7,631 ) $ (610 ) CONSOL Energy utilizes a corridor approach to amortize actuarial gains and losses that have been accumulated under the Workers’ Compensation and CWP plans. Cumulative gains and losses that are in excess of 10% of the greater of either the estimated liability or the market-related value of plan assets are amortized over the expected average remaining future service of the current active membership of the Workers’ Compensation and CWP plans. Assumptions: The weighted-average discount rates used to determine benefit obligations and net periodic cost (benefit) are as follows: CWP Workers' Compensation For the Years Ended For the Years Ended December 31, December 31, 2016 2015 2014 2016 2015 2014 Benefit obligations 4.40 % 4.60 % 4.21 % 4.05 % 4.26 % 3.84 % Net periodic cost 4.60 % 4.21 % 4.75 % 4.26 % 3.84 % 4.57 % Discount rates are determined using a Company-specific yield curve model (above-mean) developed with the assistance of an external actuary. The Company-specific yield curve models (above-mean) use a subset of the expanded bond universe to determine the Company-specific discount rate. Bonds used in the yield curve are rated AA by Moody's or Standard & Poor's as of the measurement date. The yield curve models parallel the plans' projected cash flows, and the underlying cash flows of the bonds included in the models exceed the cash flows needed to satisfy the Company's plans. Cash Flows: CONSOL Energy does not intend to make contributions to the CWP or Workers' Compensation plans in 2017, but it intends to pay benefit claims as they become due. The following benefit payments, which reflect expected future claims as appropriate, are expected to be paid: Workers' Compensation CWP Total Actuarial Other Benefits Benefits Benefits Benefits 2017 $ 10,763 $ 15,897 $ 12,416 $ 3,481 2018 $ 8,417 $ 15,193 $ 11,625 $ 3,568 2019 $ 7,606 $ 15,061 $ 11,404 $ 3,657 2020 $ 7,137 $ 15,044 $ 11,295 $ 3,749 2021 $ 6,963 $ 15,056 $ 11,214 $ 3,842 Year 2022-2026 $ 35,714 $ 76,577 $ 55,876 $ 20,701 |
Other Employee Benefits
Other Employee Benefits | 12 Months Ended |
Dec. 31, 2016 | |
OTHER EMPLOYEE BENEFIT PLANS: [Abstract] | |
Compensation and Employee Benefit Plans [Text Block] | NOTE 16—OTHER EMPLOYEE BENEFIT PLANS: UMWA Benefit Trusts: The Coal Act created two multi-employer benefit plans: (1) the United Mine Workers of America Combined Benefit Fund (the Combined Fund) into which the former UMWA Benefit Trusts were merged, and (2) the United Mine Workers of America 1992 Benefit Plan (1992 Benefit Plan). CONSOL Energy accounts for required contributions to these multi-employer trusts as expense when incurred. The Combined Fund provides medical and death benefits for all beneficiaries of the former UMWA Benefit Trusts who were actually receiving benefits as of July 20, 1992. The 1992 Benefit Plan provides medical and death benefits to orphan UMWA-represented members eligible for retirement on February 1, 1993, and for those who retired between July 20, 1992 and September 30, 1994. The Coal Act provides for the assignment of beneficiaries to former employers and the allocation of unassigned beneficiaries (referred to as orphans) to companies using a formula set forth in the Coal Act. The Coal Act requires that responsibility for funding the benefits to be paid to beneficiaries be assigned to their former signatory employers or related companies. This cost is recognized when contributions are assessed. CONSOL Energy's total contributions under the Coal Act were $8,455 , $9,239 and $10,121 for the years ended December 31, 2016 , 2015 and 2014 , respectively. Based on available information at December 31, 2016 , CONSOL Energy's obligation for the Combined Fund and 1992 Benefit Plans is estimated to be approximately $93,795 . Pursuant to the provisions of the Tax Relief and Healthcare Act of 2006 (the 2006 Act) and the 1992 Benefit Plan, CONSOL Energy is required to provide security in an amount based on the annual cost of providing health care benefits for all individuals receiving benefits from the 1992 Benefit Plan who are attributable to CONSOL Energy, plus all individuals receiving benefits from an individual employer plan maintained by CONSOL Energy who are entitled to receive such benefits. In accordance with the terms of the 2006 Act and the 1992 Benefit Plan, CONSOL Energy must secure its obligations by posting letters of credit, which were $19,170 , $21,473 and $21,394 at December 31, 2016 , 2015 and 2014 , respectively. The 2016 , 2015 and 2014 security amounts were based on the annual cost of providing health care benefits and included a reduction in the number of eligible employees. Investment Plan: CONSOL Energy has an investment plan available to most non-represented employees. Throughout the year ended December 31, 2016, the Company's matching contribution was 6% of eligible compensation contributed by eligible employees. In conjunction with the qualified pension plan changes in 2015, the Company contributed an additional 3% of eligible compensation into the 401(k) plan accounts for employees hired or rehired on or after October 1, 2014 or who were under age 40 or had less than 10 years of service with the Company as of September 30, 2014. This additional contribution was eliminated on January 1, 2016. The Company may also make discretionary contributions to the Plan ranging from 1% to 6% (1% to 4% prior to January 1, 2016) of eligible compensation for eligible employees (as defined by the Plan). Discretionary contributions made by the Company were $12,260 for the year ended December 31, 2016 . There were no such discretionary contributions made by the Company for the years ended December 31, 2015 and 2014 . Total payments and costs were $20,784 , $20,058 and $18,341 for the years ended December 31, 2016 , 2015 and 2014 , respectively. Long-Term Disability: CONSOL Energy has a Long-Term Disability Plan available to all eligible full-time salaried employees. The benefits for this plan are based on a percentage of monthly earnings, offset by all other income benefits available to the disabled. For the Years Ended December 31, 2016 2015 2014 Benefit cost $ 2,128 $ 2,619 $ 2,213 Discount rate assumption used to determine net periodic benefit costs 3.71 % 3.18 % 3.53 % Liabilities incurred under the Long-Term Disability Plan are included in Other Accrued Liabilities and Deferred Credits and Other Liabilities–Other in the Consolidated Balance Sheets and amounted to a combined total of $19,144 and $19,789 at December 31, 2016 and 2015 , respectively. |
Stock Based Compensation
Stock Based Compensation | 12 Months Ended |
Dec. 31, 2016 | |
Share-based Compensation [Abstract] | |
Disclosure of Compensation Related Costs, Share-based Payments [Text Block] | STOCK-BASED COMPENSATION: CONSOL Energy adopted the CONSOL Energy Inc. Equity Incentive Plan (the Equity Incentive Plan) on April 7, 1999. The Equity Incentive Plan provides for grants of stock-based awards to key employees and to non-employee directors. Amendments to the Equity Incentive Plan have been adopted and approved by the Board of Directors and the Company's Shareholders since the commencement of the plan. Most recently, in May 2016, the Board of Directors and the Company's Shareholders adopted and approved a 10,550,000 increase to the total number of shares available for issuance, which brought the total number of shares of common stock that can be covered by grants to 42,350,000 . At December 31, 2016 , 8,733,169 shares of common stock remain available for all awards. The Equity Incentive Plan provides that the aggregate number of shares available for issuance will be reduced by one share for each share issued in settlement of stock options and by 1.62 for each share issued in settlement of Performance Share Units (PSUs) or Restricted Stock Units (RSUs). No award of stock options may be exercised under the Equity Incentive Plan after the tenth anniversary of the effective date of the award. For only those shares expected to vest, CONSOL Energy recognizes stock-based compensation costs on a straight-line basis over the requisite service period of the award, which is generally the vesting term. Awards granted in 2014 vest immediately if granted to retiree-eligible employees who are aged 62 and older. Awards granted in 2014 vest at the end of one year when granted to employees aged 55 to 62 and who have also completed ten years of service. Awards granted in 2014 vest over a three-year term at 33% per year for all other employees. Awards granted in 2015 vest over a three-year term at 33% per year. Options and RSUs granted in 2016 vest over a three-year term at 33% per year. Performance share units granted in 2016 vest over a five-year term at 20% per year subject to performance conditions. If an employee leaves the Company, all unvested shares are forfeited. The vesting of all awards will accelerate in the event of death and disability and may accelerate upon a change in control of CONSOL Energy. See each specific award section for special vesting terms related to non-employee directors and other specific awards. The total stock-based compensation expense recognized during the years ended December 31, 2016 , 2015 and 2014 was $ 31,483 , $ 24,513 and $ 41,877 , respectively. The related deferred tax benefit totaled $ 11,255 , $ 9,229 and $ 15,243 , for the years ended December 31, 2016 , 2015 and 2014 , respectively. As of December 31, 2016 , CONSOL Energy has $ 40,234 of unrecognized compensation cost related to all nonvested stock-based compensation awards, which is expected to be recognized over a weighted-average period of 2.73 years. When stock options are exercised and restricted and performance stock unit awards become vested, the issuances are made from CONSOL Energy's common stock shares. Stock Options: CONSOL Energy examined its historical pattern of option exercises in an effort to determine if there were any discernable activity patterns based on certain employee populations. From this analysis, CONSOL Energy identified two distinct employee populations and used the Black-Scholes option pricing model to value the options for each of the employee populations. The expected term computation presented in the table below is based upon a weighted average of the historical exercise patterns and post-vesting termination behavior of the two populations. The risk-free interest rate was determined for each vesting tranche of an award based upon the calculated yield on U.S. Treasury obligations for the expected term of the award. The expected forfeiture rate is based upon historical forfeiture activity. A combination of historical and implied volatility is used to determine expected volatility and future stock price trends. The total fair value of options granted during the year ended December 31, 2016 was $19,305 , based on the following assumptions and weighted average fair values: December 31, 2016 Weighted average fair value of grants $ 5.73 Risk-free interest rate 1.13 % Expected dividend yield 0.27 % Expected forfeiture rate 2.00 % Expected volatility 61.09 % Expected term in years 4.90 CONSOL Energy did not grant stock option awards during the years ended December 31, 2015 or 2014 . A summary of the status of stock options granted is presented below: Weighted Average Weighted Remaining Aggregate Average Contractual Intrinsic Exercise Term (in Value (in Shares Price years) thousands) Balance at December 31, 2015 3,621,002 $43.15 Granted 3,369,197 $4.22 Exercised — — Forfeited (781,386 ) $36.32 Balance at December 31, 2016 6,208,813 $22.88 6.02 $ — Vested 2,990,263 $43.12 2.57 $ — Exercisable at December 31, 2016 2,990,263 $43.12 2.57 $ — At December 31, 2016 , there are 5,888,075 employee stock options outstanding under the Equity Incentive Plan. Non-employee director stock options vest one year after the grant date. There are 320,738 fully vested stock options outstanding under these grants. The aggregate intrinsic value in the table above represents the total pretax intrinsic value (the difference between CONSOL Energy's closing stock price on the last trading day of the year ended December 31, 2016 and the option's exercise price, multiplied by the number of in-the-money options) that would have been received by the option holders had all option holders exercised their options on December 31, 2016 . This amount varies based on the fair market value of CONSOL Energy's stock. No options were exercised during the year ended December 31, 2016 . The total intrinsic value of options exercised for the years ended December 31, 2015 and 2014 was $ 2,744 and $ 14,545 , respectively. Cash received from option exercises for the years ended December 31, 2015 and 2014 was $ 8,281 and $ 15,011 , respectively. The tax impact from option exercises totaled $ 208 and $ 2,629 for the years ended December 31, 2015 and 2014 , respectively. This excess tax benefit is included in cash flows from financing activities in the Consolidated Statements of Cash Flows. Restricted Stock Units: Under the Equity Incentive Plan, CONSOL Energy grants certain employees and non-employee directors restricted stock unit awards, which entitle the holder to shares of common stock as the award vests. Non-employee director restricted stock units vest at the end of one year. In 2014, restricted stock units were granted that will vest over a five year period unless certain market conditions are met, in which the award will accelerate. Compensation expense is recognized over the vesting period of the units, described above. The total fair value of restricted stock units granted during the years ended December 31, 2016 , 2015 and 2014 was $ 493 , $ 26,550 and $ 31,360 , respectively. The total fair value of restricted stock units vested during the years ended December 31, 2016 , 2015 and 2014 was $ 19,095 , $ 20,793 and $ 15,686 , respectively. The following table represents the nonvested restricted stock units and their corresponding fair value (based upon the closing share price) at the date of grant: Number of Weighted Average Shares Grant Date Fair Value Nonvested at December 31, 2015 1,303,573 $32.60 Granted 27,379 $17.99 Vested (579,246 ) $32.97 Forfeited (88,703 ) $30.42 Nonvested at December 31, 2016 663,003 $31.97 Performance Share Units: Under the Equity Incentive Plan, CONSOL Energy grants certain employees performance share unit awards, which entitle the holder to shares of common stock subject to the achievement of certain market and performance goals. Compensation expense is recognized over the performance measurement period of the units in accordance with the provisions of the Stock Compensation Topic of the FASB Accounting Standards Codification for awards with market and performance vesting conditions. For the PSUs issued in 2014 and 2015, achievement of the market goals is not probable, but achievement of the performance goals is probable. Achievement of the market goals is probable for the first tranche of the PSUs issued in 2016. The total fair value of performance share units granted during the years ended December 31, 2016 , 2015 and 2014 was $ 24,283 , $ 18,771 and $ 11,853 , respectively. No performance share units vested during the year ended December 31, 2016 . The total fair value of performance share units vested during the years ended December 31, 2015 and 2014 was $ 20,083 and $ 18,759 , respectively. The following table represents the nonvested performance share units and their corresponding fair value (based upon the closing share price) on the date of grant: Number of Weighted Average Shares Grant Date Fair Value Nonvested at December 31, 2015 491,493 $27.83 Granted 950,404 $25.55 Vested — — Forfeited (17,346 ) $19.62 Nonvested at December 31, 2016 1,424,551 $26.41 Performance Options: Under the Equity Incentive Plan in 2010, CONSOL Energy granted certain employees performance options, which entitled the holder to shares of common stock subject to the achievement of certain performance goals. Compensation expense was recognized over the vesting period of the options, described above. The Black-Scholes option valuation model was used to value each tranche separately. No performance options were granted in 2016, 2015, or 2014. No performance options vested in 2016 or 2015. The total fair value of performance options vested during the year ended December 31, 2014 was $4,949 . A summary of the status of performance options granted is presented below: Weighted Average Weighted Remaining Aggregate Average Contractual Intrinsic Exercise Term (in Value (in Shares Price years) thousands) Balance at December 31, 2015 802,804 $45.05 Granted — — Exercised — — Forfeited — — Balance at December 31, 2016 802,804 $45.05 3.42 $ — Vested 802,804 $45.05 3.42 $ — Exercisable at December 31, 2016 802,804 $45.05 3.42 $ — CONSOL Stock Units: Under the Equity Incentive Plan in 2013, CONSOL Energy granted certain employees CONSOL Stock Unit Awards, which entitled the holder to shares of common stock subject to the achievement of certain market and performance goals. Compensation expense was recognized over the performance measurement period of the units in accordance with the provisions of the Stock Compensation Topic of the FASB Accounting Standards Codification for awards with market and performance vesting conditions. CONSOL Energy used the Monte Carlo methodology to estimate the fair value of the CONSOL Stock Units. The achievement of the market and performance goals was not attained and therefore, all shares were forfeited in 2016. No CONSOL Stock Units were granted in 2016. The total fair value of CONSOL Stock Units granted during the years ended December 31, 2015 and 2014 was $ 110 and $189 respectively. The following table represents the nonvested CONSOL Stock Unit awards and their corresponding fair value at the grant date: Number of Weighted Average Shares Grant Date Fair Value Nonvested at December 31, 2015 803,998 $33.68 Granted — — Forfeited (803,998 ) $33.68 Nonvested at December 31, 2016 — — |
Supplemental Cash Flow
Supplemental Cash Flow | 12 Months Ended |
Dec. 31, 2016 | |
Supplemental Cash Flow Information [Abstract] | |
Cash Flow, Supplemental Disclosures [Text Block] | NOTE 18—SUPPLEMENTAL CASH FLOW INFORMATION: The following are non-cash transactions that impact the investing and financing activities of CONSOL Energy. For non-cash transactions that relate to acquisitions and dispositions, see Note 2 - Discontinued Operations and Note - 3 Acquisitions and Dispositions. CONSOL Energy obtains capital lease arrangements for company-used vehicles. For the years ended December 31, 2016 , 2015 and 2014 , CONSOL Energy entered into non-cash capital lease arrangements of $ 55 , $ 4,973 and $ 1,540 , respectively. As of December 31, 2016 , 2015 and 2014 , CONSOL Energy purchased goods and services related to capital projects in the amount of $ 6,706 , $ 24,347 and $68,800 , respectively, which are included in accounts payable. The following table shows cash paid (received) during the year for: For the Years Ended December 31, 2016 2015 2014 Interest (net of amounts capitalized) $ 186,924 $ 207,094 $ 233,631 Income taxes $ (18,032 ) $ (59,584 ) $ (81,962 ) |
Concentrations of Credit Risk
Concentrations of Credit Risk | 12 Months Ended |
Dec. 31, 2016 | |
CONCENTRATION OF CREDIT RISK AND MAJOR CUSTOMERS: [Abstract] | |
Concentration Risk Disclosure [Text Block] | NOTE 19—CONCENTRATION OF CREDIT RISK AND MAJOR CUSTOMERS: CONSOL Energy markets natural gas primarily to gas wholesalers and thermal coal principally to electric utilities in the United States. Concentration of credit risk is summarized below: December 31, 2016 2015 Gas wholesalers $ 124,509 $ 72,664 Thermal coal utilities 62,525 58,281 Coal brokers and distributors 28,955 14,435 Other 4,233 6,003 Total Accounts Receivable Trade $ 220,222 $ 151,383 No sales to any E&P or coal customer exceeded 10% of the Company's revenues during the year ended December 31, 2016 . During the year ended December 31, 2015 , coal sales to Duke Energy were $242,020 , which comprised over 10% of the Company's revenues. During the year ended December 31, 2014 , E&P sales to NJR Energy Services Company were $295,779 , which comprised over 10% of the Company's revenues. |
Fair Value of Financial Instrum
Fair Value of Financial Instruments | 12 Months Ended |
Dec. 31, 2016 | |
Fair Value Disclosures [Abstract] | |
Fair Value of Financial Instruments | FAIR VALUE OF FINANCIAL INSTRUMENTS: CONSOL Energy determines the fair value of assets and liabilities based on the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants. The fair values are based on assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and the risks inherent in valuation techniques and the inputs to valuations. The fair value hierarchy is based on whether the inputs to valuation techniques are observable or unobservable. Observable inputs reflect market data obtained from independent sources (including NYMEX forward curves, LIBOR-based discount rates and basis forward curves), while unobservable inputs reflect the Company's own assumptions of what market participants would use. The fair value hierarchy includes three levels of inputs that may be used to measure fair value as described below: Level One - Quoted prices for identical instruments in active markets. Level Two - The fair value of the assets and liabilities included in Level 2 are based on standard industry income approach models that use significant observable inputs, including NYMEX forward curves, LIBOR-based discount rates and basis forward curves. Level Three - Unobservable inputs significant to the fair value measurement supported by little or no market activity. The significant unobservable inputs used in the fair value measurement of the Company's third party guarantees are the credit risk of the third party and the third party surety bond markets. A significant increase or decrease in these values, in isolation, would have a directionally similar effect resulting in higher or lower fair value measurement of the Company's Level 3 guarantees. In those cases when the inputs used to measure fair value meet the definition of more than one level of the fair value hierarchy, the lowest level input that is significant to the fair value measurement in its totality determines the applicable level in the fair value hierarchy. The financial instruments measured at fair value on a recurring basis are summarized below: Fair Value Measurements at Fair Value Measurements at Description Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Gas Derivatives $ — $ (188,156 ) $ — $ — $ 266,558 $ — Murray Energy Guarantees $ — $ — $ (1,362 ) $ — $ — $ (1,228 ) |
Derivatives
Derivatives | 12 Months Ended |
Dec. 31, 2016 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Derivative Instruments and Hedging Activities Disclosure [Text Block] | DERIVATIVE INSTRUMENTS: CONSOL Energy enters into financial derivative instruments to manage its exposure to commodity price volatility. CONSOL Energy de-designated all of its cash flow hedges on December 31, 2014 and accounts for all existing and future gas and NGL commodity hedges on a mark-to-market basis with changes in fair value recorded in current period earnings. In connection with this de-designation, CONSOL Energy froze the balances recorded in Accumulated Other Comprehensive Income at December 31, 2014 and reclassified balances to earnings as the underlying physical transactions occurred. As of December 31, 2016, all gains deferred in OCI have been recognized in earnings. CONSOL Energy is exposed to credit risk in the event of non-performance by counterparties. The creditworthiness of counterparties is subject to continuing review. The Company has not experienced any issues of non-performance by derivative counterparties. None of the Company's counterparty master agreements currently require CONSOL Energy to post collateral for any of its positions. However, as stated in the counterparty master agreements, if CONSOL Energy's obligations with one of its counterparties cease to be secured on the same basis as similar obligations with the other lenders under the credit facility, CONSOL Energy would have to post collateral for instruments in a liability position in excess of defined thresholds. All of the Company's derivative instruments are subject to master netting arrangements with our counterparties. CONSOL Energy recognizes all financial derivative instruments as either assets or liabilities at fair value on the Consolidated Balance Sheets on a gross basis. Each of CONSOL Energy's counterparty master agreements allows, in the event of default, the ability to elect early termination of outstanding contracts. If early termination is elected, CONSOL Energy and the applicable counterparty would net settle all open hedge positions. The total notional amounts of production of CONSOL Energy's derivative instruments at December 31, 2016 and December 31, 2015 were as follows: December 31, Forecasted to 2016 2015 Settle Through Natural Gas Commodity Swaps (Bcf) 744.7 456.1 2021 Natural Gas Basis Swaps (Bcf) 482.0 124.4 2020 Propane Commodity Swaps (Mbbls) 126.0 — 2017 The gross fair value of CONSOL Energy's derivative instruments at December 31, 2016 and December 31, 2015 were as follows: Asset Derivative Instruments Liability Derivative Instruments December 31, December 31, 2016 2015 2016 2015 Commodity Swaps: Prepaid Expense $ 16 $ 234,409 Other Accrued Liabilities $ 209,980 $ — Other Assets 29,596 44,539 Other Liabilities 67,139 5,137 Total Asset $ 29,612 $ 278,948 Total Liability $ 277,119 $ 5,137 Basis Only Swaps: Prepaid Expense $ 56,916 $ 5,429 Other Accrued Liabilities $ 21,593 $ 12,206 Other Assets 35,603 1,093 Other Liabilities 11,575 1,569 Total Asset $ 92,519 $ 6,522 Total Liability $ 33,168 $ 13,775 The effect of derivative instruments on CONSOL Energy's Consolidated Statements of Income was as follows: Year Ended December 31, 2016 2015 2014 Cash Received (Paid) in Settlement of Commodity Derivative Instruments: Commodity Swaps: Natural Gas $ 225,797 $ 193,976 $ 19,025 Propane (650 ) — — Natural Gas Basis Swaps 20,065 2,372 — Total Cash Received in Settlement of Commodity Derivative Instruments 245,212 196,348 19,025 Unrealized (Loss) Gain on Commodity Derivative Instruments: Commodity Swaps: Natural Gas (520,170 ) 81,142 — Propane (1,148 ) — — Natural Gas Basis Swaps 66,604 (7,653 ) — Reclassified from Accumulated OCI 68,481 123,105 — Gain Recognized for Ineffectiveness* — — 4,168 Total Unrealized (Loss) Gain on Commodity Derivative Instruments (386,233 ) 196,594 4,168 (Loss) Gain on Commodity Derivative Instruments: Commodity Swaps: Natural Gas $ (294,373 ) $ 275,118 $ 19,025 Propane (1,798 ) — — Natural Gas Basis Swaps 86,669 (5,281 ) — Reclassified from Accumulated OCI 68,481 123,105 — Gain Recognized for Ineffectiveness* — — 4,168 Total (Loss) Gain on Commodity Derivative Instruments $ (141,021 ) $ 392,942 $ 23,193 * No amounts were excluded from effectiveness testing of cash flow hedges. Changes in Accumulated OCI, net of tax, attributable to cash flow hedges that were de-designated December 31, 2014 were as follows: Year Ended December 31, 2016 2015 2014 Beginning Balance – Accumulated OCI $ 43,470 $ 121,521 $ 42,493 Gain Recognized in Accumulated OCI — — 97,316 Gain Reclassified from Accumulated OCI (Net of tax: $25,011, $45,054, $10,465) (43,470 ) (78,051 ) (18,288 ) Ending Balance – Accumulated OCI $ — $ 43,470 $ 121,521 |
Commitments and Contingencies
Commitments and Contingencies | 12 Months Ended |
Dec. 31, 2016 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies | NOTE 22—COMMITMENTS AND CONTINGENT LIABILITIES: CONSOL Energy and its subsidiaries are subject to various lawsuits and claims with respect to such matters as personal injury, wrongful death, damage to property, exposure to hazardous substances, governmental regulations including environmental remediation, employment and contract disputes and other claims and actions arising out of the normal course of business. CONSOL Energy accrues the estimated loss for these lawsuits and claims when the loss is probable and can be estimated. The Company's current estimated accruals related to these pending claims, individually and in the aggregate, are immaterial to the financial position, results of operations or cash flows of CONSOL Energy. It is possible that the aggregate loss in the future with respect to these lawsuits and claims could ultimately be material to the financial position, results of operations or cash flows of CONSOL Energy; however, such amounts cannot be reasonably estimated. The amount claimed against CONSOL Energy is disclosed below when an amount is expressly stated in the lawsuit or claim, which is not often the case. The maximum aggregate amount claimed in those lawsuits and claims, regardless of probability, where a claim is expressly stated or can be estimated, exceeds the aggregate amounts accrued for all lawsuits and claims by approximately $937,421 . The following lawsuits and claims include those for which a loss is probable and an accrual has been recognized. Hale Litigation: This class action lawsuit was filed on September 23, 2010 in the U.S. District Court in Abingdon, Virginia. The putative class consists of force-pooled unleased gas owners whose ownership of the coalbed methane (CBM) gas was declared to be in conflict with rights of others. The lawsuit seeks a judicial declaration of ownership of the CBM and damages based on allegations CNX Gas Company failed to either pay royalties due to conflicting claimants or deemed lessors or paid them less than required because of the alleged practice of improper below market sales and/or taking alleged improper post-production deductions. On September 30, 2013, the District Judge entered an Order certifying the class, and CNX Gas Company appealed the Order to the U.S. Fourth Circuit Court of Appeals. On August 19, 2014, the Fourth Circuit agreed with CNX Gas Company, reversed the Order certifying the class and remanded the case to the trial court for further proceedings consistent with the decision. On April 23, 2015, Plaintiffs filed a Renewed Motion for Class Certification, and on June 23, 2015, CNX Gas Company filed its Opposition to same. The Court held a hearing on the Motion on September 18, 2015 and has not yet ruled. CONSOL Energy continues to believe this action cannot properly proceed as a class action in any form, believes the case has meritorious defenses, and intends to defend it vigorously. The Company has established an accrual to cover its estimated liability for this case. This accrual is immaterial to the overall financial position of CONSOL Energy and is included in Other Accrued Liabilities on the Consolidated Balance Sheets. Addison Litigation: This class action lawsuit was filed on April 28, 2010 in the U.S. District Court in Abingdon, Virginia. The putative class consists of gas lessors whose gas ownership is in conflict. The lawsuit seeks a judicial declaration of ownership of the CBM and damages based on the allegations that CNX Gas Company failed to either pay royalties due to these conflicting claimant lessors or paid them less than required because of the alleged practice of improper below market sales and/or taking alleged improper post-production deductions. On September 30, 2013, the District Judge entered an Order certifying the class, and CNX Gas Company appealed the Order to the U.S. Fourth Circuit Court of Appeals. On August 19, 2014, the Fourth Circuit agreed with CNX Gas Company, reversed the Order certifying the class and remanded the case to the trial court for further proceedings consistent with the decision. On April 23, 2015, Plaintiffs filed a Renewed Motion for Class Certification, and on June 23, 2015, CNX Gas Company filed its Opposition to same. The Court held a hearing on the Motion on September 18, 2015 and has not yet ruled. CONSOL Energy continues to believe this action cannot properly proceed as a class action in any form, believes the case has meritorious defenses, and intends to defend it vigorously. The Company has established an accrual to cover its estimated liability for this case. This accrual is immaterial to the overall financial position of CONSOL Energy and is included in Other Accrued Liabilities on the Consolidated Balance Sheets. The following royalty, land rights and other lawsuits and claims include those for which a loss is reasonably possible, but not probable, and accordingly, an accrual may not have been recognized. These claims are influenced by many factors which prevent the estimation of a range of potential loss. These factors include, but are not limited to, generalized allegations of unspecified damages (such as improper deductions), discovery having not commenced or not having been completed, unavailability of expert reports on damages and non-monetary issues being tried. For example, in instances where a gas lease termination is sought, damages would depend on speculation as to if and when the gas production would otherwise have occurred, how many wells would have been drilled on the lease premises, what their production would be, what the cost of production would be, and what the price of gas would be during the production period. An estimate is calculated, if applicable, when sufficient information becomes available. Fitzwater Litigation: Two nonunion retired coal miners have sued CONSOL Energy Inc., Fola Coal Company and Consolidation Coal Company in West Virginia Federal Court alleging ERISA violations in the termination of retiree health care benefits. The Plaintiffs contend they relied to their detriment on oral statements and promises of "lifetime health benefits" allegedly made by various members of management during Plaintiffs' employment and that they were allegedly denied access to Summary Plan Documents that clearly reserved to the Company the right to modify or terminate the CONSOL Energy Inc. Retiree Health and Welfare Plan. Plaintiffs request that retiree health benefits be reinstated and seek to represent a class of all nonunion retirees of CONSOL Energy and its subsidiaries. The Company believes it has meritorious defense and intends to vigorously defend this suit. Virginia Mine Void Litigation: The Company is currently defending three lawsuits naming Consolidation Coal Company (CCC), Island Creek Coal Company (ICCC), CNX Gas Company, and/or CONSOL Energy. The lawsuits were filed in the U.S. District Court for the Western District of Virginia. On October 26, 2015, the trial court granted summary judgment in favor of the defendants in two of the actions upon its finding that plaintiffs' claims are barred by the applicable statutes of limitation. Plaintiffs have appealed both cases to the U.S. Court of Appeals for the Fourth Circuit. Oral argument was held on December 8, 2016. The third case remains pending in the trial court. On January 26, 2016, six mine void lawsuits that have twice before been filed and voluntarily dismissed, were refiled for a third time in state court but have not been served. The Complaints seek damages and injunctive relief in connection with the transfer of water from mining activities at Buchanan Mine into void spaces in inactive ICCC mines adjacent to the Buchanan operations, voids ostensibly underlying plaintiffs’ properties. While some of the plaintiffs have an ownership interest in the coal, others have some interest in one or more of the fee, surface, oil/gas or other mineral estates. The suits allege the water storage precludes access to and has damaged coal, impeded coalbed methane gas production and was made without compensation to the property owners. Plaintiffs seek recovery in tort, contract and trespass assumpsit (quasi-contract). The suits each seek damages between $50,000 and in excess of $100,000 plus punitive damages. The Company intends to vigorously defend these suits. At December 31, 2016 , CONSOL Energy has provided the following financial guarantees, unconditional purchase obligations and letters of credit to certain third parties, as described by major category in the following table. These amounts represent the maximum potential of total future payments that the Company could be required to make under these instruments. These amounts have not been reduced for potential recoveries under recourse or collateralization provisions. Generally, recoveries under reclamation bonds would be limited to the extent of the work performed at the time of the default. No amounts related to these financial guarantees and letters of credit are recorded as liabilities in the financial statements. CONSOL Energy management believes that these guarantees will expire without being funded, and therefore the commitments will not have a material adverse effect on financial condition. Amount of Commitment Expiration Per Period Total Amounts Committed Less Than 1 Year 1-3 Years 3-5 Years Beyond 5 Years Letters of Credit: Employee-Related $ 82,273 $ 67,871 $ 14,402 $ — $ — Environmental 998 600 398 — — Other 242,405 228,313 14,092 — — Total Letters of Credit 325,676 296,784 28,892 — — Surety Bonds: Employee-Related 112,810 111,510 1,300 — — Environmental 514,851 483,604 31,247 — — Other 22,417 21,591 824 2 — Total Surety Bonds 650,078 616,705 33,371 2 — Guarantees: Other 74,203 41,285 17,767 13,401 1,750 Total Guarantees 74,203 41,285 17,767 13,401 1,750 Total Commitments $ 1,049,957 $ 954,774 $ 80,030 $ 13,403 $ 1,750 Included in the above table are commitments and guarantees entered into in conjunction with the sale of Consolidation Coal Company and certain of its subsidiaries, which contain all five of its longwall coal mines in West Virginia, and its river operations to a subsidiary of Murray Energy Corporation (Murray Energy). As part of the sales agreement, CONSOL Energy has guaranteed certain equipment lease obligations and coal sales agreements that were assumed by Murray Energy. In the event that Murray Energy would default on the obligations defined in the agreements, CONSOL Energy would be required to perform under the guarantees. If CONSOL Energy would be required to perform, the stock purchase agreement provides various recourse actions. At December 31, 2016 and December 31, 2015 , the fair value of these guarantees was $1,362 and $1,228 , respectively, and are included in Other Accrued Liabilities on the Consolidated Balance Sheets. The fair value of certain of the guarantees was determined using CONSOL Energy’s risk-adjusted interest rate. Significant increases or decreases in the risk-adjusted interest rates may result in a significantly higher or lower fair value measurement. Coal sales agreement guarantees were valued based on an evaluation of coal market pricing compared to contracted sales price and includes an adjustment for nonperformance risk. No other amounts related to financial guarantees and letters of credit are recorded as liabilities in the financial statements. Significant judgment is required in determining the fair value of these guarantees. The guarantees of the leases and sales agreements are classified within Level 3 of the fair value hierarchy. As part of the sale of Buchanan Mine (See Note 2 - Discontinued Operations), CONSOL Energy has guaranteed certain equipment lease obligations that were assumed by Coronado. In the event that Coronado would default on the obligations defined in the agreements, CONSOL Energy would be required to perform under the guarantees. CONSOL Energy regularly evaluates the likelihood of default for all guarantees based on an expected loss analysis and records the fair value, if any, of its guarantees as an obligation in the consolidated financial statements. CONSOL Energy and CNX Gas Company enter into long-term unconditional purchase obligations to procure major equipment purchases, natural gas firm transportation, gas drilling services and other operating goods and services. These purchase obligations are not recorded on the Consolidated Balance Sheets. As of December 31, 2016 , the purchase obligations for each of the next five years and beyond were as follows: Obligations Due Amount Less than 1 year $ 209,797 1 - 3 years 285,224 3 - 5 years 243,534 More than 5 years 622,509 Total Purchase Obligations $ 1,361,064 |
Segment Information
Segment Information | 12 Months Ended |
Dec. 31, 2016 | |
Segment Reporting [Abstract] | |
Segment Reporting Disclosure [Text Block] | SEGMENT INFORMATION: CONSOL Energy consists of two principal business divisions: Exploration and Production (E&P) and Pennsylvania (PA) Mining Operations. The principal activity of the E&P division, which includes four reportable segments, is to produce pipeline quality natural gas for sale primarily to gas wholesalers. The E&P division's reportable segments are Marcellus Shale, Utica Shale, Coalbed Methane, and Other Gas. The Other Gas segment is primarily related to shallow oil and gas production and the Chattanooga Shale in Tennessee, neither of which are significant to the Company. It also includes the Company's purchased gas activities, unrealized gain or loss on commodity derivative instruments, exploration and production related other costs, other corporate expenses, selling, general and administrative activities, as well as various other activities assigned to the E&P division but not allocated to each individual segment. The principal activities of the PA Mining Operations division are mining, preparation and marketing of thermal coal, sold primarily to power generators. It also includes selling, general and administrative activities, as well as various other activities assigned to the PA Mining Operations division. CONSOL Energy’s Other division includes expenses from various corporate and diversified business activities that are not allocated to the E&P or PA Mining Operations divisions. The diversified business activities include coal terminal operations, closed and idle mine activities, water operations, selling, general and administrative activities, as well as various other non-operated activities, none of which are individually significant to the Company. In previous periods, this division included activity from the sales of industrial supplies (this subsidiary was sold in December 2014). Prior to the sale of the Buchanan Mine on March 31, 2016 and the Fola and Miller Creek Complexes on August 1, 2016 (see Note 2 - Discontinued Operations), CONSOL Energy had a Coal division. The Coal division had three reportable segments; PA Operations, Virginia (VA) Operations and Other Coal. The VA Operations segment included the Buchanan Mine and the Other Coal segment was primarily comprised of the assets and operations of the Fola and Miller Creek Complexes, as well as coal terminal operations, closed and idle mine activities, selling, general and administrative activities and various other non-operated activities. PA Operations now constitutes its own division and reportable segment and the remaining activity in the Other Coal segment became part of CONSOL Energy's diversified business activities in the Other division. Prior periods have been reclassified to align with current period presentation. In the preparation of the following information, intersegment sales have been recorded at amounts approximating market. Operating profit for each segment is based on sales less identifiable operating and non-operating expenses. Assets are reflected at the division level for E&P and are not allocated between each individual E&P segment. These assets are not allocated to each individual segment due to the diverse asset base controlled by CONSOL Energy, whereby each individual asset may service more than one segment within the division. An allocation of such asset base would not be meaningful or representative on a segment by segment basis. |
Reconciliation Of Assets And Liabilities From Segment To Consolidated [Text Block] | Reconciliation of Segment Information to Consolidated Amounts: Revenue and Other Income: For the Years Ended December 31, 2016 2015 2014 Total Segment Sales and Freight from External Customers $ 1,980,592 $ 2,081,873 $ 2,930,172 (Loss) Gain on Commodity Derivative Instruments (141,021 ) 392,942 23,193 Other Income not Allocated to Segments (Note 4) 167,306 144,351 207,460 Gain on Sale of Assets 19,498 74,173 43,198 Total Consolidated Revenue and Other Income $ 2,026,375 $ 2,693,339 $ 3,204,023 (Loss) Earnings From Continuing Operations Before Income Tax: For the Years Ended December 31, 2016 2015 2014 Segment (Loss) Income Before Income Taxes for reportable business segments $ (248,132 ) $ (273,863 ) $ 620,682 Segment (Loss) Income Before Income Taxes for all other business segments (85,923 ) 66,713 (119,473 ) Interest expense (191,476 ) (199,266 ) (223,333 ) Eliminations (424 ) (1,538 ) (2,458 ) Loss on debt extinguishment — (67,751 ) (95,267 ) (Loss) Earnings From Continuing Operations Before Income Tax $ (525,955 ) $ (475,705 ) $ 180,151 Total Assets: December 31, 2016 2015 Segment assets for total reportable business segments $ 8,217,774 $ 8,968,585 Segment assets for all other business segments 797,830 859,675 Items excluded from segment assets: Cash and other investments 47,153 65,935 Recoverable income taxes 116,851 13,887 Deferred tax assets 4,290 — Discontinued Operations 83 1,021,820 Total Consolidated Assets $ 9,183,981 $ 10,929,902 Enterprise-Wide Disclosures: CONSOL Energy's Revenues by geographical location (I): For the Years Ended December 31, 2016 2015 2014 United States $ 1,799,336 $ 1,822,452 $ 2,713,833 Asia 109,312 106,954 66,912 Europe 40,704 112,844 121,909 South America 25,406 28,060 19,013 Canada 5,834 11,563 8,505 Total Revenues and Freight from External Customers (J) $ 1,980,592 $ 2,081,873 $ 2,930,172 _________________________ (I) CONSOL Energy attributes revenue to individual countries based on the location of the customer. (J) CONSOL Energy has contractual relationships with certain U.S. based customers who distribute coal to international markets. The table above reflects the ultimate destination of CONSOL Energy coal. CONSOL Energy's Property, Plant and Equipment by geographical location: December 31, 2016 2015 United States $ 8,129,415 $ 8,721,682 Canada 11,024 11,024 Discontinued Operations — 936,671 Total Property, Plant and Equipment, net $ 8,140,439 $ 9,669,377 |
Segment Information | Industry segment results for the year ended December 31, 2016 are: Marcellus Shale Utica Shale Coalbed Methane Other Gas Total E&P PA Mining Operations Other Adjustments and Eliminations Consolidated Sales—Outside $ 414,484 $ 163,112 $ 174,323 $ 41,329 $ 793,248 $ 1,065,582 $ — $ — $ 1,858,830 Gain (Loss) on Commodity Derivative Instruments 147,282 29,285 52,396 (369,984 ) (141,021 ) — — — (141,021 ) Other Outside Sales — — — — — — 32,038 — 32,038 Sales—Purchased Gas — — — 43,256 43,256 — — — 43,256 Freight—Outside — — — — — 46,468 — — 46,468 Intersegment Transfers — — 424 — 424 — — (424 ) — Total Sales and Freight $ 561,766 $ 192,397 $ 227,143 $ (285,399 ) $ 695,907 $ 1,112,050 $ 32,038 $ (424 ) $ 1,839,571 Earnings (Loss) From Continuing Operations $ 72,141 $ 28,390 $ 37,999 $ (517,370 ) $ (378,840 ) $ 130,708 $ (277,399 ) $ (424 ) $ (525,955 ) (A) Segment Assets $ 6,235,568 $ 1,982,206 $ 966,124 $ 83 $ 9,183,981 (B) Depreciation, Depletion and Amortization $ 417,853 $ 168,195 $ 12,455 $ — $ 598,503 Capital Expenditures $ 165,101 $ 50,809 $ 10,910 $ — $ 226,820 (A) Includes equity in earnings of unconsolidated affiliates of $51,742 and $1,336 for Total E&P and Other, respectively. (B) Includes investments in unconsolidated equity affiliates of $188,376 and $2,588 for Total E&P and Other, respectively. Industry segment results for the year ended December 31, 2015 are: Marcellus Shale Utica Shale Coalbed Methane Other Gas Total E&P PA Mining Operations Other Adjustments and Eliminations Consolidated Sales—Outside $ 379,453 $ 92,223 $ 200,645 $ 54,600 $ 726,921 $ 1,289,036 $ — $ — $ 2,015,957 (C) Gain on Commodity Derivative Instruments 100,785 6,430 67,281 218,446 392,942 — — — 392,942 Other Outside Sales — — — — — — 30,967 — 30,967 Sales—Purchased Gas — — — 14,450 14,450 — — — 14,450 Freight—Outside — — — — — 20,499 — — 20,499 Intersegment Transfers — — 1,538 — 1,538 — — (1,538 ) — Total Sales and Freight $ 480,238 $ 98,653 $ 269,464 $ 287,496 $ 1,135,851 $ 1,309,535 $ 30,967 $ (1,538 ) $ 2,474,815 Earnings (Loss) From Continuing Operations $ 56,116 $ (19,428 ) $ 59,662 $ (775,207 ) $ (678,857 ) $ 404,994 $ (200,304 ) $ (1,538 ) $ (475,705 ) (D) Segment Assets $ 6,892,284 $ 2,076,301 $ 939,497 $ 1,021,820 $ 10,929,902 (E) Depreciation, Depletion and Amortization $ 370,374 $ 176,864 $ 19,882 $ — $ 567,120 Capital Expenditures $ 832,446 $ 136,291 $ 14,197 $ — $ 982,934 (C) Included in the PA Mining Operations segment are sales of $242,020 to Duke Energy, which comprises over 10% of sales. (D) Includes equity in earnings of unconsolidated affiliates of $46,614 and $8,283 for Total E&P and Other, respectively. (E) Includes investments in unconsolidated equity affiliates of $234,803 and $2,527 for Total E&P and Other, respectively. Industry segment results for the year ended December 31, 2014 are: Marcellus Shale Utica Shale Coalbed Methane Other Gas Total E&P PA Mining Operations Other Adjustments and Eliminations Consolidated Sales—Outside $ 457,679 $ 86,948 $ 340,739 $ 119,558 $ 1,004,924 $ 1,616,874 $ — $ — $ 2,621,798 (F) Gain on Commodity Derivative Instruments 14,764 1,247 4,103 3,079 23,193 — — — 23,193 Other Outside Sales — — — — — — 276,242 — 276,242 Sales—Purchased Gas — — — 8,999 8,999 — — — 8,999 Freight—Outside — — — — — 23,133 — — 23,133 Intersegment Transfers — — 2,458 — 2,458 — 78,229 (80,687 ) — Total Sales and Freight $ 472,443 $ 88,195 $ 347,300 $ 131,636 $ 1,039,574 $ 1,640,007 $ 354,471 $ (80,687 ) $ 2,953,365 Earnings (Loss) From Continuing Operations $ 171,902 $ 43,645 $ 108,107 $ (133,940 ) $ 189,714 $ 430,968 $ (438,073 ) $ (2,458 ) $ 180,151 (G) Segment Assets $ 7,364,185 $ 2,094,041 $ 1,186,874 $ 1,009,546 $ 11,654,646 (H) Depreciation, Depletion and Amortization $ 323,600 $ 173,316 $ 35,727 $ — $ 532,643 Capital Expenditures $ 1,103,656 $ 341,229 $ 14,567 $ — $ 1,459,452 (F) Included in the Total E&P segment are sales of $295,779 to NJR Energy Services Company, which comprises over 10% of sales. (G) Includes equity in earnings of unconsolidated affiliates of $ 32,217 and $17,574 for Total E&P and Other, respectively. (H) Includes investments in unconsolidated equity affiliates of $121,721 and $31,237 for Total E&P and Other, respectively. |
Guarantor Subsidiaries Financia
Guarantor Subsidiaries Financial Information | 12 Months Ended |
Dec. 31, 2016 | |
Guarantor Subsidiaries Financial Information [Abstract] | |
Additional Financial Information Disclosure [Text Block] | NOTE 24—GUARANTOR SUBSIDIARIES FINANCIAL INFORMATION: The payment obligations under the $74,470 , 8.250% per annum senior notes due April 1, 2020 , the $20,611 , 6.375% per annum senior notes due March 1, 2021 , the $1,854,731 , 5.875% per annum senior notes due April 15, 2022 , and the $494,344 , 8.000% per annum senior notes due April 1, 2023 issued by CONSOL Energy are jointly and severally, and also fully and unconditionally, guaranteed by certain subsidiaries of CONSOL Energy. In accordance with positions established by the Securities and Exchange Commission (SEC), the following financial information sets forth separate financial information with respect to the parent, CNX Gas, a guarantor subsidiary, CNX Coal Resources LP (CNXC), a non-guarantor subsidiary, and the remaining guarantor and non-guarantor subsidiaries. The principal elimination entries include investments in subsidiaries and certain intercompany balances and transactions. CONSOL Energy, the parent, and a guarantor subsidiary manage several assets and liabilities of all other wholly owned subsidiaries. These include, for example, deferred tax assets, cash and other post-employment liabilities. These assets and liabilities are reflected as parent company or guarantor company amounts for purposes of this presentation. On September 30, 2016, CNXC acquired an additional 5% undivided interest in the Pennsylvania Mining Complex from CONSOL Energy, increasing their total undivided interest to 25%. To account for the acquisition, CNXC recast its consolidated financial statements to retrospectively reflect the additional 5% interest as if the business was owned for all periods presented. This resulted in corresponding retrospective adjustments between the Other Subsidiary Guarantors and the CNXC Non-Guarantor columns below. See Note 25 - Related Party Transactions of the Notes to the Audited Consolidated Financial Statements in Item 8 of this Form 10-K for additional information. Income Statement for the Year Ended December 31, 2016 : Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Non-Guarantor Other Subsidiary Non- Guarantors Elimination Consolidated Revenues and Other Income: Natural Gas, NGLs and Oil Sales $ — $ 793,672 $ — $ — $ — $ (424 ) $ 793,248 Loss on Commodity Derivative Instruments — (141,021 ) — — — — (141,021 ) Coal Sales — — 799,187 266,395 — — 1,065,582 Other Outside Sales — — 32,038 — — — 32,038 Purchased Gas Sales — 43,256 — — — — 43,256 Freight-Outside Coal — — 34,865 11,603 — — 46,468 Miscellaneous Other Income (712,927 ) 80,444 83,735 3,128 — 712,926 167,306 Gain (Loss) on Sale of Assets — 14,870 4,637 (9 ) — — 19,498 Total Revenue and Other Income (712,927 ) 791,221 954,462 281,117 — 712,502 2,026,375 Costs and Expenses: Exploration and Production Costs Lease Operating Expense — 96,434 — — — — 96,434 Transportation, Gathering and Compression — 374,350 — — — — 374,350 Production, Ad Valorem, and Other Fees — 31,049 — — — — 31,049 Depreciation, Depletion and Amortization — 417,853 — — — — 417,853 Exploration and Production Related Other Costs — 14,519 — — — — 14,519 Purchased Gas Costs — 42,717 — — — — 42,717 Other Corporate Expenses — 87,913 — — — — 87,913 Selling, General and Administrative Costs — 102,503 — — — — 102,503 Total Exploration and Production Costs — 1,167,338 — — — — 1,167,338 PA Mining Operations Costs Operating and Other Costs — — 550,299 183,001 — — 733,300 Depreciation, Depletion and Amortization — — 126,201 41,994 — — 168,195 Freight Expense — — 34,865 11,603 — — 46,468 Selling, General and Administrative Costs — — 27,563 9,949 — — 37,512 Total PA Mining Operations Costs — — 738,928 246,547 — — 985,475 Other Costs Miscellaneous Operating Expense 43,533 — 139,289 — 47 — 182,869 Selling, General and Administrative Costs — — 12,717 — — — 12,717 Depreciation, Depletion and Amortization 568 — 11,887 — — — 12,455 Interest Expense 173,327 2,723 6,707 8,719 — — 191,476 Total Other Costs 217,428 2,723 170,600 8,719 47 — 399,517 Total Costs And Expenses 217,428 1,170,061 909,528 255,266 47 — 2,552,330 (Loss) Earnings from Continuing Operations Before Income Tax (930,355 ) (378,840 ) 44,934 25,851 (47 ) 712,502 (525,955 ) Income Tax (Benefit) Expense (82,253 ) (150,551 ) 242,832 — (18 ) — 10,010 (Loss) Income From Continuing Operations (848,102 ) (228,289 ) (197,898 ) 25,851 (29 ) 712,502 (535,965 ) Loss From Discontinued Operations, net — — — — (303,183 ) — (303,183 ) Net (Loss) Income (848,102 ) (228,289 ) (197,898 ) 25,851 (303,212 ) 712,502 (839,148 ) Less: Net Income Attributable to Noncontrolling Interest — — — — — 8,954 8,954 Net (Loss) Income Attributable to CONSOL Energy Shareholders $ (848,102 ) $ (228,289 ) $ (197,898 ) $ 25,851 $ (303,212 ) $ 703,548 $ (848,102 ) Balance Sheet at December 31, 2016 : Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Other Subsidiary Elimination Consolidated Assets: Current Assets: Cash and Cash Equivalents $ 49,722 $ 83 $ — $ 9,785 $ 885 $ — $ 60,475 Accounts and Notes Receivable: Trade — 124,509 72,295 23,418 — — 220,222 Other Receivables 20,097 34,773 14,516 515 — — 69,901 Inventories — 15,301 38,669 11,491 — — 65,461 Recoverable Income Taxes 175,877 (59,026 ) — — — — 116,851 Prepaid Expenses 12,828 60,500 16,306 3,512 — — 93,146 Current Assets of Discontinued Operations — — — — 83 — 83 Total Current Assets 258,524 176,140 141,786 48,721 968 — 626,139 Property, Plant and Equipment: Property, Plant and Equipment 114,611 8,851,226 3,928,861 876,690 — — 13,771,388 Less-Accumulated Depreciation, Depletion and Amortization 84,788 3,106,296 1,997,687 442,178 — — 5,630,949 Total Property, Plant and Equipment-Net 29,823 5,744,930 1,931,174 434,512 — — 8,140,439 Other Assets: Deferred Income Taxes 25,904 (21,614 ) — — — — 4,290 Investment in Affiliates 7,974,260 188,376 27,269 — — (7,998,941 ) 190,964 Other 19,960 67,096 114,030 21,063 — — 222,149 Total Other Assets 8,020,124 233,858 141,299 21,063 — (7,998,941 ) 417,403 Total Assets $ 8,308,471 $ 6,154,928 $ 2,214,259 $ 504,296 $ 968 $ (7,998,941 ) $ 9,183,981 Liabilities and Equity: Current Liabilities: Accounts Payable $ 48,666 $ 127,309 $ 36,039 $ 18,797 $ — $ 10,805 $ 241,616 Accounts Payable (Recoverable)-Related Parties 1,832,908 1,034,138 (2,648,416 ) 1,666 (209,491 ) (10,805 ) — Current Portion of Long-Term Debt 1,533 6,369 4,010 88 — — 12,000 Other Accrued Liabilities 75,039 337,374 223,705 44,230 — — 680,348 Current Liabilities of Discontinued Operations — — — — 6,050 — 6,050 Total Current Liabilities 1,958,146 1,505,190 (2,384,662 ) 64,781 (203,441 ) — 940,014 Long-Term Debt: 2,421,511 26,884 115,685 197,989 — — 2,762,069 Deferred Credits and Other Liabilities: Postretirement Benefits Other Than Pensions — — 659,474 — — — 659,474 Pneumoconiosis Benefits — — 106,016 2,057 — — 108,073 Mine Closing — — 209,384 9,247 — — 218,631 Gas Well Closing — 195,704 27,549 99 — — 223,352 Workers’ Compensation — — 64,187 3,090 — — 67,277 Salary Retirement 112,543 — — — — — 112,543 Other 17,876 117,658 15,663 463 — — 151,660 Total Deferred Credits and Other Liabilities 130,419 313,362 1,082,273 14,956 — — 1,541,010 Total CONSOL Energy Inc. Stockholders’ Equity 3,798,395 4,309,492 3,400,963 226,570 204,409 (8,141,434 ) 3,798,395 Noncontrolling Interest — — — — — 142,493 142,493 Total Liabilities and Equity $ 8,308,471 $ 6,154,928 $ 2,214,259 $ 504,296 $ 968 $ (7,998,941 ) $ 9,183,981 Condensed Statement of Cash Flows for the Year Ended December 31, 2016 : Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Non-Guarantor Other Subsidiary Non-Guarantors Elimination Consolidated Net Cash Provided by (Used in) Continuing Operating Activities $ 943,652 $ (165,861 ) $ 58,648 $ 73,098 $ (377,257 ) $ (72,930 ) $ 459,350 Net Cash Provided by Discontinued Operating Activities — — — — 9,935 — 9,935 Net Cash Provided by (Used in) Operating Activities $ 943,652 $ (165,861 ) $ 58,648 $ 73,098 $ (367,322 ) $ (72,930 ) $ 469,285 Cash Flows from Investing Activities: Capital Expenditures $ (2,990 ) $ (165,101 ) $ (46,025 ) $ (12,704 ) $ — $ — $ (226,820 ) CNXC Acquisition of 5% Pennsylvania Mining Complex — — 21,500 (21,500 ) — — — Proceeds from Noble Exchange Settlement — 213,295 — — — — 213,295 Proceeds From Sales of Assets — 44,710 15,169 23 — — 59,902 Net Investments in Equity Affiliates — 79,103 (5,360 ) — — — 73,743 Net Cash (Used in) Provided by Continuing Investing Activities (2,990 ) 172,007 (14,716 ) (34,181 ) — — 120,120 Net Cash Provided by Discontinued Investing Activities — — — — 367,251 — 367,251 Net Cash (Used in) Provided by Investing Activities $ (2,990 ) $ 172,007 $ (14,716 ) $ (34,181 ) $ 367,251 $ — $ 487,371 Cash Flows from Financing Activities: Payments on Short-Term Borrowings $ (952,000 ) $ — $ — $ — $ — $ — $ (952,000 ) Payments on Miscellaneous Borrowings (1,645 ) (6,138 ) (450 ) (79 ) — — (8,312 ) Proceeds from Revolver - MLP — — — 16,000 — — 16,000 Distributions of Noncontrolling Interest — — — (42,634 ) — 20,977 (21,657 ) Net Change in Parent Advancements — — — (8,953 ) — 8,953 — Dividends Paid (2,294 ) — — — — — (2,294 ) Proceeds from Issuance of Common Stock 4 — — — — — 4 Debt Issuance and Financing Fees — — (482 ) — — — (482 ) Net Cash (Used in) Provided by Continuing Financing Activities (955,935 ) (6,138 ) (932 ) (35,666 ) — 29,930 (968,741 ) Net Cash Used in Discontinued Financing Activities — — — — (14 ) — (14 ) Net Cash (Used in) Provided by Financing Activities $ (955,935 ) $ (6,138 ) $ (932 ) $ (35,666 ) $ (14 ) $ 29,930 $ (968,755 ) Statement of Comprehensive Income for the Year Ended December 31, 2016 : Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Non- Other Subsidiary Non- Guarantors Elimination Consolidated Net (Loss) Income $ (848,102 ) $ (228,289 ) $ (197,898 ) $ 25,851 $ (303,212 ) $ 712,502 $ (839,148 ) Other Comprehensive (Loss) Income: Actuarially Determined Long-Term Liability Adjustments (33,226 ) — (34,044 ) 818 — 33,226 (33,226 ) Reclassification of Cash Flow Hedge from OCI to Earnings (43,470 ) (43,470 ) — — — 43,470 (43,470 ) Other Comprehensive (Loss) Income: (76,696 ) (43,470 ) (34,044 ) 818 — 76,696 (76,696 ) Comprehensive (Loss) Income (924,798 ) (271,759 ) (231,942 ) 26,669 (303,212 ) 789,198 (915,844 ) Less: Comprehensive Income Attributable to Noncontrolling Interest — — — — — 9,216 9,216 Comprehensive (Loss) Income Attributable to CONSOL Energy Inc. Shareholders $ (924,798 ) $ (271,759 ) $ (231,942 ) $ 26,669 $ (303,212 ) $ 779,982 $ (925,060 ) Income Statement for the Year Ended December 31, 2015 : Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Non-Guarantor Other Subsidiary Non- Guarantors Elimination Consolidated Revenues and Other Income: Natural Gas, NGLs and Oil Sales $ — $ 728,458 $ — $ — $ — $ (1,537 ) $ 726,921 Gain on Commodity Derivative Instruments — 392,942 — — — — 392,942 Coal Sales — — 966,775 322,261 — — 1,289,036 Other Outside Sales — — 30,967 — — — 30,967 Purchased Gas Sales — 14,450 — — — — 14,450 Freight-Outside Coal — — 16,690 3,809 — — 20,499 Miscellaneous Other Income (172,450 ) 62,340 82,690 880 4,105 166,786 144,351 Gain on Sale of Assets — 12,540 61,572 61 — — 74,173 Total Revenue and Other Income (172,450 ) 1,210,730 1,158,694 327,011 4,105 165,249 2,693,339 Costs and Expenses: Exploration and Production Costs Lease Operating Expense — 121,847 — — — — 121,847 Transportation, Gathering and Compression — 343,403 — — — — 343,403 Production, Ad Valorem, and Other Fees — 30,438 — — — — 30,438 Depreciation, Depletion and Amortization — 370,374 — — — — 370,374 Exploration and Production Related Other Costs — 10,120 — — 9 (9 ) 10,120 Purchased Gas Costs — 10,721 — — — — 10,721 Other Corporate Expenses — 65,939 — — — — 65,939 Impairment of Exploration and Production Properties — 828,905 — — — — 828,905 Selling, General and Administrative Costs — 102,229 — — — — 102,229 Total Exploration and Production Costs — 1,883,976 — — 9 (9 ) 1,883,976 PA Mining Operations Costs Operating and Other Costs — — 472,341 193,961 — — 666,302 Depreciation, Depletion and Amortization — — 132,728 44,136 — — 176,864 Freight Expense — — 16,690 3,809 — — 20,499 Selling, General and Administrative Costs — — 29,912 10,931 — — 40,843 Total PA Mining Operations Costs — — 651,671 252,837 — — 904,508 Other Costs Miscellaneous Operating Expense 69,059 — 9,176 — 508 — 78,743 Selling, General and Administrative Costs — — 14,918 — — — 14,918 Depreciation, Depletion and Amortization 604 — 19,278 — — — 19,882 Loss on Debt Extinguishment 67,751 — — — — — 67,751 Interest Expense 186,291 5,613 6,453 9,636 76 (8,803 ) 199,266 Total Other Costs 323,705 5,613 49,825 9,636 584 (8,803 ) 380,560 Total Costs And Expenses 323,705 1,889,589 701,496 262,473 593 (8,812 ) 3,169,044 (Loss) Earnings from Continuing Operations Before Income Tax (496,155 ) (678,859 ) 457,198 64,538 3,512 174,061 (475,705 ) Income Tax (Benefit) Expense (121,270 ) (257,056 ) 251,558 — 1,329 — (125,439 ) (Loss) Income From Continuing Operations (374,885 ) (421,803 ) 205,640 64,538 2,183 174,061 (350,266 ) Loss From Discontinued Operations, net — — — — (14,209 ) — (14,209 ) Net (Loss) Income (374,885 ) (421,803 ) 205,640 64,538 (12,026 ) 174,061 (364,475 ) Less: Net Income Attributable to Noncontrolling Interest — — — — — 10,410 10,410 Net (Loss) Income Attributable to CONSOL Energy Shareholders $ (374,885 ) $ (421,803 ) $ 205,640 $ 64,538 $ (12,026 ) $ 163,651 $ (374,885 ) Balance Sheet at December 31, 2015 : Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Other Subsidiary Elimination Consolidated Assets: Current Assets: Cash and Cash Equivalents $ 64,995 $ 75 $ — $ 6,534 $ 970 $ — $ 72,574 Accounts and Notes Receivable: Trade — 72,664 59,321 19,398 — — 151,383 Other Receivables 18,933 99,001 3,330 471 — — 121,735 Inventories — 13,815 40,739 12,238 — — 66,792 Recoverable Income Taxes 72,913 (59,026 ) — — — — 13,887 Prepaid Expenses 27,245 244,680 20,273 5,089 — — 297,287 Current Assets of Discontinued Operations — — — — 81,105 — 81,105 Total Current Assets 184,086 371,209 123,663 43,730 82,075 — 804,763 Property, Plant and Equipment: Property, Plant and Equipment 156,348 8,875,027 3,898,005 865,527 — — 13,794,907 Less-Accumulated Depreciation, Depletion and Amortization 111,367 2,695,674 1,854,249 400,911 — — 5,062,201 Property, Plant and Equipment of Discontinued Operations — — — — 936,671 — 936,671 Total Property, Plant and Equipment-Net 44,981 6,179,353 2,043,756 464,616 936,671 — 9,669,377 Other Assets: Investment in Affiliates 10,563,985 234,803 6,293 — — (10,567,751 ) 237,330 Other 53,529 47,892 95,369 17,598 — — 214,388 Other Assets of Discontinued Operations — — — — 4,044 — 4,044 Total Other Assets 10,617,514 282,695 101,662 17,598 4,044 (10,567,751 ) 455,762 Total Assets $ 10,846,581 $ 6,833,257 $ 2,269,081 $ 525,944 $ 1,022,790 $ (10,567,751 ) $ 10,929,902 Liabilities and Equity: Current Liabilities: Accounts Payable $ 32,245 $ 149,930 $ 37,212 $ 17,405 $ — $ 13,817 $ 250,609 Accounts Payable (Recoverable)-Related Parties 2,650,732 1,521,442 (3,953,215 ) 4,310 (209,452 ) (13,817 ) — Current Portion of Long-Term Debt 1,509 6,798 1,041 61 — — 9,409 Short-Term Notes Payable 952,000 — — — — — 952,000 Other Accrued Liabilities 63,668 102,753 218,186 37,220 — — 421,827 Current Liabilities of Discontinued Operations — — — — 51,514 — 51,514 Total Current Liabilities 3,700,154 1,780,923 (3,696,776 ) 58,996 (157,938 ) — 1,685,359 Long-Term Debt: Long-Term Debt 2,418,961 33,141 105,611 181,070 — — 2,738,783 Long-Term Debt of Discontinued Operations — — — — 5,001 — 5,001 Total Long-Term Debt 2,418,961 33,141 105,611 181,070 5,001 — 2,743,784 Deferred Credits and Other Liabilities: Deferred Income Taxes (122,547 ) 197,176 — — — — 74,629 Postretirement Benefits Other Than Pensions — — 630,892 — — — 630,892 Pneumoconiosis Benefits — — 109,969 1,934 — — 111,903 Mine Closing — — 218,936 8,403 — — 227,339 Gas Well Closing — 135,174 28,572 96 — — 163,842 Workers’ Compensation — — 66,883 2,929 — — 69,812 Salary Retirement 91,596 — — — — — 91,596 Reclamation — — 25 — — — 25 Other 56,390 105,588 4,266 713 — — 166,957 Deferred Credits and Other Liabilities of Discontinued Operations — — — — 107,988 — 107,988 Total Deferred Credits and Other Liabilities 25,439 437,938 1,059,543 14,075 107,988 — 1,644,983 Total CONSOL Energy Inc. Stockholders’ Equity 4,702,027 4,581,255 4,800,703 271,803 1,067,739 (10,721,500 ) 4,702,027 Noncontrolling Interest — — — — — 153,749 153,749 Total Liabilities and Equity $ 10,846,581 $ 6,833,257 $ 2,269,081 $ 525,944 $ 1,022,790 $ (10,567,751 ) $ 10,929,902 Condensed Statement of Cash Flows for the Year Ended December 31, 2015 : Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Non-Guarantor Other Subsidiary Non-Guarantors Elimination Consolidated Net Cash (Used in) Provided by Continuing Operating Activities $ (153,930 ) $ 624,788 $ 21,906 $ 76,908 $ 33,422 $ (103,417 ) $ 499,677 Net Cash Provided by Discontinued Operating Activities — — — — 6,172 — 6,172 Net Cash (Used in) Provided by Operating Activities $ (153,930 ) $ 624,788 $ 21,906 $ 76,908 $ 39,594 $ (103,417 ) $ 505,849 Cash Flows from Investing Activities: Capital Expenditures $ (9,752 ) $ (832,446 ) $ (106,663 ) $ (34,073 ) $ — $ — $ (982,934 ) Proceeds From Sales of Assets 142 10,298 100,060 71 — — 110,571 Net Investments in Equity Affiliates — (79,756 ) (4,465 ) — — — (84,221 ) Net Cash Used in Continuing Investing Activities (9,610 ) (901,904 ) (11,068 ) (34,002 ) — — (956,584 ) Net Cash Used in Discontinued Investing Activities — — — — (39,633 ) — (39,633 ) Net Cash Used in Investing Activities $ (9,610 ) $ (901,904 ) $ (11,068 ) $ (34,002 ) $ (39,633 ) $ — $ (996,217 ) Cash Flows from Financing Activities: Proceeds from (Payments on) Short-Term Borrowings $ 952,000 $ 252,900 $ — $ — $ — $ (252,900 ) $ 952,000 (Payments on) Proceeds from Miscellaneous Borrowings (1,281 ) (6,391 ) 3,443 (53 ) — — (4,282 ) Payments on Long-Term Notes, including Redemption Premium (1,263,719 ) — — (10,951 ) — 10,951 (1,263,719 ) Proceeds from Revolver - MLP — — — 185,000 — — 185,000 Distributions to Noncontrolling Interest — — — (11,353 ) — 6,293 (5,060 ) Proceeds from Sale of MLP Interest — — — 148,359 — — 148,359 Proceeds from Issuance of Long-Term Notes 492,760 — — 16,990 — (16,990 ) 492,760 Net Distributions from Offering to Parent — — — (342,711 ) — 342,711 — Net Change in Parent Advancements — — — (17,328 ) — 17,328 — Tax Benefit from Stock-Based Compensation 208 — — — — — 208 Dividends Paid (33,281 ) — — — — — (33,281 ) Proceeds from Issuance of Common Stock 8,288 — — — — — 8,288 Purchases of Treasury Stock (71,674 ) — — — — — (71,674 ) Debt Issuance and Financing Fees — — (14,281 ) (4,329 ) — (3,976 ) (22,586 ) Net Cash Provided by (Used in) Continuing Financing Activities 83,301 246,509 (10,838 ) (36,376 ) — 103,417 386,013 Net Cash Used in Discontinued Financing Activities — — — — (56 ) — (56 ) Net Cash Provided by (Used in) Financing Activities $ 83,301 $ 246,509 $ (10,838 ) $ (36,376 ) $ (56 ) $ 103,417 $ 385,957 Statement of Comprehensive Income for the Year Ended December 31, 2015 : Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Non- Other Subsidiary Non- Guarantors Elimination Consolidated Net (Loss) Income $ (374,885 ) $ (421,803 ) $ 205,640 $ 64,538 $ (12,026 ) $ 174,061 $ (364,475 ) Other Comprehensive (Loss) Income: Actuarially Determined Long-Term Liability Adjustments (86,447 ) — (84,607 ) (1,840 ) — 86,447 (86,447 ) Reclassification of Cash Flow Hedge from OCI to Earnings (78,051 ) (78,051 ) — — — 78,051 (78,051 ) Other Comprehensive (Loss) Income: (164,498 ) (78,051 ) (84,607 ) (1,840 ) — 164,498 (164,498 ) Comprehensive (Loss) Income (539,383 ) (499,854 ) 121,033 62,698 (12,026 ) 338,559 (528,973 ) Less: Comprehensive Income Attributable to Noncontrolling Interest — — — — — 10,410 10,410 Comprehensive (Loss) Income Attributable to CONSOL Energy Inc. Shareholders $ (539,383 ) $ (499,854 ) $ 121,033 $ 62,698 $ (12,026 ) $ 328,149 $ (539,383 ) Income Statement for the Year Ended December 31, 2014 : Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Non-Guarantor Other Subsidiary Non- Guarantors Elimination Consolidated Revenues and Other Income: Natural Gas, NGLs and Oil Sales $ — $ 1,007,381 $ — $ — $ — $ (2,457 ) $ 1,004,924 Gain on Commodity Derivative Instruments — 23,193 — — — — 23,193 Coal Sales — — 1,212,627 404,247 — — 1,616,874 Other Outside Sales — — 41,255 — 234,987 — 276,242 Purchased Gas Sales — 8,999 — — — — 8,999 Freight-Outside Coal — — 18,941 4,192 — — 23,133 Miscellaneous Other Income 420,030 60,634 138,201 9,475 10,305 (431,185 ) 207,460 Gain (Loss) on Sale of Assets — 45,917 (2,926 ) 185 22 — 43,198 Total Revenue and Other Income 420,030 1,146,124 1,408,098 418,099 245,314 (433,642 ) 3,204,023 Costs and Expenses: Exploration and Production Costs Lease Operating Expense — 139,242 — — — — 139,242 Transportation, Gathering and Compression — 239,591 — — — (12 ) 239,579 Production, Ad Valorem, and Other Fees — 39,418 — — — — 39,418 Depreciation, Depletion and Amortization — 323,600 — — — — 323,600 Exploration and Production Related Other Costs — 22,718 637 — 119 (119 ) 23,355 Purchased Gas Costs — 7,251 — — — — 7,251 Other Corporate Expenses — 46,838 — — — — 46,838 Selling, General and Administrative Costs — 128,731 — — — — 128,731 Total Exploration and Production Costs — 947,389 637 — 119 (131 ) 948,014 PA Mining Operations Costs Operating and Other Costs — — 742,886 239,863 — — 982,749 Depreciation, Depletion and Amortization — — 129,979 43,337 — — 173,316 Freight Expense — — 12,575 4,192 6,366 — 23,133 Selling, General and Administrative Costs — — 57,814 17,149 (6,366 ) — 68,597 Total PA Mining Operations Costs — — 943,254 304,541 — — 1,247,795 Other Costs Miscellaneous Operating Expense 99,273 — 129,257 — 231,899 — 460,429 Selling, General and Administrative Costs 788 — 12,519 — — — 13,307 Depreciation, Depletion and Amortization 640 — 33,273 — 1,814 — 35,727 Loss on Debt Extinguishment 95,267 — — — — — 95,267 Interest Expense 213,384 9,021 9,608 8,683 245 (17,608 ) 223,333 Total Other Costs 409,352 9,021 184,657 8,683 233,958 (17,608 ) 828,063 Total Costs And Expenses 409,352 956,410 1,128,548 313,224 234,077 (17,739 ) 3,023,872 Earnings (Loss) from Continuing Operations Before Income Tax 10,678 189,714 279,550 104,875 11,237 (415,903 ) 180,151 Income Tax (Benefit) Expense (152,412 ) 66,441 96,926 — 4,249 — 15,204 Income (Loss) From Continuing Operations 163,090 123,273 182,624 104,875 6,988 (415,903 ) 164,947 Loss From Discontinued Operations, net — — — — (1,857 ) — (1,857 ) Net Income (Loss) Attributable to CONSOL Energy Shareholders $ 163,090 $ 123,273 $ 182,624 $ 104,875 $ 5,131 $ (415,903 ) $ 163,090 Condensed Statement of Cash Flows for the Year Ended December 31, 2014 : Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Non-Guarantor Other Subsidiary Non-Guarantors Elimination Consolidated Net Cash (Used in) Provided by Continuing Operating Activities $ (178,921 ) $ 567,851 $ (4,086 ) $ 142,636 $ (59,441 ) $ 372,347 $ 840,386 Net Cash Provided by Discontinued Operating Activities — — — — 96,390 — 96,390 Net Cash (Used in) Provided by Operating Activities $ (178,921 ) $ 567,851 $ (4,086 ) $ 142,636 $ 36,949 $ 372,347 $ 936,776 Cash Flows from Investing Activities: Capital Expenditures $ (4,420 ) $ (1,103,656 ) $ (266,300 ) $ (85,076 ) $ — $ — $ (1,459,452 ) Proceeds From Sales of Assets 44,049 92,507 201,221 19,046 13 — 356,836 Net Investments in Equity Affiliates — 85,248 9,959 — — — 95,207 Net Cash Provided by (Used in) Continuing Investing Activities 39,629 (925,901 ) (55,120 ) (66,030 ) 13 — (1,007,409 ) Net Cash Used in Discontinued Investing Activities — — — — (33,973 ) — (33,973 ) Net Cash Provided by (Used in) Investing Activities $ 39,629 $ (925,901 ) $ (55,120 ) $ (66,030 ) $ (33,960 ) $ — $ (1,041,382 ) Cash Flows from Financing Activities: Payments on Short-Term Borrowings $ (11,736 ) $ — $ — $ — $ — $ — $ (11,736 ) (Payments on) Proceeds from Miscellaneous Borrowings (399 ) 387,663 (7,233 ) (24 ) (2,630 ) (387,663 ) (10,286 ) Payments on Long-Term Notes, including Redemption Premium (1,819,005 ) — — (2,311 ) — 2,311 (1,819,005 ) Proceeds from Issuance of Long-Term Notes 1,859,920 — — 14,214 — (14,214 ) 1,859,920 Net Change in Parent Advancements — — — (88,485 ) — 88,485 — Tax Benefit from Stock-Based Compensation 2,629 — — — — — 2,629 Dividends Paid (57,506 ) — — — — — (57,506 ) Proceeds from Issuance of Common Stock 15,016 — — — — — 15,016 Debt Issuance and Financing Fees (24,861 ) — — — — — (24,861 ) Other Financing Activities — (5,169 ) 5,169 — — — — Net Cash (Used in) Provided by Financing Activities $ (35,942 ) $ 382,494 $ (2,064 ) $ (76,606 ) $ (2,630 ) $ (311,081 ) $ (45,829 ) Statement of Comprehensive Income for the Year Ended December 31, 2014 : Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Non- Other Subsidiary Non- Guarantors Elimination Consolidated Net Income (Loss) $ 163,090 $ 123,273 $ 182,624 $ 104,875 $ 5,131 $ (415,903 ) $ 163,090 Other Comprehensive Income (Loss): Actuarially Determined Long-Term Liability Adjustments 94,989 — 53,190 41,799 — (94,989 ) 94,989 Net Increase (Decrease) in the Value of Cash Flow Hedge 97,316 97,316 — — — (97,316 ) 97,316 Reclassification of Cash Flow Hedge from OCI to Earnings (18,288 ) (18,288 ) — — — 18,288 (18,288 ) Other Comprehensive Income (Loss): 174,017 79,028 53,190 41,799 — (174,017 ) 174,017 Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders $ 337,107 $ 202,301 $ 235,814 $ 146,674 $ 5,131 $ (589,920 ) $ 337,107 |
Related Party
Related Party | 12 Months Ended |
Dec. 31, 2016 | |
Related Party Transactions [Abstract] | |
Related Party Transactions Disclosure [Text Block] | NOTE 25 — RELATED PARTY TRANSACTIONS CONE Gathering LLC and CONE Midstream Partners LP In September 2011, CNX Gas Company, a wholly owned subsidiary of CONSOL Energy, and Noble Energy, Inc. (Noble Energy), an unrelated third party, formed CONE Gathering LLC (CONE) to develop and operate each company's gas gathering system needs in the Marcellus Shale play. CONSOL Energy accounts for CNX Gas Company's 50% ownership interest in CONE under the equity method of accounting. In May 2014, CONSOL Energy and Noble Energy (collectively, “the Sponsors”) formed CONE Midstream Partners LP (the Partnership), a master limited partnership, to own, operate, develop and acquire natural gas gathering and other midstream energy assets to service each company’s production in the Marcellus Shale in Pennsylvania and West Virginia. The Partnership's general partner is CONE Midstream GP LLC, a wholly owned subsidiary of CONE. In September 2014, the Partnership closed its initial public offering of 20,125,000 common units representing limited partnership interests, which included a 2,625,000 common unit over-allotment option that was exercised in full by the underwriters. Following the IPO, CONE had a 2% general partner interest in the Partnership, while each sponsor had a 32.1% limited partner interest. CNX Gas Company accounts for its portion of the earnings in the Partnership under the equity method of accounting. In November 2016, the Partnership acquired from CONE an additional 25% ownership interest in CONE Midstream DevCo I LP, commonly referred to as the “Anchor Systems.” The transaction included a total purchase consideration of $248,000 , comprised of $ 140,000 in cash and issuance of approximately 5,200,000 common limited partnership units to the Sponsors. Following the acquisition, CONE continues to have a 2 % general partner interest in the Partnership, while each Sponsor’s limited partner interest increased to 33.5%. At December 31, 2016 , CNX Gas Company and Noble Energy each continue to own a 50% interest in the assets of CONE that were not contributed to the Partnership. The following is a summary of the Company's Investment in Affiliates balances included within the Consolidated Balance Sheets associated with CONE and the Partnership, respectively: CONE The Partnership Total Balance at December 31, 2014 $ 94,467 $ 4,883 $ 99,350 Equity in Earnings 20,916 22,883 43,799 Additional Contributions 87,187 — 87,187 Distribution of Earnings — (16,719 ) (16,719 ) Balance at December 31, 2015 202,570 11,047 213,617 Equity in Earnings 17,112 31,148 48,260 Additional Contributions 4,621 — 4,621 Distribution of Earnings (8,224 ) (19,066 ) (27,290 ) Funds received on dropdown transaction (70,000 ) — (70,000 ) Basis differential 4,996 (4,996 ) — Balance at December 31, 2016 $ 151,075 $ 18,133 $ 169,208 The following transactions were included within Miscellaneous Other Income and Transportation, Gathering and Compression within the Consolidated Statements of Income: For the Years Ended December 31, 2016 2015 2014 Miscellaneous Other Income: Equity in Earnings of Affiliates - CONE $ 17,112 $ 20,916 $ 25,521 Equity in Earnings of Affiliates - the Partnership $ 31,148 $ 22,883 $ 4,286 Transportation, Gathering and Compression: Gathering Services - CONE $ 706 $ 1,077 $ 219 Gathering Services - the Partnership $ 123,020 $ 104,291 $ 65,365 At December 31, 2016 and December 31, 2015 , CONSOL Energy had a net payable of $5,815 and $12,216 , respectively, due to both the Partnership and CONE primarily for accrued but unpaid gathering services. Additionally, during the year ended December 31, 2015 , CONSOL Energy purchased $2,239 of supply inventory from the Partnership. CONSOL Energy did not have any supply inventory purchases from the Partnership during the year ended December 31, 2016 . CNX Coal Resources LP In July 2015, CNX Coal Resources LP (CNXC) closed its initial public offering of 5,000,000 common units representing limited partnership interests at a price to the public of $15.00 per unit. Additionally, Greenlight Capital entered into a common unit purchase agreement with CNXC pursuant to which Greenlight Capital agreed to purchase, and CNXC agreed to sell, 5,000,000 common units at a price per unit equal to $15.00 , which equates to $75,000 in net proceeds. CNXC's general partner is CNX Coal Resources GP, a wholly owned subsidiary of CONSOL Energy. The underwriters of the IPO filing exercised an over-allotment option of 561,067 common units to the public at $15.00 per unit. In connection with the Initial Public Offering (IPO), CNXC entered into a $400,000 senior secured revolving credit facility with certain lenders and PNC Bank, National Association (PNC), as administrative agent. Obligations under the revolving credit facility are guaranteed by CNXC's subsidiaries (the guarantor subsidiaries) and are secured by substantially all of CNXC's and CNXC's subsidiaries' assets pursuant to a security agreement and various mortgages. Under the new revolving credit facility, CNXC made an initial draw of $200,000 , and after origination fees of $3,000 , the net proceeds were $197,000 . The total net proceeds related to these transactions that were distributed to CONSOL Energy were $342,711 . In September 2016, CNXC and its wholly owned subsidiary, CNX Thermal Holdings LLC (CNX Thermal), entered into a Contribution Agreement with CONSOL Energy, CONSOL Pennsylvania Coal Company LLC and Conrhein Coal Company (the Contributing Parties) under which CNX Thermal acquired an additional 5% undivided interest in and to the Pennsylvania Mine Complex, in exchange for (i) cash consideration in the amount of $21,500 and (ii) CNXC's issuance of 3,956,496 Class A Preferred Units representing limited partner interests in CNXC at an issue price of $17.01 per Class A preferred Unit (the "Class A Preferred Unit Issue Price"), or an aggregate $67,300 in equity consideration. The Class A Preferred Unit Issue Price was calculated as the volume-weighted average trading price of CNXC's common units (the "Common Units") over the trailing 15-day trading period ending on September 29, 2016 (or $14.79 per unit), plus a 15% premium. In connection with the PA Mining acquisition, in September 2016, the General Partner and CNXC entered into the First Amended and Restated Omnibus Agreement (the "Amended Omnibus Agreement") with CONSOL Energy and certain of its subsidiaries. Under the Amended Omnibus Agreement, CONSOL Energy indemnified CNXC for certain liabilities. The Amended Omnibus Agreement also amended CNXC's obligations to CONSOL Energy with respect to the payment of an annual administrative support fee and reimbursement for the provisions of certain management and operating services provided, in each case to reflect structural changes in how those services are provided to CNXC by CONSOL Energy. Charges for services from CONSOL Energy include the following: For the Years Ended December 31, 2016 2015 2014 Operating and Other Costs $ 4,251 $ 6,793 $ 6,707 Selling, General and Administrative Expenses 3,826 8,926 11,384 Total Services from CONSOL Energy $ 8,077 $ 15,719 $ 18,091 At December 31, 2016 and December 31, 2015 , CNXC had a net payable to CONSOL Energy in the amount of $1,666 and $4,310 , respectively. This payable includes reimbursements for business expenses, executive fees, stock-based compensation and other items under the omnibus agreement. |
Supplemental Coal Data (Unaudit
Supplemental Coal Data (Unaudited) | 12 Months Ended |
Dec. 31, 2016 | |
SUPPLEMENTAL COAL DATA [Abstract] | |
Mineral Industries Disclosures [Text Block] | Supplemental Coal Data (unaudited) Millions of Tons For the Year Ended December 31, 2016 2015 2014 2013 2012 Proven and probable coal reserves at beginning of period 3,047 3,238 3,032 4,229 4,314 Purchased reserves — 24 — 1 — Reserves sold in place (601 ) (43 ) (233 ) (1,199 ) (155 ) Production (26 ) (29 ) (32 ) (55 ) (55 ) Revisions and other changes (59 ) (143 ) 471 56 125 Consolidated proven and probable coal reserves at end of period* (1) 2,361 3,047 3,238 3,032 4,229 Proportionate share of proven and probable coal reserves of unconsolidated equity affiliates (excluded from the table above)* — — 55 57 41 ______________ * Proven and probable coal reserves are the equivalent of “demonstrated reserves” under the coal resource classification system of the U.S. Geological Survey. Generally, these reserves would be commercially mineable at year-end prices and cost levels, using current technology and mining practices. (1) 143.3 Million tons for the Mason Dixon Project are controlled by CCC, a former subsidiary of CONSOL Energy that was sold in December 2013. As of filing, these tons are still controlled by CCC but are shown in CONSOL Energy's reserves due to a binding agreement that these tons will be released to CONSOL Energy upon consent of the lessor. CONSOL Energy's coal reserves are located in nearly every major coal-producing region in North America. Our estimate of proven and probable coal reserves has been determined by CONSOL Energy. At December 31, 2016, 141 million tons were assigned to mines either in production or temporarily idled. The proven and probable coal reserves at December 31, 2016 include 2,274 million tons of thermal coal reserves, of which approximately 2 percent has a sulfur content equivalent to less than 1.2 pounds sulfur dioxide per million British thermal unit (Btu), 8 percent has a sulfur content equivalent to between 1.2 and 2.5 pounds sulfur dioxide per million Btu, and 90 percent has a sulfur content equivalent to greater than 2.5 pounds sulfur dioxide per million Btu. The reserves also include 87 million tons of metallurgical coal in consolidated reserves, of which approximately 24 percent has a sulfur content equivalent to less than 1.2 pounds sulfur dioxide per million Btu and 76 percent has a sulfur content equivalent to between 1.2 and 2.5 pounds sulfur dioxide per million Btu. |
Supplemental Gas Data
Supplemental Gas Data | 12 Months Ended |
Dec. 31, 2016 | |
SUPPLEMENTAL GAS DATA: [Abstract] | |
Oil and Gas Exploration and Production Industries Disclosures [Text Block] | Supplemental Gas Data (unaudited): The following information was prepared in accordance with the FASB's Accounting Standards Update No. 2010-03, “Extractive Activities-Oil and Gas (Topic 932).” Capitalized Costs: As of December 31, 2016 2015 Proved gas properties $ 2,016,916 $ 1,922,602 Unproved gas properties 1,116,282 1,421,083 Intangible drilling costs 3,583,565 3,452,989 Gas wells and related equipment 791,996 785,744 Gas gathering assets 1,138,299 1,147,173 Gas well plugging 176,961 115,121 Total Property, Plant and Equipment 8,824,019 8,844,712 Accumulated Depreciation, Depletion and Amortization (3,099,622 ) (2,691,005 ) Net Capitalized Costs $ 5,724,397 $ 6,153,707 Costs incurred for property acquisition, exploration and development (*): For the Years Ended December 31, 2016 2015 2014 Property acquisitions Proved properties $ — $ — $ — Unproved properties 1,537 76,676 119,597 Development 138,813 666,315 952,733 Exploration 32,259 95,371 45,006 Total $ 172,609 $ 838,362 $ 1,117,336 __________ (*) Includes costs incurred whether capitalized or expensed. Results of Operations for Producing Activities: For the Years Ended December 31, 2016 2015 2014 Natural Gas, NGLs and Oil Sales $ 793,673 $ 728,458 $ 1,007,381 (Loss) Gain on Commodity Derivative Instruments (141,021 ) 392,942 23,193 Purchased Gas Sales 43,256 14,450 8,999 Total Revenue 695,908 1,135,850 1,039,573 Lease Operating Expense 96,434 121,847 139,242 Production, Ad Valorem, and Other Fees 31,049 30,438 39,418 Transportation, Gathering and Compression 374,350 343,403 239,591 Purchased Gas Costs 42,717 10,721 7,251 Impairment of Exploration and Production Properties — 828,905 — Other Costs 14,519 10,120 22,718 DD&A 417,853 370,374 323,600 Total Costs 976,922 1,715,808 771,820 Pre-tax Operating Income / (Loss) (281,014 ) (579,958 ) 267,753 Income Taxes / (Benefit) (69,308 ) (250,220 ) 45,162 Results of Operations for Producing Activities excluding Corporate and Interest Costs $ (211,706 ) $ (329,738 ) $ 222,591 The following is production, average sales price and average production costs, excluding ad valorem and severance taxes, per unit of production: For the Years Ended December 31, 2016 2015 2014 Production (MMcfe) 394,387 328,657 235,714 Total average sales price before effects of financial settlements (per Mcfe) $ 2.01 $ 2.22 $ 4.27 Average effects of financial settlements (per Mcfe) $ 0.62 $ 0.60 $ 0.10 Total average sales price including effects of financial settlements (per Mcfe) $ 2.63 $ 2.82 $ 4.37 Average lifting costs, excluding ad valorem and severance taxes (per Mcfe) $ 0.24 $ 0.37 $ 0.59 During the years ended December 31, 2016 , 2015 and 2014 , we drilled 36.0 , 132.8 , and 180.3 net development wells, respectively. There were no net dry development wells in 2016 , 2015 , or 2014 . During the year ended December 31, 2016 , there were no net exploratory wells. During the years ended December 31, 2015 and 2014 , we drilled 2.5 and 8.5 net exploratory wells, respectively. There were no net dry exploratory wells in 2016 , 2015 , or 2014 . At December 31, 2016 , there were 15.0 net development wells and no exploratory wells that have been partially drilled but not turned in-line. Additionally there are 65.5 net developmental wells that are drilled but uncompleted and 3.0 net developmental wells and no net exploratory well that have been completed and are awaiting final tie-in to production. We are committed to provide 431.4 Bcf of gas under existing sales contracts or agreements over the course of the next four years. We expect to produce sufficient quantities from existing proved developed reserves to satisfy these commitments. Most of our development wells and proved acreage are located in Virginia, West Virginia and Pennsylvania. Some leases are beyond their primary term, but these leases are extended in accordance with their terms as long as certain drilling commitments or other term commitments are satisfied. The following table sets forth, at December 31, 2016 , the number of producing wells, developed acreage and undeveloped acreage: Gross Net(1) Producing Gas Wells (including gob wells) 17,314 12,846 Producing Oil Wells 189 30 Acreage Position: Proved Developed Acreage 549,816 541,282 Proved Undeveloped Acreage 34,467 30,038 Unproved Acreage 4,804,804 3,745,533 Total Acreage 5,389,087 4,316,853 ____________ (1) Net acres include acreage attributable to our working interests of the properties. Additional adjustments (either increases or decreases) may be required as we further develop title to and further confirm our rights with respect to our various properties in anticipation of development. We believe that our assumptions and methodology in this regard are reasonable. Proved Oil and Gas Reserves Quantities: Annually, the preparation of natural gas reserves estimates are completed in accordance with CONSOL Energy's prescribed internal control procedures, which include verification of input data into a gas reserves forecasting and economic evaluation software, as well as multi-functional management review. The input data verification includes reviews of the price and cost assumptions used in the economic model to determine the reserves. Also, the production volumes are reconciled between the system used to calculate the reserves and other accounting/measurement systems. The technical employee responsible for overseeing the preparation of the reserve estimates is a petroleum engineer with over 10 years of experience in the oil and gas industry. Our 2016 gas reserves results, which are reported in the Supplemental Gas Data year ended December 31, 2016 Form 10-K, were audited by Netherland, Sewell & Associates, Inc. The technical person primarily responsible for overseeing the audit of our reserves is a registered professional engineer in the state of Texas with over 15 years of experience in the oil and gas industry. The gas reserves estimates are as follows: Condensate Consolidated Natural Gas NGLs & Crude Oil Operations (MMcf) (Mbbls) (Mbbls) (MMcfe) Balance December 31, 2013 (a) 5,585,107 21,546 2,806 5,731,214 Revisions (b) (46,560 ) 40,363 3,756 218,168 Price Changes 15,512 — — 15,512 Extensions and Discoveries (c) 979,801 18,459 1,314 1,098,436 Production (216,260 ) (2,578 ) (664 ) (235,714 ) Balance December 31, 2014 (a) 6,317,600 77,790 7,212 6,827,616 Revisions (d) 1,052,978 45,993 6,662 1,368,909 Price Changes (2,866,123 ) (45,675 ) (3,208 ) (3,159,421 ) Extensions and Discoveries (e) 840,800 13,916 1,707 934,542 Production (285,041 ) (5,812 ) (1,458 ) (328,657 ) Balance December 31, 2015 (a) 5,060,214 86,212 10,915 5,642,989 Revisions (f) 21,280 (20,669 ) 481 (99,849 ) Price Changes (179,914 ) (1,647 ) (35 ) (190,009 ) Extensions and Discoveries (g) 643,688 10,960 1,783 720,146 Production (358,474 ) (5,119 ) (867 ) (394,387 ) Purchases of Reserves In-Place (h) 1,352,759 13,177 1,970 1,443,642 Sales of Reserves In-Place (h) (711,155 ) (22,382 ) (4,240 ) (870,884 ) Balance December 31, 2016 (a) 5,828,398 60,532 10,007 6,251,648 Proved developed reserves (i): December 31, 2014 2,979,906 32,405 4,061 3,198,706 December 31, 2015 3,310,894 59,196 5,180 3,697,152 December 31, 2016 3,478,464 30,666 3,474 3,683,302 Proved undeveloped reserves: December 31, 2014 3,337,694 45,385 3,151 3,628,910 December 31, 2015 1,749,320 27,016 5,736 1,945,837 December 31, 2016 2,349,934 29,866 6,536 2,568,346 __________ (a) Proved developed and proved undeveloped gas reserves are defined by SEC Rule 4.10(a) of Regulation S-X. Generally, these reserves would be commercially recovered under current economic conditions, operating methods and government regulations. CONSOL Energy cautions that there are many inherent uncertainties in estimating proved reserve quantities, projecting future production rates and timing of development expenditures. Proved oil and gas reserves are estimated quantities of natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions and government regulations. Proved developed reserves are reserves expected to be recovered through existing wells, with existing equipment and operating methods. (b) Revisions for 2014 are primarily due to efficiencies in operations and well optimization and had the total effect of positive revisions. Additionally, the 2014 revisions include a reclassification of ethane volumes from natural gas to NGLs. (c) Extensions and Discoveries in 2014 are primarily due to the addition of wells on our Marcellus and Utica Shale acreage. We also included Marcellus Shale wells which are more than one offset location away due to continued use of reliable technology. (d) The upward revisions in 2015 are attributable to efficiencies in operations and well performance. (e) Extensions and Discoveries in 2015 are due mainly to the high grading of locations which resulted in the addition of wells on our Marcellus and Utica Shale acreage more than one offset location away with continued use of reliable technology. (f) The net downward revisions for 2016 are primarily due to changes in plans related to future locations. (g) Extensions and Discoveries in 2016 are due to the addition of wells on our Marcellus and Utica Shale acreage more than one offset location away with continued use of reliable technology. (h) Purchases and Sales of Reserves In-Place in 2016 is the result of our fourth quarter realignment of the Marcellus Shale properties as part of dissolving our joint venture with Noble Energy. (i) Included in our proved developed reserves at December 31, 2016 are producing wells with negative undiscounted cash flows that represent 199.3 Bcfe of natural gas and equivalents which represents 3.2% of our total reserves quantities. These consist primarily of conventional wells and the company includes these wells in our reserves as we continue to produce the properties. For the Year Ended December 31, 2016 Proved Undeveloped Reserves (MMcfe) Beginning proved undeveloped reserves 1,945,837 Undeveloped reserves transferred to developed(a) (211,876 ) Disposition of reserves in place (199,401 ) Acquisition of reserves in place 547,680 Price Changes (188,066 ) Plan and other revisions (b) 4,906 Extension and discoveries (c) 669,266 Ending proved undeveloped reserves(d)(e) 2,568,346 _________ (a) During 2016 , various exploration and development drilling and evaluations were completed. Approximately, $ 58,694 of capital was spent in the year ended December 31, 2016 related to undeveloped reserves that were transferred to developed. (b) Plan and other revisions are due to high grading of locations. These changes along with upward revisions attributable to efficiencies in operations and well performance had the total affect of a positive revision. (c) Extensions and discoveries are due mainly to the high grading of locations which resulted in the addition of wells on our Marcellus and Utica Shale acreage more than one offset location away with continued use of reliable technology. (d) Included in proved undeveloped reserves at December 31, 2016 are approximately 215,861 MMcfe of reserves that have been reported for more than five years. These reserves specifically relate to GOB (a rubble zone formed in the cavity created by the extraction of coal) production due to a complex fracture being generated in the overburden strata above the mined seam. Mining operations take a significant amount of time and our GOB forecasts are consistent with the future plans of the Buchanan Mine that was sold in March 2016 to Coronado IV LLC (See Note 2 - Discontinued Operations for more information) with the rights to this gas being retained by the Company. Evidence also exists that supports the continual operation of the mine beyond the current plan, unless there was an extreme circumstance resulting from an external factor. These reasons constitute the specific circumstances that exist to continue recognizing these reserves for CONSOL Energy. (e) Included in proved undeveloped reserves at December 31, 2016 are 175 gross proved undeveloped locations that generate positive future net revenue but have negative present worth discounted at 10 percent as of December 31, 2016 , representing 58.9% of our total proved undeveloped reserves. Additionally, the 1,511.8 Bcfe of natural gas and equivalents attributable to these locations represent approximately 24.2% of our total proved reserves. The Company includes these well sites in its current drilling plans and currently intends to drill these sites as our economic modeling of these well locations generate positive future cash flows. At December 31, 2016 there were no wells pending the determination of proved reserves. The following table represents the capitalized exploratory well cost activity as indicated: December 31, 2016 2015 2014 Costs reclassified to wells, equipment and facilities based on the determination of proved reserves $ 40,917 $ 17,179 $ 27,453 Costs expensed due to determination of dry hole or abandonment of project $ — $ — $ 2,041 CONSOL Energy's proved natural gas reserves are located in the United States. |
Supplemental Quarterly Info (Un
Supplemental Quarterly Info (Unaudited) | 12 Months Ended |
Dec. 31, 2016 | |
Quarterly Financial Information [Text Block] | Supplemental Quarterly Information (unaudited): (Dollars in thousands, except per share data) Three Months Ended March 31, June 30, September 30, December 31, 2016 2016 2016 2016 Sales (A) $ 478,864 $ 235,251 $ 688,590 $ 390,398 Freight Revenue $ 13,110 $ 11,447 $ 9,392 $ 12,519 Costs and Expenses (B) $ 329,071 $ 369,392 $ 361,551 $ 415,224 Freight Expense $ 13,110 $ 11,447 $ 9,392 $ 12,519 (Loss) Income from Continuing Operations $ (43,291 ) $ (234,044 ) $ 62,568 $ (321,198 ) (Loss) Income from Discontinued Operations $ (53,167 ) $ (234,605 ) $ (34,975 ) $ 19,564 Net (Loss) Income Attributable to CONSOL Energy Shareholders $ (97,572 ) $ (469,828 ) $ 25,345 $ (306,047 ) Earnings Per Share Basic: (Loss) Income from Continuing Operations $ (0.19 ) $ (1.03 ) $ 0.26 $ (1.42 ) (Loss) Income from Discontinued Operations $ (0.24 ) $ (1.02 ) $ (0.15 ) $ 0.09 Net (Loss) Income $ (0.43 ) $ (2.05 ) $ 0.11 $ (1.33 ) Dilutive: (Loss) Income from Continuing Operations $ (0.19 ) $ (1.03 ) $ 0.26 $ (1.42 ) (Loss) Income from Discontinued Operations $ (0.24 ) $ (1.02 ) $ (0.15 ) $ 0.09 Net (Loss) Income $ (0.43 ) $ (2.05 ) $ 0.11 $ (1.33 ) Three Months Ended March 31, June 30, September 30, December 31, 2015 2015 2015 2015 Sales (A) $ 715,740 $ 503,825 $ 631,979 $ 602,772 Freight Revenue $ 5,018 $ 2,750 $ 2,436 $ 10,295 Costs and Expenses (B) $ 399,281 $ 351,200 $ 267,826 $ 243,267 Freight Expense $ 5,018 $ 2,750 $ 2,436 $ 10,295 Income (Loss) from Continuing Operations (C) $ 52,964 $ (577,884 ) $ 129,312 $ 45,342 Income (Loss) from Discontinued Operations $ 26,067 $ (25,417 ) $ (3,842 ) $ (11,017 ) Net Income (Loss) Attributable to CONSOL Energy Shareholders $ 79,031 $ (603,301 ) $ 118,980 $ 30,405 Earnings Per Share Basic: Income (Loss) from Continuing Operations $ 0.23 $ (2.52 ) $ 0.54 $ 0.18 Income (Loss) from Discontinued Operations $ 0.11 $ (0.12 ) $ (0.02 ) $ (0.05 ) Net Income (Loss) $ 0.34 $ (2.64 ) $ 0.52 $ 0.13 Dilutive: Income (Loss) from Continuing Operations $ 0.23 $ (2.52 ) $ 0.54 $ 0.18 Income (Loss) from Discontinued Operations $ 0.11 $ (0.12 ) $ (0.02 ) $ (0.05 ) Net Income (Loss) $ 0.34 $ (2.64 ) $ 0.52 $ 0.13 (A) Includes natural gas, NGLs, and oil sales; gain (loss) on commodity derivative instruments; coal sales; other outside sales; and purchased gas sales. (B) Includes exploration and production costs, coal costs and miscellaneous operating expense, excluding DD&A, other corporate expenses, selling, general and administrative, loss on debt extinguishment, interest expense and freight expense. (C) Includes an impairment of $828,905 that was recorded during the three months ended June 30, 2015 related to CONSOL Energy's exploration and production properties. The impairment primarily related to the write down of the Company's shallow oil and gas asset values including impairments to unproved property. See Note 1 - Significant Accounting Policies in Item 8 of this Form 10-K for additional information. |
Significant Accounting Policy (
Significant Accounting Policy (Policies) | 12 Months Ended |
Dec. 31, 2016 | |
Accounting Policies [Abstract] | |
Consolidation, Policy [Policy Text Block] | Basis of Consolidation: The Consolidated Financial Statements include the accounts of CONSOL Energy Inc, and its wholly owned and majority-owned and/or controlled subsidiaries, including certain variable interest entities that the Company is required to consolidate pursuant to the Consolidated topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification. The portion of these entities that is not owned by the Company is presented as non-controlling interest. Investments in business entities in which CONSOL Energy does not have control, but has the ability to exercise significant influence over the operating and financial policies, are accounted for under the equity method. All significant intercompany transactions and accounts have been eliminated in consolidation. Investments in oil and natural gas producing entities are accounted for under the proportionate consolidation method. |
Use of Estimates, Policy [Policy Text Block] | Use of Estimates: The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, as well as various disclosures. Actual results could differ from those estimates. The most significant estimates included in the preparation of the consolidated financial statements are related to other postretirement benefits, coal workers' pneumoconiosis, workers' compensation, salary retirement benefits, stock-based compensation, asset retirement obligations, deferred income tax assets and liabilities, contingencies and the values of coal and natural gas, NGLs, condensate and oil (collectively "natural gas") reserves. |
Cash and Cash Equivalents, Policy [Policy Text Block] | Cash and Cash Equivalents: Cash and cash equivalents include cash on hand and on deposit at banking institutions as well as all highly liquid short-term securities with original maturities of three months or less. |
Trade and Other Accounts Receivable, Policy [Policy Text Block] | Trade Accounts Receivable: Trade accounts receivable are recorded at the invoiced amount and do not bear interest. CONSOL Energy reserves for specific accounts receivable when it is probable that all or a part of an outstanding balance will not be collected, such as customer bankruptcies. Collectability is determined based on terms of sale, credit status of customers and various other circumstances. CONSOL Energy regularly reviews collectability and establishes or adjusts the allowance as necessary using the specific identification method. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote. Reserves for uncollectable amounts were not material in the periods presented. In addition, there were no material financing receivables with a contractual maturity greater than one year at December 31, 2016 or 2015 . |
Inventory, Policy [Policy Text Block] | Inventories: Inventories are stated at the lower of cost or net realizable value. The cost of coal inventories is determined by the first-in, first-out (FIFO) method. Coal inventory costs include labor, supplies, equipment costs, operating overhead, depreciation, depletion, amortization, and other related costs. The cost of supplies inventory is determined by the average cost method and includes operating and maintenance supplies to be used in the Company's E&P and coal operations. |
Property, Plant and Equipment, Policy [Policy Text Block] | Property, Plant and Equipment: CONSOL Energy uses the successful efforts method of accounting for natural gas producing activities. Costs of property acquisitions, successful exploratory, development wells and related support equipment and facilities are capitalized. Periodic valuation provisions for impairment of capitalized costs of unproved mineral interests are expensed. Costs of unsuccessful exploratory wells are expensed when such wells are determined to be non-productive, or if the determination cannot be made after finding sufficient quantities of reserves to continue evaluating the viability of the project. The costs of producing properties and mineral interests are amortized using the units-of-production method. Wells and related equipment and intangible drilling costs are also amortized on a units-of-production method. Units-of-production amortization rates are revised at least once per year, or more frequently if events and circumstances indicate an adjustment is necessary. Such revisions are accounted for prospectively as changes in accounting estimates. Property, plant and equipment is recorded at cost upon acquisition. Expenditures which extend the useful lives of existing plant and equipment are capitalized. Interest costs applicable to major asset additions are capitalized during the construction period. Costs of additional mine facilities required to maintain production after a mine reaches the production stage, generally referred to as “receding face costs,” are expensed as incurred; however, the costs of additional airshafts and new portals are capitalized. Planned major maintenance costs which do not extend the useful lives of existing plant and equipment are expensed as incurred. Coal exploration costs are expensed as incurred. Coal exploration costs include those incurred to ascertain existence, location, extent or quality of ore or minerals before beginning the development stage of the mine. Costs of developing new underground mines and certain underground expansion projects are capitalized. Underground development costs, which are costs incurred to make the mineral physically accessible, include costs to prepare property for shafts, driving main entries for ventilation, haulage, personnel, construction of airshafts, roof protection and other facilities. Airshafts and capitalized mine development associated with a coal reserve are amortized on a units-of-production basis as the coal is produced so that each ton of coal is assigned a portion of the unamortized costs. The Company employs this method to match costs with the related revenues realized in a particular period. Rates are updated when revisions to coal reserve estimates are made. Coal reserve estimates are reviewed when information becomes available that indicates a reserve change is needed, or at a minimum once per year. Any material effect from changes in estimates is disclosed in the period the change occurs. Amortization of development cost begins when the development phase is complete and the production phase begins. At an underground mine, the end of the development phase and the beginning of the production phase takes place when construction of the mine for economic extraction is substantially complete. Coal extracted during the development phase is incidental to the mine's production capacity and is not considered to shift the mine into the production phase. Coal reserves are controlled either through fee ownership or by lease. The duration of the leases vary; however, the lease terms are generally extended automatically through the exhaustion of economically recoverable reserves, as long as active mining continues. Coal interests held by lease provide the same rights as fee ownership for mineral extraction and are legally considered real property interests. Depletion of leased coal interests is computed using the units-of-productions method over proven and probable coal reserves. The Company also makes advance payments (advanced mining royalties) to lessors under certain lease agreements that are recoupable against future production, and it makes payments that are generally based upon a specified rate per ton or a percentage of gross realization from the sale of the coal. The Company evaluates its properties periodically for impairment issues or whenever events or circumstances indicate that the carrying amount may not be recoverable. Gas advance royalties are similar in nature to advance mining royalties and are evaluated periodically, or at a minimum once per year, for impairment issues or whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. Any revisions are accounted for prospectively as changes in accounting estimates. Depreciation of plant and equipment is calculated on the straight-line method over their estimated useful lives or lease terms, generally as follows: Years Buildings and improvements 10 to 45 Machinery and equipment 3 to 25 Leasehold improvements Life of Lease Costs to obtain coal lands are capitalized based on the cost at acquisition and are amortized using the units-of-production method over all estimated proven and probable coal reserve tons assigned and accessible to the mine. Proven and probable coal reserves are calculated on a clean coal ton equivalent, which excludes non-recoverable coal reserves and anticipated preparation plant processing refuse. Rates are updated when revisions to coal reserve estimates are made. Coal reserve estimates are reviewed when events and circumstances indicate a reserve change is needed, or at a minimum once a year. Amortization of coal interests begins when the coal reserve is produced. At an underground coal mine, a ton is considered produced once it reaches the surface area of the mine. Any material effect from changes in estimates is disclosed in the period the change occurs. Costs for purchased and internally developed software are expensed until it has been determined that the software will result in probable future economic benefits and management has committed to funding the project. Thereafter, all direct costs of materials and services incurred in developing or obtaining software, including certain payroll and benefit costs of employees associated with the project, are capitalized and amortized using the straight-line method over the estimated useful life which does not exceed seven years. The following assets are amortized using the units-of-production method. Amounts reflect properties where mining or drilling operations have not yet commenced and therefore, are not being amortized for the years ended December 31, 2016 and 2015 , respectively. |
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block] | Impairment of Long-lived Assets: Impairment of long-lived assets is recorded when indicators of impairment are present and the undiscounted cash flows estimated to be generated by those assets are less than the assets' carrying value. The carrying value of the assets is then reduced to its estimated fair value which is usually measured based on an estimate of future discounted cash flows. Impairment of equity investments is recorded when indicators of impairment are present and the estimated fair value of the investment is less than the assets' carrying value. |
Income Tax, Policy [Policy Text Block] | Income Taxes: Deferred tax assets and liabilities are recognized for the expected future tax consequences of events that have been recognized in CONSOL Energy's financial statements or tax returns. The provision for income taxes represents income taxes paid or payable for the current year and the change in deferred taxes, excluding the effects of acquisitions during the year. Deferred taxes result from differences between the financial and tax bases of CONSOL Energy's assets and liabilities and are adjusted for changes in tax rates and tax laws when changes are enacted. Valuation allowances are recorded to reduce deferred tax assets when it is more likely than not that a deferred tax benefit will not be realized. CONSOL Energy evaluates all tax positions taken on the state and federal tax filings to determine if the position is more likely than not to be sustained upon examination. For positions that do not meet the more likely than not to be sustained criteria, the Company determines, on a cumulative probability basis, the largest amount of benefit that is more likely than not to be realized upon ultimate settlement. A previously recognized tax position is reversed when it is subsequently determined that a tax position no longer meets the more likely than not threshold to be sustained. The evaluation of the sustainability of a tax position and the probable amount that is more likely than not is based on judgment, historical experience and on various other assumptions that the Company believes are reasonable under the circumstances. The results of these estimates, that are not readily apparent from other sources, form the basis for recognizing an uncertain tax position liability. Actual results could differ from those estimates upon subsequent resolution of identified matters. |
Pension and Other Postretirement Plans, Nonpension Benefits, Policy [Policy Text Block] | Postretirement Benefits Other Than Pensions: Postretirement benefit obligations established by the Coal Industry Retiree Health Benefit Act of 1992 (the Coal Act) are treated as a multi-employer plan which requires expense to be recorded for the associated obligations as payments are made. Postretirement benefits other than pensions, except for those established pursuant to the Coal Act, are accounted for in accordance with the Retirement Benefits Compensation and Non-retirement Postemployment Benefits Compensation Topics of the FASB Accounting Standards Codification, which requires employers to accrue the cost of such retirement benefits for the employees' active service periods. Such liabilities are determined on an actuarial basis and CONSOL Energy is primarily self-insured for these benefits. |
Postemployment Benefit Plans, Policy [Policy Text Block] | Pneumoconiosis Benefits and Workers' Compensation: CONSOL Energy is required by federal and state statutes to provide benefits to certain current and former totally disabled employees or their dependents for awards related to coal workers' pneumoconiosis. CONSOL Energy is also required by various state statutes to provide workers' compensation benefits for employees who sustain employment-related physical injuries or some types of occupational disease. Workers' compensation benefits include compensation for their disability, medical costs, and on some occasions, the cost of rehabilitation. CONSOL Energy is primarily self-insured for these benefits. Provisions for estimated benefits are determined on an actuarial basis. |
Asset Retirement Obligations, Policy [Policy Text Block] | : CONSOL Energy accrues for dismantling and removing costs of gas-related facilities, mine closing costs, perpetual water care costs, and surface reclamation using the accounting treatment prescribed by the Asset Retirement and Environmental Obligations Topic of the FASB Accounting Standards Codification. This topic requires the fair value of an asset retirement obligation be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. Accrued costs of dismantling and removing natural gas-related facilities, mine closing costs (including surface reclamation costs) and perpetual care costs are regularly reviewed by management and are revised for changes in future estimated costs and regulatory requirements. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. Amortization of the capitalized asset retirement cost is generally determined on a units-of-production basis. Accretion of the asset retirement obligation is recognized over time and generally will escalate over the life of the producing asset, typically as production declines. Accretion is included in Deprecation, Depletion and Amortization on the Consolidated Statements of Income. Asset retirement obligations primarily relate to the closure of natural gas wells and coal mines, which includes treatment of water and the reclamation of land upon exhaustion of coal and natural gas reserves. CONSOL Energy accrues for dismantling and removing costs of natural gas related facilities, mine closing costs, perpetual water care costs, and surface reclamation using the accounting treatment prescribed by the Asset Retirement and Environmental Obligations Topic of the FASB Accounting Standards Codification. CONSOL Energy recognizes capitalized asset retirement costs by increasing the carrying amount of related long-lived assets. The obligation for asset retirements is included in Gas Well Closing, Mine Closing and Other Accrued Liabilities on the Consolidated Balance Sheets. |
Pension and Other Postretirement Plans, Pensions, Policy [Policy Text Block] | Retirement Plans: |
Revenue Recognition, Policy [Policy Text Block] | Revenue Recognition: Revenues are recognized when title passes to the customers. For natural gas, NGL and oil sales, this occurs at the contractual point of delivery. For domestic coal sales, this generally occurs when coal is loaded at the mine, the preparation facility, or offsite storage locations. For export coal sales, this generally occurs when coal is loaded onto marine vessels at terminal locations. For terminal, land, and research and development, revenue is recognized generally as the service is provided to the customer. CONSOL Energy has operational natural gas-balancing agreements. These imbalance agreements are managed internally using the sales method of accounting. The sales method recognizes revenue when the gas is taken by the purchaser. CONSOL Energy sells natural gas to accommodate the delivery points of its customers. In general, this gas is purchased at market price and re-sold on the same day at market price less a small transaction fee. These matching buy/sell transactions include a legal right of offset of obligations and have been simultaneously entered into with the counterparty. These transactions qualify for netting under the Nonmonetary Transactions Topic of the FASB Accounting Standards Codification and are, therefore, recorded net within the Consolidated Statements of Income in the Purchased Gas Sales line. CONSOL Energy purchases natural gas produced by third-parties at market prices less a fee. The gas purchased from third-parties is then resold to end users or gas marketers at current market prices. These revenues and expenses are recorded gross as Purchased Gas Sales in the Consolidated Statements of Income. Purchased gas sales are recognized when title passes to the customer. Purchased gas costs are recognized when title passes to CONSOL Energy from the third-party. |
Revenue Recognition, Cargo and Freight, Policy [Policy Text Block] | Freight Revenue and Expense: Shipping and handling costs invoiced to coal customers and paid to third-party carriers are recorded as Freight-Outside Coal revenue and Freight Expense, respectively. |
Revenue Recognition, Services, Royalty Fees [Policy Text Block] | |
Commitments and Contingencies, Policy [Policy Text Block] | Contingencies: From time to time, CONSOL Energy, or its subsidiaries, is subject to various lawsuits and claims with respect to such matters as personal injury, wrongful death, damage to property, exposure to hazardous substances, governmental regulations (including environmental remediation), employment and contract disputes, and other claims and actions, arising out of the normal course of business. Liabilities are recorded when it is probable that obligations have been incurred and the amounts can be reasonably estimated. Estimates are developed through consultation with legal counsel involved in the defense of these matters and are based upon the nature of the lawsuit, progress of the case in court, view of legal counsel, prior experience in similar matters and management's intended response. Environmental liabilities are not discounted or reduced by possible recoveries from third-parties. Legal fees associated with defending these various lawsuits and claims are expensed when incurred. |
Share-based Compensation, Option and Incentive Plans Policy [Policy Text Block] | Stock-Based Compensation: Stock-based compensation expense for all stock-based compensation awards is based on the grant date fair value estimated in accordance with the provisions of the Stock Compensation Topic of the FASB Accounting Standards Codification. CONSOL Energy recognizes these compensation costs on a straight-line basis over the requisite service period of the award, which is generally the award's vesting term. See Note 17–Stock-Based Compensation for |
Earnings Per Share, Policy [Policy Text Block] | Earnings per Share: Basic earnings per share are computed by dividing net income attributable to CONSOL Energy Shareholders by the weighted average shares outstanding during the reporting period. Dilutive earnings per share are computed similarly to basic earnings per share, except that the weighted average shares outstanding are increased to include additional shares from stock options, performance stock options, restricted stock units and performance share units, if dilutive. The number of additional shares is calculated by assuming that outstanding stock options and performance share options were exercised, that outstanding restricted stock units and performance share units were released, and that the proceeds from such activities were used to acquire shares of common stock at the average market price during the reporting period. CONSOL Energy includes the impact of pro forma deferred tax assets in determining potential windfalls and shortfalls for purposes of calculating assumed proceeds under the treasury stock method. The table below sets forth the share-based awards that have been excluded from the computation of the diluted earnings per share because their effect would be anti-dilutive: |
Derivatives, Policy [Policy Text Block] | Accounting for Derivative Instruments: |
Significant Accounting Policies [Text Block] | SIGNIFICANT ACCOUNTING POLICIES: A summary of the significant accounting policies of CONSOL Energy Inc. and subsidiaries ("CONSOL Energy" or "the Company") is presented below. These, together with the other notes that follow, are an integral part of the Consolidated Financial Statements. Basis of Consolidation: The Consolidated Financial Statements include the accounts of CONSOL Energy Inc, and its wholly owned and majority-owned and/or controlled subsidiaries, including certain variable interest entities that the Company is required to consolidate pursuant to the Consolidated topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification. The portion of these entities that is not owned by the Company is presented as non-controlling interest. Investments in business entities in which CONSOL Energy does not have control, but has the ability to exercise significant influence over the operating and financial policies, are accounted for under the equity method. All significant intercompany transactions and accounts have been eliminated in consolidation. Investments in oil and natural gas producing entities are accounted for under the proportionate consolidation method. Discontinued Operations: Businesses divested are classified in the Consolidated Financial Statements as either discontinued operations or held for sale when the provision of Accounting Standards Codification (ASC) Topic 205 or ASC Topic 360 are met. For businesses classified as discontinued operations, the balance sheet amounts and results of operations are reclassified from their historical presentation to assets and liabilities of discontinued operations on the Consolidated Balance Sheets and to discontinued operations on the Consolidated Statements of Income and Cash Flows for all periods presented. The gains or losses associated with these divested businesses are recorded in discontinued operations on the Consolidated Statements of Income. The disclosures outside of Note 2- Discontinued Operations, for all periods presented, in the accompanying notes generally do not include the assets, liabilities, or operating results of businesses classified as discontinued operations. Use of Estimates: The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, as well as various disclosures. Actual results could differ from those estimates. The most significant estimates included in the preparation of the consolidated financial statements are related to other postretirement benefits, coal workers' pneumoconiosis, workers' compensation, salary retirement benefits, stock-based compensation, asset retirement obligations, deferred income tax assets and liabilities, contingencies and the values of coal and natural gas, NGLs, condensate and oil (collectively "natural gas") reserves. Cash and Cash Equivalents: Cash and cash equivalents include cash on hand and on deposit at banking institutions as well as all highly liquid short-term securities with original maturities of three months or less. Trade Accounts Receivable: Trade accounts receivable are recorded at the invoiced amount and do not bear interest. CONSOL Energy reserves for specific accounts receivable when it is probable that all or a part of an outstanding balance will not be collected, such as customer bankruptcies. Collectability is determined based on terms of sale, credit status of customers and various other circumstances. CONSOL Energy regularly reviews collectability and establishes or adjusts the allowance as necessary using the specific identification method. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote. Reserves for uncollectable amounts were not material in the periods presented. In addition, there were no material financing receivables with a contractual maturity greater than one year at December 31, 2016 or 2015 . Inventories: Inventories are stated at the lower of cost or net realizable value. The cost of coal inventories is determined by the first-in, first-out (FIFO) method. Coal inventory costs include labor, supplies, equipment costs, operating overhead, depreciation, depletion, amortization, and other related costs. The cost of supplies inventory is determined by the average cost method and includes operating and maintenance supplies to be used in the Company's E&P and coal operations. Property, Plant and Equipment: CONSOL Energy uses the successful efforts method of accounting for natural gas producing activities. Costs of property acquisitions, successful exploratory, development wells and related support equipment and facilities are capitalized. Periodic valuation provisions for impairment of capitalized costs of unproved mineral interests are expensed. Costs of unsuccessful exploratory wells are expensed when such wells are determined to be non-productive, or if the determination cannot be made after finding sufficient quantities of reserves to continue evaluating the viability of the project. The costs of producing properties and mineral interests are amortized using the units-of-production method. Wells and related equipment and intangible drilling costs are also amortized on a units-of-production method. Units-of-production amortization rates are revised at least once per year, or more frequently if events and circumstances indicate an adjustment is necessary. Such revisions are accounted for prospectively as changes in accounting estimates. Property, plant and equipment is recorded at cost upon acquisition. Expenditures which extend the useful lives of existing plant and equipment are capitalized. Interest costs applicable to major asset additions are capitalized during the construction period. Costs of additional mine facilities required to maintain production after a mine reaches the production stage, generally referred to as “receding face costs,” are expensed as incurred; however, the costs of additional airshafts and new portals are capitalized. Planned major maintenance costs which do not extend the useful lives of existing plant and equipment are expensed as incurred. Coal exploration costs are expensed as incurred. Coal exploration costs include those incurred to ascertain existence, location, extent or quality of ore or minerals before beginning the development stage of the mine. Costs of developing new underground mines and certain underground expansion projects are capitalized. Underground development costs, which are costs incurred to make the mineral physically accessible, include costs to prepare property for shafts, driving main entries for ventilation, haulage, personnel, construction of airshafts, roof protection and other facilities. Airshafts and capitalized mine development associated with a coal reserve are amortized on a units-of-production basis as the coal is produced so that each ton of coal is assigned a portion of the unamortized costs. The Company employs this method to match costs with the related revenues realized in a particular period. Rates are updated when revisions to coal reserve estimates are made. Coal reserve estimates are reviewed when information becomes available that indicates a reserve change is needed, or at a minimum once per year. Any material effect from changes in estimates is disclosed in the period the change occurs. Amortization of development cost begins when the development phase is complete and the production phase begins. At an underground mine, the end of the development phase and the beginning of the production phase takes place when construction of the mine for economic extraction is substantially complete. Coal extracted during the development phase is incidental to the mine's production capacity and is not considered to shift the mine into the production phase. Coal reserves are controlled either through fee ownership or by lease. The duration of the leases vary; however, the lease terms are generally extended automatically through the exhaustion of economically recoverable reserves, as long as active mining continues. Coal interests held by lease provide the same rights as fee ownership for mineral extraction and are legally considered real property interests. Depletion of leased coal interests is computed using the units-of-productions method over proven and probable coal reserves. The Company also makes advance payments (advanced mining royalties) to lessors under certain lease agreements that are recoupable against future production, and it makes payments that are generally based upon a specified rate per ton or a percentage of gross realization from the sale of the coal. The Company evaluates its properties periodically for impairment issues or whenever events or circumstances indicate that the carrying amount may not be recoverable. Gas advance royalties are similar in nature to advance mining royalties and are evaluated periodically, or at a minimum once per year, for impairment issues or whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. Any revisions are accounted for prospectively as changes in accounting estimates. Depreciation of plant and equipment is calculated on the straight-line method over their estimated useful lives or lease terms, generally as follows: Years Buildings and improvements 10 to 45 Machinery and equipment 3 to 25 Leasehold improvements Life of Lease Costs to obtain coal lands are capitalized based on the cost at acquisition and are amortized using the units-of-production method over all estimated proven and probable coal reserve tons assigned and accessible to the mine. Proven and probable coal reserves are calculated on a clean coal ton equivalent, which excludes non-recoverable coal reserves and anticipated preparation plant processing refuse. Rates are updated when revisions to coal reserve estimates are made. Coal reserve estimates are reviewed when events and circumstances indicate a reserve change is needed, or at a minimum once a year. Amortization of coal interests begins when the coal reserve is produced. At an underground coal mine, a ton is considered produced once it reaches the surface area of the mine. Any material effect from changes in estimates is disclosed in the period the change occurs. Costs for purchased and internally developed software are expensed until it has been determined that the software will result in probable future economic benefits and management has committed to funding the project. Thereafter, all direct costs of materials and services incurred in developing or obtaining software, including certain payroll and benefit costs of employees associated with the project, are capitalized and amortized using the straight-line method over the estimated useful life which does not exceed seven years. Capitalization of Interest: Interest costs associated with the development of significant properties and projects are capitalized until the project is substantially complete and ready for its intended use. A weighted average cost of borrowing rate is used. For the years ended December 31, 2016, 2015, and 2014, capitalized interest totaled $1,467 , $2,509 and $13,573 , respectively. Impairment of Long-lived Assets: Impairment of long-lived assets is recorded when indicators of impairment are present and the undiscounted cash flows estimated to be generated by those assets are less than the assets' carrying value. The carrying value of the assets is then reduced to its estimated fair value which is usually measured based on an estimate of future discounted cash flows. Impairment of equity investments is recorded when indicators of impairment are present and the estimated fair value of the investment is less than the assets' carrying value. Impairment of Proved Properties CONSOL Energy performs a quantitative annual impairment test, during the fourth quarter of each year, over proved properties using the published NYMEX forward prices, timing, methods and other assumptions consistent with historical periods. During interim periods, management updates these annual tests whenever events or changes in circumstances indicate that a property’s carrying amount may not be recoverable. Impairment tests require that the Company first compare future undiscounted cash flows by asset group to their respective carrying values. If the carrying amount exceeds the estimated undiscounted future cash flows, a reduction of the carrying amount of the natural gas properties to their estimated fair values is required, which is determined based on discounted cash flow techniques using a market-specific weighted average cost of capital. During the year ended December 31, 2015 , certain of the Company’s proved properties, primarily shallow oil and gas assets, failed the undiscounted cash flow portion of the test. After performing the discounted cash flow portion of the test, CONSOL Energy recorded an impairment of $824,742 , included in Impairment of Exploration and Production Properties in the Consolidated Statements of Income. Valuation of the impaired assets is a Level 3 measurement as it incorporates significant unobservable inputs, such as future production levels and operating costs, within the discounted cash flow analysis. The impairment related to approximately 95% of the Company’s shallow oil and gas assets in West Virginia and Pennsylvania. There were no other additional impairments related to proved properties in the year ended December 31, 2015. There were no such impairments for the years ended December 31, 2016 or 2014. Impairment of Unproved Properties CONSOL Energy evaluates capitalized costs of unproved gas properties for recoverability on a prospective basis. Indicators of potential impairment include potential shifts in business strategy, overall economic factors and historical experience. If it is determined that the properties will not yield proved reserves, the related costs are expensed in the period the determination is made. For the year ended December 31, 2015 , unproved property impairments relating to the determination that the properties will not yield proved reserves were $4,163 and are included in Impairment of Exploration and Production Properties in the Consolidated Statements of Income. Valuation of the impaired assets is a Level 3 measurement as it incorporates significant unobservable inputs, such as future production levels and operating costs, within the discounted cash flow analysis. This impairment primarily related to the court ruling in June 2015 in the state of New York that officially bans hydraulic fracturing. There were no other additional impairments related to unproved properties in the year ended December 31, 2015. There were no such impairments for the years ended December 31, 2016 and 2014. Exploration expense, which is associated primarily with lease expirations, was $ 14,519 , $ 10,120 and $ 23,355 for the years ended December 31, 2016 , 2015 and 2014 , respectively, and is included in Exploration and Production Related Other Costs in the Consolidated Statements of Income. Income Taxes: Deferred tax assets and liabilities are recognized for the expected future tax consequences of events that have been recognized in CONSOL Energy's financial statements or tax returns. The provision for income taxes represents income taxes paid or payable for the current year and the change in deferred taxes, excluding the effects of acquisitions during the year. Deferred taxes result from differences between the financial and tax bases of CONSOL Energy's assets and liabilities and are adjusted for changes in tax rates and tax laws when changes are enacted. Valuation allowances are recorded to reduce deferred tax assets when it is more likely than not that a deferred tax benefit will not be realized. CONSOL Energy evaluates all tax positions taken on the state and federal tax filings to determine if the position is more likely than not to be sustained upon examination. For positions that do not meet the more likely than not to be sustained criteria, the Company determines, on a cumulative probability basis, the largest amount of benefit that is more likely than not to be realized upon ultimate settlement. A previously recognized tax position is reversed when it is subsequently determined that a tax position no longer meets the more likely than not threshold to be sustained. The evaluation of the sustainability of a tax position and the probable amount that is more likely than not is based on judgment, historical experience and on various other assumptions that the Company believes are reasonable under the circumstances. The results of these estimates, that are not readily apparent from other sources, form the basis for recognizing an uncertain tax position liability. Actual results could differ from those estimates upon subsequent resolution of identified matters. Postretirement Benefits Other Than Pensions: Postretirement benefit obligations established by the Coal Industry Retiree Health Benefit Act of 1992 (the Coal Act) are treated as a multi-employer plan which requires expense to be recorded for the associated obligations as payments are made. Postretirement benefits other than pensions, except for those established pursuant to the Coal Act, are accounted for in accordance with the Retirement Benefits Compensation and Non-retirement Postemployment Benefits Compensation Topics of the FASB Accounting Standards Codification, which requires employers to accrue the cost of such retirement benefits for the employees' active service periods. Such liabilities are determined on an actuarial basis and CONSOL Energy is primarily self-insured for these benefits. Differences between actual and expected results or changes in the value of obligations are recognized through Other Comprehensive Income. Pneumoconiosis Benefits and Workers' Compensation: CONSOL Energy is required by federal and state statutes to provide benefits to certain current and former totally disabled employees or their dependents for awards related to coal workers' pneumoconiosis. CONSOL Energy is also required by various state statutes to provide workers' compensation benefits for employees who sustain employment-related physical injuries or some types of occupational disease. Workers' compensation benefits include compensation for their disability, medical costs, and on some occasions, the cost of rehabilitation. CONSOL Energy is primarily self-insured for these benefits. Provisions for estimated benefits are determined on an actuarial basis. Gas Well Closing and Mine Closing Costs: CONSOL Energy accrues for dismantling and removing costs of gas-related facilities, mine closing costs, perpetual water care costs, and surface reclamation using the accounting treatment prescribed by the Asset Retirement and Environmental Obligations Topic of the FASB Accounting Standards Codification. This topic requires the fair value of an asset retirement obligation be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. Accrued costs of dismantling and removing natural gas-related facilities, mine closing costs (including surface reclamation costs) and perpetual care costs are regularly reviewed by management and are revised for changes in future estimated costs and regulatory requirements. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. Amortization of the capitalized asset retirement cost is generally determined on a units-of-production basis. Accretion of the asset retirement obligation is recognized over time and generally will escalate over the life of the producing asset, typically as production declines. Accretion is included in Deprecation, Depletion and Amortization on the Consolidated Statements of Income. Asset retirement obligations primarily relate to the closure of natural gas wells and coal mines, which includes treatment of water and the reclamation of land upon exhaustion of coal and natural gas reserves. Subsidence: Subsidence occurs when there is sinking or shifting of the ground surface due to the removal of underlying coal. Areas affected may include, although are not limited to, streams, property, roads, pipelines and other land and surface structures. Total estimated subsidence claims are recognized in the period when the related coal has been extracted and are included in Operating and Other Costs on the Consolidated Statements of Income and Other Accrued Liabilities on the Consolidated Balance Sheets. On occasion, CONSOL Energy prepays the estimated damages prior to undermining the property, in return for a release of liability. Prepayments are included as assets and either recognized as Prepaid Expenses or in Other Assets on the Consolidated Balance Sheets if the payment is made less than or greater than one year, respectively, prior to undermining the property. Retirement Plans: CONSOL Energy has non-contributory defined benefit retirement plans. Effective December 31, 2015, CONSOL's qualified defined benefit retirement plans have been frozen. The benefits for these plans are based primarily on years of service and employees' pay. These plans are accounted for using the guidance outlined in the Compensation - Retirement Benefits Topic of the FASB Accounting Standards Codification. The cost of these retiree benefits are recognized over the employees' service periods. CONSOL Energy uses actuarial methods and assumptions in the valuation of defined benefit obligations and the determination of expense. Differences between actual and expected results or changes in the value of obligations and plan assets are recognized through Other Comprehensive Income. Revenue Recognition: Revenues are recognized when title passes to the customers. For natural gas, NGL and oil sales, this occurs at the contractual point of delivery. For domestic coal sales, this generally occurs when coal is loaded at the mine, the preparation facility, or offsite storage locations. For export coal sales, this generally occurs when coal is loaded onto marine vessels at terminal locations. For terminal, land, and research and development, revenue is recognized generally as the service is provided to the customer. CONSOL Energy has operational natural gas-balancing agreements. These imbalance agreements are managed internally using the sales method of accounting. The sales method recognizes revenue when the gas is taken by the purchaser. CONSOL Energy sells natural gas to accommodate the delivery points of its customers. In general, this gas is purchased at market price and re-sold on the same day at market price less a small transaction fee. These matching buy/sell transactions include a legal right of offset of obligations and have been simultaneously entered into with the counterparty. These transactions qualify for netting under the Nonmonetary Transactions Topic of the FASB Accounting Standards Codification and are, therefore, recorded net within the Consolidated Statements of Income in the Purchased Gas Sales line. CONSOL Energy purchases natural gas produced by third-parties at market prices less a fee. The gas purchased from third-parties is then resold to end users or gas marketers at current market prices. These revenues and expenses are recorded gross as Purchased Gas Sales in the Consolidated Statements of Income. Purchased gas sales are recognized when title passes to the customer. Purchased gas costs are recognized when title passes to CONSOL Energy from the third-party. Freight Revenue and Expense: Shipping and handling costs invoiced to coal customers and paid to third-party carriers are recorded as Freight-Outside Coal revenue and Freight Expense, respectively. Contingencies: From time to time, CONSOL Energy, or its subsidiaries, is subject to various lawsuits and claims with respect to such matters as personal injury, wrongful death, damage to property, exposure to hazardous substances, governmental regulations (including environmental remediation), employment and contract disputes, and other claims and actions, arising out of the normal course of business. Liabilities are recorded when it is probable that obligations have been incurred and the amounts can be reasonably estimated. Estimates are developed through consultation with legal counsel involved in the defense of these matters and are based upon the nature of the lawsuit, progress of the case in court, view of legal counsel, prior experience in similar matters and management's intended response. Environmental liabilities are not discounted or reduced by possible recoveries from third-parties. Legal fees associated with defending these various lawsuits and claims are expensed when incurred. Stock-Based Compensation: Stock-based compensation expense for all stock-based compensation awards is based on the grant date fair value estimated in accordance with the provisions of the Stock Compensation Topic of the FASB Accounting Standards Codification. CONSOL Energy recognizes these compensation costs on a straight-line basis over the requisite service period of the award, which is generally the award's vesting term. See Note 17–Stock-Based Compensation for more information. Earnings per Share: Basic earnings per share are computed by dividing net income attributable to CONSOL Energy Shareholders by the weighted average shares outstanding during the reporting period. Dilutive earnings per share are computed similarly to basic earnings per share, except that the weighted average shares outstanding are increased to include additional shares from stock options, performance stock options, restricted stock units and performance share units, if dilutive. The number of additional shares is calculated by assuming that outstanding stock options and performance share options were exercised, that outstanding restricted stock units and performance share units were released, and that the proceeds from such activities were used to acquire shares of common stock at the average market price during the reporting period. CONSOL Energy includes the impact of pro forma deferred tax assets in determining potential windfalls and shortfalls for purposes of calculating assumed proceeds under the treasury stock method. The table below sets forth the share-based awards that have been excluded from the computation of the diluted earnings per share because their effect would be anti-dilutive: For the Years Ended December 31, 2016 2015 2014 Anti-Dilutive Options 6,208,813 3,621,002 358,731 Anti-Dilutive Restricted Stock Units 663,003 1,375,659 — Anti-Dilutive Performance Share Units 2,400,326 113,531 — Anti-Dilutive Performance Share Options 802,804 802,804 — 10,074,946 5,912,996 358,731 The computations for basic and dilutive earnings per share are as follows: For the Years Ended December 31, 2016 2015 2014 Numerator: (Loss) Income from Continuing Operations $ (535,965 ) $ (350,266 ) $ 164,947 Less: Net Income Attributable to Noncontrolling Interest 8,954 10,410 — Net (Loss) Income from Continuing Operations attributable to CONSOL Energy Shareholders $ (544,919 ) $ (360,676 ) $ 164,947 Loss from Discontinued Operations $ (303,183 ) $ (14,209 ) $ (1,857 ) Net (Loss) Income Attributable to CONSOL Energy Shareholders $ (848,102 ) $ (374,885 ) $ 163,090 Denominator: Weighted-average shares of common stock outstanding 229,387,403 229,186,125 229,994,407 Effect of dilutive shares — — 1,585,871 Weighted-average diluted shares of common stock outstanding 229,387,403 229,186,125 231,580,278 (Loss) Earnings Per Share: Basic (Continuing Operations) $ (2.38 ) $ (1.57 ) $ 0.72 Basic (Discontinued Operations) (1.32 ) (0.07 ) (0.01 ) Total Basic $ (3.70 ) $ (1.64 ) $ 0.71 Dilutive (Continuing Operations) $ (2.38 ) $ (1.57 ) $ 0.71 Dilutive (Discontinued Operations) (1.32 ) (0.07 ) (0.01 ) Total Dilutive $ (3.70 ) $ (1.64 ) $ 0.70 Shares of common stock outstanding were as follows: 2016 2015 2014 Balance, Beginning of Year 229,054,236 230,265,463 229,145,736 Issuance Related to Stock-Based Compensation (1) 388,772 1,001,873 1,119,727 Retirement of Common Stock (2) — (2,213,100 ) — Balance, End of Year 229,443,008 229,054,236 230,265,463 (1) See Note 17–Stock-Based Compensation for additional information. (2) See Note 5–Stock Repurchase for additional information. Other Comprehensive Loss: Changes in Accumulated Other Comprehensive Loss by component, net of tax, were as follows: Gains on Cash Flow Hedges Postretirement Benefits Total Balance at December 31, 2015 $ 43,470 $ (359,068 ) $ (315,598 ) Other Comprehensive Loss before Reclassifications — (61,730 ) (61,730 ) Amounts Reclassified from Accumulated Other Comprehensive Loss (43,470 ) 28,504 (14,966 ) Current Period Other Comprehensive Loss (43,470 ) (33,226 ) (76,696 ) Less: Other Comprehensive Income Attributable to Non-Controlling Interest — 262 262 Balance at December 31, 2016 $ — $ (392,556 ) $ (392,556 ) The following table shows the reclassification of adjustments out of Accumulated Other Comprehensive Loss: For the Years Ended December 31, 2016 2015 2014 Derivative Instruments (Note 21) Natural Gas Price Swaps and Options $ (68,481 ) $ (123,105 ) $ (28,753 ) Tax Expense 25,011 45,054 10,465 Net of Tax $ (43,470 ) $ (78,051 ) $ (18,288 ) Actuarially Determined Long-Term Liability Adjustments* (Note 14 and Note 15) Amortization of Prior Service Costs $ (590 ) $ (336,993 ) $ (22,381 ) Recognized Net Actuarial Loss 23,857 119,222 46,155 Curtailment Loss (Gain) — 5 (36,182 ) Settlement Loss 22,196 19,053 29,095 Total 45,463 (198,713 ) 16,687 Tax (Benefit) Expense (16,959 ) 74,687 (6,139 ) Net of Tax $ 28,504 $ (124,026 ) $ 10,548 *Excludes amounts related to the remeasurement of the Actuarially Determined Long-Term Liabilities for the years ended December 31, 2016 , December 31, 2015 and December 31, 2014 . Accounting for Derivative Instruments: CONSOL Energy enters into financial derivative instruments to manage its exposure to commodity price volatility. The derivatives are accounted for as an asset or a liability in the accompanying Consolidated Balance Sheets at their fair value using “Level Two” inputs, which is further defined in Note 20 - Fair Value of Financial Instruments. Changes in the fair values of derivatives are recorded in earnings unless special hedge accounting criteria are met. For derivatives designated as cash flow hedges, the effective portions of changes in the fair values of the derivatives are reported in Other Comprehensive Income or Loss (OCI) on the Consolidated Balance Sheets, net of tax, and reclassified into Gain (Loss) on Commodity Derivative Instruments on the Consolidated Statements of Income in the same period or periods in which the forecasted transactions affect earnings. Any ineffective portion of a hedge is recognized in earnings in the current period. CONSOL Energy de-designated all of its cash flow hedges on December 31, 2014 and accounts for all existing and future natural gas and NGL commodity hedges on a mark-to-market basis, and records changes in fair value in current period earnings. In connection with this de-designation, CONSOL Energy froze the balances recorded in Accumulated Other Comprehensive Income at December 31, 2014 and reclassified balances to earnings as the underlying physical transactions occurred. As of December 31, 2016, all gains deferred in OCI have been recognized in earnings. All of CONSOL Energy’s derivative instruments are subject to master netting arrangements with its counterparties, none of which currently require CONSOL Energy to post collateral for any of its hedges. However, as stated in the counterparty master agreements, if CONSOL Energy's obligations with one of its counterparties cease to be secured on the same basis as similar obligations with the other lenders under the credit facility, CONSOL Energy would be required to post collateral for hedges that are in a liability position in excess of defined thresholds. Each of CONSOL Energy's counterparty master agreements allows, in the event of default, the ability to elect early termination of outstanding contracts. If early termination is elected, CONSOL Energy and the applicable counterparty would net settle all open hedge positions. CONSOL Energy is exposed to credit risk in the event of non-performance by counterparties, whose creditworthiness is subject to continuing review. Historically, CONSOL Energy has not exp |
Mine Closing, Reclamation, and
Mine Closing, Reclamation, and Gas Well Closing ARO Accounting Policy (Policies) | 12 Months Ended |
Dec. 31, 2016 | |
MINE CLOSING, RECLAMATION & GAS WELL CLOSING [Abstract] | |
Asset Retirement Obligation Disclosure [Text Block] | NOTE 7—GAS WELL CLOSING and MINE CLOSING: CONSOL Energy accrues for dismantling and removing costs of natural gas related facilities, mine closing costs, perpetual water care costs, and surface reclamation using the accounting treatment prescribed by the Asset Retirement and Environmental Obligations Topic of the FASB Accounting Standards Codification. CONSOL Energy recognizes capitalized asset retirement costs by increasing the carrying amount of related long-lived assets. The obligation for asset retirements is included in Gas Well Closing, Mine Closing and Other Accrued Liabilities on the Consolidated Balance Sheets. The reconciliation of changes in the asset retirement obligations at December 31, 2016 and 2015 is as follows: As of December 31, 2016 2015 Balance at beginning of period $ 429,967 $ 454,832 Accretion expense 23,924 32,438 Payments (15,882 ) (18,033 ) Revisions in estimated cash flows 36,320 (33,984 ) Other (785 ) (5,286 ) Balance at end of period $ 473,544 $ 429,967 For the year ended December 31, 2015, Other includes ($2,133) related to the disposition of two Perpetual Care sites as part of the WAE sale (see Note 3 - Acquisitions and Dispositions for more information) and ($2,355) related to the disposition of a non-producing mine. |
Asset Retirement Obligations, Policy [Policy Text Block] | : CONSOL Energy accrues for dismantling and removing costs of gas-related facilities, mine closing costs, perpetual water care costs, and surface reclamation using the accounting treatment prescribed by the Asset Retirement and Environmental Obligations Topic of the FASB Accounting Standards Codification. This topic requires the fair value of an asset retirement obligation be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. Accrued costs of dismantling and removing natural gas-related facilities, mine closing costs (including surface reclamation costs) and perpetual care costs are regularly reviewed by management and are revised for changes in future estimated costs and regulatory requirements. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. Amortization of the capitalized asset retirement cost is generally determined on a units-of-production basis. Accretion of the asset retirement obligation is recognized over time and generally will escalate over the life of the producing asset, typically as production declines. Accretion is included in Deprecation, Depletion and Amortization on the Consolidated Statements of Income. Asset retirement obligations primarily relate to the closure of natural gas wells and coal mines, which includes treatment of water and the reclamation of land upon exhaustion of coal and natural gas reserves. CONSOL Energy accrues for dismantling and removing costs of natural gas related facilities, mine closing costs, perpetual water care costs, and surface reclamation using the accounting treatment prescribed by the Asset Retirement and Environmental Obligations Topic of the FASB Accounting Standards Codification. CONSOL Energy recognizes capitalized asset retirement costs by increasing the carrying amount of related long-lived assets. The obligation for asset retirements is included in Gas Well Closing, Mine Closing and Other Accrued Liabilities on the Consolidated Balance Sheets. |
Property, Plant and Equipment P
Property, Plant and Equipment PP&E Accounting Policy (Policies) | 12 Months Ended |
Dec. 31, 2016 | |
Property, Plant and Equipment [Abstract] | |
Property, Plant and Equipment, Policy [Policy Text Block] | Property, Plant and Equipment: CONSOL Energy uses the successful efforts method of accounting for natural gas producing activities. Costs of property acquisitions, successful exploratory, development wells and related support equipment and facilities are capitalized. Periodic valuation provisions for impairment of capitalized costs of unproved mineral interests are expensed. Costs of unsuccessful exploratory wells are expensed when such wells are determined to be non-productive, or if the determination cannot be made after finding sufficient quantities of reserves to continue evaluating the viability of the project. The costs of producing properties and mineral interests are amortized using the units-of-production method. Wells and related equipment and intangible drilling costs are also amortized on a units-of-production method. Units-of-production amortization rates are revised at least once per year, or more frequently if events and circumstances indicate an adjustment is necessary. Such revisions are accounted for prospectively as changes in accounting estimates. Property, plant and equipment is recorded at cost upon acquisition. Expenditures which extend the useful lives of existing plant and equipment are capitalized. Interest costs applicable to major asset additions are capitalized during the construction period. Costs of additional mine facilities required to maintain production after a mine reaches the production stage, generally referred to as “receding face costs,” are expensed as incurred; however, the costs of additional airshafts and new portals are capitalized. Planned major maintenance costs which do not extend the useful lives of existing plant and equipment are expensed as incurred. Coal exploration costs are expensed as incurred. Coal exploration costs include those incurred to ascertain existence, location, extent or quality of ore or minerals before beginning the development stage of the mine. Costs of developing new underground mines and certain underground expansion projects are capitalized. Underground development costs, which are costs incurred to make the mineral physically accessible, include costs to prepare property for shafts, driving main entries for ventilation, haulage, personnel, construction of airshafts, roof protection and other facilities. Airshafts and capitalized mine development associated with a coal reserve are amortized on a units-of-production basis as the coal is produced so that each ton of coal is assigned a portion of the unamortized costs. The Company employs this method to match costs with the related revenues realized in a particular period. Rates are updated when revisions to coal reserve estimates are made. Coal reserve estimates are reviewed when information becomes available that indicates a reserve change is needed, or at a minimum once per year. Any material effect from changes in estimates is disclosed in the period the change occurs. Amortization of development cost begins when the development phase is complete and the production phase begins. At an underground mine, the end of the development phase and the beginning of the production phase takes place when construction of the mine for economic extraction is substantially complete. Coal extracted during the development phase is incidental to the mine's production capacity and is not considered to shift the mine into the production phase. Coal reserves are controlled either through fee ownership or by lease. The duration of the leases vary; however, the lease terms are generally extended automatically through the exhaustion of economically recoverable reserves, as long as active mining continues. Coal interests held by lease provide the same rights as fee ownership for mineral extraction and are legally considered real property interests. Depletion of leased coal interests is computed using the units-of-productions method over proven and probable coal reserves. The Company also makes advance payments (advanced mining royalties) to lessors under certain lease agreements that are recoupable against future production, and it makes payments that are generally based upon a specified rate per ton or a percentage of gross realization from the sale of the coal. The Company evaluates its properties periodically for impairment issues or whenever events or circumstances indicate that the carrying amount may not be recoverable. Gas advance royalties are similar in nature to advance mining royalties and are evaluated periodically, or at a minimum once per year, for impairment issues or whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. Any revisions are accounted for prospectively as changes in accounting estimates. Depreciation of plant and equipment is calculated on the straight-line method over their estimated useful lives or lease terms, generally as follows: Years Buildings and improvements 10 to 45 Machinery and equipment 3 to 25 Leasehold improvements Life of Lease Costs to obtain coal lands are capitalized based on the cost at acquisition and are amortized using the units-of-production method over all estimated proven and probable coal reserve tons assigned and accessible to the mine. Proven and probable coal reserves are calculated on a clean coal ton equivalent, which excludes non-recoverable coal reserves and anticipated preparation plant processing refuse. Rates are updated when revisions to coal reserve estimates are made. Coal reserve estimates are reviewed when events and circumstances indicate a reserve change is needed, or at a minimum once a year. Amortization of coal interests begins when the coal reserve is produced. At an underground coal mine, a ton is considered produced once it reaches the surface area of the mine. Any material effect from changes in estimates is disclosed in the period the change occurs. Costs for purchased and internally developed software are expensed until it has been determined that the software will result in probable future economic benefits and management has committed to funding the project. Thereafter, all direct costs of materials and services incurred in developing or obtaining software, including certain payroll and benefit costs of employees associated with the project, are capitalized and amortized using the straight-line method over the estimated useful life which does not exceed seven years. The following assets are amortized using the units-of-production method. Amounts reflect properties where mining or drilling operations have not yet commenced and therefore, are not being amortized for the years ended December 31, 2016 and 2015 , respectively. |
Significant Accounting Policy38
Significant Accounting Policy (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Accounting Policies [Abstract] | |
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block] | The table below sets forth the share-based awards that have been excluded from the computation of the diluted earnings per share because their effect would be anti-dilutive: For the Years Ended December 31, 2016 2015 2014 Anti-Dilutive Options 6,208,813 3,621,002 358,731 Anti-Dilutive Restricted Stock Units 663,003 1,375,659 — Anti-Dilutive Performance Share Units 2,400,326 113,531 — Anti-Dilutive Performance Share Options 802,804 802,804 — 10,074,946 5,912,996 358,731 |
Schedule of Basic and Dilutive Earnings Per Share [Text Block] | For the Years Ended December 31, 2016 2015 2014 Numerator: (Loss) Income from Continuing Operations $ (535,965 ) $ (350,266 ) $ 164,947 Less: Net Income Attributable to Noncontrolling Interest 8,954 10,410 — Net (Loss) Income from Continuing Operations attributable to CONSOL Energy Shareholders $ (544,919 ) $ (360,676 ) $ 164,947 Loss from Discontinued Operations $ (303,183 ) $ (14,209 ) $ (1,857 ) Net (Loss) Income Attributable to CONSOL Energy Shareholders $ (848,102 ) $ (374,885 ) $ 163,090 Denominator: Weighted-average shares of common stock outstanding 229,387,403 229,186,125 229,994,407 Effect of dilutive shares — — 1,585,871 Weighted-average diluted shares of common stock outstanding 229,387,403 229,186,125 231,580,278 (Loss) Earnings Per Share: Basic (Continuing Operations) $ (2.38 ) $ (1.57 ) $ 0.72 Basic (Discontinued Operations) (1.32 ) (0.07 ) (0.01 ) Total Basic $ (3.70 ) $ (1.64 ) $ 0.71 Dilutive (Continuing Operations) $ (2.38 ) $ (1.57 ) $ 0.71 Dilutive (Discontinued Operations) (1.32 ) (0.07 ) (0.01 ) Total Dilutive $ (3.70 ) $ (1.64 ) $ 0.70 |
Schedule of Stock by Class [Table Text Block] | Shares of common stock outstanding were as follows: 2016 2015 2014 Balance, Beginning of Year 229,054,236 230,265,463 229,145,736 Issuance Related to Stock-Based Compensation (1) 388,772 1,001,873 1,119,727 Retirement of Common Stock (2) — (2,213,100 ) — Balance, End of Year 229,443,008 229,054,236 230,265,463 (1) See Note 17–Stock-Based Compensation for additional information. |
Other Income (Tables)
Other Income (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Component of Operating Income [Abstract] | |
Schedule of Other Nonoperating Income, by Component [Table Text Block] | For the Years Ended December 31, 2016 2015 2014 Equity in Earnings of Affiliates - CONE $ 48,260 $ 43,799 $ 29,807 Rental Income 36,059 37,984 45,059 Right of Way Issuance 27,343 13,289 7,333 Royalty Income - Non-Operated Coal 20,083 15,402 19,653 Gathering Revenue 10,834 9,530 23,520 Coal Contract Buyout 6,288 — 30,000 Purchased Coal Sales 5,757 1,596 9,029 Equity in Earnings of Affiliates - Other 4,818 11,098 19,984 Interest Income 1,507 2,299 2,303 Other 6,357 9,354 20,772 Miscellaneous Other Income $ 167,306 $ 144,351 $ 207,460 |
Mine Closing, Reclamation, an40
Mine Closing, Reclamation, and Gas Well Closing (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
MINE CLOSING, RECLAMATION & GAS WELL CLOSING [Abstract] | |
Schedule of Change in Asset Retirement Obligation [Table Text Block] | As of December 31, 2016 2015 Balance at beginning of period $ 429,967 $ 454,832 Accretion expense 23,924 32,438 Payments (15,882 ) (18,033 ) Revisions in estimated cash flows 36,320 (33,984 ) Other (785 ) (5,286 ) Balance at end of period $ 473,544 $ 429,967 |
Inventories (Tables)
Inventories (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Inventory Disclosure [Abstract] | |
Schedule of Inventory, Current [Table Text Block] | N |
Property, Plant and Equipment (
Property, Plant and Equipment (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Property, Plant and Equipment [Abstract] | |
Property, Plant and Equipment | December 31, E&P Property, Plant and Equipment 2016 2015 Intangible drilling cost $ 3,583,565 $ 3,452,989 Proved gas properties 2,016,916 1,922,602 Unproved gas properties 1,116,282 1,421,083 Gas gathering equipment 1,138,299 1,147,173 Gas wells and related equipment 791,996 785,744 Other gas assets 190,406 125,691 Gas advance royalties 13,762 19,745 Total E&P Property, Plant and Equipment $ 8,851,226 $ 8,875,027 Less: Accumulated Depreciation, Depletion and Amortization 3,106,296 2,695,674 Total E&P Property, Plant and Equipment - Net $ 5,744,930 $ 6,179,353 PA Mining Operations Property, Plant and Equipment Coal and other plant and equipment $ 2,307,668 $ 2,284,103 Coal properties and surface lands 458,398 456,044 Airshafts 371,752 351,870 Mine development 326,152 326,225 Coal advance mining royalties 16,224 16,263 Leased coal lands 26,566 26,402 Total PA Mining Operations Property, Plant and Equipment $ 3,506,760 $ 3,460,907 Less: Accumulated Depreciation, Depletion and Amortization 1,768,712 1,603,642 Total PA Mining Operations Property, Plant and Equipment - Net $ 1,738,048 $ 1,857,265 Other Property, Plant and Equipment Coal and other plant and equipment $ 532,919 $ 569,333 Coal properties and surface lands 481,126 484,348 Airshafts 10,003 10,002 Mine development 17,988 18,073 Coal advance mining royalties 310,530 312,452 Leased coal lands 60,836 64,765 Total Other Property, Plant and Equipment $ 1,413,402 $ 1,458,973 Less: Accumulated Depreciation, Depletion and Amortization 755,941 762,885 Total Other Property, Plant and Equipment - Net $ 657,461 $ 696,088 Total Company Property, Plant and Equipment $ 13,771,388 $ 13,794,907 Less - Total Company Accumulated Depreciation, Depletion and Amortization 5,630,949 5,062,201 Total Company Property, Plant and Equipment - Net $ 8,140,439 $ 8,732,706 |
Schedule of Amortization Expense Per Unit of Production [Table Text Block] | December 31, 2016 2015 Unproved gas properties $ 1,116,282 $ 1,421,083 Coal properties 195,354 258,099 Leased coal lands 36,788 44,805 Airshafts 19,693 24,674 Coal advance mining royalties 16,270 21,544 Gas advance royalties 13,762 19,745 Mine development 7,771 7,930 Total $ 1,405,920 $ 1,797,880 |
Other Accrued Liabilities (Tabl
Other Accrued Liabilities (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Other Liabilities Disclosure [Abstract] | |
Schedule of Accrued Liabilities [Table Text Block] | December 31, 2016 2015 Gas derivatives $ 231,573 $ 12,206 Subsidence liability 104,437 86,860 Royalties 44,657 38,707 Accrued interest 37,366 38,406 Accrued payroll & benefits 24,649 24,952 Accrued other taxes 20,679 10,927 Short-term incentive compensation 19,497 6,802 Deferred Revenue 18,211 11,557 Equipment leases 15,286 15,286 Other 59,025 60,052 Current portion of long-term liabilities: Postretirement benefits other than pensions 42,001 46,105 Gas well closing 17,285 15,648 Mine closing 14,276 22,599 Workers' compensation 13,874 14,803 Pneumoconiosis benefits 10,763 9,382 Long-term disability 3,865 4,248 Salary retirement 2,904 2,772 Reclamation — 515 Total Other Accrued Liabilities $ 680,348 $ 421,827 |
Long-Term Debt Annual Discounte
Long-Term Debt Annual Discounted Maturities (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Debt Instrument [Line Items] | |
Schedule of Long-term Debt Instruments [Table Text Block] | December 31, 2016 2015 Debt: Senior Notes due April 2022 at 5.875% (Principal of $1,850,000 plus Unamortized Premium of $4,731 and $5,617, respectively) $ 1,854,731 $ 1,855,617 Senior Notes due April 2023 at 8.00% (Principal of $500,000 less Unamortized Discount of $5,656 and $6,561, respectively) 494,344 493,439 Revolving Credit Facility - CNX Coal Resources LP 201,000 185,000 MEDCO Revenue Bonds in Series due September 2025 at 5.75% 102,865 102,865 Senior Notes due April 2020 at 8.25%, Issued at Par Value 74,470 74,470 Senior Notes due March 2021 at 6.375%, Issued at Par Value 20,611 20,611 Advance Royalty Commitments (7.73% and 16.35% Weighted Average Interest Rate, respectively) 2,678 3,964 Other Long-Term Note Maturing in 2018 (Principal of $1,789 and $3,096 less Unamortized Discount of $117 and $327, respectively) 1,672 2,769 Less: Unamortized Debt Issuance Costs 27,699 33,017 2,724,672 2,705,718 Less: Amounts Due in One Year* 1,677 1,819 Long-Term Debt $ 2,722,995 $ 2,703,899 |
Schedule of Maturities of Long-term Debt [Table Text Block] | Annual undiscounted maturities on long-term debt during the next five years and thereafter are as follows: Year ended December 31, Amount 2017 $ 1,804 2018 672 2019 292 2020 275,740 2021 20,861 Thereafter 2,454,043 Total Long-Term Debt Maturities $ 2,753,412 |
Leases (Tables)
Leases (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Sale Leaseback Transaction [Line Items] | |
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block] | Capital Operating Leases Leases Year Ended December 31, 2017 $ 13,237 $ 103,325 2018 12,442 64,520 2019 11,977 37,272 2020 11,007 27,722 2021 8,959 26,816 Thereafter — 80,692 Total minimum lease payments $ 57,622 $ 340,347 Less amount representing interest (2.00% – 7.36%) 8,225 Present value of minimum lease payments 49,397 Less amount due in one year 10,323 Total Long-Term Capital Lease Obligation $ 39,074 |
333131 Mining Machinery and Equipment Manufacturing [Member] | |
Sale Leaseback Transaction [Line Items] | |
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block] | 2017 2018 2019 2020 2021 Thereafter Total $ 40,299 $ 13,819 $ 6,909 $ — $ — $ — $ 61,027 |
Discontinued Operations [Member] | |
Sale Leaseback Transaction [Line Items] | |
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block] | 2017 2018 2019 2020 2021 Thereafter Total $ 4,496 $ 2,992 $ 1,701 $ 627 $ — $ — $ 9,816 |
Pension and OPEB (Tables)
Pension and OPEB (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract] | |
Schedule of Changes in Accumulated Postemployment Benefit Obligations [Table Text Block] | Pension Benefits Other Postretirement Benefits at December 31, at December 31, 2016 2015 2016 2015 Change in benefit obligation: Benefit obligation at beginning of period $ 763,407 $ 870,471 $ 671,755 $ 760,959 Service cost 1,927 8,653 — — Interest cost 25,491 32,095 24,241 27,238 Actuarial loss (gain) 46,962 (39,563 ) 77,640 (9,224 ) Plan amendments — — (28,164 ) (43,598 ) Plan transfer* — — — (5,242 ) Plan curtailments — (26,352 ) — — Plan settlements (54,197 ) (51,497 ) — — Participant contributions — — — 1,649 Benefits and other payments (35,709 ) (30,400 ) (45,387 ) (60,027 ) Benefit obligation at end of period $ 747,881 $ 763,407 $ 700,085 $ 671,755 Change in plan assets: Fair value of plan assets at beginning of period $ 669,039 $ 751,176 $ — $ — Actual return (loss) on plan assets 50,575 (9,293 ) — — Company contributions 2,726 9,053 45,387 58,378 Participant contributions — — — 1,649 Benefits and other payments (35,709 ) (30,400 ) (45,387 ) (60,027 ) Plan settlements (54,197 ) (51,497 ) — — Fair value of plan assets at end of period $ 632,434 $ 669,039 $ — $ — Funded status: Current liabilities $ (2,904 ) $ (2,772 ) $ (40,611 ) $ (40,863 ) Noncurrent liabilities (112,543 ) (91,596 ) (659,474 ) (630,892 ) Net obligation recognized $ (115,447 ) $ (94,368 ) $ (700,085 ) $ (671,755 ) Amounts recognized in accumulated other comprehensive income consist of: Net actuarial loss $ 299,865 $ 288,695 $ 426,392 $ 367,920 Prior service credit (1,611 ) (2,201 ) (28,164 ) — Net amount recognized (before tax effect) $ 298,254 $ 286,494 $ 398,228 $ 367,920 |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | The components of net periodic benefit costs are as follows: |
Schedule of Amounts in Accumulated Other Comprehensive Income (Loss) to be Recognized over Next Fiscal Year [Table Text Block] | Other Pension Postretirement Benefits Benefits Prior service credit recognition $ (590 ) $ (2,405 ) Actuarial loss recognition $ 9,403 $ 23,112 |
Schedule of Accumulated Benefit Obligations in Excess of Fair Value of Plan Assets [Table Text Block] | As of December 31, 2016 2015 Projected benefit obligation $ 747,881 $ 763,407 Accumulated benefit obligation $ 745,793 $ 761,124 Fair value of plan assets $ 632,434 $ 669,039 |
Schedule of Assumptions Used [Table Text Block] | The weighted-average assumptions used to determine benefit obligations are as follows: Pension Benefits Other Postretirement Benefits For the Year Ended For the Year Ended December 31, December 31, 2016 2015 2016 2015 Discount rate 4.31 % 4.50 % 4.22 % 4.50 % Rate of compensation increase 3.90 % 3.80 % — — The discount rates are determined using a Company-specific yield curve model (above-mean) developed with the assistance of an external actuary. The Company-specific yield curve models (above-mean) use a subset of the expanded bond universe to determine the Company-specific discount rate. Bonds used in the yield curve are rated AA by Moody's or Standard & Poor's as of the measurement date. The yield curve models parallel the plans' projected cash flows, and the underlying cash flows of the bonds included in the models exceed the cash flows needed to satisfy the Company plans. The weighted-average assumptions used to determine net periodic benefit costs are as follows: Pension Benefits at Other Postretirement Benefits at December 31, December 31, 2016 2015 2014 2016 2015 2014 Discount rate 4.52 % 4.07 % 4.87 % 4.50 % 4.03 % 4.88 % Expected long-term return on plan assets 7.25 % 7.75 % 7.75 % — — — Rate of compensation increase 3.80 % 3.80 % 4.21 % — — — |
Schedule of Health Care Cost Trend Rates [Table Text Block] | The assumed health care cost trend rates are as follows: At December 31, 2016 2015 2014 Health care cost trend rate for next year 6.31 % 6.49 % 6.03 % Rate to which the cost trend is assumed to decline (ultimate trend rate) 4.50 % 4.50 % 4.50 % Year that the rate reaches ultimate trend rate 2038 2038 2026 |
Schedule of Effect of One-Percentage-Point Change in Assumed Health Care Cost Trend Rates [Table Text Block] | Assumed health care cost trend rates have a significant effect on the amounts reported for the medical plans. A one-percentage point change in assumed health care cost trend rates would have the following effects: 1 Percentage 1 Percentage Point Increase Point Decrease Effect on total of service and interest cost components $ 3,659 $ (3,053 ) Effect on accumulated postretirement benefit obligation $ 84,381 $ (71,751 ) |
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets [Table Text Block] | |
Schedule of Allocation of Plan Assets [Table Text Block] | The fair values of plan assets at December 31, 2016 and 2015 by asset category are as follows: Fair Value Measurements at December 31, 2016 Fair Value Measurements at December 31, 2015 Quoted Quoted Prices in Prices in Active Active Markets for Significant Significant Markets for Significant Significant Identical Observable Unobservable Identical Observable Unobservable Assets Inputs Inputs Assets Inputs Inputs Total (Level 1) (Level 2) (Level 3) Total (Level 1) (Level 2) (Level 3) Asset Category Cash/Accrued Income $ 639 $ 639 $ — $ — $ 631 $ 631 $ — $ — US Equities (a) 11 11 — — 10 10 — — Mercer Common Collective Trusts (b) 631,784 — — — 668,398 — — — Total $ 632,434 $ 650 $ — $ — $ 669,039 $ 641 $ — $ — |
Schedule of Expected Benefit Payments [Table Text Block] | The following benefit payments, reflecting expected future service, are expected to be paid: |
CWP and Workers Comp (Tables)
CWP and Workers Comp (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Amounts in Accumulated Other Comprehensive Income (Loss) to be Recognized over Next Fiscal Year [Table Text Block] | Other Pension Postretirement Benefits Benefits Prior service credit recognition $ (590 ) $ (2,405 ) Actuarial loss recognition $ 9,403 $ 23,112 |
Schedule of Assumptions Used [Table Text Block] | The weighted-average assumptions used to determine benefit obligations are as follows: Pension Benefits Other Postretirement Benefits For the Year Ended For the Year Ended December 31, December 31, 2016 2015 2016 2015 Discount rate 4.31 % 4.50 % 4.22 % 4.50 % Rate of compensation increase 3.90 % 3.80 % — — The discount rates are determined using a Company-specific yield curve model (above-mean) developed with the assistance of an external actuary. The Company-specific yield curve models (above-mean) use a subset of the expanded bond universe to determine the Company-specific discount rate. Bonds used in the yield curve are rated AA by Moody's or Standard & Poor's as of the measurement date. The yield curve models parallel the plans' projected cash flows, and the underlying cash flows of the bonds included in the models exceed the cash flows needed to satisfy the Company plans. The weighted-average assumptions used to determine net periodic benefit costs are as follows: Pension Benefits at Other Postretirement Benefits at December 31, December 31, 2016 2015 2014 2016 2015 2014 Discount rate 4.52 % 4.07 % 4.87 % 4.50 % 4.03 % 4.88 % Expected long-term return on plan assets 7.25 % 7.75 % 7.75 % — — — Rate of compensation increase 3.80 % 3.80 % 4.21 % — — — |
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets [Table Text Block] | |
Schedule of Expected Benefit Payments [Table Text Block] | The following benefit payments, reflecting expected future service, are expected to be paid: |
Workers Comp and CWP [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | The components of the net periodic cost are as follows: CWP Workers’ Compensation For the Years Ended For the Years Ended December 31, December 31, 2016 2015 2014 2016 2015 2014 Service cost $ 4,327 $ 6,491 $ 5,674 $ 7,618 $ 9,389 $ 9,781 Interest cost 4,283 5,116 5,537 2,550 3,195 3,577 Recognized net actuarial gain (4,948 ) (5,576 ) (6,196 ) (403 ) (31 ) (382 ) State administrative fees and insurance bond premiums — — — 3,265 3,581 3,352 Curtailment gain (1,307 ) — — — — — Settlement gain — — — — — — Net periodic cost $ 2,355 $ 6,031 $ 5,015 $ 13,030 $ 16,134 $ 16,328 |
Schedule of Amounts in Accumulated Other Comprehensive Income (Loss) to be Recognized over Next Fiscal Year [Table Text Block] | The following are amounts included in accumulated other comprehensive income that are expected to be recognized in 2017 net periodic benefit costs: Workers' CWP Compensation Benefits Benefits Actuarial gain recognition $ (7,631 ) $ (610 ) |
Schedule of Assumptions Used [Table Text Block] | Assumptions: The weighted-average discount rates used to determine benefit obligations and net periodic cost (benefit) are as follows: CWP Workers' Compensation For the Years Ended For the Years Ended December 31, December 31, 2016 2015 2014 2016 2015 2014 Benefit obligations 4.40 % 4.60 % 4.21 % 4.05 % 4.26 % 3.84 % Net periodic cost 4.60 % 4.21 % 4.75 % 4.26 % 3.84 % 4.57 % |
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets [Table Text Block] | |
Schedule of Expected Benefit Payments [Table Text Block] | The following benefit payments, which reflect expected future claims as appropriate, are expected to be paid: Workers' Compensation CWP Total Actuarial Other Benefits Benefits Benefits Benefits 2017 $ 10,763 $ 15,897 $ 12,416 $ 3,481 2018 $ 8,417 $ 15,193 $ 11,625 $ 3,568 2019 $ 7,606 $ 15,061 $ 11,404 $ 3,657 2020 $ 7,137 $ 15,044 $ 11,295 $ 3,749 2021 $ 6,963 $ 15,056 $ 11,214 $ 3,842 Year 2022-2026 $ 35,714 $ 76,577 $ 55,876 $ 20,701 |
Other Employee Benefits (Tables
Other Employee Benefits (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | The components of net periodic benefit costs are as follows: |
Long term disability [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | CONSOL Energy has a Long-Term Disability Plan available to all eligible full-time salaried employees. The benefits for this plan are based on a percentage of monthly earnings, offset by all other income benefits available to the disabled. For the Years Ended December 31, 2016 2015 2014 Benefit cost $ 2,128 $ 2,619 $ 2,213 Discount rate assumption used to determine net periodic benefit costs 3.71 % 3.18 % 3.53 % |
Stock Based Compensation (Table
Stock Based Compensation (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Share-based Compensation [Abstract] | |
Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block] | A summary of the status of stock options granted is presented below: Weighted Average Weighted Remaining Aggregate Average Contractual Intrinsic Exercise Term (in Value (in Shares Price years) thousands) Balance at December 31, 2015 3,621,002 $43.15 Granted 3,369,197 $4.22 Exercised — — Forfeited (781,386 ) $36.32 Balance at December 31, 2016 6,208,813 $22.88 6.02 $ — Vested 2,990,263 $43.12 2.57 $ — Exercisable at December 31, 2016 2,990,263 $43.12 2.57 $ — |
Schedule of Nonvested Restricted Stock Units Activity [Table Text Block] | Number of Weighted Average Shares Grant Date Fair Value Nonvested at December 31, 2015 1,303,573 $32.60 Granted 27,379 $17.99 Vested (579,246 ) $32.97 Forfeited (88,703 ) $30.42 Nonvested at December 31, 2016 663,003 $31.97 |
Schedule of Nonvested Performance-based Units Activity [Table Text Block] | he following table represents the nonvested performance share units and their corresponding fair value (based upon the closing share price) on the date of grant: Number of Weighted Average Shares Grant Date Fair Value Nonvested at December 31, 2015 491,493 $27.83 Granted 950,404 $25.55 Vested — — Forfeited (17,346 ) $19.62 Nonvested at December 31, 2016 1,424,551 $26.41 |
Supplemental Cash Flow (Tables)
Supplemental Cash Flow (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Supplemental Cash Flow Information [Abstract] | |
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block] | For the Years Ended December 31, 2016 2015 2014 Interest (net of amounts capitalized) $ 186,924 $ 207,094 $ 233,631 Income taxes $ (18,032 ) $ (59,584 ) $ (81,962 ) |
Fair Value of Financial Instr51
Fair Value of Financial Instruments (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Fair Value Disclosures [Abstract] | |
Fair Value, Assets Measured on Recurring Basis [Table Text Block] | The financial instruments measured at fair value on a recurring basis are summarized below: Fair Value Measurements at Fair Value Measurements at Description Level 1 Level 2 Level 3 Level 1 Level 2 Level 3 Gas Derivatives $ — $ (188,156 ) $ — $ — $ 266,558 $ — Murray Energy Guarantees $ — $ — $ (1,362 ) $ — $ — $ (1,228 ) |
Derivatives (Tables)
Derivatives (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Table Text Block] | Year Ended December 31, 2016 2015 2014 Beginning Balance – Accumulated OCI $ 43,470 $ 121,521 $ 42,493 Gain Recognized in Accumulated OCI — — 97,316 Gain Reclassified from Accumulated OCI (Net of tax: $25,011, $45,054, $10,465) (43,470 ) (78,051 ) (18,288 ) Ending Balance – Accumulated OCI $ — $ 43,470 $ 121,521 |
Commitments and Contingencies (
Commitments and Contingencies (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Commitments and Contingencies Disclosure [Abstract] | |
Long-term Purchase Commitment [Table Text Block] | Amount of Commitment Expiration Per Period Total Amounts Committed Less Than 1 Year 1-3 Years 3-5 Years Beyond 5 Years Letters of Credit: Employee-Related $ 82,273 $ 67,871 $ 14,402 $ — $ — Environmental 998 600 398 — — Other 242,405 228,313 14,092 — — Total Letters of Credit 325,676 296,784 28,892 — — Surety Bonds: Employee-Related 112,810 111,510 1,300 — — Environmental 514,851 483,604 31,247 — — Other 22,417 21,591 824 2 — Total Surety Bonds 650,078 616,705 33,371 2 — Guarantees: Other 74,203 41,285 17,767 13,401 1,750 Total Guarantees 74,203 41,285 17,767 13,401 1,750 Total Commitments $ 1,049,957 $ 954,774 $ 80,030 $ 13,403 $ 1,750 |
Unrecorded Unconditional Purchase Obligations Disclosure | . These purchase obligations are not recorded on the Consolidated Balance Sheets. As of December 31, 2016 , the purchase obligations for each of the next five years and beyond were as follows: Obligations Due Amount Less than 1 year $ 209,797 1 - 3 years 285,224 3 - 5 years 243,534 More than 5 years 622,509 Total Purchase Obligations $ 1,361,064 |
Segment Information (Tables)
Segment Information (Tables) | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Segment Reporting [Abstract] | |||
Industry segment results | Industry segment results for the year ended December 31, 2016 are: Marcellus Shale Utica Shale Coalbed Methane Other Gas Total E&P PA Mining Operations Other Adjustments and Eliminations Consolidated Sales—Outside $ 414,484 $ 163,112 $ 174,323 $ 41,329 $ 793,248 $ 1,065,582 $ — $ — $ 1,858,830 Gain (Loss) on Commodity Derivative Instruments 147,282 29,285 52,396 (369,984 ) (141,021 ) — — — (141,021 ) Other Outside Sales — — — — — — 32,038 — 32,038 Sales—Purchased Gas — — — 43,256 43,256 — — — 43,256 Freight—Outside — — — — — 46,468 — — 46,468 Intersegment Transfers — — 424 — 424 — — (424 ) — Total Sales and Freight $ 561,766 $ 192,397 $ 227,143 $ (285,399 ) $ 695,907 $ 1,112,050 $ 32,038 $ (424 ) $ 1,839,571 Earnings (Loss) From Continuing Operations $ 72,141 $ 28,390 $ 37,999 $ (517,370 ) $ (378,840 ) $ 130,708 $ (277,399 ) $ (424 ) $ (525,955 ) (A) Segment Assets $ 6,235,568 $ 1,982,206 $ 966,124 $ 83 $ 9,183,981 (B) Depreciation, Depletion and Amortization $ 417,853 $ 168,195 $ 12,455 $ — $ 598,503 Capital Expenditures $ 165,101 $ 50,809 $ 10,910 $ — $ 226,820 (A) Includes equity in earnings of unconsolidated affiliates of $51,742 and $1,336 for Total E&P and Other, respectively. (B) Includes investments in unconsolidated equity affiliates of $188,376 and $2,588 for Total E&P and Other, respectively. | Industry segment results for the year ended December 31, 2015 are: Marcellus Shale Utica Shale Coalbed Methane Other Gas Total E&P PA Mining Operations Other Adjustments and Eliminations Consolidated Sales—Outside $ 379,453 $ 92,223 $ 200,645 $ 54,600 $ 726,921 $ 1,289,036 $ — $ — $ 2,015,957 (C) Gain on Commodity Derivative Instruments 100,785 6,430 67,281 218,446 392,942 — — — 392,942 Other Outside Sales — — — — — — 30,967 — 30,967 Sales—Purchased Gas — — — 14,450 14,450 — — — 14,450 Freight—Outside — — — — — 20,499 — — 20,499 Intersegment Transfers — — 1,538 — 1,538 — — (1,538 ) — Total Sales and Freight $ 480,238 $ 98,653 $ 269,464 $ 287,496 $ 1,135,851 $ 1,309,535 $ 30,967 $ (1,538 ) $ 2,474,815 Earnings (Loss) From Continuing Operations $ 56,116 $ (19,428 ) $ 59,662 $ (775,207 ) $ (678,857 ) $ 404,994 $ (200,304 ) $ (1,538 ) $ (475,705 ) (D) Segment Assets $ 6,892,284 $ 2,076,301 $ 939,497 $ 1,021,820 $ 10,929,902 (E) Depreciation, Depletion and Amortization $ 370,374 $ 176,864 $ 19,882 $ — $ 567,120 Capital Expenditures $ 832,446 $ 136,291 $ 14,197 $ — $ 982,934 (C) Included in the PA Mining Operations segment are sales of $242,020 to Duke Energy, which comprises over 10% of sales. (D) Includes equity in earnings of unconsolidated affiliates of $46,614 and $8,283 for Total E&P and Other, respectively. (E) Includes investments in unconsolidated equity affiliates of $234,803 and $2,527 for Total E&P and Other, respectively. | Industry segment results for the year ended December 31, 2014 are: Marcellus Shale Utica Shale Coalbed Methane Other Gas Total E&P PA Mining Operations Other Adjustments and Eliminations Consolidated Sales—Outside $ 457,679 $ 86,948 $ 340,739 $ 119,558 $ 1,004,924 $ 1,616,874 $ — $ — $ 2,621,798 (F) Gain on Commodity Derivative Instruments 14,764 1,247 4,103 3,079 23,193 — — — 23,193 Other Outside Sales — — — — — — 276,242 — 276,242 Sales—Purchased Gas — — — 8,999 8,999 — — — 8,999 Freight—Outside — — — — — 23,133 — — 23,133 Intersegment Transfers — — 2,458 — 2,458 — 78,229 (80,687 ) — Total Sales and Freight $ 472,443 $ 88,195 $ 347,300 $ 131,636 $ 1,039,574 $ 1,640,007 $ 354,471 $ (80,687 ) $ 2,953,365 Earnings (Loss) From Continuing Operations $ 171,902 $ 43,645 $ 108,107 $ (133,940 ) $ 189,714 $ 430,968 $ (438,073 ) $ (2,458 ) $ 180,151 (G) Segment Assets $ 7,364,185 $ 2,094,041 $ 1,186,874 $ 1,009,546 $ 11,654,646 (H) Depreciation, Depletion and Amortization $ 323,600 $ 173,316 $ 35,727 $ — $ 532,643 Capital Expenditures $ 1,103,656 $ 341,229 $ 14,567 $ — $ 1,459,452 (F) Included in the Total E&P segment are sales of $295,779 to NJR Energy Services Company, which comprises over 10% of sales. (G) Includes equity in earnings of unconsolidated affiliates of $ 32,217 and $17,574 for Total E&P and Other, respectively. (H) Includes investments in unconsolidated equity affiliates of $121,721 and $31,237 for Total E&P and Other, respectively. |
Segment Reporting, Revenue Reconciling Item [Line Items] | |||
Reconciliation of Operating Profit (Loss) from Segments to Consolidated [Table Text Block] | From Continuing Operations Before Income Tax: For the Years Ended December 31, 2016 2015 2014 Segment (Loss) Income Before Income Taxes for reportable business segments $ (248,132 ) $ (273,863 ) $ 620,682 Segment (Loss) Income Before Income Taxes for all other business segments (85,923 ) 66,713 (119,473 ) Interest expense (191,476 ) (199,266 ) (223,333 ) Eliminations (424 ) (1,538 ) (2,458 ) Loss on debt extinguishment — (67,751 ) (95,267 ) (Loss) Earnings From Continuing Operations Before Income Tax $ (525,955 ) $ (475,705 ) $ 180,151 | ||
Reconciliation of Revenue from Segments to Consolidated [Table Text Block] | Revenue and Other Income: For the Years Ended December 31, 2016 2015 2014 Total Segment Sales and Freight from External Customers $ 1,980,592 $ 2,081,873 $ 2,930,172 (Loss) Gain on Commodity Derivative Instruments (141,021 ) 392,942 23,193 Other Income not Allocated to Segments (Note 4) 167,306 144,351 207,460 Gain on Sale of Assets 19,498 74,173 43,198 Total Consolidated Revenue and Other Income $ 2,026,375 $ 2,693,339 $ 3,204,023 | ||
Schedule of Revenue from External Customers Attributed to Foreign Countries by Geographic Area [Table Text Block] | Enterprise-Wide Disclosures: CONSOL Energy's Revenues by geographical location (I): For the Years Ended December 31, 2016 2015 2014 United States $ 1,799,336 $ 1,822,452 $ 2,713,833 Asia 109,312 106,954 66,912 Europe 40,704 112,844 121,909 South America 25,406 28,060 19,013 Canada 5,834 11,563 8,505 Total Revenues and Freight from External Customers (J) $ 1,980,592 $ 2,081,873 $ 2,930,172 | ||
Schedule of Disclosure on Geographic Areas, Long-Lived Assets in Individual Foreign Countries by Country [Table Text Block] | CONSOL Energy's Property, Plant and Equipment by geographical location: December 31, 2016 2015 United States $ 8,129,415 $ 8,721,682 Canada 11,024 11,024 Discontinued Operations — 936,671 Total Property, Plant and Equipment, net $ 8,140,439 $ 9,669,377 | ||
Reconciliation of Assets and Liabilities from Segment to Consolidated | December 31, 2016 2015 Segment assets for total reportable business segments $ 8,217,774 $ 8,968,585 Segment assets for all other business segments 797,830 859,675 Items excluded from segment assets: Cash and other investments 47,153 65,935 Recoverable income taxes 116,851 13,887 Deferred tax assets 4,290 — Discontinued Operations 83 1,021,820 Total Consolidated Assets $ 9,183,981 $ 10,929,902 |
Guarantor Subsidiaries Financ55
Guarantor Subsidiaries Financial Information (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Guarantor Subsidiaries Financial Information [Abstract] | |
Guarantor Income Statements [Table Text Block] | Income Statement for the Year Ended December 31, 2016 : Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Non-Guarantor Other Subsidiary Non- Guarantors Elimination Consolidated Revenues and Other Income: Natural Gas, NGLs and Oil Sales $ — $ 793,672 $ — $ — $ — $ (424 ) $ 793,248 Loss on Commodity Derivative Instruments — (141,021 ) — — — — (141,021 ) Coal Sales — — 799,187 266,395 — — 1,065,582 Other Outside Sales — — 32,038 — — — 32,038 Purchased Gas Sales — 43,256 — — — — 43,256 Freight-Outside Coal — — 34,865 11,603 — — 46,468 Miscellaneous Other Income (712,927 ) 80,444 83,735 3,128 — 712,926 167,306 Gain (Loss) on Sale of Assets — 14,870 4,637 (9 ) — — 19,498 Total Revenue and Other Income (712,927 ) 791,221 954,462 281,117 — 712,502 2,026,375 Costs and Expenses: Exploration and Production Costs Lease Operating Expense — 96,434 — — — — 96,434 Transportation, Gathering and Compression — 374,350 — — — — 374,350 Production, Ad Valorem, and Other Fees — 31,049 — — — — 31,049 Depreciation, Depletion and Amortization — 417,853 — — — — 417,853 Exploration and Production Related Other Costs — 14,519 — — — — 14,519 Purchased Gas Costs — 42,717 — — — — 42,717 Other Corporate Expenses — 87,913 — — — — 87,913 Selling, General and Administrative Costs — 102,503 — — — — 102,503 Total Exploration and Production Costs — 1,167,338 — — — — 1,167,338 PA Mining Operations Costs Operating and Other Costs — — 550,299 183,001 — — 733,300 Depreciation, Depletion and Amortization — — 126,201 41,994 — — 168,195 Freight Expense — — 34,865 11,603 — — 46,468 Selling, General and Administrative Costs — — 27,563 9,949 — — 37,512 Total PA Mining Operations Costs — — 738,928 246,547 — — 985,475 Other Costs Miscellaneous Operating Expense 43,533 — 139,289 — 47 — 182,869 Selling, General and Administrative Costs — — 12,717 — — — 12,717 Depreciation, Depletion and Amortization 568 — 11,887 — — — 12,455 Interest Expense 173,327 2,723 6,707 8,719 — — 191,476 Total Other Costs 217,428 2,723 170,600 8,719 47 — 399,517 Total Costs And Expenses 217,428 1,170,061 909,528 255,266 47 — 2,552,330 (Loss) Earnings from Continuing Operations Before Income Tax (930,355 ) (378,840 ) 44,934 25,851 (47 ) 712,502 (525,955 ) Income Tax (Benefit) Expense (82,253 ) (150,551 ) 242,832 — (18 ) — 10,010 (Loss) Income From Continuing Operations (848,102 ) (228,289 ) (197,898 ) 25,851 (29 ) 712,502 (535,965 ) Loss From Discontinued Operations, net — — — — (303,183 ) — (303,183 ) Net (Loss) Income (848,102 ) (228,289 ) (197,898 ) 25,851 (303,212 ) 712,502 (839,148 ) Less: Net Income Attributable to Noncontrolling Interest — — — — — 8,954 8,954 Net (Loss) Income Attributable to CONSOL Energy Shareholders $ (848,102 ) $ (228,289 ) $ (197,898 ) $ 25,851 $ (303,212 ) $ 703,548 $ (848,102 ) |
Guarantor Balance Sheet [Table Text Block] | Parent Issuer CNX Gas Guarantor Other Subsidiary Guarantors CNXC Other Subsidiary Elimination Consolidated Assets: Current Assets: Cash and Cash Equivalents $ 49,722 $ 83 $ — $ 9,785 $ 885 $ — $ 60,475 Accounts and Notes Receivable: Trade — 124,509 72,295 23,418 — — 220,222 Other Receivables 20,097 34,773 14,516 515 — — 69,901 Inventories — 15,301 38,669 11,491 — — 65,461 Recoverable Income Taxes 175,877 (59,026 ) — — — — 116,851 Prepaid Expenses 12,828 60,500 16,306 3,512 — — 93,146 Current Assets of Discontinued Operations — — — — 83 — 83 Total Current Assets 258,524 176,140 141,786 48,721 968 — 626,139 Property, Plant and Equipment: Property, Plant and Equipment 114,611 8,851,226 3,928,861 876,690 — — 13,771,388 Less-Accumulated Depreciation, Depletion and Amortization 84,788 3,106,296 1,997,687 442,178 — — 5,630,949 Total Property, Plant and Equipment-Net 29,823 5,744,930 1,931,174 434,512 — — 8,140,439 Other Assets: Deferred Income Taxes 25,904 (21,614 ) — — — — 4,290 Investment in Affiliates 7,974,260 188,376 27,269 — — (7,998,941 ) 190,964 Other 19,960 67,096 114,030 21,063 — — 222,149 Total Other Assets 8,020,124 233,858 141,299 21,063 — (7,998,941 ) 417,403 Total Assets $ 8,308,471 $ 6,154,928 $ 2,214,259 $ 504,296 $ 968 $ (7,998,941 ) $ 9,183,981 Liabilities and Equity: Current Liabilities: Accounts Payable $ 48,666 $ 127,309 $ 36,039 $ 18,797 $ — $ 10,805 $ 241,616 Accounts Payable (Recoverable)-Related Parties 1,832,908 1,034,138 (2,648,416 ) 1,666 (209,491 ) (10,805 ) — Current Portion of Long-Term Debt 1,533 6,369 4,010 88 — — 12,000 Other Accrued Liabilities 75,039 337,374 223,705 44,230 — — 680,348 Current Liabilities of Discontinued Operations — — — — 6,050 — 6,050 Total Current Liabilities 1,958,146 1,505,190 (2,384,662 ) 64,781 (203,441 ) — 940,014 Long-Term Debt: 2,421,511 26,884 115,685 197,989 — — 2,762,069 Deferred Credits and Other Liabilities: Postretirement Benefits Other Than Pensions — — 659,474 — — — 659,474 Pneumoconiosis Benefits — — 106,016 2,057 — — 108,073 Mine Closing — — 209,384 9,247 — — 218,631 Gas Well Closing — 195,704 27,549 99 — — 223,352 Workers’ Compensation — — 64,187 3,090 — — 67,277 Salary Retirement 112,543 — — — — — 112,543 Other 17,876 117,658 15,663 463 — — 151,660 Total Deferred Credits and Other Liabilities 130,419 313,362 1,082,273 14,956 — — 1,541,010 Total CONSOL Energy Inc. Stockholders’ Equity 3,798,395 4,309,492 3,400,963 226,570 204,409 (8,141,434 ) 3,798,395 Noncontrolling Interest — — — — — 142,493 142,493 Total Liabilities and Equity $ 8,308,471 $ 6,154,928 $ 2,214,259 $ 504,296 $ 968 $ (7,998,941 ) $ 9,183,981 |
Guarantor Condensed Cash Flow [Table Text Block] | Condensed Statement of Cash Flows for the Year Ended December 31, 2016 : |
Supplemental Coal Data (Unaud56
Supplemental Coal Data (Unaudited) (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
SUPPLEMENTAL COAL DATA [Abstract] | |
Reserves Reported to Other Agencies [Table Text Block] | Supplemental Coal Data (unaudited) Millions of Tons For the Year Ended December 31, 2016 2015 2014 2013 2012 Proven and probable coal reserves at beginning of period 3,047 3,238 3,032 4,229 4,314 Purchased reserves — 24 — 1 — Reserves sold in place (601 ) (43 ) (233 ) (1,199 ) (155 ) Production (26 ) (29 ) (32 ) (55 ) (55 ) Revisions and other changes (59 ) (143 ) 471 56 125 Consolidated proven and probable coal reserves at end of period* (1) 2,361 3,047 3,238 3,032 4,229 Proportionate share of proven and probable coal reserves of unconsolidated equity affiliates (excluded from the table above)* — — 55 57 41 ______________ * Proven and probable coal reserves are the equivalent of “demonstrated reserves” under the coal resource classification system of the U.S. Geological Survey. Generally, these reserves would be commercially mineable at year-end prices and cost levels, using current technology and mining practices. |
Supplemental Gas Data (Tables)
Supplemental Gas Data (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
SUPPLEMENTAL GAS DATA: [Abstract] | |
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block] | The standardized measure is intended to provide a better means for comparing the value of CONSOL Energy's proved reserves at a given time with those of other gas producing companies than is provided by a comparison of raw proved reserve quantities. December 31, 2016 2015 2014 Future Cash Flows (a) Revenues $ 11,303,409 $ 11,837,732 $ 28,502,852 Production costs (5,850,941 ) (6,584,947 ) (10,100,868 ) Development costs (1,550,294 ) (1,220,010 ) (3,368,621 ) Income tax expense (1,482,826 ) (1,532,454 ) (5,711,989 ) Future Net Cash Flows 2,419,348 2,500,321 9,321,374 Discounted to present value at a 10% annual rate (1,464,231 ) (1,481,017 ) (6,337,216 ) Total standardized measure of discounted net cash flows $ 955,117 $ 1,019,304 $ 2,984,158 (a) For 2016, the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2016, adjusted for energy content and a regional price differential. For 2016, this adjusted natural gas price was $1.73 per mcf, the adjusted oil price was $25.04 per barrel and the adjusted NGL price was $15.77 per barrel. For 2015, the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2015, adjusted for energy content and a regional price differential. For 2015, this adjusted natural gas price was $2.02 per mcf, the adjusted oil price was $25.29 per barrel and the adjusted NGL price was $15.59 per barrel. For 2014, the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2014, adjusted for energy content and a regional price differential. For 2014, this adjusted natural gas price was $3.85 per mcf, the adjusted oil price was $77.30 per barrel and the adjusted NGL price was $46.54 per barrel. The following are the principal sources of change in the standardized measure of discounted future net cash flows for consolidated operations during: December 31, 2016 2015 2014 Balance at beginning of period $ 1,019,304 $ 2,984,158 $ 1,680,811 Net changes in sales prices and production costs (172,812 ) (4,151,684 ) 517,731 Sales net of production costs (150,819 ) (589,533 ) (559,563 ) Net change due to revisions in quantity estimates (35,502 ) 408,006 151,233 Net change due to extensions, discoveries and improved recovery (54,628 ) 157,016 418,775 Development costs incurred during the period 138,813 666,315 952,733 Difference in previously estimated development costs compared to actual costs incurred during the period (39,821 ) 8,911 (102,949 ) Purchase of Reserves In-Place 238,819 — — Sales of Reserves In-Place (137,998 ) — — Changes in estimated future development costs (158,000 ) 374,982 595,221 Net change in future income taxes 36,513 1,259,744 (798,470 ) Accretion of discount and other 271,248 (98,611 ) 128,636 Total discounted cash flow at end of period $ 955,117 $ 1,019,304 $ 2,984,158 |
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block] | Capitalized Costs: As of December 31, 2016 2015 Proved gas properties $ 2,016,916 $ 1,922,602 Unproved gas properties 1,116,282 1,421,083 Intangible drilling costs 3,583,565 3,452,989 Gas wells and related equipment 791,996 785,744 Gas gathering assets 1,138,299 1,147,173 Gas well plugging 176,961 115,121 Total Property, Plant and Equipment 8,824,019 8,844,712 Accumulated Depreciation, Depletion and Amortization (3,099,622 ) (2,691,005 ) Net Capitalized Costs $ 5,724,397 $ 6,153,707 |
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block] | Costs incurred for property acquisition, exploration and development (*): For the Years Ended December 31, 2016 2015 2014 Property acquisitions Proved properties $ — $ — $ — Unproved properties 1,537 76,676 119,597 Development 138,813 666,315 952,733 Exploration 32,259 95,371 45,006 Total $ 172,609 $ 838,362 $ 1,117,336 __________ (*) Includes costs incurred whether capitalized or expensed. |
Results of Operations for Oil and Gas Producing Activities Disclosure [Table Text Block] | Results of Operations for Producing Activities: For the Years Ended December 31, 2016 2015 2014 Natural Gas, NGLs and Oil Sales $ 793,673 $ 728,458 $ 1,007,381 (Loss) Gain on Commodity Derivative Instruments (141,021 ) 392,942 23,193 Purchased Gas Sales 43,256 14,450 8,999 Total Revenue 695,908 1,135,850 1,039,573 Lease Operating Expense 96,434 121,847 139,242 Production, Ad Valorem, and Other Fees 31,049 30,438 39,418 Transportation, Gathering and Compression 374,350 343,403 239,591 Purchased Gas Costs 42,717 10,721 7,251 Impairment of Exploration and Production Properties — 828,905 — Other Costs 14,519 10,120 22,718 DD&A 417,853 370,374 323,600 Total Costs 976,922 1,715,808 771,820 Pre-tax Operating Income / (Loss) (281,014 ) (579,958 ) 267,753 Income Taxes / (Benefit) (69,308 ) (250,220 ) 45,162 Results of Operations for Producing Activities excluding Corporate and Interest Costs $ (211,706 ) $ (329,738 ) $ 222,591 |
Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure [Table Text Block] | The following is production, average sales price and average production costs, excluding ad valorem and severance taxes, per unit of production: For the Years Ended December 31, 2016 2015 2014 Production (MMcfe) 394,387 328,657 235,714 Total average sales price before effects of financial settlements (per Mcfe) $ 2.01 $ 2.22 $ 4.27 Average effects of financial settlements (per Mcfe) $ 0.62 $ 0.60 $ 0.10 Total average sales price including effects of financial settlements (per Mcfe) $ 2.63 $ 2.82 $ 4.37 Average lifting costs, excluding ad valorem and severance taxes (per Mcfe) $ 0.24 $ 0.37 $ 0.59 |
Schedule of Gas and Oil Acreage [Table Text Block] | Most of our development wells and proved acreage are located in Virginia, West Virginia and Pennsylvania. Some leases are beyond their primary term, but these leases are extended in accordance with their terms as long as certain drilling commitments or other term commitments are satisfied. The following table sets forth, at December 31, 2016 , the number of producing wells, developed acreage and undeveloped acreage: Gross Net(1) Producing Gas Wells (including gob wells) 17,314 12,846 Producing Oil Wells 189 30 Acreage Position: Proved Developed Acreage 549,816 541,282 Proved Undeveloped Acreage 34,467 30,038 Unproved Acreage 4,804,804 3,745,533 Total Acreage 5,389,087 4,316,853 ____________ (1) Net acres include acreage attributable to our working interests of the properties. Additional adjustments (either increases or decreases) may be required as we further develop title to and further confirm our rights with respect to our various properties in anticipation of development. We believe that our assumptions and methodology in this regard are reasonable. |
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block] | The gas reserves estimates are as follows: Condensate Consolidated Natural Gas NGLs & Crude Oil Operations (MMcf) (Mbbls) (Mbbls) (MMcfe) Balance December 31, 2013 (a) 5,585,107 21,546 2,806 5,731,214 Revisions (b) (46,560 ) 40,363 3,756 218,168 Price Changes 15,512 — — 15,512 Extensions and Discoveries (c) 979,801 18,459 1,314 1,098,436 Production (216,260 ) (2,578 ) (664 ) (235,714 ) Balance December 31, 2014 (a) 6,317,600 77,790 7,212 6,827,616 Revisions (d) 1,052,978 45,993 6,662 1,368,909 Price Changes (2,866,123 ) (45,675 ) (3,208 ) (3,159,421 ) Extensions and Discoveries (e) 840,800 13,916 1,707 934,542 Production (285,041 ) (5,812 ) (1,458 ) (328,657 ) Balance December 31, 2015 (a) 5,060,214 86,212 10,915 5,642,989 Revisions (f) 21,280 (20,669 ) 481 (99,849 ) Price Changes (179,914 ) (1,647 ) (35 ) (190,009 ) Extensions and Discoveries (g) 643,688 10,960 1,783 720,146 Production (358,474 ) (5,119 ) (867 ) (394,387 ) Purchases of Reserves In-Place (h) 1,352,759 13,177 1,970 1,443,642 Sales of Reserves In-Place (h) (711,155 ) (22,382 ) (4,240 ) (870,884 ) Balance December 31, 2016 (a) 5,828,398 60,532 10,007 6,251,648 Proved developed reserves (i): December 31, 2014 2,979,906 32,405 4,061 3,198,706 December 31, 2015 3,310,894 59,196 5,180 3,697,152 December 31, 2016 3,478,464 30,666 3,474 3,683,302 Proved undeveloped reserves: December 31, 2014 3,337,694 45,385 3,151 3,628,910 December 31, 2015 1,749,320 27,016 5,736 1,945,837 December 31, 2016 2,349,934 29,866 6,536 2,568,346 __________ (a) Proved developed and proved undeveloped gas reserves are defined by SEC Rule 4.10(a) of Regulation S-X. Generally, these reserves would be commercially recovered under current economic conditions, operating methods and government regulations. CONSOL Energy cautions that there are many inherent uncertainties in estimating proved reserve quantities, projecting future production rates and timing of development expenditures. Proved oil and gas reserves are estimated quantities of natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operat |
Schedule of Aging of Capitalized Exploratory Well Costs [Table Text Block] | The following table represents the capitalized exploratory well cost activity as indicated: December 31, 2016 2015 2014 Costs reclassified to wells, equipment and facilities based on the determination of proved reserves $ 40,917 $ 17,179 $ 27,453 Costs expensed due to determination of dry hole or abandonment of project $ — $ — $ 2,041 |
Capitalized Exploratory Well Costs, Roll Forward [Table Text Block] | December 31, 2016 2015 2014 Costs reclassified to wells, equipment and facilities based on the determination of proved reserves $ 40,917 $ 17,179 $ 27,453 Costs expensed due to determination of dry hole or abandonment of project $ — $ — $ 2,041 |
Supplemental Quarterly Info (58
Supplemental Quarterly Info (Unaudited) (Tables) | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
SUPPLEMENTAL QUARTER INFORMATION: [Abstract] | ||
Schedule of Quarterly Financial Information [Table Text Block] | Supplemental Quarterly Information (unaudited): (Dollars in thousands, except per share data) Three Months Ended March 31, June 30, September 30, December 31, 2016 2016 2016 2016 Sales (A) $ 478,864 $ 235,251 $ 688,590 $ 390,398 Freight Revenue $ 13,110 $ 11,447 $ 9,392 $ 12,519 Costs and Expenses (B) $ 329,071 $ 369,392 $ 361,551 $ 415,224 Freight Expense $ 13,110 $ 11,447 $ 9,392 $ 12,519 (Loss) Income from Continuing Operations $ (43,291 ) $ (234,044 ) $ 62,568 $ (321,198 ) (Loss) Income from Discontinued Operations $ (53,167 ) $ (234,605 ) $ (34,975 ) $ 19,564 Net (Loss) Income Attributable to CONSOL Energy Shareholders $ (97,572 ) $ (469,828 ) $ 25,345 $ (306,047 ) Earnings Per Share Basic: (Loss) Income from Continuing Operations $ (0.19 ) $ (1.03 ) $ 0.26 $ (1.42 ) (Loss) Income from Discontinued Operations $ (0.24 ) $ (1.02 ) $ (0.15 ) $ 0.09 Net (Loss) Income $ (0.43 ) $ (2.05 ) $ 0.11 $ (1.33 ) Dilutive: (Loss) Income from Continuing Operations $ (0.19 ) $ (1.03 ) $ 0.26 $ (1.42 ) (Loss) Income from Discontinued Operations $ (0.24 ) $ (1.02 ) $ (0.15 ) $ 0.09 Net (Loss) Income $ (0.43 ) $ (2.05 ) $ 0.11 $ (1.33 ) | Three Months Ended March 31, June 30, September 30, December 31, 2015 2015 2015 2015 Sales (A) $ 715,740 $ 503,825 $ 631,979 $ 602,772 Freight Revenue $ 5,018 $ 2,750 $ 2,436 $ 10,295 Costs and Expenses (B) $ 399,281 $ 351,200 $ 267,826 $ 243,267 Freight Expense $ 5,018 $ 2,750 $ 2,436 $ 10,295 Income (Loss) from Continuing Operations (C) $ 52,964 $ (577,884 ) $ 129,312 $ 45,342 Income (Loss) from Discontinued Operations $ 26,067 $ (25,417 ) $ (3,842 ) $ (11,017 ) Net Income (Loss) Attributable to CONSOL Energy Shareholders $ 79,031 $ (603,301 ) $ 118,980 $ 30,405 Earnings Per Share Basic: Income (Loss) from Continuing Operations $ 0.23 $ (2.52 ) $ 0.54 $ 0.18 Income (Loss) from Discontinued Operations $ 0.11 $ (0.12 ) $ (0.02 ) $ (0.05 ) Net Income (Loss) $ 0.34 $ (2.64 ) $ 0.52 $ 0.13 Dilutive: Income (Loss) from Continuing Operations $ 0.23 $ (2.52 ) $ 0.54 $ 0.18 Income (Loss) from Discontinued Operations $ 0.11 $ (0.12 ) $ (0.02 ) $ (0.05 ) Net Income (Loss) $ 0.34 $ (2.64 ) $ 0.52 $ 0.13 |
Significant Accounting Policy A
Significant Accounting Policy Anit-Dilutive Securities (Details) - shares | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | |||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 10,074,946 | 5,912,996 | 358,731 |
Employee Stock Option [Member] | |||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | |||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 6,208,813 | 3,621,002 | 358,731 |
Restricted Stock Units (RSUs) [Member] | |||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | |||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 663,003 | 1,375,659 | 0 |
Performance Share Units [Member] | |||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | |||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 2,400,326 | 113,531 | 0 |
Performance Share Options [Member] | |||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | |||
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 802,804 | 802,804 | 0 |
Significant Accounting Policy E
Significant Accounting Policy Earnings Per Share (Details) - USD ($) $ / shares in Units, $ in Thousands | 3 Months Ended | 12 Months Ended | |||||||||
Dec. 31, 2016 | Sep. 30, 2016 | Dec. 31, 2015 | Jun. 30, 2015 | Mar. 31, 2015 | Sep. 30, 2014 | Jun. 30, 2014 | Mar. 31, 2014 | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items] | |||||||||||
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest | $ (535,965) | $ (350,266) | $ 164,947 | ||||||||
Income (Loss) from Continuing Operations Attributable to Parent | $ (321,198) | $ 62,568 | $ 45,342 | $ (234,044) | $ (43,291) | $ 129,312 | $ (577,884) | $ 52,964 | (544,919) | (360,676) | 164,947 |
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax | 19,564 | (34,975) | (11,017) | (234,605) | (53,167) | (3,842) | (25,417) | 26,067 | (303,183) | (14,209) | (1,857) |
Less: Net Loss (Income) Attributable to Noncontrolling Interest | (8,954) | (10,410) | 0 | ||||||||
Net Income Attributable to CONSOL Energy Inc Shareholders | $ (306,047) | $ 25,345 | $ 30,405 | $ (469,828) | $ (97,572) | $ 118,980 | $ (603,301) | $ 79,031 | $ (848,102) | $ (374,885) | $ 163,090 |
Weighted Average Number of Shares Outstanding, Basic | 229,387,403 | 229,186,125 | 229,994,407 | ||||||||
Effect of stock-based compensation awards | 0 | 0 | 1,585,871 | ||||||||
Weighted Average Number of Shares Outstanding, Diluted | 229,387,403 | 229,186,125 | 231,580,278 | ||||||||
Earnings Per Share, Basic | $ (1.33) | $ 0.11 | $ 0.13 | $ (2.05) | $ (0.43) | $ 0.52 | $ (2.64) | $ 0.34 | $ (3.70) | $ (1.64) | $ 0.71 |
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Basic Share | 0.09 | (0.15) | (0.05) | (1.02) | (0.24) | (0.02) | (0.12) | 0.11 | (1.32) | (0.07) | (0.01) |
Income (Loss) from Continuing Operations, Per Basic Share | (1.42) | 0.26 | 0.18 | (1.03) | (0.19) | 0.54 | (2.52) | 0.23 | (2.38) | (1.57) | 0.72 |
Earnings Per Share, Diluted | (1.33) | 0.11 | 0.13 | (2.05) | (0.43) | 0.52 | (2.64) | 0.34 | (3.70) | (1.64) | 0.70 |
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Diluted Share | 0.09 | (0.15) | (0.05) | (1.02) | (0.24) | (0.02) | (0.12) | 0.11 | (1.32) | (0.07) | (0.01) |
Income (Loss) from Continuing Operations, Per Diluted Share | $ (1.42) | $ 0.26 | $ 0.18 | $ (1.03) | $ (0.19) | $ 0.54 | $ (2.52) | $ 0.23 | $ (2.38) | $ (1.57) | $ 0.71 |
Significant Accounting Policy C
Significant Accounting Policy Common Stock Rollforward (Details) - shares | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Common Stock [Roll Forward] | |||
Common Stock, Shares, Outstanding | 229,054,236 | 230,265,463 | 229,145,736 |
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures | 388,772 | 1,001,873 | 1,119,727 |
Common Stock, Shares, Outstanding | 229,443,008 | 229,054,236 | 230,265,463 |
Stock Repurchased and Retired During Period, Shares | 0 | (2,213,100) | 0 |
Significant Accounting Policy O
Significant Accounting Policy Other (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Property, Plant and Equipment [Line Items] | |||
Impairment of Oil and Gas Properties | $ 0 | $ 828,905 | $ 0 |
Exploration and Production Costs | 14,519 | $ 10,120 | $ 23,355 |
Proved Developed [Member] | |||
Property, Plant and Equipment [Line Items] | |||
Impairment of Oil and Gas Properties | 824,742 | ||
proved undeveloped [Member] | |||
Property, Plant and Equipment [Line Items] | |||
Impairment of Oil and Gas Properties | $ 4,163 |
Significant Accounting Policy63
Significant Accounting Policy Other Comprehensive Income (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Accumulated Other Comprehensive Income (Loss), Net of Tax | $ (392,556) | $ (315,598) | |
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax | (392,556) | (359,068) | |
Other Comprehensive Income (Loss), Net of Tax | (76,696) | (164,498) | $ 174,017 |
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax | 0 | $ 43,470 | |
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | (61,730) | ||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (14,966) | ||
Postretirement Benefit Costs [Member] | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Net of Tax | (33,226) | ||
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | (61,730) | ||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 28,504 | ||
Cash Flow Hedging [Member] | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Net of Tax | (43,470) | ||
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 0 | ||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | $ (43,470) |
Significant Accounting Policy64
Significant Accounting Policy Accumulated Other Comprehensive Income (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax | $ 0 | $ 43,470 | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, before Tax | (68,481) | (123,105) | $ (28,753) |
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax | 25,011 | 45,054 | 10,465 |
Defined Benefit Plan, Actuarial Net (Gains) Losses | 23,857 | 119,222 | 46,155 |
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Curtailments | 0 | 5 | (36,182) |
Defined Benefit Plan, Net Periodic Benefit Cost | 22,196 | 19,053 | 29,095 |
Net periodic (benefit) cost | 45,463 | (198,713) | 16,687 |
Actuarially Determined Long-Term Liability Tax Expense | (16,959) | 74,687 | (6,139) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (590) | (336,993) | (22,381) |
Actuarially Long-Term Liabilities Net of Tax | 28,504 | (124,026) | 10,548 |
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax | (392,556) | (359,068) | |
Accumulated Other Comprehensive Income (Loss), Net of Tax | (392,556) | (315,598) | |
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | (61,730) | ||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (14,966) | ||
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Noncontrolling Interest | 262 | ||
Commodity Contract [Member] | Cash Flow Hedging [Member] | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Derivative Instruments, Gain Reclassified from Accumulated OCI into Income, Effective Portion | (43,470) | $ (78,051) | $ (18,288) |
Postretirement Benefit Costs [Member] | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | (61,730) | ||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 28,504 | ||
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Noncontrolling Interest | 262 | ||
Cash Flow Hedging [Member] | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 0 | ||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (43,470) | ||
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Noncontrolling Interest | $ 0 |
Significant Accounting Policy65
Significant Accounting Policy Capitalized Interest (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Accounting Policies [Abstract] | |||
Capitalized Interest Costs, Including Allowance for Funds Used During Construction | $ 1,467 | $ 2,509 | $ 13,573 |
Discontinued Operations (Detail
Discontinued Operations (Details) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016USD ($)TRate | Dec. 31, 2015USD ($) | Dec. 31, 2014USD ($) | |
Impairment of Long-Lived Assets to be Disposed of | $ 0 | $ 828,905 | $ 0 |
Fola/Miller Creek [Member] | |||
Cash Paid to Close Deal | 28,271 | ||
Escrow Deposits Related to Property Sales | 17,200 | ||
Gain (Loss) on Sale of Assets and Asset Impairment Charges | 53,130 | ||
Impairment of Long-Lived Assets to be Disposed of | $ 355,681 | ||
Buchanan and Other Assets [Member] | |||
Royalty Percent | Rate | 20.00% | ||
Royalty Per Ton - Year 1 | T | 75 | ||
Royalty Per Ton - Year 2 | T | 78.75 | ||
Royalty Per Ton - Year 3 | T | 82.69 | ||
Royalty Per Ton - Year 4 | T | 86.82 | ||
Royalty Per Ton - Year 5 | T | 91.16 | ||
Proceeds from Sale of Property Held-for-sale | $ 402,799 | ||
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax | $ (38,364) |
Discontinued Operations Income
Discontinued Operations Income Statement (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Impairment of Long-Lived Assets to be Disposed of | $ 0 | $ 828,905 | $ 0 |
Buchanan and Other Assets [Member] | |||
Disposal group, including discontinued operations, coal sales | 102,904 | 367,234 | 426,263 |
Disposal Group, Including Discontinued Operations, Cargo and Freight Revenue | 1,322 | 5,098 | 5,015 |
Disposal Group, Including Discontinued Operation, Other Income | 740 | 51 | 2,635 |
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax | (91,785) | 336 | (6,640) |
Disposal Group, Including Discontinued Operation, Revenue | 13,181 | 372,719 | 427,273 |
Disposal Group, Including Discontinued Operation, Operating Expense | 134,248 | 395,913 | 431,344 |
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax | (121,067) | (23,194) | (4,071) |
Impairment of Long-Lived Assets to be Disposed of | 355,681 | 0 | 0 |
Discontinued Operation, Tax Effect of Discontinued Operation | (173,565) | (8,985) | (2,214) |
Disposal Group, Including Discontinued Operation, Operating Income (Loss) | $ (303,183) | $ (14,209) | $ (1,857) |
Discontinued Operations Balance
Discontinued Operations Balance Sheet (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Disposal Group, Including Discontinued Operation, Assets, Current | $ 83 | $ 81,105 |
Disposal Group, Including Discontinued Operation, Property, Plant and Equipment | 0 | 936,671 |
Disposal Group, Including Discontinued Operation, Liabilities, Current | 6,050 | 51,514 |
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent | 0 | 107,988 |
Disposal Group, including discontinued operations, reclamation, non-current | 0 | 34,126 |
Disposal Group, Including Discontinued Operation, Liabilities | 0 | 5,001 |
Buchanan and Other Assets [Member] | ||
Disposal Group, Including Discontinued Operation, Accounts, Notes and Loans Receivable, Net | 83 | 49,125 |
Disposal Group, Including Discontinued Operation, Inventory | 0 | 30,646 |
Disposal Group, Including Discontinued Operation, Prepaid and Other Assets | 0 | 970 |
Disposal Group, Including Discontinued Operation, Prepaid and Other Assets, Current | 0 | 364 |
Disposal Group, Including Discontinued Operation, Assets, Current | 83 | 81,105 |
Disposal Group, Including Discontinued Operation, Property, Plant and Equipment | 0 | 936,671 |
Disposal Group, Including Discontinued Operation, Other Assets, Noncurrent | 0 | 4,044 |
Disposal Group, Including Discontinued Operation, Assets | 83 | 1,021,820 |
Disposal Group, Including Discontinued Operation, Accounts Payable | 36 | 20,786 |
Disposal Group, Including Discontinued Operation, Liabilities, Current | 6,014 | 30,728 |
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent | 0 | 5,001 |
Disposal Group, including discontinued operations, Pneumoconiosis Benefits | 0 | 1,129 |
Disposal Group, including discontinued operations, Mine Closing non current | 0 | 71,941 |
Disposal Group, Including Discontinued Operation, Other Liabilities, Noncurrent | 0 | 792 |
Disposal Group, Including Discontinued Operation, Liabilities | $ 6,050 | $ 164,503 |
Acquisitions (Details)
Acquisitions (Details) a in Thousands, $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016USD ($)a | Dec. 31, 2015USD ($) | Dec. 31, 2014USD ($) | |
Business Acquisition [Line Items] | |||
Gas and Oil Area, Undeveloped, Gross | a | 34,467 | ||
Payments to Acquire Property, Plant, and Equipment | $ 226,820 | $ 982,934 | $ 1,459,452 |
Columbia Energy Ventures [Member] | |||
Business Acquisition [Line Items] | |||
Business Acquisition, Cost of Acquired Entity, Transaction Costs | $ 96,106 | ||
Payments to Acquire Property, Plant, and Equipment | 9,000 | 50,969 | |
Other Liabilities, Current | 3,947 | 8,349 | |
Other Long-term Debt, Noncurrent | $ 26,461 | $ 29,333 |
Dispositions (Details)
Dispositions (Details) a in Thousands, $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016USD ($)a | Dec. 31, 2015USD ($) | Dec. 31, 2014USD ($) | |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||
Payments to Acquire Property, Plant, and Equipment | $ 226,820 | $ 982,934 | $ 1,459,452 |
Gas and Oil Area, Undeveloped, Gross | a | 34,467 | ||
Gain (Loss) on Disposition of Assets | $ 19,498 | 74,173 | 43,198 |
Working Capital Adjustment | 6,258 | ||
Industrial Supplies Subsidiary [Member] | |||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||
Proceeds from Sale of Property, Plant, and Equipment | 51,000 | ||
cash flow from investing activities | 44,035 | ||
Gain (Loss) on Disposition of Assets | 30,845 | ||
Western Allegheny Energy [Member] | |||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||
Gain (Loss) on Disposition of Assets | 48,468 | ||
Business Acquisition, Cost of Acquired Entity, Transaction Costs | 76,297 | ||
Certain Loans Acquired in Transfer, Nonaccretable Difference | 2,136 | ||
Accumulated Distributions in Excess of Net Income | 10,780 | ||
Columbia Energy Ventures [Member] | |||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||
Payments to Acquire Property, Plant, and Equipment | 9,000 | 50,969 | |
Business Acquisition, Cost of Acquired Entity, Transaction Costs | $ 96,106 | ||
Other Liabilities, Current | 3,947 | 8,349 | |
Other Long-term Debt, Noncurrent | $ 26,461 | $ 29,333 |
Other Income (Details)
Other Income (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Component of Operating Income [Abstract] | |||
Interest Income (Expense), Net | $ 10,834 | $ 9,530 | $ 23,520 |
Equity in Earnings of Affiliates | (36,059) | (37,984) | (45,059) |
Contracts Revenue | 6,288 | 0 | 30,000 |
Royalty Revenue | 20,083 | 15,402 | 19,653 |
Right of Way Issuance | 27,343 | 13,289 | 7,333 |
Interest Income, Other | 1,507 | 2,299 | 2,303 |
Income (Loss) from Equity Method Investments | 48,260 | 43,799 | 29,807 |
Other Nonoperating Income | 6,357 | 9,354 | 20,772 |
Revenue, Coal Services | 5,757 | 1,596 | 9,029 |
Proceeds from Divestiture of Businesses and Interests in Affiliates | $ (4,818) | $ (11,098) | $ (19,984) |
Income Taxes Income Tax Compone
Income Taxes Income Tax Components (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Income Tax Contingency [Line Items] | |||
Valuation Allowance, Deferred Tax Asset, Change in Amount | $ 10,591 | $ 9,420 | |
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount | 76,750 | ||
Unrecognized Tax Benefits | $ 9,103 | $ 4,265 | |
Effective Income Tax Rate Reconciliation, Amount [Abstract] | |||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 35.00% | 35.00% | 35.00% |
Effective Income Tax Rate Reconciliation, Tax Settlement, State and Local, Amount | $ 20,047 | $ 39,492 | $ (1,436) |
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Depletion, Amount | $ (18,960) | $ (29,526) | $ (42,302) |
Income Taxes Effective Tax Rate
Income Taxes Effective Tax Rate Reconciliation (Details) - USD ($) | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Effective Tax Rate Reconciliation [Abstract] | |||
Income Tax Examination, Liability (Refund) Adjustment from Settlement with Taxing Authority | $ 92,000,000 | $ 36,619,000 | |
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount | $ (187,218,000) | $ (166,497,000) | $ 63,053,000 |
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 35.00% | 35.00% | 35.00% |
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Depletion, Amount | $ (18,960,000) | $ (29,526,000) | $ (42,302,000) |
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Depletion, Percent | 3.50% | 6.20% | (23.50%) |
Effective Income Tax Rate Reconciliation, Deduction, Qualified Production Activity, Amount | $ 0 | $ 0 | $ 1,235,000 |
Effective Income Tax Rate Reconciliation, Deduction, Qualified Production Activity, Percent | (0.00%) | (0.00%) | 0.70% |
Effective Income Tax Rate Reconciliation, Tax Contingency, Amount | $ (6,789,000) | $ 13,576,000 | $ (8,331,000) |
Effective Income Tax Rate Reconciliation, Tax Contingency, Percent | 1.30% | (2.90%) | (4.60%) |
Effective Income Tax Rate Reconciliation, Tax Settlement, Amount | $ 36,619,000 | $ (36,000) | $ (5,248,000) |
Effective Income Tax Rate Reconciliation, Tax Settlement, Percent | (6.80%) | 0.00% | (3.00%) |
Effective Income Tax Rate Reconciliation, Tax Settlement, State and Local, Amount | $ (25,629,000) | $ (10,109,000) | $ 5,235,000 |
Effective Income Tax Rate Reconciliation, Tax Settlement, State and Local, Percent | 4.80% | 2.10% | 2.90% |
Effective Income Tax Rate Reconciliation, Tax Settlement, State and Local, Amount | $ 20,047,000 | $ 39,492,000 | $ (1,436,000) |
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent | (3.70%) | (8.30%) | (0.80%) |
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount | $ 187,759,000 | $ 25,903,000 | $ 0 |
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Percent | (35.10%) | (5.00%) | |
Effective Income Tax Rate Reconciliation, Tax Credit, Foreign, Amount | $ 1,966,000 | $ 964,000 | $ 1,411,000 |
Effective Income Tax Rate Reconciliation, Tax Credit, Foreign, Percent | (0.40%) | 0.20% | (1.00%) |
Effective Income Tax Rate Reconciliation, Deduction, Other, Amount | $ 2,215,000 | $ 794,000 | $ 4,057,000 |
Effective Income Tax Rate Reconciliation, Deduction, Other, Percent | (0.50%) | 0.20% | (2.10%) |
Income Tax Expense (Benefit) | $ 10,010,000 | $ (125,439,000) | $ 15,204,000 |
Effective Income Tax Rate Reconciliation, Percent | (1.90%) | 26.30% | 8.30% |
Income Taxes Income Taxes (Deta
Income Taxes Income Taxes (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Valuation Allowance [Line Items] | |||
Deferred Tax Assets, Tax Credit Carryforwards, Foreign | $ 39,850 | $ 25,903 | |
Deferred Tax Assets, Tax Credit Carryforwards, Alternative Minimum Tax | 219,872 | 143,122 | |
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 305 | 53 | |
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense | 252 | 53 | |
Deferred Tax Assets, Valuation Allowance, Noncurrent | 60,488 | 42,983 | |
Valuation Allowance, Deferred Tax Asset, Change in Amount | 10,591 | 9,420 | |
Current Federal Tax Expense (Benefit) | (103,562) | 19,726 | $ 18,388 |
Current State and Local Tax Expense (Benefit) | (8,699) | (5,657) | 2,724 |
Current Foreign Tax Expense (Benefit) | 1,966 | 964 | 1,411 |
Current Income Tax Expense (Benefit) | (110,295) | 15,033 | 22,523 |
Deferred Federal Income Tax Expense (Benefit) | 124,766 | (181,859) | (12,581) |
Deferred State and Local Income Tax Expense (Benefit) | (4,461) | 41,387 | 5,262 |
Deferred Income Tax Expense (Benefit) | 120,305 | (140,472) | (7,319) |
Income Tax Expense (Benefit) | 10,010 | $ (125,439) | $ 15,204 |
Charitable Contributions [Member] | |||
Valuation Allowance [Line Items] | |||
Deferred Tax Assets, Valuation Allowance, Noncurrent | 5,051 | ||
Alternative Minimum tax credit [Member] | |||
Valuation Allowance [Line Items] | |||
Deferred Tax Assets, Valuation Allowance, Noncurrent | $ 166,798 |
Income Taxes Net Deferred Tax a
Income Taxes Net Deferred Tax assets/Liabilities (Details) - USD ($) | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Income Tax Disclosure [Abstract] | ||
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Postretirement Benefits | $ 260,959,000 | $ 257,604,000 |
Deferred Tax Assets, Operating Loss Carryforwards, Domestic | 144,450,000 | 165,951,000 |
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Asset Retirement Obligations | 39,860,000 | 63,399,000 |
Deferred Tax Assets, Property, Plant and Equipment | 2,925,000 | 4,404,000 |
Deferred Tax Assets, Equity Method Investments | 0 | 45,746,000 |
Deferred Tax Assets, Tax Credit Carryforwards, Alternative Minimum Tax | 219,872,000 | 143,122,000 |
deferred tax assets - gas well closing | 68,585,000 | 79,246,000 |
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits | 43,997,000 | 44,830,000 |
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Other | 30,758,000 | 31,544,000 |
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Pensions | 42,393,000 | 30,177,000 |
Deferred Tax Assets, Operating Loss Carryforwards | 74,310,000 | 76,171,000 |
Deferred Tax Assets, Hedging Transactions | 72,105,000 | 0 |
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Accrued Liabilities | 29,532,000 | 44,317,000 |
Deferred Tax Assets, Tax Credit Carryforwards, Foreign | 39,850,000 | 39,850,000 |
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals | 0 | 14,122,000 |
Deferred Tax Assets, Other | 66,724,000 | 65,427,000 |
Deferred Tax Assets, Gross | 1,136,320,000 | 1,105,910,000 |
Deferred Tax Assets, Valuation Allowance | (282,778,000) | (78,306,000) |
Deferred Tax Assets | 853,542,000 | 1,027,604,000 |
Deferred Tax Liabilities, Property, Plant and Equipment | (782,710,000) | (946,778,000) |
Deferred Tax Liabilities, Investment in Noncontrolled Affiliates | (40,200,000) | 0 |
Deferred Tax Liabilities, Derivatives | 0 | (105,864,000) |
Deferred Tax Liabilities, Leasing Arrangements | (22,326,000) | (44,921,000) |
Deferred Tax Liabilities, Other | (4,016,000) | (4,670,000) |
Deferred Tax Liabilities, Gross | (849,252,000) | (1,102,233,000) |
Deferred Tax Liabilities, Net | 4,290,000 | (74,629,000) |
Deferred Federal Income Tax Expense (Benefit) | 74,310 | 76,171 |
Deferred Tax Assets, Valuation Allowance, Noncurrent | 60,488,000 | 42,983,000 |
Valuation Allowance, Deferred Tax Asset, Change in Amount | $ 10,591,000 | $ 9,420,000 |
Income Taxes Unrecognized tax b
Income Taxes Unrecognized tax benefits (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Income Tax Disclosure [Abstract] | |||
Unrecognized Tax Benefits | $ 12,702 | $ 4,265 | |
Increase in Unrecognized Tax Benefits is Reasonably Possible | $ 666 | ||
Unrecognized Tax Benefits | 9,103 | 4,265 | |
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued | 305 | 53 | |
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions | 0 | ||
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions | 0 | 8,437 | |
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities | 4,265 | 0 | |
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense | $ 252 | $ 53 |
Stock Repurchase (Details)
Stock Repurchase (Details) - USD ($) $ / shares in Units, $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Class of Stock [Line Items] | ||
Stock Repurchase Program, Authorized Amount | $ 250,000 | |
Stock Repurchased During Period, Shares | 2,213,100 | |
Treasury Stock Acquired, Average Cost Per Share | $ 32.37 |
Mine Closing, Reclamation, an78
Mine Closing, Reclamation, and Gas Well Closing (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Asset Retirement Obligation, Beginning of Period | $ 429,967 | $ 454,832 |
Asset Retirement Obligation, Cash Paid to Settle | (15,882) | (18,033) |
Accretion Expense | 23,924 | 32,438 |
Asset Retirement Obligation, End of Period | 473,544 | 429,967 |
Asset Retirement Obligation, Other Change | (785) | (5,286) |
Asset Retirement Obligation, Revision of Estimate | $ 36,320 | (33,984) |
Jones Fork Mine [Member] | ||
Asset Retirement Obligation, Other Change | (2,355) | |
Hamilton No. 1 and 2 Mines [Member] | ||
Asset Retirement Obligation, Other Change | $ (2,133) |
Inventory Components (Details)
Inventory Components (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Inventory Disclosure [Abstract] | ||
Coal | $ 7,800 | $ 4,660 |
Supplies | 57,661 | 62,132 |
Total Inventories | $ 65,461 | $ 66,792 |
Property, Plant and Equipment80
Property, Plant and Equipment PROPERTY PLANT AND EQUIPMENT (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Impairment of Oil and Gas Properties | $ 0 | $ 828,905 | $ 0 |
Proved Oil and Gas Property, Successful Effort Method | 2,016,916 | 1,922,602 | |
Drilling Cost | 3,583,565 | 3,452,989 | |
Unproved Oil and Gas Property, Successful Effort Method | 1,116,282 | 1,421,083 | |
Property, Plant and Equipment, Gross | 13,771,388 | 13,794,907 | |
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | 5,630,949 | 5,062,201 | |
Total Property, Plant and Equipment-Net | 8,140,439 | 9,669,377 | |
Property, Plant, and Equipment, Owned, Net | 8,140,439 | 8,732,706 | |
Gas Segment [Member] | |||
Proved Oil and Gas Property, Successful Effort Method | 1,922,602 | ||
Drilling Cost | 3,583,565 | 3,452,989 | |
Unproved Oil and Gas Property, Successful Effort Method | 1,421,083 | ||
Gas Gathering Systems Net | 1,138,299 | 1,147,173 | |
Gas wells and related equipment | 791,996 | 785,744 | |
Other gas assets | 190,406 | 125,691 | |
Advances for Gas Exploration, Development and Production Amount | 13,762 | 19,745 | |
Property, Plant and Equipment, Gross | 8,851,226 | 8,875,027 | |
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | 3,106,296 | 2,695,674 | |
Total Property, Plant and Equipment-Net | 5,744,930 | 6,179,353 | |
PA Operations [Member] | |||
Coal and other plant and equipment | 2,307,668 | 2,284,103 | |
Coal Properties And Surface Lands | 458,398 | 456,044 | |
Property, Plant and Equipment, Other, Gross | 371,752 | 351,870 | |
Mine development | 326,152 | 326,225 | |
Prepaid Royalties | 16,224 | 16,263 | |
Property Subject to or Available for Operating Lease, Gross | 26,566 | 26,402 | |
Property, Plant and Equipment, Gross | 3,506,760 | 3,460,907 | |
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | 1,768,712 | 1,603,642 | |
Total Property, Plant and Equipment-Net | 1,738,048 | 1,857,265 | |
Other Segments [Member] | |||
Coal and other plant and equipment | 532,919 | 569,333 | |
Coal Properties And Surface Lands | 481,126 | 484,348 | |
Property, Plant and Equipment, Other, Gross | 10,003 | 10,002 | |
Mine development | 17,988 | 18,073 | |
Prepaid Royalties | 310,530 | 312,452 | |
Property Subject to or Available for Operating Lease, Gross | 60,836 | 64,765 | |
Property, Plant and Equipment, Gross | 1,413,402 | 1,458,973 | |
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | 755,941 | 762,885 | |
Total Property, Plant and Equipment-Net | 657,461 | $ 696,088 | |
Proved Developed [Member] | |||
Impairment of Oil and Gas Properties | 824,742 | ||
proved undeveloped [Member] | |||
Impairment of Oil and Gas Properties | $ 4,163 |
Property, Plant and Equipment A
Property, Plant and Equipment Assets Amortized by Units of Production (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Property, Plant and Equipment [Line Items] | ||
Unproved Oil and Gas Property, Successful Effort Method | $ 1,116,282 | $ 1,421,083 |
Property, Plant and Equipment, Gross | 13,771,388 | 13,794,907 |
Assets amortized by units of production [Member] | ||
Property, Plant and Equipment [Line Items] | ||
Unproved Oil and Gas Property, Successful Effort Method | 1,116,282 | 1,421,083 |
Coal Properties And Surface Lands | 195,354 | 258,099 |
Mine development | 7,771 | 7,930 |
Property Subject to or Available for Operating Lease, Gross | 36,788 | 44,805 |
Prepaid Royalties | 16,270 | 21,544 |
Advances for Gas Exploration, Development and Production Amount | 13,762 | 19,745 |
Property, Plant and Equipment, Gross | 1,405,920 | 1,797,880 |
Property, Plant and Equipment, Other, Gross | $ 19,693 | $ 24,674 |
Property, Plant and Equipment C
Property, Plant and Equipment Capital Leases (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Capital Leased Assets [Line Items] | ||
Capital Lease Obligations | $ 77,438 | $ 79,551 |
Capital Leases, Lessee Balance Sheet, Assets by Major Class, Accumulated Depreciation | 51,213 | 46,503 |
PA Operations [Member] | ||
Capital Leased Assets [Line Items] | ||
Capital Lease Obligations | 2,525 | 1,923 |
Computer Equipment [Member] | ||
Capital Leased Assets [Line Items] | ||
Capital Lease Obligations | 1,979 | 3,235 |
jewell ridge pipeline [Member] | ||
Capital Leased Assets [Line Items] | ||
Capital Lease Obligations | 66,919 | |
Gas Segment [Member] | ||
Capital Leased Assets [Line Items] | ||
Capital Lease Obligations | $ 6,015 | $ 7,474 |
Property, Plant and Equipment J
Property, Plant and Equipment Joint Participation Agreements (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Proceeds from Divestiture of Interest in Joint Venture | $ 213,295 | $ 0 | $ 0 |
Hess [Member] | |||
Drilling commitment carry | $ 335,000 |
Short-Term Notes Payable (Detai
Short-Term Notes Payable (Details) | 12 Months Ended | ||
Dec. 31, 2016USD ($)Rate | Sep. 30, 2016USD ($) | Dec. 31, 2015USD ($) | |
Short-term Debt [Line Items] | |||
Credit facility, face amount | $ 400,000,000 | ||
Short-Term Notes Payable (Note 12) | $ 0 | $ 952,000,000 | |
Terms of Credit Facility | $ 150,000,000 | ||
minimum current ratio per credit facility | Rate | 1 | ||
Interest coverage ratio | Rate | 2.59 | ||
Current Maximum Leverage Ratio | Rate | 2.75 | ||
Senior Secured Credit Facility April122016 Member [Member] | |||
Short-term Debt [Line Items] | |||
Credit facility, face amount | 2,000,000,000 | ||
letters of credit sub limit | $ 750,000 | ||
Additional Capacity Available On Credit Lines At Request | $ 500,000,000 | ||
Minimum interest coverage ratio | Rate | 2.50 | ||
Interest coverage ratio | 3.49 | ||
Letters of credit outstanding | $ 325,676,000 | 258,177,000 | |
Borrowings and issuance of letters of credit remaining capacity | $ 1,674,324,000 | $ 789,823,000 |
Other Accrued Liabilities (Deta
Other Accrued Liabilities (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Other Liabilities Disclosure [Abstract] | ||
Derivative Instruments and Hedges, Liabilities | $ 231,573 | $ 12,206 |
Subsidence Liability | 104,437 | 86,860 |
Accrued Royalties | 44,657 | 38,707 |
Interest Payable, Current | 37,366 | 38,406 |
Accrual for Taxes Other than Income Taxes, Current | 20,679 | 10,927 |
Accrued Bonuses, Current | 19,497 | 6,802 |
Deferred Revenue | 18,211 | 11,557 |
Employee-related Liabilities | 24,649 | 24,952 |
Lease Incentive, Payable, Current | 15,286 | 15,286 |
Accrued Liabilities and Other Liabilities | 59,025 | 60,052 |
Other Postretirement Benefits Payable | 42,001 | 46,105 |
Accrued Reclamation Costs, Current | 0 | 515 |
Pneumoconiosis Liability, Current | 10,763 | 9,382 |
Defined Benefit Pension Plan Liabilities, Current | 2,904 | 2,772 |
Long Term Disability, Current | 3,865 | 4,248 |
Mine closing liability, current | 14,276 | 22,599 |
Gas well closing liability, current | 17,285 | 15,648 |
Workers' Compensation Liability, Current | 13,874 | 14,803 |
Other Accrued Liabilities | $ 680,348 | $ 421,827 |
Long-Term Debt (Details)
Long-Term Debt (Details) - USD ($) | 9 Months Ended | 12 Months Ended | |||
Sep. 30, 2016 | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | Mar. 31, 2016 | |
Debt Instrument [Line Items] | |||||
Proceeds from Issuance of Private Placement | $ 500,000,000 | ||||
Long-term Debt | $ 2,724,672,000 | $ 2,705,718,000 | |||
Unamortized Debt Issuance Expense | 27,699,000 | 33,017,000 | |||
Less amounts due in one year | (1,677,000) | (1,819,000) | |||
Long-term Debt, Excluding Current Maturities | 2,722,995,000 | 2,703,899,000 | |||
Debt and Capital Lease Obligations | 10,323,000 | 7,590,000 | |||
Gains (Losses) on Extinguishment of Debt | 0 | (67,751,000) | $ (95,267,000) | ||
Senior Secured Notes due April 2022 [Member] | |||||
Debt Instrument [Line Items] | |||||
Long-term Debt | 1,854,731,000 | ||||
Senior Notes due April 2023 [Member] | |||||
Debt Instrument [Line Items] | |||||
Long-term Debt | 494,344,000 | 493,439,000 | |||
Long-term Debt, Percentage Bearing Fixed Interest, Amount | 0.0800 | ||||
Debt Instrument, Unamortized Discount | 7,240,000 | ||||
Senior Notes 8.25 Percent Due April 2020 Amount Purchased [Member] | |||||
Debt Instrument [Line Items] | |||||
Long-term Debt | 2,508,000 | $ 937,822,000 | |||
Gains (Losses) on Extinguishment of Debt | (67,734,000) | ||||
Senior notes due April 2020 at 8.25% | |||||
Debt Instrument [Line Items] | |||||
Long-term Debt | 74,470,000 | 74,470,000 | |||
Long-term Debt, Percentage Bearing Fixed Interest, Amount | 0.0825 | ||||
Gains (Losses) on Extinguishment of Debt | (17,000) | ||||
Revolving Credit Facility [Member] | |||||
Debt Instrument [Line Items] | |||||
Line of Credit Facility, Maximum Borrowing Capacity | 400,000,000 | ||||
Long-term Debt | 201,000,000 | 185,000,000 | |||
Senior Secured Notes Due March 2021 Par Value Amount Purchased [Member] | |||||
Debt Instrument [Line Items] | |||||
Long-term Debt | 213,000 | $ 229,176,000 | |||
Senior notes due March 2021 at 6.375% | |||||
Debt Instrument [Line Items] | |||||
Long-term Debt | 20,611,000 | 20,611,000 | |||
Long-term Debt, Percentage Bearing Fixed Interest, Amount | 0.06375 | ||||
Senior Secured Notes Due April 2022 Par Value [Member] | |||||
Debt Instrument [Line Items] | |||||
Long-term Debt | 1,855,617,000 | ||||
Baltimore Port Facility revenue bonds in series due September 2025 at 5.75% | |||||
Debt Instrument [Line Items] | |||||
Long-term Debt | 102,865,000 | 102,865,000 | |||
Advance royalty commitments | |||||
Debt Instrument [Line Items] | |||||
Long-term Debt | 2,678,000 | 3,964,000 | |||
Note due through December 2012 at 6.10% | |||||
Debt Instrument [Line Items] | |||||
Long-term Debt | $ 1,672,000 | $ 2,769,000 |
Long-Term Debt Debt Maturity Sc
Long-Term Debt Debt Maturity Schedule (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Debt Instrument [Line Items] | ||
Long-term Debt | $ 2,724,672 | $ 2,705,718 |
Unamortized Debt Issuance Expense | 27,699 | 33,017 |
Less amounts due in one year | (1,677) | (1,819) |
Long-term Debt, Excluding Current Maturities | 2,722,995 | 2,703,899 |
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months | 1,804 | |
Long-term Debt, Maturities, Repayments of Principal in Year Two | 672 | |
Long-term Debt, Maturities, Repayments of Principal in Year Three | 292 | |
Long-term Debt, Maturities, Repayments of Principal in Year Four | 275,740 | |
Long-term Debt, Maturities, Repayments of Principal in Year Five | 20,861 | |
Long-term Debt, Maturities, Repayments of Principal after Year Five | 2,454,043 | |
Long-term Debt | 2,753,412 | |
Senior notes due April 2020 at 8.25% | ||
Debt Instrument [Line Items] | ||
Long-term Debt | 74,470 | 74,470 |
Senior notes due March 2021 at 6.375% | ||
Debt Instrument [Line Items] | ||
Long-term Debt | 20,611 | 20,611 |
Revolving Credit Facility [Member] | ||
Debt Instrument [Line Items] | ||
Long-term Debt | 201,000 | 185,000 |
Senior Secured Notes Due April 2022 Par Value [Member] | ||
Debt Instrument [Line Items] | ||
Long-term Debt | 1,855,617 | |
Senior Notes due April 2023 [Member] | ||
Debt Instrument [Line Items] | ||
Long-term Debt | 494,344 | 493,439 |
Baltimore Port Facility revenue bonds in series due September 2025 at 5.75% | ||
Debt Instrument [Line Items] | ||
Long-term Debt | 102,865 | 102,865 |
Advance royalty commitments | ||
Debt Instrument [Line Items] | ||
Long-term Debt | 2,678 | 3,964 |
Note due through December 2012 at 6.10% | ||
Debt Instrument [Line Items] | ||
Long-term Debt | $ 1,672 | $ 2,769 |
Leases Operating Leases (Detail
Leases Operating Leases (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Operating Leased Assets [Line Items] | |||
Assets Subleased to a Third party | $ 26,005 | $ 15,603 | |
Operating Leases, Rent Expense | 108,698 | $ 109,789 | $ 111,257 |
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract] | |||
Operating Leases, Future Minimum Payments Due, Current | 103,325 | ||
Operating Leases, Future Minimum Payments, Due in Two Years | 64,520 | ||
Operating Leases, Future Minimum Payments, Due in Three Years | 37,272 | ||
Operating Leases, Future Minimum Payments, Due in Four Years | 27,722 | ||
Operating Leases, Future Minimum Payments, Due in Five Years | 26,816 | ||
Operating Leases, Future Minimum Payments, Due Thereafter | 80,692 | ||
Operating Leases, Future Minimum Payments Due | 340,347 | ||
Discontinued Operations [Member] | |||
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract] | |||
Operating Leases, Future Minimum Payments Due, Current | 4,496 | ||
Operating Leases, Future Minimum Payments, Due in Two Years | 2,992 | ||
Operating Leases, Future Minimum Payments, Due in Three Years | 1,701 | ||
Operating Leases, Future Minimum Payments, Due in Four Years | 627 | ||
Operating Leases, Future Minimum Payments, Due in Five Years | 0 | ||
Operating Leases, Future Minimum Payments, Due Thereafter | 0 | ||
Operating Leases, Future Minimum Payments Due | 9,816 | ||
333131 Mining Machinery and Equipment Manufacturing [Member] | |||
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract] | |||
Operating Leases, Future Minimum Payments Due, Current | 40,299 | ||
Operating Leases, Future Minimum Payments, Due in Two Years | 13,819 | ||
Operating Leases, Future Minimum Payments, Due in Three Years | 6,909 | ||
Operating Leases, Future Minimum Payments, Due in Four Years | 0 | ||
Operating Leases, Future Minimum Payments, Due in Five Years | 0 | ||
Operating Leases, Future Minimum Payments, Due Thereafter | 0 | ||
Operating Leases, Future Minimum Payments Due | $ 61,027 |
Leases Capital Leases (Details)
Leases Capital Leases (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Capital Leased Assets [Line Items] | ||
Capital Leases, Future Minimum Payments, Interest Included in Payments | $ 8,225 | |
Capital Lease Obligations | 39,074 | $ 34,884 |
Capital Leases, Future Minimum Payments Due | 57,622 | |
Operating Leases, Future Minimum Payments Due | 340,347 | |
Capital Leases, Future Minimum Payments, Net Minimum Payments, Fiscal Year Maturity [Abstract] | ||
Capital Leases, Future Minimum Payments Due, Current | 13,237 | |
Operating Leases, Future Minimum Payments Due, Current | 103,325 | |
Capital Leases, Future Minimum Payments Due in Two Years | 12,442 | |
Operating Leases, Future Minimum Payments, Due in Two Years | 64,520 | |
Capital Leases, Future Minimum Payments Due in Three Years | 11,977 | |
Operating Leases, Future Minimum Payments, Due in Three Years | 37,272 | |
Capital Leases, Future Minimum Payments Due in Four Years | 11,007 | |
Operating Leases, Future Minimum Payments, Due in Four Years | 27,722 | |
Capital Leases, Future Minimum Payments Due in Five Years | 8,959 | |
Operating Leases, Future Minimum Payments, Due in Five Years | 26,816 | |
Capital Leases, Future Minimum Payments Due Thereafter | 0 | |
Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments | 49,397 | |
Operating Leases, Future Minimum Payments, Due Thereafter | 80,692 | |
Capital Lease Obligations, Current | 10,323 | |
Discontinued Operations [Member] | ||
Capital Leased Assets [Line Items] | ||
Capital Leases, Future Minimum Payments Due | 16,953 | |
Operating Leases, Future Minimum Payments Due | 9,816 | |
Capital Leases, Future Minimum Payments, Net Minimum Payments, Fiscal Year Maturity [Abstract] | ||
Capital Leases, Future Minimum Payments Due, Current | 3,699 | |
Operating Leases, Future Minimum Payments Due, Current | 4,496 | |
Capital Leases, Future Minimum Payments Due in Two Years | 3,699 | |
Operating Leases, Future Minimum Payments, Due in Two Years | 2,992 | |
Capital Leases, Future Minimum Payments Due in Three Years | 3,699 | |
Operating Leases, Future Minimum Payments, Due in Three Years | 1,701 | |
Capital Leases, Future Minimum Payments Due in Four Years | 3,699 | |
Operating Leases, Future Minimum Payments, Due in Four Years | 627 | |
Capital Leases, Future Minimum Payments Due in Five Years | 2,157 | |
Operating Leases, Future Minimum Payments, Due in Five Years | 0 | |
Capital Leases, Future Minimum Payments Due Thereafter | 0 | |
Operating Leases, Future Minimum Payments, Due Thereafter | $ 0 |
Pension and OPEB Pension and OP
Pension and OPEB Pension and OPEB Liability Disclosures (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Defined Benefit Plan Disclosure [Line Items] | |||
Pension Contributions | $ 2,900 | ||
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | |||
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (590) | $ (336,993) | $ (22,381) |
Defined Benefit Plan, Service Cost | 235,541 | ||
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Curtailments | 0 | 5 | (36,182) |
Defined Benefit Plan, Net Periodic Benefit Cost | 22,196 | 19,053 | 29,095 |
Net periodic (benefit) cost | 45,463 | (198,713) | 16,687 |
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Actuarial Net (Gains) Losses | (23,857) | (119,222) | (46,155) |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 632,434 | 669,039 | |
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss) [Abstract] | |||
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax | (392,556) | (359,068) | |
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract] | |||
Defined Benefit Plan, Expected Future Benefit Payments in Year Two | 15,193 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Three | 15,061 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Four | 15,044 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Five | 15,056 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter | 76,577 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year One | 15,897 | ||
Pension Plan [Member] | |||
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | |||
Defined Benefit Plan, Service Cost | 1,927 | 8,653 | 17,187 |
Defined Benefit Plan, Interest Cost | 25,491 | 32,095 | 35,363 |
Expected return on plan assets | (46,674) | (51,528) | (51,400) |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | (590) | (666) | (1,217) |
Amortization of actuarial gain | 9,694 | 21,519 | 23,927 |
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Curtailments | 0 | 5 | (549) |
Defined Benefit Plan, Net Periodic Benefit Cost | 22,196 | 19,053 | 29,095 |
Net periodic (benefit) cost | 12,044 | 29,131 | 52,406 |
Defined Benefit Plan, Plan Amendments | 0 | 0 | |
Defined Benefit Plan, Assets Transferred to (from) Plan | 0 | 0 | |
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation | 747,881 | 763,407 | 870,471 |
service cost - prior year | 8,653 | ||
Defined Benefit Plan, Curtailments | 0 | 26,352 | 21,624 |
Defined Benefit Plan, Settlements, Benefit Obligation | (54,197) | (51,497) | |
Defined Benefit Plan, Contributions by Plan Participants | 0 | 0 | |
Defined Benefit Plan, Benefits Paid | (35,709) | (30,400) | |
Defined Benefit Plan, Actuarial Net (Gains) Losses | 46,962 | (39,563) | |
Defined Benefit Plan, Settlements, Plan Assets | (54,197) | (51,497) | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 632,434 | 669,039 | $ 751,176 |
Defined Benefit Plan, Actual Return on Plan Assets | 50,575 | (9,293) | |
Defined Benefit Plan, Contributions by Employer | 2,726 | 9,053 | |
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent | (112,543) | (91,596) | |
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities | (2,904) | (2,772) | |
Defined Benefit Plan, Amounts Recognized in Balance Sheet | (115,447) | (94,368) | |
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss) [Abstract] | |||
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Gains (Losses), before Tax | 299,865 | 288,695 | |
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax | (1,611) | (2,201) | |
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax | 298,254 | 286,494 | |
Defined Benefit Plan, Amount to be Amortized from Accumulated Other Comprehensive Income (Loss) Next Fiscal Year [Abstract] | |||
Defined Benefit Plan, Amortization of Net Prior Service Cost (Credit) | (590) | ||
Defined Benefit Plan, Amortization of Net Gains (Losses) | 9,403 | ||
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets [Abstract] | |||
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation | 745,793 | 761,124 | |
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Projected Benefit Obligation | 747,881 | 763,407 | |
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets | $ 632,434 | $ 669,039 | |
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract] | |||
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate | 4.31% | 4.50% | |
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase | 3.90% | 3.80% | |
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets | 7.25% | 7.75% | 7.75% |
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase | 3.80% | 3.80% | 4.21% |
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 4.52% | 4.07% | 4.87% |
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract] | |||
Defined Benefit Plan, Expected Future Benefit Payments in Year Two | $ 47,100 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Three | 46,211 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Four | 45,773 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Five | 44,206 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter | 223,745 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year One | 47,374 | ||
Other Postretirement Benefit Plan [Member] | |||
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | |||
Defined Benefit Plan, Service Cost | 0 | $ 0 | $ 7,089 |
Defined Benefit Plan, Interest Cost | 24,241 | 27,238 | 44,177 |
Expected return on plan assets | 0 | 0 | 0 |
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) | 0 | (336,327) | (21,163) |
Amortization of actuarial gain | 19,168 | 102,875 | 28,682 |
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Curtailments | 0 | 0 | (35,633) |
Defined Benefit Plan, Net Periodic Benefit Cost | 0 | (8,932) | 0 |
Net periodic (benefit) cost | 43,409 | (215,146) | 23,152 |
Cash Transition Payment | 46,282 | ||
Defined Benefit Plan, Plan Amendments | (28,164) | 43,598 | 315,439 |
Defined Benefit Plan, Assets Transferred to (from) Plan | 0 | (5,242) | |
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation | 700,085 | 671,755 | 760,959 |
Defined Benefit Plan, Curtailments | 0 | 0 | |
Defined Benefit Plan, Settlements, Benefit Obligation | 0 | 0 | |
Defined Benefit Plan, Contributions by Plan Participants | 0 | 1,649 | |
Defined Benefit Plan, Benefits Paid | (45,387) | (60,027) | |
Defined Benefit Plan, Actuarial Net (Gains) Losses | 77,640 | (9,224) | |
Defined Benefit Plan, Settlements, Plan Assets | 0 | 0 | |
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | $ 0 |
Defined Benefit Plan, Actual Return on Plan Assets | 0 | 0 | |
Defined Benefit Plan, Contributions by Employer | 45,387 | 58,378 | |
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent | (659,474) | (630,892) | |
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities | (40,611) | (40,863) | |
Defined Benefit Plan, Amounts Recognized in Balance Sheet | (700,085) | (671,755) | |
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss) [Abstract] | |||
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Gains (Losses), before Tax | 426,392 | 367,920 | |
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax | (28,164) | 0 | |
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax | 398,228 | $ 367,920 | |
Defined Benefit Plan, Amount to be Amortized from Accumulated Other Comprehensive Income (Loss) Next Fiscal Year [Abstract] | |||
Defined Benefit Plan, Amortization of Net Prior Service Cost (Credit) | (2,405) | ||
Defined Benefit Plan, Amortization of Net Gains (Losses) | $ 23,112 | ||
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract] | |||
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate | 4.22% | 4.50% | |
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase | 0.00% | 0.00% | |
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets | 0.00% | 0.00% | 0.00% |
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase | 0.00% | 0.00% | 0.00% |
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 4.50% | 4.03% | 4.88% |
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract] | |||
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year | 6.31% | 6.49% | 6.03% |
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate | 4.50% | 4.50% | 4.50% |
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate | 2,038 | 2,038 | 2,026 |
Defined Benefit Plan, Effect of One-Percentage Point Change in Assumed Health Care Cost Trend Rates [Abstract] | |||
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components | $ 3,659 | ||
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components | 3,053 | ||
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation | 84,381 | ||
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation | 71,751 | ||
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract] | |||
Defined Benefit Plan, Expected Future Benefit Payments in Year Two | 43,829 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Three | 43,932 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Four | 44,136 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Five | 44,233 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter | 215,248 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year One | 40,611 | ||
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements and Curtailments | $ 35,633 | ||
Liability [Member] | Pension Plan [Member] | |||
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract] | |||
DB Plan Curtailment OCI, net of tax | $ 17,793 | ||
Liability [Member] | Other Postretirement Benefit Plan [Member] | |||
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | |||
Defined Benefit Plan, Plan Amendments | $ (1,070) |
Pension and OPEB Pension Plan A
Pension and OPEB Pension Plan Assets Fair Value (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Net Periodic Benefit Cost | $ 22,196 | $ 19,053 | $ 29,095 |
Defined Benefit Plan, Fair Value of Plan Assets | 632,434 | 669,039 | |
Defined Benefit Plan, Actuarial Net (Gains) Losses | (23,857) | (119,222) | (46,155) |
Fair Value, Inputs, Level 1 [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 650 | 641 | |
Fair Value, Inputs, Level 2 [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | |
Cash and Cash Equivalents [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 639 | 631 | |
Cash and Cash Equivalents [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 639 | 631 | |
Cash and Cash Equivalents [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | |
Cash and Cash Equivalents [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | |
Equity Securities [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 11 | 10 | |
Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 11 | 10 | |
Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | |
Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | |
Private Equity Funds [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 631,784 | 668,398 | |
Private Equity Funds [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | |
Private Equity Funds [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | |
Private Equity Funds [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | |
Pension Plan [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Benefit Obligation | 747,881 | 763,407 | 870,471 |
Defined Benefit Plan, Net Periodic Benefit Cost | 22,196 | 19,053 | 29,095 |
Defined Benefit Plan, Fair Value of Plan Assets | 632,434 | 669,039 | 751,176 |
Defined Benefit Plan, Service Cost | 1,927 | 8,653 | 17,187 |
service cost - prior year | 8,653 | ||
Defined Benefit Plan, Interest Cost | 25,491 | 32,095 | 35,363 |
Defined Benefit Plan, Actuarial Net (Gains) Losses | 46,962 | (39,563) | |
Defined Benefit Plan, Plan Amendments | 0 | 0 | |
Defined Benefit Plan, Curtailments | 0 | (26,352) | (21,624) |
Defined Benefit Plan, Settlements, Benefit Obligation | (54,197) | (51,497) | |
Defined Benefit Plan, Contributions by Plan Participants | 0 | 0 | |
Defined Benefit Plan, Benefits Paid | 35,709 | 30,400 | |
Other Postretirement Benefit Plan, Defined Benefit [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Benefit Obligation | 700,085 | 671,755 | 760,959 |
Defined Benefit Plan, Net Periodic Benefit Cost | 0 | (8,932) | 0 |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | 0 |
Defined Benefit Plan, Service Cost | 0 | 0 | 7,089 |
Defined Benefit Plan, Interest Cost | 24,241 | 27,238 | 44,177 |
Defined Benefit Plan, Actuarial Net (Gains) Losses | 77,640 | (9,224) | |
Defined Benefit Plan, Plan Amendments | (28,164) | 43,598 | $ 315,439 |
Defined Benefit Plan, Curtailments | 0 | 0 | |
Defined Benefit Plan, Settlements, Benefit Obligation | 0 | 0 | |
Defined Benefit Plan, Contributions by Plan Participants | 0 | 1,649 | |
Defined Benefit Plan, Benefits Paid | $ 45,387 | $ 60,027 |
CWP and Workers Comp (Details)
CWP and Workers Comp (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | |||
Defined Benefit Plan, Net Periodic Benefit Cost | $ 22,196 | $ 19,053 | $ 29,095 |
Net periodic (benefit) cost | 45,463 | (198,713) | 16,687 |
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Actuarial Net (Gains) Losses | (23,857) | (119,222) | (46,155) |
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss) [Abstract] | |||
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax | (392,556) | (359,068) | |
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract] | |||
Defined Benefit Plan, Expected Future Benefit Payments in Year One | 15,897 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Two | 15,193 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Three | 15,061 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Four | 15,044 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Five | 15,056 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter | 76,577 | ||
Workers Compensation [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Curtailments | 0 | 0 | 0 |
Defined Benefit Plan, Settlements, Plan Assets | 0 | 347 | |
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | |||
Defined Benefit Plan, Service Cost | 7,618 | 9,389 | 9,781 |
Defined Benefit Plan, Interest Cost | 2,550 | 3,195 | 3,577 |
Amortization of actuarial gain | (403) | (31) | (382) |
State administrative fees and insurance bond premiums | 3,265 | 3,581 | 3,352 |
Defined Benefit Plan, Net Periodic Benefit Cost | 0 | 0 | 0 |
Legal and administrative costs | 7,618 | 9,389 | |
Net periodic (benefit) cost | 13,030 | 16,134 | 16,328 |
Legal and administrative costs | 7,618 | 9,389 | |
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation | 79,693 | 83,165 | $ 89,741 |
Defined Benefit Plan, Actuarial Net (Gains) Losses | 123 | (4,089) | |
Defined Benefit Plan, Benefits Paid | (17,028) | (18,999) | |
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets | 1,458 | 1,450 | |
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract] | |||
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent | (67,277) | (69,812) | |
Defined Benefit Plan, Amounts Recognized in Balance Sheet | (79,693) | (83,165) | |
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities | (13,874) | (14,803) | |
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss) [Abstract] | |||
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Gains (Losses), before Tax | (12,914) | (13,440) | |
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax | (12,914) | $ (13,440) | |
Defined Benefit Plan, Amount to be Amortized from Accumulated Other Comprehensive Income (Loss) Next Fiscal Year [Abstract] | |||
Defined Benefit Plan, Amortization of Net Gains (Losses) | $ (610) | ||
Defined Benefit Plan, Assumptions Used in Calculations [Abstract] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 4.26% | 3.84% | 4.57% |
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate | 4.05% | 4.26% | 3.84% |
Coal Workers Pneumoconiosis [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Curtailments | $ 1,307 | $ 0 | |
Defined Benefit Plan, Settlements, Plan Assets | 0 | 0 | |
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | |||
Defined Benefit Plan, Service Cost | 4,327 | 6,491 | $ 5,674 |
Defined Benefit Plan, Interest Cost | 4,283 | 5,116 | 5,537 |
Amortization of actuarial gain | (4,948) | (5,576) | (6,196) |
State administrative fees and insurance bond premiums | 0 | 0 | 0 |
Defined Benefit Plan, Net Periodic Benefit Cost | 0 | 0 | 0 |
Legal and administrative costs | 4,327 | 6,491 | |
Net periodic (benefit) cost | 2,355 | 6,031 | 5,015 |
Legal and administrative costs | 4,327 | 6,491 | |
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||
Defined Benefit Plan, Benefit Obligation | 118,836 | 122,503 | $ 126,098 |
Defined Benefit Plan, Actuarial Net (Gains) Losses | 439 | (5,089) | |
Defined Benefit Plan, Benefits Paid | (11,409) | (10,113) | |
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets | 0 | 0 | |
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract] | |||
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent | (108,073) | (113,032) | |
Defined Benefit Plan, Amounts Recognized in Balance Sheet | (118,836) | (122,503) | |
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities | (10,763) | (9,471) | |
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss) [Abstract] | |||
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Gains (Losses), before Tax | (62,714) | (68,101) | |
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax | (62,714) | $ (68,101) | |
Defined Benefit Plan, Amount to be Amortized from Accumulated Other Comprehensive Income (Loss) Next Fiscal Year [Abstract] | |||
Defined Benefit Plan, Amortization of Net Gains (Losses) | $ (7,631) | ||
Defined Benefit Plan, Assumptions Used in Calculations [Abstract] | |||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 4.60% | 4.21% | 4.75% |
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate | 4.40% | 4.60% | 4.21% |
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract] | |||
Defined Benefit Plan, Expected Future Benefit Payments in Year One | $ 10,763 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Two | 8,417 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Three | 7,606 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Four | 7,137 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Five | 6,963 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter | 35,714 | ||
Deferred Income Taxes and Tax Credits | $ 7,713 | ||
Actuarial Benefits [Member] | |||
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract] | |||
Defined Benefit Plan, Expected Future Benefit Payments in Year One | 12,416 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Two | 11,625 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Three | 11,404 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Four | 11,295 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Five | 11,214 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter | 55,876 | ||
Other Workers Comp benefits [Member] | |||
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract] | |||
Defined Benefit Plan, Expected Future Benefit Payments in Year One | 3,481 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Two | 3,568 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Three | 3,657 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Four | 3,749 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Year Five | 3,842 | ||
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter | 20,701 | ||
Discontinued Operations [Member] | Coal Workers Pneumoconiosis [Member] | |||
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | |||
Defined Benefit Plan, Net Periodic Benefit Cost | $ 1,290 | $ (297) | $ (87) |
Other Employee Benefits Long-Te
Other Employee Benefits Long-Term Disability (Details) - USD ($) | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Net Periodic Benefit Cost | $ 45,463,000 | $ (198,713,000) | $ 16,687,000 |
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax | 33,226,000 | 86,447,000 | (94,989,000) |
Long term disability [Member] | |||
Defined Benefit Plan Disclosure [Line Items] | |||
Defined Benefit Plan, Net Periodic Benefit Cost | $ 2,128 | $ 2,619 | $ 2,213 |
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate | 3.71% | 3.18% | 3.53% |
Defined Benefit Plan, Benefit Obligation | $ 19,144,000 | $ 19,789,000 |
Other Employee Benefits MultiEm
Other Employee Benefits MultiEmployer Plans (Details) - USD ($) | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Net periodic (benefit) cost | $ 45,463,000 | $ (198,713,000) | $ 16,687,000 |
Long term disability [Member] | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Net periodic (benefit) cost | 2,128 | 2,619 | $ 2,213 |
Defined Benefit Plan, Benefit Obligation | $ 19,144,000 | $ 19,789,000 | |
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate | 3.71% | 3.18% | 3.53% |
Retiree Health Benefit Act of 1992 [Domain] | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Multiemployer Plan, Period Contributions | $ 8,455,000 | $ 9,239,000 | $ 10,121,000 |
Multiemployer Plan, Withdrawal Obligation | 93,795,000 | ||
Non-Pension Multiemployer Plans [Domain] | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Letters of Credit Outstanding, Amount | 19,170,000 | 21,473,000 | 21,394,000 |
401k Defined Contribution [Member] | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Defined Contribution Plan, Employer Discretionary Contribution Amount | 12,260 | ||
Defined Contribution Plan, Cost Recognized | $ 20,784,000 | $ 20,058,000 | $ 18,341,000 |
Stock Based Compensation (Detai
Stock Based Compensation (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized | 42,350,000 | ||
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized | $ 40,234 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant | 8,733,169 | ||
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense | $ 11,255 | $ 9,229 | $ 15,243 |
Allocated Share-based Compensation Expense | $ 31,483 | $ 24,513 | 41,877 |
Board Approved Share Increase [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized | 10,550,000 | ||
Performance Options [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value | $ 4,949 |
Stock Based Compensation Weight
Stock Based Compensation Weighted Average Fair Value of Grants (Details) - USD ($) | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 5.73 | |
Stock Options [Member] | ||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Remaining Contractual Te | $ 2.57 | |
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Remaining Contractual Te | 2.57 | |
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual TER | $ 6.02 | |
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Number of Outstanding Options | 6,208,813 | 3,621,002 |
Stock Based Compensation Stock
Stock Based Compensation Stock Option Rollforward (Details) - USD ($) | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward] | |||
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized, Period for Recognition | $ 2.73 | ||
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities | $ 0 | $ 208,000 | $ 2,629,000 |
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures | 388,772 | 1,001,873 | 1,119,727 |
Restricted Stock [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward] | |||
Stock Issued During Period, Value, Restricted Stock Award, Net of Forfeitures | $ 493,000 | $ 26,550,000 | $ 31,360,000 |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value | $ 19,095,000 | $ 20,793,000 | 15,686,000 |
Performance Shares [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number | 1,424,551 | 491,493 | |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value | $ 26.41 | $ 27.83 | |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period | 950,404 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 25.55 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period | 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value | $ 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures in Period | (17,346) | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price | $ 19.62 | ||
Employee Stock Option [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward] | |||
Proceeds from Stock Options Exercised | $ 8,281,000 | 15,011,000 | |
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities | $ 208,000 | 2,629,000 | |
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Number of Outstanding Options | 6,208,813 | 3,621,002 | |
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period, Total Intrinsic Value | $ 2,744,000 | 14,545,000 | |
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price | $ 22.88 | $ 43.15 | |
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures | 3,369,197 | ||
Share-based comp Options Granted Weighted average exercise price | $ 4.22 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period | 0 | ||
Share Based Comp, Exercises, Weighted Average Exercise Price | $ 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures in Period | (781,386) | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price | $ 36.32 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Number | 2,990,263 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value | $ 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Exercise Price | $ 43.12 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Aggregate Intrinsic Value | $ 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Intrinsic Value | $ 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number | 2,990,263 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price | $ 43.12 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual TER | $ 6.02 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Remaining Contractual Te | 2.57 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Remaining Contractual Te | $ 2.57 | ||
Performance Options [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward] | |||
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Number of Outstanding Options | 802,804 | 802,804 | |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value | $ 4,949,000 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price | $ 45.05 | $ 45.05 | |
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures | 0 | ||
Share-based comp Options Granted Weighted average exercise price | $ 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period | 0 | ||
Share Based Comp, Exercises, Weighted Average Exercise Price | $ 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures in Period | 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price | $ 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Number | 802,804 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value | $ 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Exercise Price | $ 45.05 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Aggregate Intrinsic Value | $ 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Intrinsic Value | $ 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number | 802,804 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price | $ 45.05 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual TER | $ 3.42 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Remaining Contractual Te | 3.42 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Remaining Contractual Te | $ 3.42 | ||
Restricted Stock [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number | 663,003 | 1,303,573 | |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value | $ 31.97 | $ 32.60 | |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period | 27,379 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 17.99 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period | (579,246) | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value | $ 32.97 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period | 88,703 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value | $ 30.42 | ||
Directors - thirty three percent per year [Member] | Employee Stock Option [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward] | |||
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Number of Outstanding Options | 320,738 | ||
thirty three percent per year [Member] | Employee Stock Option [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward] | |||
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Number of Outstanding Options | 5,888,075 |
Stock Based Compensation Restri
Stock Based Compensation Restricted and Performance Stock Unit Rollforward (Details) - USD ($) | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant | 8,733,169 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 5.73 | ||
Employee Stock Option [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Number of Outstanding Options | 6,208,813 | 3,621,002 | |
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures in Period | (781,386) | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price | $ 36.32 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Remaining Contractual Te | $ 2.57 | ||
Performance Share Units [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Stock Issued During Period, Value, Restricted Stock Award, Net of Forfeitures | $ 24,283,000 | $ 18,771,000 | $ 11,853,000 |
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Remaining Contractual Te | $ 20,083,000 | 18,759,000 | |
Restricted Stock [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number | 663,003 | 1,303,573 | |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value | $ 31.97 | $ 32.60 | |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period | 27,379 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 17.99 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period | (579,246) | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value | $ 32.97 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value | $ 30.42 | ||
CONSOL Stock Units (CSUs) [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value | $ 110,000 | $ 189,000 | |
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Number of Outstanding Options | 0 | 803,998 | |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value | $ 0 | $ 33.68 | |
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant | 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 0 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures in Period | (803,998) | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price | $ 33.68 |
Stock Based Compensation Option
Stock Based Compensation Option Assumptions and Weighted Average Fair Values (Details) | 12 Months Ended |
Dec. 31, 2016$ / sharesRate | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value | $ / shares | $ 5.73 |
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate | 1.00% |
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate | 0.00% |
Share Based Comp expected forfeiture rate | 2.00% |
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate | 61.00% |
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term, Simplified Method | 4.9 |
Supplemental Cash Flow Suppleme
Supplemental Cash Flow Supplemental Cash Flow (Details) - USD ($) | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Supplemental Cash Flow Information [Abstract] | |||
Income Taxes Paid | $ (81,962,000) | ||
Interest Paid, Net | $ 186,924,000 | $ 207,094,000 | 233,631,000 |
Proceeds from Income Tax Refunds | (18,032,000) | (59,584,000) | |
Capital Lease Obligations [Member] | |||
Other Significant Noncash Transactions [Line Items] | |||
Noncash or Part Noncash Acquisition, Value of Liabilities Assumed | 55 | 4,973 | 1,540 |
Notes Received from Property Sales [Member] | |||
Other Significant Noncash Transactions [Line Items] | |||
Other Significant Noncash Transaction, Value of Consideration Received | $ 6,706 | $ 24,347 | $ 68,800 |
Concentrations of Credit Risk (
Concentrations of Credit Risk (Details) - Customer Concentration Risk [Member] | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Sales Revenue, Goods, Net [Member] | Duke Energy [Member] | |||
Concentration Risk [Line Items] | |||
Concentration Risk, Customer | 242,020 | ||
Sales Revenue, Goods, Net [Member] | NJR Energy Services Company [Member] | |||
Concentration Risk [Line Items] | |||
Concentration Risk, Customer | 295,779 | ||
Accounts Receivable [Member] | |||
Concentration Risk [Line Items] | |||
Concentration Risk, Customer | 220,222 | 151,383 | |
Accounts Receivable [Member] | Gas Customers [Member] | |||
Concentration Risk [Line Items] | |||
Concentration Risk, Customer | 124,509 | 72,664 | |
Accounts Receivable [Member] | All Other [Member] | |||
Concentration Risk [Line Items] | |||
Concentration Risk, Customer | 4,233 | 6,003 | |
Accounts Receivable [Member] | Coal Brokers and Distributors [Member] | |||
Concentration Risk [Line Items] | |||
Concentration Risk, Customer | 28,955 | 14,435 | |
Accounts Receivable [Member] | Steam Coal Utilities [Member] | |||
Concentration Risk [Line Items] | |||
Concentration Risk, Customer | 62,525 | 58,281 |
Financial Instruments Measured
Financial Instruments Measured at Fair Value on a Recurring Basis (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 |
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items] | ||||
Cash and Cash Equivalents | $ 60,475 | $ 72,574 | $ 176,985 | $ 327,420 |
Long-term Debt | 2,724,672 | 2,705,718 | ||
Quoted Prices in Active Markets for Identical Liabilities (Level 1) | ||||
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items] | ||||
Derivative Asset | 0 | 0 | ||
Guarantees, Fair Value Disclosure | 0 | 0 | ||
Significant Other Observable Inputs (Level 2) | ||||
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items] | ||||
Derivative Asset | (188,156) | 266,558 | ||
Guarantees, Fair Value Disclosure | 0 | 0 | ||
Significant Unobservable Inputs (Level 3) | ||||
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items] | ||||
Derivative Asset | 0 | 0 | ||
Guarantees, Fair Value Disclosure | $ (1,362) | $ (1,228) |
Carrying Amounts and Fair Value
Carrying Amounts and Fair Values of Financial Instruments for Which the Fair Value Option Was Not Elected (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Sep. 30, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Short-Term Notes Payable (Note 12) | $ 0 | $ 952,000 | |||
Cash and Cash Equivalents | 60,475 | 72,574 | $ 176,985 | $ 327,420 | |
Long-term debt | $ (2,724,672) | (2,705,718) | |||
Reported Value Measurement [Member] | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Short-Term Notes Payable (Note 12) | $ 0 | 952,000 | |||
Long-term debt | (2,752,371) | (2,738,735) | |||
Estimate of Fair Value Measurement [Member] | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Short-Term Notes Payable (Note 12) | 0 | 952,000 | |||
Cash and Cash Equivalents | 60,475 | ||||
Long-term debt | $ (2,717,582) | $ (1,808,936) |
Derivatives Derivates Impact on
Derivatives Derivates Impact on Income (Details) MMcf in Billions | 12 Months Ended | ||
Dec. 31, 2016USD ($)MMcf | Dec. 31, 2015USD ($)MMcf | Dec. 31, 2014USD ($) | |
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Cash Received on Hedge | $ 245,212,000 | $ 196,348,000 | $ 19,025,000 |
Unrealized Gain (Loss) on Derivatives and Commodity Contracts | (386,233,000) | 196,594,000 | 4,168,000 |
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | (43,470,000) | (18,288,000) | |
Derivative Instruments, Loss Reclassified from Accumulated OCI into Income, Effective Portion | 0 | 0 | 97,316,000 |
Accumulated Other Comprehensive Income (Loss), Net of Tax | (392,556,000) | (315,598,000) | |
Accumulated Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Roll Forward] | |||
Derivative Instruments, Gain (Loss) Recognized in Other Comprehensive Income (Loss), Effective Portion, Net | 43,470,000 | 121,521,000 | 42,493,000 |
Gain (Loss) on Hedging Activity | $ (141,021,000) | $ 392,942,000 | 23,193,000 |
Commodity Member [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Nonmonetary Notional Amount, Volume | MMcf | 0 | 456.1 | |
Reclassification out of Accumulated Other Comprehensive Income [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Unrealized Gain (Loss) on Derivatives and Commodity Contracts | $ 68,481,000 | $ 123,105,000 | 0 |
Accumulated Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Roll Forward] | |||
Gain (Loss) on Hedging Activity | 68,481,000 | 123,105,000 | 0 |
ineffectiveness member [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Unrealized Gain (Loss) on Derivatives and Commodity Contracts | 0 | 0 | 4,168,000 |
Accumulated Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Roll Forward] | |||
Gain (Loss) on Hedging Activity | 0 | 0 | 4,168,000 |
Swap [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Cash Received on Hedge | (225,797,000) | (193,976,000) | (19,025,000) |
Unrealized Gain (Loss) on Derivatives and Commodity Contracts | (520,170,000) | 81,142,000 | 0 |
Accumulated Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Roll Forward] | |||
Gain (Loss) on Hedging Activity | (294,373,000) | 275,118,000 | 19,025,000 |
Natural Gas Liquids [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Cash Received on Hedge | 650,000 | 0 | 0 |
Unrealized Gain (Loss) on Derivatives and Commodity Contracts | (1,148,000) | 0 | 0 |
Accumulated Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Roll Forward] | |||
Gain (Loss) on Hedging Activity | (1,798,000) | 0 | 0 |
Basis Swap [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Cash Received on Hedge | (20,065,000) | (2,372,000) | 0 |
Unrealized Gain (Loss) on Derivatives and Commodity Contracts | 66,604,000 | (7,653,000) | 0 |
Accumulated Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Roll Forward] | |||
Gain (Loss) on Hedging Activity | $ 86,669,000 | $ (5,281,000) | 0 |
Basis Member [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Nonmonetary Notional Amount, Volume | MMcf | 482 | 124.4 | |
Propane [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Nonmonetary Notional Amount, Volume | MMcf | 126 | 0 | |
Natural Gas [Member] | Swap [Member] | Cash Flow Hedging [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Accumulated Other Comprehensive Income (Loss), Net of Tax | $ 0 | $ 43,470,000 | 121,521,000 |
Revenue Mineral Sales [Member] | Natural Gas [Member] | Swap [Member] | Cash Flow Hedging [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | $ (43,470,000) | $ (78,051,000) | $ (18,288,000) |
Derivatives Derivatives by Bala
Derivatives Derivatives by Balance Sheet Location (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Commodity Member [Member] | ||
Derivative [Line Items] | ||
Derivative Asset, Current | $ 16 | $ 234,409 |
Derivative Liability | 277,119 | 5,137 |
Derivative Liability, Current | 67,139 | 5,137 |
Derivative Asset | 29,612 | 278,948 |
Derivative Liability, Noncurrent | 209,980 | 0 |
Derivative Asset, Noncurrent | 29,596 | 44,539 |
Basis Swap [Member] | ||
Derivative [Line Items] | ||
Derivative Asset, Current | 56,916 | 5,429 |
Derivative Liability | 33,168 | 13,775 |
Derivative Liability, Current | 11,575 | 1,569 |
Derivative Asset | 92,519 | 6,522 |
Derivative Liability, Noncurrent | 21,593 | 12,206 |
Derivative Asset, Noncurrent | $ 35,603 | $ 1,093 |
Maximum Potential Total of Futu
Maximum Potential Total of Future Payments Under Commitment Instruments (Details) $ in Thousands | Dec. 31, 2016USD ($) |
Loss Contingencies [Line Items] | |
Loss Contingency, Range of Possible Loss, Portion Not Accrued | $ 937,421 |
Maximum potential total of future payments under commitments | 1,049,957 |
Surety Bond [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 325,676 |
Surety Bond [Member] | Employee-Related | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 82,273 |
Surety Bond [Member] | Environmental | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 998 |
Surety Bond [Member] | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 242,405 |
Surety Bonds: | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 650,078 |
Surety Bonds: | Employee-Related | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 112,810 |
Surety Bonds: | Environmental | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 514,851 |
Surety Bonds: | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 22,417 |
Guarantees [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 74,203 |
Guarantees [Member] | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 74,203 |
Balance on First Anniversary [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 954,774 |
Balance on First Anniversary [Member] | Surety Bond [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 296,784 |
Balance on First Anniversary [Member] | Surety Bond [Member] | Employee-Related | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 67,871 |
Balance on First Anniversary [Member] | Surety Bond [Member] | Environmental | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 600 |
Balance on First Anniversary [Member] | Surety Bond [Member] | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 228,313 |
Balance on First Anniversary [Member] | Surety Bonds: | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 616,705 |
Balance on First Anniversary [Member] | Surety Bonds: | Employee-Related | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 111,510 |
Balance on First Anniversary [Member] | Surety Bonds: | Environmental | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 483,604 |
Balance on First Anniversary [Member] | Surety Bonds: | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 21,591 |
Balance on First Anniversary [Member] | Guarantees [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 41,285 |
Balance on First Anniversary [Member] | Guarantees [Member] | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 41,285 |
More Than One And Within Three Years From Balance Sheet Date [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 80,030 |
More Than One And Within Three Years From Balance Sheet Date [Member] | Surety Bond [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 28,892 |
More Than One And Within Three Years From Balance Sheet Date [Member] | Surety Bond [Member] | Employee-Related | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 14,402 |
More Than One And Within Three Years From Balance Sheet Date [Member] | Surety Bond [Member] | Environmental | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 398 |
More Than One And Within Three Years From Balance Sheet Date [Member] | Surety Bond [Member] | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 14,092 |
More Than One And Within Three Years From Balance Sheet Date [Member] | Surety Bonds: | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 33,371 |
More Than One And Within Three Years From Balance Sheet Date [Member] | Surety Bonds: | Employee-Related | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 1,300 |
More Than One And Within Three Years From Balance Sheet Date [Member] | Surety Bonds: | Environmental | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 31,247 |
More Than One And Within Three Years From Balance Sheet Date [Member] | Surety Bonds: | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 824 |
More Than One And Within Three Years From Balance Sheet Date [Member] | Guarantees [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 17,767 |
More Than One And Within Three Years From Balance Sheet Date [Member] | Guarantees [Member] | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 17,767 |
More Than Three And Within Five Years From Balance Sheet Date [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 13,403 |
More Than Three And Within Five Years From Balance Sheet Date [Member] | Surety Bond [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
More Than Three And Within Five Years From Balance Sheet Date [Member] | Surety Bond [Member] | Employee-Related | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
More Than Three And Within Five Years From Balance Sheet Date [Member] | Surety Bond [Member] | Environmental | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
More Than Three And Within Five Years From Balance Sheet Date [Member] | Surety Bond [Member] | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
More Than Three And Within Five Years From Balance Sheet Date [Member] | Surety Bonds: | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 2 |
More Than Three And Within Five Years From Balance Sheet Date [Member] | Surety Bonds: | Employee-Related | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
More Than Three And Within Five Years From Balance Sheet Date [Member] | Surety Bonds: | Environmental | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
More Than Three And Within Five Years From Balance Sheet Date [Member] | Surety Bonds: | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 2 |
More Than Three And Within Five Years From Balance Sheet Date [Member] | Guarantees [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 13,401 |
More Than Three And Within Five Years From Balance Sheet Date [Member] | Guarantees [Member] | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 13,401 |
Beyond Five Years of Balance Sheet Date [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 1,750 |
Beyond Five Years of Balance Sheet Date [Member] | Surety Bond [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
Beyond Five Years of Balance Sheet Date [Member] | Surety Bond [Member] | Employee-Related | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
Beyond Five Years of Balance Sheet Date [Member] | Surety Bond [Member] | Environmental | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
Beyond Five Years of Balance Sheet Date [Member] | Surety Bond [Member] | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
Beyond Five Years of Balance Sheet Date [Member] | Surety Bonds: | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
Beyond Five Years of Balance Sheet Date [Member] | Surety Bonds: | Employee-Related | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
Beyond Five Years of Balance Sheet Date [Member] | Surety Bonds: | Environmental | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
Beyond Five Years of Balance Sheet Date [Member] | Surety Bonds: | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 0 |
Beyond Five Years of Balance Sheet Date [Member] | Guarantees [Member] | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | 1,750 |
Beyond Five Years of Balance Sheet Date [Member] | Guarantees [Member] | Other Commitments | |
Loss Contingencies [Line Items] | |
Maximum potential total of future payments under commitments | $ 1,750 |
Unrecorded Unconditional Purcha
Unrecorded Unconditional Purchase Obligation (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Purchase Commitment [Member] | ||
Unrecorded Unconditional Purchase Obligation [Line Items] | ||
Less than 1 year | $ 209,797 | |
1 - 3 years | 285,224 | |
3 - 5 years | 243,534 | |
More than 5 years | 622,509 | |
Total Purchase Obligations | 1,361,064 | |
Murray Energy [Member] | ||
Unrecorded Unconditional Purchase Obligation [Line Items] | ||
Contractual Obligation | $ 1,362 | $ 1,228 |
Segment Information Industry Se
Segment Information Industry Segment Results (Details) - USD ($) $ in Thousands | 3 Months Ended | 12 Months Ended | |||||||||
Dec. 31, 2016 | Sep. 30, 2016 | Dec. 31, 2015 | Jun. 30, 2015 | Mar. 31, 2015 | Sep. 30, 2014 | Jun. 30, 2014 | Mar. 31, 2014 | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Segment Reporting Information [Line Items] | |||||||||||
Oil and Gas Sales Revenue | $ 793,248 | $ 726,921 | $ 1,004,924 | ||||||||
Sales-Outside | 1,858,830 | 2,015,957 | 2,621,798 | ||||||||
Gain (Loss) on Hedging Activity | (141,021) | 392,942 | 23,193 | ||||||||
Sales Revenue, Services, Other | 32,038 | 30,967 | 276,242 | ||||||||
Sales-Purchased Gas | 43,256 | 14,450 | 8,999 | ||||||||
Freight-Outside | $ 12,519 | $ 9,392 | $ 10,295 | $ 11,447 | $ 13,110 | $ 2,436 | $ 2,750 | $ 5,018 | 46,468 | 20,499 | 23,133 |
Segment Reporting - Intersegment Transfers | 0 | 0 | 0 | ||||||||
Total Revenue and Other Income | 2,026,375 | 2,693,339 | 3,204,023 | ||||||||
Sales Revenue, Services, Net | 1,839,571 | 2,474,815 | 2,953,365 | ||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (525,955) | (475,705) | 180,151 | ||||||||
Total Assets | 9,183,981 | 10,929,902 | 9,183,981 | 10,929,902 | 11,654,646 | ||||||
Depreciation, Depletion and Amortization | 598,503 | 567,120 | 532,643 | ||||||||
Segment Reporting - Capital Expenditures | 226,820 | 982,934 | 1,459,452 | ||||||||
Equity in Earnings of Affiliates | (53,078) | (54,897) | (49,791) | ||||||||
Total Reportable Business Segments | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (248,132) | (273,863) | 620,682 | ||||||||
Total Assets | 8,217,774 | 8,968,585 | 8,217,774 | 8,968,585 | |||||||
All Other [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Equity in Earnings of Affiliates | (17,574) | ||||||||||
Investments in Unconsolidated Equity Affiliates | 31,237 | ||||||||||
Gas Segment [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Oil and Gas Sales Revenue | 793,248 | 726,921 | 1,004,924 | ||||||||
Gain (Loss) on Hedging Activity | (141,021) | 392,942 | 23,193 | ||||||||
Sales Revenue, Services, Other | 0 | 0 | 0 | ||||||||
Sales-Purchased Gas | 43,256 | 14,450 | 8,999 | ||||||||
Freight-Outside | 0 | 0 | 0 | ||||||||
Segment Reporting - Intersegment Transfers | 424 | 1,538 | 2,458 | ||||||||
Total Revenue and Other Income | 695,907 | 1,135,851 | 1,039,574 | ||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (378,840) | (678,857) | 189,714 | ||||||||
Total Assets | 6,235,568 | 6,892,284 | 6,235,568 | 6,892,284 | 7,364,185 | ||||||
Depreciation, Depletion and Amortization | 417,853 | 370,374 | 323,600 | ||||||||
Segment Reporting - Capital Expenditures | 165,101 | 832,446 | 1,103,656 | ||||||||
Equity in Earnings of Affiliates | (51,742) | (46,614) | (32,217) | ||||||||
Investments in Unconsolidated Equity Affiliates | 188,376 | 234,803 | 188,376 | 234,803 | 121,721 | ||||||
Other Segments [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Sales-Outside | 0 | 0 | 0 | ||||||||
Gain (Loss) on Hedging Activity | 0 | 0 | 0 | ||||||||
Sales Revenue, Services, Other | 32,038 | 30,967 | 276,242 | ||||||||
Sales-Purchased Gas | 0 | 0 | 0 | ||||||||
Freight-Outside | 0 | 0 | 0 | ||||||||
Segment Reporting - Intersegment Transfers | 0 | 0 | 78,229 | ||||||||
Total Revenue and Other Income | 32,038 | 30,967 | 354,471 | ||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (277,399) | (200,304) | (438,073) | ||||||||
Total Assets | 966,124 | 939,497 | 966,124 | 939,497 | 1,186,874 | ||||||
Depreciation, Depletion and Amortization | 12,455 | 19,882 | 35,727 | ||||||||
Segment Reporting - Capital Expenditures | 10,910 | 14,197 | 14,567 | ||||||||
Equity in Earnings of Affiliates | (1,336) | (8,283) | |||||||||
Investments in Unconsolidated Equity Affiliates | 2,588 | 2,527 | 2,588 | 2,527 | |||||||
Intersegment Eliminations [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Sales-Outside | 0 | 0 | 0 | ||||||||
Gain (Loss) on Hedging Activity | 0 | 0 | 0 | ||||||||
Sales Revenue, Services, Other | 0 | 0 | 0 | ||||||||
Sales-Purchased Gas | 0 | 0 | 0 | ||||||||
Freight-Outside | 0 | 0 | 0 | ||||||||
Segment Reporting - Intersegment Transfers | (424) | (1,538) | (80,687) | ||||||||
Total Revenue and Other Income | (424) | (1,538) | (80,687) | ||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (424) | (1,538) | (2,458) | ||||||||
Total Assets | 83 | 1,021,820 | 83 | 1,021,820 | 1,009,546 | ||||||
Depreciation, Depletion and Amortization | 0 | 0 | 0 | ||||||||
Segment Reporting - Capital Expenditures | 0 | 0 | 0 | ||||||||
PA Operations [Member] | Coal Segment [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Sales-Outside | 1,065,582 | 1,289,036 | 1,616,874 | ||||||||
Gain (Loss) on Hedging Activity | 0 | 0 | 0 | ||||||||
Sales Revenue, Services, Other | 0 | 0 | 0 | ||||||||
Sales-Purchased Gas | 0 | 0 | 0 | ||||||||
Freight-Outside | 46,468 | 20,499 | 23,133 | ||||||||
Segment Reporting - Intersegment Transfers | 0 | 0 | 0 | ||||||||
Total Revenue and Other Income | 1,112,050 | 1,309,535 | 1,640,007 | ||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | 130,708 | 404,994 | 430,968 | ||||||||
Total Assets | $ 1,982,206 | $ 2,076,301 | 1,982,206 | 2,076,301 | 2,094,041 | ||||||
Depreciation, Depletion and Amortization | 168,195 | 176,864 | 173,316 | ||||||||
Segment Reporting - Capital Expenditures | 50,809 | 136,291 | 341,229 | ||||||||
Coalbed Methane | Gas Segment [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Oil and Gas Sales Revenue | 174,323 | 200,645 | 340,739 | ||||||||
Gain (Loss) on Hedging Activity | 52,396 | 67,281 | 4,103 | ||||||||
Sales Revenue, Services, Other | 0 | 0 | 0 | ||||||||
Sales-Purchased Gas | 0 | 0 | 0 | ||||||||
Freight-Outside | 0 | 0 | 0 | ||||||||
Segment Reporting - Intersegment Transfers | 424 | 1,538 | 2,458 | ||||||||
Total Revenue and Other Income | 227,143 | 269,464 | 347,300 | ||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | 37,999 | 59,662 | 108,107 | ||||||||
Marcellus Shale | Gas Segment [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Oil and Gas Sales Revenue | 414,484 | 379,453 | 457,679 | ||||||||
Gain (Loss) on Hedging Activity | 147,282 | 100,785 | 14,764 | ||||||||
Sales Revenue, Services, Other | 0 | 0 | 0 | ||||||||
Sales-Purchased Gas | 0 | 0 | 0 | ||||||||
Freight-Outside | 0 | 0 | 0 | ||||||||
Segment Reporting - Intersegment Transfers | 0 | 0 | 0 | ||||||||
Total Revenue and Other Income | 561,766 | 480,238 | 472,443 | ||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | 72,141 | 56,116 | 171,902 | ||||||||
Utica Shale [Member] | Gas Segment [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Oil and Gas Sales Revenue | 163,112 | 92,223 | 86,948 | ||||||||
Gain (Loss) on Hedging Activity | 29,285 | 6,430 | 1,247 | ||||||||
Sales Revenue, Services, Other | 0 | 0 | 0 | ||||||||
Sales-Purchased Gas | 0 | 0 | 0 | ||||||||
Freight-Outside | 0 | 0 | 0 | ||||||||
Segment Reporting - Intersegment Transfers | 0 | 0 | 0 | ||||||||
Total Revenue and Other Income | 192,397 | 98,653 | 88,195 | ||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | 28,390 | (19,428) | 43,645 | ||||||||
Other Gas | Gas Segment [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Oil and Gas Sales Revenue | 41,329 | 54,600 | 119,558 | ||||||||
Gain (Loss) on Hedging Activity | (369,984) | 218,446 | 3,079 | ||||||||
Sales Revenue, Services, Other | 0 | 0 | 0 | ||||||||
Sales-Purchased Gas | 43,256 | 14,450 | 8,999 | ||||||||
Freight-Outside | 0 | 0 | 0 | ||||||||
Segment Reporting - Intersegment Transfers | 0 | 0 | 0 | ||||||||
Total Revenue and Other Income | (285,399) | 287,496 | 131,636 | ||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | $ (517,370) | (775,207) | (133,940) | ||||||||
Duke Energy [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Total Revenue and Other Income | $ 242,020 | ||||||||||
NJR Energy Services Company [Member] | |||||||||||
Segment Reporting Information [Line Items] | |||||||||||
Total Revenue and Other Income | $ 295,779 |
Reconciliation of Segment Infor
Reconciliation of Segment Information, Revenue and Other Income (Details) - USD ($) $ in Thousands | 3 Months Ended | 12 Months Ended | |||||||||
Dec. 31, 2016 | Sep. 30, 2016 | Dec. 31, 2015 | Jun. 30, 2015 | Mar. 31, 2015 | Sep. 30, 2014 | Jun. 30, 2014 | Mar. 31, 2014 | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Segment Reporting, Revenue Reconciling Item [Line Items] | |||||||||||
Revenue From External Customers | $ 1,980,592 | $ 2,081,873 | $ 2,930,172 | ||||||||
Gain (Loss) on Hedging Activity | (141,021) | 392,942 | 23,193 | ||||||||
Earnings Before Income Taxes: | |||||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (525,955) | (475,705) | 180,151 | ||||||||
Other Income | 167,306 | 144,351 | 207,460 | ||||||||
Gain (Loss) on Disposition of Assets | 19,498 | 74,173 | 43,198 | ||||||||
Sales | $ 390,398 | $ 688,590 | $ 602,772 | $ 235,251 | $ 478,864 | $ 631,979 | $ 503,825 | $ 715,740 | 2,026,375 | 2,693,339 | 3,204,023 |
Total Reportable Business Segments | |||||||||||
Earnings Before Income Taxes: | |||||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (248,132) | (273,863) | 620,682 | ||||||||
Gas Segment [Member] | |||||||||||
Segment Reporting, Revenue Reconciling Item [Line Items] | |||||||||||
Gain (Loss) on Hedging Activity | (141,021) | 392,942 | 23,193 | ||||||||
Earnings Before Income Taxes: | |||||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (378,840) | (678,857) | 189,714 | ||||||||
Corporate and Other [Member] | |||||||||||
Earnings Before Income Taxes: | |||||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (85,923) | 66,713 | (119,473) | ||||||||
Other Segments [Member] | |||||||||||
Segment Reporting, Revenue Reconciling Item [Line Items] | |||||||||||
Gain (Loss) on Hedging Activity | 0 | 0 | 0 | ||||||||
Earnings Before Income Taxes: | |||||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (277,399) | (200,304) | (438,073) | ||||||||
Excludes Gas Segment [Member] | |||||||||||
Earnings Before Income Taxes: | |||||||||||
Interest Income (Expense), Net and Other Non-operating Activity | (191,476) | (199,266) | (223,333) | ||||||||
Fees for Disposing Non-core Assets | (424) | (1,538) | 2,458 | ||||||||
Corporate Adjustments And Eliminations [Member] | |||||||||||
Earnings Before Income Taxes: | |||||||||||
Gain (Loss) Estimates on Extinguishment of Debt | 0 | (67,751) | (95,267) | ||||||||
Intersegment Eliminations [Member] | |||||||||||
Segment Reporting, Revenue Reconciling Item [Line Items] | |||||||||||
Gain (Loss) on Hedging Activity | 0 | 0 | 0 | ||||||||
Earnings Before Income Taxes: | |||||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (424) | (1,538) | (2,458) | ||||||||
UNITED STATES | |||||||||||
Segment Reporting, Revenue Reconciling Item [Line Items] | |||||||||||
Revenue From External Customers | 1,799,336 | 1,822,452 | 2,713,833 | ||||||||
Asia [Member] | |||||||||||
Segment Reporting, Revenue Reconciling Item [Line Items] | |||||||||||
Revenue From External Customers | 109,312 | 106,954 | 66,912 | ||||||||
Europe [Member] | |||||||||||
Segment Reporting, Revenue Reconciling Item [Line Items] | |||||||||||
Revenue From External Customers | 40,704 | 112,844 | 121,909 | ||||||||
South America [Member] | |||||||||||
Segment Reporting, Revenue Reconciling Item [Line Items] | |||||||||||
Revenue From External Customers | 25,406 | 28,060 | 19,013 | ||||||||
CANADA | |||||||||||
Segment Reporting, Revenue Reconciling Item [Line Items] | |||||||||||
Revenue From External Customers | $ 5,834 | $ 11,563 | $ 8,505 |
Reconciliation of Segment In110
Reconciliation of Segment Information, Total Assets (Details) - USD ($) | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 |
Assets: | |||
Total Assets | $ 9,183,981,000 | $ 10,929,902,000 | $ 11,654,646,000 |
Items excluded from segment assets: | |||
Income Taxes Receivable, Current | 116,851,000 | 13,887,000 | |
Total Property, Plant and Equipment-Net | 8,140,439,000 | 9,669,377,000 | |
Deferred Tax Assets | 853,542,000 | 1,027,604,000 | |
Unamortized Debt Issuance Expense | 27,699,000 | 33,017,000 | |
Total Reportable Business Segments | |||
Assets: | |||
Total Assets | 8,217,774,000 | 8,968,585,000 | |
Gas Segment [Member] | |||
Assets: | |||
Total Assets | 6,235,568,000 | 6,892,284,000 | 7,364,185,000 |
Items excluded from segment assets: | |||
Total Property, Plant and Equipment-Net | 5,744,930,000 | 6,179,353,000 | |
Corporate and Other [Member] | |||
Assets: | |||
Total Assets | 797,830,000 | 859,675,000 | |
Other Segments [Member] | |||
Assets: | |||
Total Assets | 966,124,000 | 939,497,000 | 1,186,874,000 |
Items excluded from segment assets: | |||
Total Property, Plant and Equipment-Net | 657,461,000 | 696,088,000 | |
Excludes Gas Segment [Member] | |||
Items excluded from segment assets: | |||
Cash and Other Investments | 47,153,000 | 65,935,000 | |
Intersegment Eliminations [Member] | |||
Assets: | |||
Total Assets | 83,000 | 1,021,820,000 | $ 1,009,546,000 |
Items excluded from segment assets: | |||
Income Taxes Receivable, Current | 116,851,000 | 13,887,000 | |
Deferred Tax Assets | 4,290,000 | 0 | |
Disposal Group, Including Discontinued Operation, Assets | 83,000 | 1,021,820,000 | |
UNITED STATES | |||
Segment Reporting, Asset Reconciling Item [Line Items] | |||
Disclosure of Long-Live Assets by Geographic Region | 8,129,415,000 | 8,721,682,000 | |
CANADA | |||
Segment Reporting, Asset Reconciling Item [Line Items] | |||
Disclosure of Long-Live Assets by Geographic Region | 11,024,000 | 11,024,000 | |
Discontinued Operations [Member] | |||
Segment Reporting, Asset Reconciling Item [Line Items] | |||
Disclosure of Long-Live Assets by Geographic Region | $ 0 | $ 936,671,000 |
Segment Information Reconciliat
Segment Information Reconciliation of Earnings Before Income Tax (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Excludes Gas Segment [Member] | |||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | |||
Interest Income (Expense), Net and Other Non-operating Activity | $ (191,476) | $ (199,266) | $ (223,333) |
Fees For Disposing Non Core Assets | 424 | 1,538 | (2,458) |
Corporate, Adjustments and Eliminations | |||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | |||
Gain (Loss) Estimates on Extinguishment of Debt | $ 0 | $ (67,751) | $ (95,267) |
Guarantor Subsidiaries Income S
Guarantor Subsidiaries Income Statement (Details) - USD ($) $ in Thousands | 3 Months Ended | 9 Months Ended | 12 Months Ended | |||||||||
Dec. 31, 2016 | Sep. 30, 2016 | Dec. 31, 2015 | Jun. 30, 2015 | Mar. 31, 2015 | Sep. 30, 2014 | Jun. 30, 2014 | Mar. 31, 2014 | Sep. 30, 2016 | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Schedule of Condensed Consolidating Statement of Operations [Line Items] | ||||||||||||
Oil and Gas Sales Revenue | $ 793,248 | $ 726,921 | $ 1,004,924 | |||||||||
Gain (Loss) on Hedging Activity | (141,021) | 392,942 | 23,193 | |||||||||
Coal Products and Services Revenue | 1,065,582 | 1,289,036 | 1,616,874 | |||||||||
Other Revenue, Net | 32,038 | 30,967 | 276,242 | |||||||||
Gas Royalty Interests and Purchased Gas Sales | 43,256 | 14,450 | 8,999 | |||||||||
Freight-Outside | $ 12,519 | $ 9,392 | $ 10,295 | $ 11,447 | $ 13,110 | $ 2,436 | $ 2,750 | $ 5,018 | 46,468 | 20,499 | 23,133 | |
Other Income | 167,306 | 144,351 | 207,460 | |||||||||
Gain (Loss) on Disposition of Assets | 19,498 | 74,173 | 43,198 | |||||||||
Oil and Gas Property, Lease Operating Expense | 96,434 | 121,847 | 139,242 | |||||||||
Gas Gathering, Transportation, Marketing and Processing Costs | 374,350 | 343,403 | 239,579 | |||||||||
Production Tax Expense | 31,049 | 30,438 | 39,418 | |||||||||
E&P Depreciation, Depletion, and Amortization | 417,853 | 370,374 | 323,600 | |||||||||
Exploration and Production Costs | 14,519 | 10,120 | 23,355 | |||||||||
Production Royalty Interests and Purchased Gas Costs | 42,717 | 10,721 | 7,251 | |||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (525,955) | (475,705) | 180,151 | |||||||||
Other Expenses | 87,913 | 65,939 | 46,838 | |||||||||
Results of Operations, General and Administrative Related to Oil and Gas Producing Activities | 102,503 | 102,229 | 128,731 | |||||||||
Oil and Gas Production Expense | 1,167,338 | 1,883,976 | 948,014 | |||||||||
Operating Expenses | 733,300 | 666,302 | 982,749 | |||||||||
Coal Depreciation, Depletion, Amortization | 168,195 | 176,864 | 173,316 | |||||||||
Freight Expense | 12,519 | 9,392 | 10,295 | 11,447 | 13,110 | 2,436 | 2,750 | 5,018 | 46,468 | 20,499 | 23,133 | |
General and Administrative Expense | 37,512 | 40,843 | 68,597 | |||||||||
Cost of Coal Products and Services | 985,475 | 904,508 | 1,247,795 | |||||||||
Other Nonoperating Income (Expense) | 460,429 | |||||||||||
Other Nonoperating Expense | 182,869 | 78,743 | 460,429 | |||||||||
Other General and Administrative Expense | 12,717 | 14,918 | 13,307 | |||||||||
Depreciation, Depletion and Amortization, Nonproduction | 12,455 | 19,882 | 35,727 | |||||||||
Gains (Losses) on Extinguishment of Debt | 0 | 67,751 | 95,267 | |||||||||
Interest Expense | 191,476 | 199,266 | 223,333 | |||||||||
Other General Expense | 399,517 | 380,560 | 828,063 | |||||||||
Total Costs | 2,552,330 | 3,169,044 | 3,023,872 | |||||||||
Income Taxes | 10,010 | (125,439) | 15,204 | |||||||||
Income (Loss) from Continuing Operations Attributable to Parent | (321,198) | 62,568 | 45,342 | (234,044) | (43,291) | 129,312 | (577,884) | 52,964 | (544,919) | (360,676) | 164,947 | |
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest | (535,965) | (350,266) | 164,947 | |||||||||
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent | (303,183) | (14,209) | (1,857) | |||||||||
Net Income (Loss) | $ (839,148) | (839,148) | (364,475) | 163,090 | ||||||||
Net Income (Loss) Attributable to Noncontrolling Interest | 8,954 | 10,410 | 0 | |||||||||
Net Income Attributable to CONSOL Energy Inc Shareholders | $ (306,047) | $ 25,345 | $ 30,405 | $ (469,828) | $ (97,572) | $ 118,980 | $ (603,301) | $ 79,031 | (848,102) | (374,885) | 163,090 | |
Impairment of Oil and Gas Properties | 0 | 828,905 | 0 | |||||||||
Revenues | 2,026,375 | 2,693,339 | 3,204,023 | |||||||||
Parent Company [Member] | ||||||||||||
Schedule of Condensed Consolidating Statement of Operations [Line Items] | ||||||||||||
Oil and Gas Sales Revenue | 0 | 0 | 0 | |||||||||
Gain (Loss) on Hedging Activity | 0 | 0 | 0 | |||||||||
Coal Products and Services Revenue | 0 | 0 | 0 | |||||||||
Other Revenue, Net | 0 | 0 | 0 | |||||||||
Gas Royalty Interests and Purchased Gas Sales | 0 | 0 | 0 | |||||||||
Freight-Outside | 0 | 0 | 0 | |||||||||
Other Income | (712,927) | (172,450) | 420,030 | |||||||||
Gain (Loss) on Disposition of Assets | 0 | 0 | 0 | |||||||||
Oil and Gas Property, Lease Operating Expense | 0 | 0 | 0 | |||||||||
Gas Gathering, Transportation, Marketing and Processing Costs | 0 | 0 | 0 | |||||||||
Production Tax Expense | 0 | 0 | 0 | |||||||||
E&P Depreciation, Depletion, and Amortization | 0 | 0 | 0 | |||||||||
Exploration and Production Costs | 0 | 0 | 0 | |||||||||
Production Royalty Interests and Purchased Gas Costs | 0 | 0 | 0 | |||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (930,355) | (496,155) | 10,678 | |||||||||
Other Expenses | 0 | 0 | 0 | |||||||||
Results of Operations, General and Administrative Related to Oil and Gas Producing Activities | 0 | 0 | 0 | |||||||||
Oil and Gas Production Expense | 0 | 0 | 0 | |||||||||
Operating Expenses | 0 | 0 | 0 | |||||||||
Coal Depreciation, Depletion, Amortization | 0 | 0 | 0 | |||||||||
Freight Expense | 0 | 0 | 0 | |||||||||
General and Administrative Expense | 0 | 0 | 0 | |||||||||
Cost of Coal Products and Services | 0 | 0 | 0 | |||||||||
Other Nonoperating Income (Expense) | 99,273 | |||||||||||
Other Nonoperating Expense | 43,533 | 69,059 | ||||||||||
Other General and Administrative Expense | 0 | 0 | 788 | |||||||||
Depreciation, Depletion and Amortization, Nonproduction | 568 | 604 | 640 | |||||||||
Gains (Losses) on Extinguishment of Debt | 67,751 | 95,267 | ||||||||||
Interest Expense | 173,327 | 186,291 | 213,384 | |||||||||
Other General Expense | 217,428 | 323,705 | 409,352 | |||||||||
Total Costs | 217,428 | 323,705 | 409,352 | |||||||||
Income Taxes | (82,253) | (121,270) | (152,412) | |||||||||
Income (Loss) from Continuing Operations Attributable to Parent | 163,090 | |||||||||||
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest | (848,102) | (374,885) | ||||||||||
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent | 0 | 0 | 0 | |||||||||
Net Income (Loss) | (848,102) | (374,885) | 163,090 | |||||||||
Net Income (Loss) Attributable to Noncontrolling Interest | 0 | 0 | ||||||||||
Net Income Attributable to CONSOL Energy Inc Shareholders | (848,102) | (374,885) | 163,090 | |||||||||
Impairment of Oil and Gas Properties | 0 | |||||||||||
Revenues | (712,927) | (172,450) | 420,030 | |||||||||
Cnx Gas Guarantor [Member] | ||||||||||||
Schedule of Condensed Consolidating Statement of Operations [Line Items] | ||||||||||||
Oil and Gas Sales Revenue | 793,672 | 728,458 | 1,007,381 | |||||||||
Gain (Loss) on Hedging Activity | (141,021) | 392,942 | 23,193 | |||||||||
Coal Products and Services Revenue | 0 | 0 | 0 | |||||||||
Other Revenue, Net | 0 | 0 | 0 | |||||||||
Gas Royalty Interests and Purchased Gas Sales | 43,256 | 14,450 | 8,999 | |||||||||
Freight-Outside | 0 | 0 | 0 | |||||||||
Other Income | 80,444 | 62,340 | 60,634 | |||||||||
Gain (Loss) on Disposition of Assets | 14,870 | 12,540 | 45,917 | |||||||||
Oil and Gas Property, Lease Operating Expense | 96,434 | 121,847 | 139,242 | |||||||||
Gas Gathering, Transportation, Marketing and Processing Costs | 374,350 | 343,403 | 239,591 | |||||||||
Production Tax Expense | 31,049 | 30,438 | 39,418 | |||||||||
E&P Depreciation, Depletion, and Amortization | 417,853 | 370,374 | 323,600 | |||||||||
Exploration and Production Costs | 14,519 | 10,120 | 22,718 | |||||||||
Production Royalty Interests and Purchased Gas Costs | 42,717 | 10,721 | 7,251 | |||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (378,840) | (678,859) | 189,714 | |||||||||
Other Expenses | 87,913 | 65,939 | 46,838 | |||||||||
Results of Operations, General and Administrative Related to Oil and Gas Producing Activities | 102,503 | 102,229 | 128,731 | |||||||||
Oil and Gas Production Expense | 1,167,338 | 1,883,976 | 947,389 | |||||||||
Operating Expenses | 0 | 0 | 0 | |||||||||
Coal Depreciation, Depletion, Amortization | 0 | 0 | 0 | |||||||||
Freight Expense | 0 | 0 | 0 | |||||||||
General and Administrative Expense | 0 | 0 | 0 | |||||||||
Cost of Coal Products and Services | 0 | 0 | 0 | |||||||||
Other Nonoperating Income (Expense) | 0 | |||||||||||
Other Nonoperating Expense | 0 | 0 | ||||||||||
Other General and Administrative Expense | 0 | 0 | 0 | |||||||||
Depreciation, Depletion and Amortization, Nonproduction | 0 | 0 | 0 | |||||||||
Gains (Losses) on Extinguishment of Debt | 0 | 0 | ||||||||||
Interest Expense | 2,723 | 5,613 | 9,021 | |||||||||
Other General Expense | 2,723 | 5,613 | 9,021 | |||||||||
Total Costs | 1,170,061 | 1,889,589 | 956,410 | |||||||||
Income Taxes | (150,551) | (257,056) | 66,441 | |||||||||
Income (Loss) from Continuing Operations Attributable to Parent | 123,273 | |||||||||||
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest | (228,289) | (421,803) | ||||||||||
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent | 0 | 0 | 0 | |||||||||
Net Income (Loss) | (228,289) | (421,803) | 123,273 | |||||||||
Net Income (Loss) Attributable to Noncontrolling Interest | 0 | 0 | ||||||||||
Net Income Attributable to CONSOL Energy Inc Shareholders | (228,289) | (421,803) | 123,273 | |||||||||
Impairment of Oil and Gas Properties | 0 | 828,905 | 0 | |||||||||
Revenues | 791,221 | 1,210,730 | 1,146,124 | |||||||||
Other Guarantors Subsidiaries [Member] | ||||||||||||
Schedule of Condensed Consolidating Statement of Operations [Line Items] | ||||||||||||
Oil and Gas Sales Revenue | 0 | 0 | 0 | |||||||||
Gain (Loss) on Hedging Activity | 0 | 0 | 0 | |||||||||
Coal Products and Services Revenue | 799,187 | 966,775 | 1,212,627 | |||||||||
Other Revenue, Net | 32,038 | 30,967 | 41,255 | |||||||||
Gas Royalty Interests and Purchased Gas Sales | 0 | 0 | 0 | |||||||||
Freight-Outside | 34,865 | 16,690 | 18,941 | |||||||||
Other Income | 83,735 | 82,690 | 138,201 | |||||||||
Gain (Loss) on Disposition of Assets | 4,637 | 61,572 | (2,926) | |||||||||
Oil and Gas Property, Lease Operating Expense | 0 | 0 | 0 | |||||||||
Gas Gathering, Transportation, Marketing and Processing Costs | 0 | 0 | 0 | |||||||||
Production Tax Expense | 0 | 0 | 0 | |||||||||
E&P Depreciation, Depletion, and Amortization | 0 | 0 | 0 | |||||||||
Exploration and Production Costs | 0 | 0 | 637 | |||||||||
Production Royalty Interests and Purchased Gas Costs | 0 | 0 | 0 | |||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | 44,934 | 457,198 | 279,550 | |||||||||
Other Expenses | 0 | 0 | 0 | |||||||||
Results of Operations, General and Administrative Related to Oil and Gas Producing Activities | 0 | 0 | 0 | |||||||||
Oil and Gas Production Expense | 0 | 0 | 637 | |||||||||
Operating Expenses | 550,299 | 472,341 | 742,886 | |||||||||
Coal Depreciation, Depletion, Amortization | 126,201 | 132,728 | 129,979 | |||||||||
Freight Expense | 34,865 | 16,690 | 12,575 | |||||||||
General and Administrative Expense | 27,563 | 29,912 | 57,814 | |||||||||
Cost of Coal Products and Services | 738,928 | 651,671 | 943,254 | |||||||||
Other Nonoperating Income (Expense) | 129,257 | |||||||||||
Other Nonoperating Expense | 139,289 | 9,176 | ||||||||||
Other General and Administrative Expense | 12,717 | 14,918 | 12,519 | |||||||||
Depreciation, Depletion and Amortization, Nonproduction | 11,887 | 19,278 | 33,273 | |||||||||
Gains (Losses) on Extinguishment of Debt | 0 | 0 | ||||||||||
Interest Expense | 6,707 | 6,453 | 9,608 | |||||||||
Other General Expense | 170,600 | 49,825 | 184,657 | |||||||||
Total Costs | 909,528 | 701,496 | 1,128,548 | |||||||||
Income Taxes | 242,832 | 251,558 | 96,926 | |||||||||
Income (Loss) from Continuing Operations Attributable to Parent | 182,624 | |||||||||||
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest | (197,898) | 205,640 | ||||||||||
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent | 0 | 0 | 0 | |||||||||
Net Income (Loss) | (197,898) | 205,640 | 182,624 | |||||||||
Net Income (Loss) Attributable to Noncontrolling Interest | 0 | 0 | ||||||||||
Net Income Attributable to CONSOL Energy Inc Shareholders | (197,898) | 205,640 | 182,624 | |||||||||
Impairment of Oil and Gas Properties | 0 | |||||||||||
Revenues | 954,462 | 1,158,694 | 1,408,098 | |||||||||
Non-Guarantor Subsidiaries [Member] | ||||||||||||
Schedule of Condensed Consolidating Statement of Operations [Line Items] | ||||||||||||
Oil and Gas Sales Revenue | 0 | 0 | 0 | |||||||||
Gain (Loss) on Hedging Activity | 0 | 0 | 0 | |||||||||
Coal Products and Services Revenue | 0 | 0 | 0 | |||||||||
Other Revenue, Net | 0 | 0 | 234,987 | |||||||||
Gas Royalty Interests and Purchased Gas Sales | 0 | 0 | 0 | |||||||||
Freight-Outside | 0 | 0 | 0 | |||||||||
Other Income | 0 | 4,105 | 10,305 | |||||||||
Gain (Loss) on Disposition of Assets | 0 | 0 | 22 | |||||||||
Oil and Gas Property, Lease Operating Expense | 0 | 0 | 0 | |||||||||
Gas Gathering, Transportation, Marketing and Processing Costs | 0 | 0 | 0 | |||||||||
Production Tax Expense | 0 | 0 | 0 | |||||||||
E&P Depreciation, Depletion, and Amortization | 0 | 0 | 0 | |||||||||
Exploration and Production Costs | 0 | 9 | 119 | |||||||||
Production Royalty Interests and Purchased Gas Costs | 0 | 0 | 0 | |||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | (47) | 3,512 | 11,237 | |||||||||
Other Expenses | 0 | 0 | 0 | |||||||||
Results of Operations, General and Administrative Related to Oil and Gas Producing Activities | 0 | 0 | 0 | |||||||||
Oil and Gas Production Expense | 0 | 9 | 119 | |||||||||
Operating Expenses | 0 | 0 | 0 | |||||||||
Coal Depreciation, Depletion, Amortization | 0 | 0 | 0 | |||||||||
Freight Expense | 0 | 0 | 6,366 | |||||||||
General and Administrative Expense | 0 | 0 | (6,366) | |||||||||
Cost of Coal Products and Services | 0 | 0 | 0 | |||||||||
Other Nonoperating Income (Expense) | 231,899 | |||||||||||
Other Nonoperating Expense | 47 | 508 | ||||||||||
Other General and Administrative Expense | 0 | 0 | 0 | |||||||||
Depreciation, Depletion and Amortization, Nonproduction | 0 | 0 | 1,814 | |||||||||
Gains (Losses) on Extinguishment of Debt | 0 | 0 | ||||||||||
Interest Expense | 0 | 76 | 245 | |||||||||
Other General Expense | 47 | 584 | 233,958 | |||||||||
Total Costs | 47 | 593 | 234,077 | |||||||||
Income Taxes | (18) | 1,329 | 4,249 | |||||||||
Income (Loss) from Continuing Operations Attributable to Parent | 6,988 | |||||||||||
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest | (29) | 2,183 | ||||||||||
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent | (303,183) | (14,209) | (1,857) | |||||||||
Net Income (Loss) | (303,212) | (12,026) | 5,131 | |||||||||
Net Income (Loss) Attributable to Noncontrolling Interest | 0 | 0 | ||||||||||
Net Income Attributable to CONSOL Energy Inc Shareholders | (303,212) | (12,026) | 5,131 | |||||||||
Impairment of Oil and Gas Properties | 0 | |||||||||||
Revenues | 0 | 4,105 | 245,314 | |||||||||
CNX Coal Resources LP [Member] | ||||||||||||
Schedule of Condensed Consolidating Statement of Operations [Line Items] | ||||||||||||
Oil and Gas Sales Revenue | 0 | 0 | 0 | |||||||||
Gain (Loss) on Hedging Activity | 0 | 0 | 0 | |||||||||
Coal Products and Services Revenue | 266,395 | 322,261 | 404,247 | |||||||||
Other Revenue, Net | 0 | 0 | 0 | |||||||||
Gas Royalty Interests and Purchased Gas Sales | 0 | 0 | 0 | |||||||||
Freight-Outside | 11,603 | 3,809 | 4,192 | |||||||||
Other Income | 3,128 | 880 | 9,475 | |||||||||
Gain (Loss) on Disposition of Assets | (9) | 61 | 185 | |||||||||
Oil and Gas Property, Lease Operating Expense | 0 | 0 | 0 | |||||||||
Gas Gathering, Transportation, Marketing and Processing Costs | 0 | 0 | 0 | |||||||||
Production Tax Expense | 0 | 0 | 0 | |||||||||
E&P Depreciation, Depletion, and Amortization | 0 | 0 | 0 | |||||||||
Exploration and Production Costs | 0 | 0 | 0 | |||||||||
Production Royalty Interests and Purchased Gas Costs | 0 | 0 | 0 | |||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | 25,851 | 64,538 | 104,875 | |||||||||
Other Expenses | 0 | 0 | 0 | |||||||||
Results of Operations, General and Administrative Related to Oil and Gas Producing Activities | 0 | 0 | 0 | |||||||||
Oil and Gas Production Expense | 0 | 0 | 0 | |||||||||
Operating Expenses | 183,001 | 193,961 | 239,863 | |||||||||
Coal Depreciation, Depletion, Amortization | 41,994 | 44,136 | 43,337 | |||||||||
Freight Expense | 11,603 | 3,809 | 4,192 | |||||||||
General and Administrative Expense | 9,949 | 10,931 | 17,149 | |||||||||
Cost of Coal Products and Services | 246,547 | 252,837 | 304,541 | |||||||||
Other Nonoperating Income (Expense) | 0 | |||||||||||
Other Nonoperating Expense | 0 | 0 | ||||||||||
Other General and Administrative Expense | 0 | 0 | 0 | |||||||||
Depreciation, Depletion and Amortization, Nonproduction | 0 | 0 | 0 | |||||||||
Gains (Losses) on Extinguishment of Debt | 0 | 0 | ||||||||||
Interest Expense | 8,719 | 9,636 | 8,683 | |||||||||
Other General Expense | 8,719 | 9,636 | 8,683 | |||||||||
Total Costs | 255,266 | 262,473 | 313,224 | |||||||||
Income Taxes | 0 | 0 | 0 | |||||||||
Income (Loss) from Continuing Operations Attributable to Parent | 104,875 | |||||||||||
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest | 25,851 | 64,538 | ||||||||||
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent | 0 | 0 | 0 | |||||||||
Net Income (Loss) | 25,851 | 64,538 | 104,875 | |||||||||
Net Income (Loss) Attributable to Noncontrolling Interest | 0 | 0 | ||||||||||
Net Income Attributable to CONSOL Energy Inc Shareholders | 25,851 | 64,538 | 104,875 | |||||||||
Impairment of Oil and Gas Properties | 0 | |||||||||||
Revenues | 281,117 | 327,011 | 418,099 | |||||||||
Consolidation, Eliminations [Member] | ||||||||||||
Schedule of Condensed Consolidating Statement of Operations [Line Items] | ||||||||||||
Oil and Gas Sales Revenue | (424) | (1,537) | (2,457) | |||||||||
Gain (Loss) on Hedging Activity | 0 | 0 | 0 | |||||||||
Coal Products and Services Revenue | 0 | 0 | 0 | |||||||||
Other Revenue, Net | 0 | 0 | 0 | |||||||||
Gas Royalty Interests and Purchased Gas Sales | 0 | 0 | 0 | |||||||||
Freight-Outside | 0 | 0 | 0 | |||||||||
Other Income | 712,926 | 166,786 | (431,185) | |||||||||
Gain (Loss) on Disposition of Assets | 0 | 0 | 0 | |||||||||
Oil and Gas Property, Lease Operating Expense | 0 | 0 | 0 | |||||||||
Gas Gathering, Transportation, Marketing and Processing Costs | 0 | 0 | (12) | |||||||||
Production Tax Expense | 0 | 0 | 0 | |||||||||
E&P Depreciation, Depletion, and Amortization | 0 | 0 | 0 | |||||||||
Exploration and Production Costs | 0 | (9) | (119) | |||||||||
Production Royalty Interests and Purchased Gas Costs | 0 | 0 | 0 | |||||||||
Income (Loss) from Continuing Operations before Income Taxes, Domestic | 712,502 | 174,061 | (415,903) | |||||||||
Other Expenses | 0 | 0 | 0 | |||||||||
Results of Operations, General and Administrative Related to Oil and Gas Producing Activities | 0 | 0 | 0 | |||||||||
Oil and Gas Production Expense | 0 | (9) | (131) | |||||||||
Operating Expenses | 0 | 0 | 0 | |||||||||
Coal Depreciation, Depletion, Amortization | 0 | 0 | 0 | |||||||||
Freight Expense | 0 | 0 | 0 | |||||||||
General and Administrative Expense | 0 | 0 | 0 | |||||||||
Cost of Coal Products and Services | 0 | 0 | 0 | |||||||||
Other Nonoperating Income (Expense) | 0 | |||||||||||
Other Nonoperating Expense | 0 | 0 | ||||||||||
Other General and Administrative Expense | 0 | 0 | 0 | |||||||||
Depreciation, Depletion and Amortization, Nonproduction | 0 | 0 | 0 | |||||||||
Gains (Losses) on Extinguishment of Debt | 0 | 0 | ||||||||||
Interest Expense | 0 | (8,803) | (17,608) | |||||||||
Other General Expense | 0 | (8,803) | (17,608) | |||||||||
Total Costs | 0 | (8,812) | (17,739) | |||||||||
Income Taxes | 0 | 0 | 0 | |||||||||
Income (Loss) from Continuing Operations Attributable to Parent | (415,903) | |||||||||||
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest | 712,502 | 174,061 | ||||||||||
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent | 0 | 0 | 0 | |||||||||
Net Income (Loss) | 712,502 | 174,061 | (415,903) | |||||||||
Net Income (Loss) Attributable to Noncontrolling Interest | 8,954 | 10,410 | ||||||||||
Net Income Attributable to CONSOL Energy Inc Shareholders | 703,548 | 163,651 | (415,903) | |||||||||
Impairment of Oil and Gas Properties | 0 | |||||||||||
Revenues | $ 712,502 | $ 165,249 | $ (433,642) |
Guarantor Subsidiaries Finan113
Guarantor Subsidiaries Financial Information Additional Information (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Condensed Financial Statements, Captions [Line Items] | ||
Long-term Debt | $ 2,724,672 | $ 2,705,718 |
Senior notes due April 2020 at 8.25% | ||
Condensed Financial Statements, Captions [Line Items] | ||
Long-term Debt | $ 74,470 | 74,470 |
Debt Instrument, Interest Rate, Stated Percentage | 6.375% | |
Senior Secured Notes due April 2022 [Member] | ||
Condensed Financial Statements, Captions [Line Items] | ||
Long-term Debt | $ 1,854,731 | |
Senior Notes Due April 2017 at 8.00% | ||
Condensed Financial Statements, Captions [Line Items] | ||
Debt Instrument, Interest Rate, Stated Percentage | 8.25% | |
Senior notes due March 2021 at 6.375% | ||
Condensed Financial Statements, Captions [Line Items] | ||
Long-term Debt | $ 20,611 | 20,611 |
Debt Instrument, Interest Rate, Stated Percentage | 5.875% | |
Senior Notes due April 2023 [Member] | ||
Condensed Financial Statements, Captions [Line Items] | ||
Long-term Debt | $ 494,344 | $ 493,439 |
Senior Notes 8 Percent Due April 2023 Par Value [Member] [Member] | ||
Condensed Financial Statements, Captions [Line Items] | ||
Debt Instrument, Interest Rate, Stated Percentage | 8.00% |
Guarantor Subsidiaries Balance
Guarantor Subsidiaries Balance Sheet (Detail) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 |
Current Assets: | ||||
Cash and Cash Equivalents | $ 60,475 | $ 72,574 | $ 176,985 | $ 327,420 |
Accounts and Notes Receivable: | ||||
Trade | 220,222 | 151,383 | ||
Inventories | 65,461 | 66,792 | ||
Income Taxes Receivable, Current | 116,851 | 13,887 | ||
Prepaid Expenses | 93,146 | 297,287 | ||
Other Receivables, Net, Current | 69,901 | 121,735 | ||
Disposal Group, Including Discontinued Operation, Assets, Current | 83 | 81,105 | ||
Total Current Assets | 626,139 | 804,763 | ||
Property, Plant and Equipment: | ||||
Property, Plant and Equipment, Gross | 13,771,388 | 13,794,907 | ||
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | 5,630,949 | 5,062,201 | ||
Disposal Group, Including Discontinued Operation, Property, Plant and Equipment | 0 | 936,671 | ||
Total Property, Plant and Equipment-Net | 8,140,439 | 9,669,377 | ||
Other Assets: | ||||
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures | 190,964 | 237,330 | ||
Other | 222,149 | 214,388 | ||
Disposal Group, Including Discontinued Operation, Other Assets | 0 | 4,044 | ||
Total Assets | 9,183,981 | 10,929,902 | $ 11,654,646 | |
Other Assets | 417,403 | 455,762 | ||
Current Liabilities: | ||||
Other Accrued Liabilities, Current | 680,348 | 421,827 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Current | 6,050 | 51,514 | ||
Accounts Payable | 241,616 | 250,609 | ||
Accounts Payable (Recoverable)- Related Parties | 0 | 0 | ||
Total Current Liabilities | 940,014 | 1,685,359 | ||
Short-Term Notes Payable (Note 12) | 0 | 952,000 | ||
Long-term Debt, Excluding Current Maturities | 2,722,995 | 2,703,899 | ||
Long-term Debt and Capital Lease Obligations, Including Current Maturities | 2,738,783 | |||
Disposal Group, Including Discontinued Operation, Liabilities | 0 | 5,001 | ||
Long-term Debt and Capital Lease Obligations | 2,762,069 | 2,743,784 | ||
Deferred Credits and Other Liabilities | ||||
Deferred Tax Liabilities, Net, Noncurrent | 0 | 74,629 | ||
Postretirement Benefits Other Than Pensions | 659,474 | 630,892 | ||
Pneumoconiosis | 108,073 | 111,903 | ||
Mine Closing | 218,631 | 227,339 | ||
Gas Well Closing | 223,352 | 163,842 | ||
Workers' Compensation | 67,277 | 69,812 | ||
Salary Retirement | 112,543 | 91,596 | ||
Reclamation | 0 | 25 | ||
Other | 151,660 | 166,957 | ||
Noncontrolling Interest in Limited Partnerships | 142,493 | 153,749 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent | 0 | 107,988 | ||
Total deferred credits and other liabilities | 1,541,010 | 1,644,983 | ||
Long-term Debt and Capital Lease Obligations, Current | 12,000 | 9,409 | ||
Total CONSOL Energy Inc. Stockholders' Equity | 3,798,395 | 4,702,027 | ||
TOTAL LIABILITIES AND EQUITY | 9,183,981 | 10,929,902 | ||
Deferred Tax Assets, Net of Valuation Allowance, Noncurrent | 4,290 | 0 | ||
Parent Company [Member] | ||||
Current Assets: | ||||
Cash and Cash Equivalents | 49,722 | 64,995 | ||
Accounts and Notes Receivable: | ||||
Trade | 0 | 0 | ||
Inventories | 0 | 0 | ||
Income Taxes Receivable, Current | 175,877 | 72,913 | ||
Prepaid Expenses | 12,828 | 27,245 | ||
Other Receivables, Net, Current | 20,097 | 18,933 | ||
Disposal Group, Including Discontinued Operation, Assets, Current | 0 | 0 | ||
Total Current Assets | 258,524 | 184,086 | ||
Property, Plant and Equipment: | ||||
Property, Plant and Equipment, Gross | 114,611 | 156,348 | ||
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | 84,788 | 111,367 | ||
Disposal Group, Including Discontinued Operation, Property, Plant and Equipment | 0 | |||
Total Property, Plant and Equipment-Net | 29,823 | 44,981 | ||
Other Assets: | ||||
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures | 7,974,260 | 10,563,985 | ||
Other | 19,960 | 53,529 | ||
Disposal Group, Including Discontinued Operation, Other Assets | 0 | |||
Total Assets | 8,308,471 | 10,846,581 | ||
Other Assets | 8,020,124 | 10,617,514 | ||
Current Liabilities: | ||||
Other Accrued Liabilities, Current | 75,039 | 63,668 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Current | 0 | 0 | ||
Accounts Payable | 48,666 | 32,245 | ||
Accounts Payable (Recoverable)- Related Parties | 1,832,908 | 2,650,732 | ||
Total Current Liabilities | 1,958,146 | 3,700,154 | ||
Short-Term Notes Payable (Note 12) | 952,000 | |||
Long-term Debt and Capital Lease Obligations, Including Current Maturities | 2,418,961 | |||
Disposal Group, Including Discontinued Operation, Liabilities | 0 | |||
Long-term Debt and Capital Lease Obligations | 2,421,511 | 2,418,961 | ||
Deferred Credits and Other Liabilities | ||||
Deferred Tax Liabilities, Net, Noncurrent | (122,547) | |||
Postretirement Benefits Other Than Pensions | 0 | 0 | ||
Pneumoconiosis | 0 | 0 | ||
Mine Closing | 0 | 0 | ||
Gas Well Closing | 0 | 0 | ||
Workers' Compensation | 0 | 0 | ||
Salary Retirement | 112,543 | 91,596 | ||
Reclamation | 0 | |||
Other | 17,876 | 56,390 | ||
Noncontrolling Interest in Limited Partnerships | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent | 0 | |||
Total deferred credits and other liabilities | 130,419 | 25,439 | ||
Long-term Debt and Capital Lease Obligations, Current | 1,533 | 1,509 | ||
Total CONSOL Energy Inc. Stockholders' Equity | 3,798,395 | 4,702,027 | ||
TOTAL LIABILITIES AND EQUITY | 8,308,471 | 10,846,581 | ||
Deferred Tax Assets, Net of Valuation Allowance, Noncurrent | 25,904 | |||
Cnx Gas Guarantor [Member] | ||||
Current Assets: | ||||
Cash and Cash Equivalents | 83 | 75 | ||
Accounts and Notes Receivable: | ||||
Trade | 124,509 | 72,664 | ||
Inventories | 15,301 | 13,815 | ||
Income Taxes Receivable, Current | (59,026) | (59,026) | ||
Prepaid Expenses | 60,500 | 244,680 | ||
Other Receivables, Net, Current | 34,773 | 99,001 | ||
Disposal Group, Including Discontinued Operation, Assets, Current | 0 | 0 | ||
Total Current Assets | 176,140 | 371,209 | ||
Property, Plant and Equipment: | ||||
Property, Plant and Equipment, Gross | 8,851,226 | 8,875,027 | ||
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | 3,106,296 | 2,695,674 | ||
Disposal Group, Including Discontinued Operation, Property, Plant and Equipment | 0 | |||
Total Property, Plant and Equipment-Net | 5,744,930 | 6,179,353 | ||
Other Assets: | ||||
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures | 188,376 | 234,803 | ||
Other | 67,096 | 47,892 | ||
Disposal Group, Including Discontinued Operation, Other Assets | 0 | |||
Total Assets | 6,154,928 | 6,833,257 | ||
Other Assets | 233,858 | 282,695 | ||
Current Liabilities: | ||||
Other Accrued Liabilities, Current | 337,374 | 102,753 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Current | 0 | 0 | ||
Accounts Payable | 127,309 | 149,930 | ||
Accounts Payable (Recoverable)- Related Parties | 1,034,138 | 1,521,442 | ||
Total Current Liabilities | 1,505,190 | 1,780,923 | ||
Short-Term Notes Payable (Note 12) | 0 | |||
Long-term Debt and Capital Lease Obligations, Including Current Maturities | 33,141 | |||
Disposal Group, Including Discontinued Operation, Liabilities | 0 | |||
Long-term Debt and Capital Lease Obligations | 26,884 | 33,141 | ||
Deferred Credits and Other Liabilities | ||||
Deferred Tax Liabilities, Net, Noncurrent | 197,176 | |||
Postretirement Benefits Other Than Pensions | 0 | 0 | ||
Pneumoconiosis | 0 | 0 | ||
Mine Closing | 0 | 0 | ||
Gas Well Closing | 195,704 | 135,174 | ||
Workers' Compensation | 0 | 0 | ||
Salary Retirement | 0 | 0 | ||
Reclamation | 0 | |||
Other | 117,658 | 105,588 | ||
Noncontrolling Interest in Limited Partnerships | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent | 0 | |||
Total deferred credits and other liabilities | 313,362 | 437,938 | ||
Long-term Debt and Capital Lease Obligations, Current | 6,369 | 6,798 | ||
Total CONSOL Energy Inc. Stockholders' Equity | 4,309,492 | 4,581,255 | ||
TOTAL LIABILITIES AND EQUITY | 6,154,928 | 6,833,257 | ||
Deferred Tax Assets, Net of Valuation Allowance, Noncurrent | (21,614) | |||
Other Guarantors Subsidiaries [Member] | ||||
Current Assets: | ||||
Cash and Cash Equivalents | 0 | 0 | ||
Accounts and Notes Receivable: | ||||
Trade | 72,295 | 59,321 | ||
Inventories | 38,669 | 40,739 | ||
Income Taxes Receivable, Current | 0 | 0 | ||
Prepaid Expenses | 16,306 | 20,273 | ||
Other Receivables, Net, Current | 14,516 | 3,330 | ||
Disposal Group, Including Discontinued Operation, Assets, Current | 0 | 0 | ||
Total Current Assets | 141,786 | 123,663 | ||
Property, Plant and Equipment: | ||||
Property, Plant and Equipment, Gross | 3,928,861 | 3,898,005 | ||
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | 1,997,687 | 1,854,249 | ||
Disposal Group, Including Discontinued Operation, Property, Plant and Equipment | 0 | |||
Total Property, Plant and Equipment-Net | 1,931,174 | 2,043,756 | ||
Other Assets: | ||||
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures | 27,269 | 6,293 | ||
Other | 114,030 | 95,369 | ||
Disposal Group, Including Discontinued Operation, Other Assets | 0 | |||
Total Assets | 2,214,259 | 2,269,081 | ||
Other Assets | 141,299 | 101,662 | ||
Current Liabilities: | ||||
Other Accrued Liabilities, Current | 223,705 | 218,186 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Current | 0 | 0 | ||
Accounts Payable | 36,039 | 37,212 | ||
Accounts Payable (Recoverable)- Related Parties | (2,648,416) | (3,953,215) | ||
Total Current Liabilities | (2,384,662) | (3,696,776) | ||
Short-Term Notes Payable (Note 12) | 0 | |||
Long-term Debt and Capital Lease Obligations, Including Current Maturities | 105,611 | |||
Disposal Group, Including Discontinued Operation, Liabilities | 0 | |||
Long-term Debt and Capital Lease Obligations | 115,685 | 105,611 | ||
Deferred Credits and Other Liabilities | ||||
Deferred Tax Liabilities, Net, Noncurrent | 0 | |||
Postretirement Benefits Other Than Pensions | 659,474 | 630,892 | ||
Pneumoconiosis | 106,016 | 109,969 | ||
Mine Closing | 209,384 | 218,936 | ||
Gas Well Closing | 27,549 | 28,572 | ||
Workers' Compensation | 64,187 | 66,883 | ||
Salary Retirement | 0 | 0 | ||
Reclamation | 25 | |||
Other | 15,663 | 4,266 | ||
Noncontrolling Interest in Limited Partnerships | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent | 0 | |||
Total deferred credits and other liabilities | 1,082,273 | 1,059,543 | ||
Long-term Debt and Capital Lease Obligations, Current | 4,010 | 1,041 | ||
Total CONSOL Energy Inc. Stockholders' Equity | 3,400,963 | 4,800,703 | ||
TOTAL LIABILITIES AND EQUITY | 2,214,259 | 2,269,081 | ||
Deferred Tax Assets, Net of Valuation Allowance, Noncurrent | 0 | |||
Non-Guarantor Subsidiaries [Member] | ||||
Current Assets: | ||||
Cash and Cash Equivalents | 885 | 970 | ||
Accounts and Notes Receivable: | ||||
Trade | 0 | 0 | ||
Inventories | 0 | 0 | ||
Income Taxes Receivable, Current | 0 | 0 | ||
Prepaid Expenses | 0 | 0 | ||
Other Receivables, Net, Current | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Assets, Current | 83 | 81,105 | ||
Total Current Assets | 968 | 82,075 | ||
Property, Plant and Equipment: | ||||
Property, Plant and Equipment, Gross | 0 | 0 | ||
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Property, Plant and Equipment | 936,671 | |||
Total Property, Plant and Equipment-Net | 0 | 936,671 | ||
Other Assets: | ||||
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures | 0 | 0 | ||
Other | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Other Assets | 4,044 | |||
Total Assets | 968 | 1,022,790 | ||
Other Assets | 0 | 4,044 | ||
Current Liabilities: | ||||
Other Accrued Liabilities, Current | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Current | 6,050 | 51,514 | ||
Accounts Payable | 0 | 0 | ||
Accounts Payable (Recoverable)- Related Parties | (209,491) | (209,452) | ||
Total Current Liabilities | (203,441) | (157,938) | ||
Short-Term Notes Payable (Note 12) | 0 | |||
Long-term Debt and Capital Lease Obligations, Including Current Maturities | 0 | |||
Disposal Group, Including Discontinued Operation, Liabilities | 5,001 | |||
Long-term Debt and Capital Lease Obligations | 0 | 5,001 | ||
Deferred Credits and Other Liabilities | ||||
Deferred Tax Liabilities, Net, Noncurrent | 0 | |||
Postretirement Benefits Other Than Pensions | 0 | 0 | ||
Pneumoconiosis | 0 | 0 | ||
Mine Closing | 0 | 0 | ||
Gas Well Closing | 0 | 0 | ||
Workers' Compensation | 0 | 0 | ||
Salary Retirement | 0 | 0 | ||
Reclamation | 0 | |||
Other | 0 | 0 | ||
Noncontrolling Interest in Limited Partnerships | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent | 107,988 | |||
Total deferred credits and other liabilities | 0 | 107,988 | ||
Long-term Debt and Capital Lease Obligations, Current | 0 | 0 | ||
Total CONSOL Energy Inc. Stockholders' Equity | 204,409 | 1,067,739 | ||
TOTAL LIABILITIES AND EQUITY | 968 | 1,022,790 | ||
Deferred Tax Assets, Net of Valuation Allowance, Noncurrent | 0 | |||
CNX Coal Resources LP [Member] | ||||
Current Assets: | ||||
Cash and Cash Equivalents | 9,785 | 6,534 | ||
Accounts and Notes Receivable: | ||||
Trade | 23,418 | 19,398 | ||
Inventories | 11,491 | 12,238 | ||
Income Taxes Receivable, Current | 0 | 0 | ||
Prepaid Expenses | 3,512 | 5,089 | ||
Other Receivables, Net, Current | 515 | 471 | ||
Disposal Group, Including Discontinued Operation, Assets, Current | 0 | 0 | ||
Total Current Assets | 48,721 | 43,730 | ||
Property, Plant and Equipment: | ||||
Property, Plant and Equipment, Gross | 876,690 | 865,527 | ||
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | 442,178 | 400,911 | ||
Disposal Group, Including Discontinued Operation, Property, Plant and Equipment | 0 | |||
Total Property, Plant and Equipment-Net | 434,512 | 464,616 | ||
Other Assets: | ||||
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures | 0 | 0 | ||
Other | 21,063 | 17,598 | ||
Disposal Group, Including Discontinued Operation, Other Assets | 0 | |||
Total Assets | 504,296 | 525,944 | ||
Other Assets | 21,063 | 17,598 | ||
Current Liabilities: | ||||
Other Accrued Liabilities, Current | 44,230 | 37,220 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Current | 0 | 0 | ||
Accounts Payable | 18,797 | 17,405 | ||
Accounts Payable (Recoverable)- Related Parties | 1,666 | 4,310 | ||
Total Current Liabilities | 64,781 | 58,996 | ||
Short-Term Notes Payable (Note 12) | 0 | |||
Long-term Debt and Capital Lease Obligations, Including Current Maturities | 181,070 | |||
Disposal Group, Including Discontinued Operation, Liabilities | 0 | |||
Long-term Debt and Capital Lease Obligations | 197,989 | 181,070 | ||
Deferred Credits and Other Liabilities | ||||
Deferred Tax Liabilities, Net, Noncurrent | 0 | |||
Postretirement Benefits Other Than Pensions | 0 | 0 | ||
Pneumoconiosis | 2,057 | 1,934 | ||
Mine Closing | 9,247 | 8,403 | ||
Gas Well Closing | 99 | 96 | ||
Workers' Compensation | 3,090 | 2,929 | ||
Salary Retirement | 0 | 0 | ||
Reclamation | 0 | |||
Other | 463 | 713 | ||
Noncontrolling Interest in Limited Partnerships | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent | 0 | |||
Total deferred credits and other liabilities | 14,956 | 14,075 | ||
Long-term Debt and Capital Lease Obligations, Current | 88 | 61 | ||
Total CONSOL Energy Inc. Stockholders' Equity | 226,570 | 271,803 | ||
TOTAL LIABILITIES AND EQUITY | 504,296 | 525,944 | ||
Deferred Tax Assets, Net of Valuation Allowance, Noncurrent | 0 | |||
Consolidation, Eliminations [Member] | ||||
Current Assets: | ||||
Cash and Cash Equivalents | 0 | 0 | ||
Accounts and Notes Receivable: | ||||
Trade | 0 | 0 | ||
Inventories | 0 | 0 | ||
Income Taxes Receivable, Current | 0 | 0 | ||
Prepaid Expenses | 0 | 0 | ||
Other Receivables, Net, Current | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Assets, Current | 0 | 0 | ||
Total Current Assets | 0 | 0 | ||
Property, Plant and Equipment: | ||||
Property, Plant and Equipment, Gross | 0 | 0 | ||
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Property, Plant and Equipment | 0 | |||
Total Property, Plant and Equipment-Net | 0 | 0 | ||
Other Assets: | ||||
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures | (7,998,941) | (10,567,751) | ||
Other | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Other Assets | 0 | |||
Total Assets | (7,998,941) | (10,567,751) | ||
Other Assets | (7,998,941) | (10,567,751) | ||
Current Liabilities: | ||||
Other Accrued Liabilities, Current | 0 | 0 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Current | 0 | 0 | ||
Accounts Payable | 10,805 | 13,817 | ||
Accounts Payable (Recoverable)- Related Parties | (10,805) | (13,817) | ||
Total Current Liabilities | 0 | 0 | ||
Short-Term Notes Payable (Note 12) | 0 | |||
Long-term Debt and Capital Lease Obligations, Including Current Maturities | 0 | |||
Disposal Group, Including Discontinued Operation, Liabilities | 0 | |||
Long-term Debt and Capital Lease Obligations | 0 | 0 | ||
Deferred Credits and Other Liabilities | ||||
Deferred Tax Liabilities, Net, Noncurrent | 0 | |||
Postretirement Benefits Other Than Pensions | 0 | 0 | ||
Pneumoconiosis | 0 | 0 | ||
Mine Closing | 0 | 0 | ||
Gas Well Closing | 0 | 0 | ||
Workers' Compensation | 0 | 0 | ||
Salary Retirement | 0 | 0 | ||
Reclamation | 0 | |||
Other | 0 | 0 | ||
Noncontrolling Interest in Limited Partnerships | 142,493 | 153,749 | ||
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent | 0 | |||
Total deferred credits and other liabilities | 0 | 0 | ||
Long-term Debt and Capital Lease Obligations, Current | 0 | 0 | ||
Total CONSOL Energy Inc. Stockholders' Equity | (8,141,434) | (10,721,500) | ||
TOTAL LIABILITIES AND EQUITY | (7,998,941) | $ (10,567,751) | ||
Deferred Tax Assets, Net of Valuation Allowance, Noncurrent | $ 0 |
Guarantor Subsidiaries, Condens
Guarantor Subsidiaries, Condensed Statement of Cash Flows (Detail) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items] | |||
Net Cash Provided by (Used in) Operating Activities, Continuing Operations | $ 459,350 | $ 499,677 | $ 840,386 |
Cash Provided by (Used in) Operating Activities, Discontinued Operations | 9,935 | 6,172 | 96,390 |
Net Cash Provided by Operating Activities | 469,285 | 505,849 | 936,776 |
Investing Activities: | |||
Capital Expenditures | (226,820) | (982,934) | (1,459,452) |
Proceeds from Divestiture of Interest in Joint Venture | 213,295 | 0 | 0 |
Proceeds from Sales of Assets | 59,902 | 110,571 | 356,836 |
Net Investment in Equity Affiliates | 73,743 | (84,221) | 95,207 |
Net Cash Provided by (Used in) Investing Activities, Continuing Operations | 120,120 | (956,584) | (1,007,409) |
Cash Provided by (Used in) Investing Activities, Discontinued Operations | 367,251 | (39,633) | (33,973) |
Net Cash Used in Investing Activities | 487,371 | (996,217) | (1,041,382) |
Financing Activities: | |||
Proceeds from (Repayments of) Debt | (4,282) | ||
Payments On Long Term Notes Including Redemption Premium | 0 | (1,263,719) | (1,819,005) |
Proceeds from Issuance of Long-Term Notes | 0 | 492,760 | 1,859,920 |
Proceeds from Contributions from Parent | 0 | 0 | |
Payments for Repurchase of Initial Public Offering | 0 | ||
Proceeds from Collection of Advance to Affiliate | 0 | ||
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities | 0 | 208 | 2,629 |
Dividends Paid | (2,294) | (33,281) | (57,506) |
(Payments on) Proceeds from Short-Term Borrowings | (952,000) | 952,000 | (11,736) |
Repayments of Other Debt | 8,312 | 4,282 | 10,286 |
Proceeds from Issuance of Common Stock | 4 | 8,288 | 15,016 |
Other Financing Activities | 0 | ||
Net Cash Provided by (Used in) Financing Activities, Continuing Operations | (968,741) | 386,013 | (45,829) |
Cash Provided by (Used in) Financing Activities, Discontinued Operations | (14) | (56) | 0 |
Net Cash (Used in) Provided by Financing Activities | (968,755) | 385,957 | (45,829) |
Net Proceeds from Revolver - MLP | 16,000 | 185,000 | 0 |
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | (21,657) | (5,060) | 0 |
Proceeds from Sale of Interest in Partnership Unit | 0 | ||
Proceeds from Noncontrolling Interests | 0 | 148,359 | 0 |
Treasury Stock, Value, Acquired, Cost Method | 0 | (71,674) | 0 |
Payments of Debt Issuance Costs | (482) | (22,586) | (24,861) |
Parent Company [Member] | |||
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items] | |||
Net Cash Provided by (Used in) Operating Activities, Continuing Operations | 943,652 | (153,930) | (178,921) |
Cash Provided by (Used in) Operating Activities, Discontinued Operations | 0 | 0 | 0 |
Net Cash Provided by Operating Activities | 943,652 | (153,930) | (178,921) |
Investing Activities: | |||
Capital Expenditures | (2,990) | (9,752) | (4,420) |
Proceeds from Divestiture of Interest in Joint Venture | 0 | ||
Proceeds from Sales of Assets | 0 | 142 | 44,049 |
Net Investment in Equity Affiliates | 0 | 0 | 0 |
Net Cash Provided by (Used in) Investing Activities, Continuing Operations | (2,990) | (9,610) | 39,629 |
Cash Provided by (Used in) Investing Activities, Discontinued Operations | 0 | 0 | 0 |
Net Cash Used in Investing Activities | (2,990) | (9,610) | 39,629 |
Financing Activities: | |||
Proceeds from (Repayments of) Debt | (1,281) | ||
Payments On Long Term Notes Including Redemption Premium | (1,263,719) | (1,819,005) | |
Proceeds from Issuance of Long-Term Notes | 492,760 | 1,859,920 | |
Proceeds from Contributions from Parent | 0 | 0 | |
Payments for Repurchase of Initial Public Offering | 0 | ||
Proceeds from Collection of Advance to Affiliate | 0 | ||
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities | 208 | 2,629 | |
Dividends Paid | (2,294) | (33,281) | (57,506) |
(Payments on) Proceeds from Short-Term Borrowings | (952,000) | 952,000 | (11,736) |
Repayments of Other Debt | 1,645 | 399 | |
Proceeds from Issuance of Common Stock | 4 | 8,288 | 15,016 |
Other Financing Activities | 0 | ||
Net Cash Provided by (Used in) Financing Activities, Continuing Operations | (955,935) | 83,301 | |
Cash Provided by (Used in) Financing Activities, Discontinued Operations | 0 | 0 | |
Net Cash (Used in) Provided by Financing Activities | (955,935) | 83,301 | (35,942) |
Net Proceeds from Revolver - MLP | 0 | 0 | |
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | 0 | 0 | |
Proceeds from Sale of Interest in Partnership Unit | 0 | ||
Proceeds from Noncontrolling Interests | 0 | ||
Treasury Stock, Value, Acquired, Cost Method | (71,674) | ||
Payments of Debt Issuance Costs | 0 | (24,861) | |
Payments of Financing Costs | 0 | ||
Cnx Gas Guarantor [Member] | |||
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items] | |||
Net Cash Provided by (Used in) Operating Activities, Continuing Operations | (165,861) | 624,788 | 567,851 |
Cash Provided by (Used in) Operating Activities, Discontinued Operations | 0 | 0 | 0 |
Net Cash Provided by Operating Activities | (165,861) | 624,788 | 567,851 |
Investing Activities: | |||
Capital Expenditures | (165,101) | (832,446) | (1,103,656) |
Proceeds from Divestiture of Interest in Joint Venture | 213,295 | ||
Proceeds from Sales of Assets | 44,710 | 10,298 | 92,507 |
Net Investment in Equity Affiliates | 79,103 | (79,756) | 85,248 |
Net Cash Provided by (Used in) Investing Activities, Continuing Operations | 172,007 | (901,904) | (925,901) |
Cash Provided by (Used in) Investing Activities, Discontinued Operations | 0 | 0 | 0 |
Net Cash Used in Investing Activities | 172,007 | (901,904) | (925,901) |
Financing Activities: | |||
Proceeds from (Repayments of) Debt | (6,391) | ||
Payments On Long Term Notes Including Redemption Premium | 0 | 0 | |
Proceeds from Issuance of Long-Term Notes | 0 | 0 | |
Proceeds from Contributions from Parent | 0 | 0 | |
Payments for Repurchase of Initial Public Offering | 0 | ||
Proceeds from Collection of Advance to Affiliate | 0 | ||
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities | 0 | 0 | |
Dividends Paid | 0 | 0 | 0 |
(Payments on) Proceeds from Short-Term Borrowings | 0 | 252,900 | 0 |
Repayments of Other Debt | 6,138 | (387,663) | |
Proceeds from Issuance of Common Stock | 0 | 0 | 0 |
Other Financing Activities | (5,169) | ||
Net Cash Provided by (Used in) Financing Activities, Continuing Operations | (6,138) | 246,509 | |
Cash Provided by (Used in) Financing Activities, Discontinued Operations | 0 | 0 | |
Net Cash (Used in) Provided by Financing Activities | (6,138) | 246,509 | 382,494 |
Net Proceeds from Revolver - MLP | 0 | 0 | |
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | 0 | 0 | |
Proceeds from Sale of Interest in Partnership Unit | 0 | ||
Proceeds from Noncontrolling Interests | 0 | ||
Treasury Stock, Value, Acquired, Cost Method | 0 | ||
Payments of Debt Issuance Costs | 0 | 0 | |
Payments of Financing Costs | 0 | ||
Other Guarantors Subsidiaries [Member] | |||
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items] | |||
Net Cash Provided by (Used in) Operating Activities, Continuing Operations | 58,648 | 21,906 | (4,086) |
Cash Provided by (Used in) Operating Activities, Discontinued Operations | 0 | 0 | 0 |
Net Cash Provided by Operating Activities | 58,648 | 21,906 | (4,086) |
Investing Activities: | |||
Capital Expenditures | (46,025) | (106,663) | (266,300) |
Proceeds from Divestiture of Interest in Joint Venture | 0 | ||
Proceeds from Sales of Assets | 15,169 | 100,060 | 201,221 |
Net Investment in Equity Affiliates | (5,360) | (4,465) | 9,959 |
Net Cash Provided by (Used in) Investing Activities, Continuing Operations | (14,716) | (11,068) | (55,120) |
Cash Provided by (Used in) Investing Activities, Discontinued Operations | 0 | 0 | 0 |
Net Cash Used in Investing Activities | (14,716) | (11,068) | (55,120) |
Financing Activities: | |||
Proceeds from (Repayments of) Debt | 3,443 | ||
Payments On Long Term Notes Including Redemption Premium | 0 | 0 | |
Proceeds from Issuance of Long-Term Notes | 0 | 0 | |
Proceeds from Contributions from Parent | 0 | 0 | |
Payments for Repurchase of Initial Public Offering | 0 | ||
Proceeds from Collection of Advance to Affiliate | 0 | ||
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities | 0 | 0 | |
Dividends Paid | 0 | 0 | 0 |
(Payments on) Proceeds from Short-Term Borrowings | 0 | 0 | 0 |
Repayments of Other Debt | 450 | 7,233 | |
Proceeds from Issuance of Common Stock | 0 | 0 | 0 |
Other Financing Activities | 5,169 | ||
Net Cash Provided by (Used in) Financing Activities, Continuing Operations | (932) | (10,838) | |
Cash Provided by (Used in) Financing Activities, Discontinued Operations | 0 | 0 | |
Net Cash (Used in) Provided by Financing Activities | (932) | (10,838) | (2,064) |
Net Proceeds from Revolver - MLP | 0 | 0 | |
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | 0 | 0 | |
Proceeds from Sale of Interest in Partnership Unit | 21,500 | ||
Proceeds from Noncontrolling Interests | 0 | ||
Treasury Stock, Value, Acquired, Cost Method | 0 | ||
Payments of Debt Issuance Costs | (482) | 0 | |
Payments of Financing Costs | (14,281) | ||
Non-Guarantor Subsidiaries [Member] | |||
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items] | |||
Net Cash Provided by (Used in) Operating Activities, Continuing Operations | (377,257) | 33,422 | (59,441) |
Cash Provided by (Used in) Operating Activities, Discontinued Operations | 9,935 | 6,172 | 96,390 |
Net Cash Provided by Operating Activities | (367,322) | 39,594 | 36,949 |
Investing Activities: | |||
Capital Expenditures | 0 | 0 | 0 |
Proceeds from Divestiture of Interest in Joint Venture | 0 | ||
Proceeds from Sales of Assets | 0 | 0 | 13 |
Net Investment in Equity Affiliates | 0 | 0 | 0 |
Net Cash Provided by (Used in) Investing Activities, Continuing Operations | 0 | 0 | 13 |
Cash Provided by (Used in) Investing Activities, Discontinued Operations | 367,251 | (39,633) | (33,973) |
Net Cash Used in Investing Activities | 367,251 | (39,633) | (33,960) |
Financing Activities: | |||
Proceeds from (Repayments of) Debt | 0 | ||
Payments On Long Term Notes Including Redemption Premium | 0 | 0 | |
Proceeds from Issuance of Long-Term Notes | 0 | 0 | |
Proceeds from Contributions from Parent | 0 | 0 | |
Payments for Repurchase of Initial Public Offering | 0 | ||
Proceeds from Collection of Advance to Affiliate | 0 | ||
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities | 0 | 0 | |
Dividends Paid | 0 | 0 | 0 |
(Payments on) Proceeds from Short-Term Borrowings | 0 | 0 | 0 |
Repayments of Other Debt | 0 | 2,630 | |
Proceeds from Issuance of Common Stock | 0 | 0 | 0 |
Other Financing Activities | 0 | ||
Net Cash Provided by (Used in) Financing Activities, Continuing Operations | 0 | 0 | |
Cash Provided by (Used in) Financing Activities, Discontinued Operations | (14) | (56) | |
Net Cash (Used in) Provided by Financing Activities | (14) | (56) | (2,630) |
Net Proceeds from Revolver - MLP | 0 | 0 | |
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | 0 | 0 | |
Proceeds from Sale of Interest in Partnership Unit | 0 | ||
Proceeds from Noncontrolling Interests | 0 | ||
Treasury Stock, Value, Acquired, Cost Method | 0 | ||
Payments of Debt Issuance Costs | 0 | 0 | |
Payments of Financing Costs | 0 | ||
CNX Coal Resources LP [Member] | |||
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items] | |||
Net Cash Provided by (Used in) Operating Activities, Continuing Operations | 73,098 | 76,908 | 142,636 |
Cash Provided by (Used in) Operating Activities, Discontinued Operations | 0 | 0 | 0 |
Net Cash Provided by Operating Activities | 73,098 | 76,908 | 142,636 |
Investing Activities: | |||
Capital Expenditures | (12,704) | (34,073) | (85,076) |
Proceeds from Divestiture of Interest in Joint Venture | 0 | ||
Proceeds from Sales of Assets | 23 | 71 | 19,046 |
Net Investment in Equity Affiliates | 0 | 0 | 0 |
Net Cash Provided by (Used in) Investing Activities, Continuing Operations | (34,181) | (34,002) | (66,030) |
Cash Provided by (Used in) Investing Activities, Discontinued Operations | 0 | 0 | 0 |
Net Cash Used in Investing Activities | (34,181) | (34,002) | (66,030) |
Financing Activities: | |||
Proceeds from (Repayments of) Debt | (53) | ||
Payments On Long Term Notes Including Redemption Premium | (10,951) | (2,311) | |
Proceeds from Issuance of Long-Term Notes | 16,990 | 14,214 | |
Proceeds from Contributions from Parent | (8,953) | (88,485) | |
Payments for Repurchase of Initial Public Offering | (342,711) | ||
Proceeds from Collection of Advance to Affiliate | (17,328) | ||
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities | 0 | 0 | |
Dividends Paid | 0 | 0 | 0 |
(Payments on) Proceeds from Short-Term Borrowings | 0 | 0 | 0 |
Repayments of Other Debt | 79 | 24 | |
Proceeds from Issuance of Common Stock | 0 | 0 | 0 |
Other Financing Activities | 0 | ||
Net Cash Provided by (Used in) Financing Activities, Continuing Operations | (35,666) | (36,376) | |
Cash Provided by (Used in) Financing Activities, Discontinued Operations | 0 | 0 | |
Net Cash (Used in) Provided by Financing Activities | (35,666) | (36,376) | (76,606) |
Net Proceeds from Revolver - MLP | 16,000 | 185,000 | |
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | (42,634) | (11,353) | |
Proceeds from Sale of Interest in Partnership Unit | (21,500) | ||
Proceeds from Noncontrolling Interests | 148,359 | ||
Treasury Stock, Value, Acquired, Cost Method | 0 | ||
Payments of Debt Issuance Costs | 0 | 0 | |
Payments of Financing Costs | (4,329) | ||
Consolidation, Eliminations [Member] | |||
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items] | |||
Net Cash Provided by (Used in) Operating Activities, Continuing Operations | (72,930) | (103,417) | 372,347 |
Cash Provided by (Used in) Operating Activities, Discontinued Operations | 0 | 0 | 0 |
Net Cash Provided by Operating Activities | (72,930) | (103,417) | 372,347 |
Investing Activities: | |||
Capital Expenditures | 0 | 0 | 0 |
Proceeds from Divestiture of Interest in Joint Venture | 0 | ||
Proceeds from Sales of Assets | 0 | 0 | 0 |
Net Investment in Equity Affiliates | 0 | 0 | 0 |
Net Cash Provided by (Used in) Investing Activities, Continuing Operations | 0 | 0 | 0 |
Cash Provided by (Used in) Investing Activities, Discontinued Operations | 0 | 0 | 0 |
Net Cash Used in Investing Activities | 0 | 0 | 0 |
Financing Activities: | |||
Proceeds from (Repayments of) Debt | 0 | ||
Payments On Long Term Notes Including Redemption Premium | 10,951 | 2,311 | |
Proceeds from Issuance of Long-Term Notes | (16,990) | (14,214) | |
Proceeds from Contributions from Parent | 8,953 | 88,485 | |
Payments for Repurchase of Initial Public Offering | 342,711 | ||
Proceeds from Collection of Advance to Affiliate | 17,328 | ||
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities | 0 | 0 | |
Dividends Paid | 0 | 0 | 0 |
(Payments on) Proceeds from Short-Term Borrowings | 0 | (252,900) | 0 |
Repayments of Other Debt | 0 | 387,663 | |
Proceeds from Issuance of Common Stock | 0 | 0 | 0 |
Other Financing Activities | 0 | ||
Net Cash Provided by (Used in) Financing Activities, Continuing Operations | 29,930 | 103,417 | |
Cash Provided by (Used in) Financing Activities, Discontinued Operations | 0 | 0 | |
Net Cash (Used in) Provided by Financing Activities | 29,930 | 103,417 | (311,081) |
Net Proceeds from Revolver - MLP | 0 | 0 | |
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | 20,977 | 6,293 | |
Proceeds from Sale of Interest in Partnership Unit | 0 | ||
Proceeds from Noncontrolling Interests | 0 | ||
Treasury Stock, Value, Acquired, Cost Method | 0 | ||
Payments of Debt Issuance Costs | $ 0 | $ 0 | |
Payments of Financing Costs | $ (3,976) |
Guarantor Subsidiaries Finan116
Guarantor Subsidiaries Financial Information Guarantor Subsidiaries Comprehensive Income Statement (Details) - USD ($) $ in Thousands | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2016 | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Net Income (Loss) | $ (839,148) | $ (839,148) | $ (364,475) | $ 163,090 |
Net Income (Loss) Attributable to Noncontrolling Interest | 8,954 | 10,410 | 0 | |
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent | (33,226) | (86,447) | 94,989 | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 0 | (97,316) | ||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | (43,470) | (18,288) | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | (78,051) | |||
Other Comprehensive Income (Loss), Net of Tax | (76,696) | (164,498) | 174,017 | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | (915,844) | (528,973) | 337,107 | |
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 9,216 | 10,410 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | (925,060) | (539,383) | 337,107 | |
Parent Company [Member] | ||||
Net Income (Loss) | (848,102) | (374,885) | 163,090 | |
Net Income (Loss) Attributable to Noncontrolling Interest | 0 | 0 | ||
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent | (33,226) | (86,447) | 94,989 | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 0 | (97,316) | ||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | (43,470) | (18,288) | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | (78,051) | |||
Other Comprehensive Income (Loss), Net of Tax | (76,696) | (164,498) | 174,017 | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | (924,798) | (539,383) | ||
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 0 | 0 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | (924,798) | (539,383) | 337,107 | |
Cnx Gas Guarantor [Member] | ||||
Net Income (Loss) | (228,289) | (421,803) | 123,273 | |
Net Income (Loss) Attributable to Noncontrolling Interest | 0 | 0 | ||
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent | 0 | 0 | 0 | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | (97,316) | |||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | (43,470) | (18,288) | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | (78,051) | |||
Other Comprehensive Income (Loss), Net of Tax | (43,470) | (78,051) | 79,028 | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | (271,759) | (499,854) | ||
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 0 | 0 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | (271,759) | (499,854) | 202,301 | |
Other Guarantors Subsidiaries [Member] | ||||
Net Income (Loss) | (197,898) | 205,640 | 182,624 | |
Net Income (Loss) Attributable to Noncontrolling Interest | 0 | 0 | ||
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent | (34,044) | (84,607) | 53,190 | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 0 | |||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | 0 | 0 | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | 0 | |||
Other Comprehensive Income (Loss), Net of Tax | (34,044) | (84,607) | 53,190 | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | (231,942) | 121,033 | ||
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 0 | 0 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | (231,942) | 121,033 | 235,814 | |
Non-Guarantor Subsidiaries [Member] | ||||
Net Income (Loss) | (303,212) | (12,026) | 5,131 | |
Net Income (Loss) Attributable to Noncontrolling Interest | 0 | 0 | ||
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent | 0 | 0 | 0 | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 0 | |||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | 0 | 0 | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | 0 | |||
Other Comprehensive Income (Loss), Net of Tax | 0 | 0 | 0 | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | (303,212) | (12,026) | ||
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 0 | 0 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | (303,212) | (12,026) | 5,131 | |
CNX Coal Resources LP [Member] | ||||
Net Income (Loss) | 25,851 | 64,538 | 104,875 | |
Net Income (Loss) Attributable to Noncontrolling Interest | 0 | 0 | ||
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent | 818 | (1,840) | 41,799 | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 0 | |||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | 0 | 0 | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | 0 | |||
Other Comprehensive Income (Loss), Net of Tax | 818 | (1,840) | 41,799 | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | 26,669 | 62,698 | ||
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 0 | 0 | ||
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | 26,669 | 62,698 | 146,674 | |
Consolidation, Eliminations [Member] | ||||
Net Income (Loss) | 712,502 | 174,061 | (415,903) | |
Net Income (Loss) Attributable to Noncontrolling Interest | 8,954 | 10,410 | ||
Other Comprehensive Income (Loss), Net of Tax [Abstract] | ||||
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent | 33,226 | 86,447 | (94,989) | |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax | 97,316 | |||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | 43,470 | 18,288 | ||
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred | 78,051 | |||
Other Comprehensive Income (Loss), Net of Tax | 76,696 | 164,498 | (174,017) | |
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest | 789,198 | 338,559 | ||
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest | 9,216 | 10,410 | 0 | |
Comprehensive Income (Loss), Net of Tax, Attributable to Parent | $ 779,982 | $ 328,149 | $ (589,920) |
Related Party (Details)
Related Party (Details) - USD ($) | 9 Months Ended | 12 Months Ended | |||
Sep. 30, 2016 | Sep. 30, 2014 | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Related Party Transaction [Line Items] | |||||
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures | $ 190,964,000 | $ 237,330,000 | |||
Additional Paid in Capital | 2,460,864,000 | 2,435,497,000 | |||
Initial Public Offering overallotment | 561,067 | ||||
Income (Loss) from Equity Method Investments | (53,078,000) | (54,897,000) | $ (49,791,000) | ||
Partners' Capital Account, Units, Sold in Public Offering | 5,000,000 | ||||
Initial Public Offering Share Price | $ 15 | ||||
Debt Instrument, Face Amount | $ 400,000,000 | ||||
Long-term Debt | 2,724,672,000 | 2,705,718,000 | |||
Financing Related Fees | 3,000,000 | ||||
Long-term debt, net of fees | 197,000,000 | ||||
Net Proceeds from Initial Public Offering | 342,711,000 | ||||
Proceeds from Noncontrolling Interests | $ 21,500 | ||||
Shares Issued by Noncontrolling Interest - Drop | 3,956,496 | ||||
Share Price - Drop | $ 17.01 | ||||
Total Equity Consideration - Drop | $ 67,300 | ||||
Accounts Payable, Related Parties | 1,666,000 | 4,000 | |||
CONE Gathering [Member] | |||||
Related Party Transaction [Line Items] | |||||
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures | 151,075,000 | 202,570,000 | 94,467,000 | ||
Limited Partners' Contributed Capital | 17,112,000 | 20,916,000 | |||
Additional Paid in Capital | 4,621,000 | 87,187,000 | |||
Related Party Transaction, Expenses from Transactions with Related Party | 706,000 | 1,077 | 219 | ||
Income (Loss) from Equity Method Investments | 17,112,000 | 20,916,000 | 25,521,000 | ||
Distribution Made to Limited Partner, Cash Distributions Paid | (8,224,000) | 0 | |||
Equity Method Investment, Net Sales Proceeds | (70,000,000) | ||||
Equity Method Investment, Change in Basis | 4,996,000 | ||||
CONE Midstream [Member] | |||||
Related Party Transaction [Line Items] | |||||
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures | 18,133,000 | 11,047,000 | 4,883,000 | ||
Limited Partners' Contributed Capital | 31,148,000 | 22,883,000 | |||
Additional Paid in Capital | 0 | 0 | |||
Sale of Stock, Description of Transaction | 20,125,000 | ||||
Excess Stock, Shares Authorized | 2,625,000 | ||||
Total Purchase Consideration of Drop | 248,000,000 | ||||
Equity Method Investment, Cash Consideration for Drop | $ 140,000,000 | ||||
Equity Method Investment, Stock Issued on Drop | 5,200,000 | ||||
Related Party Transaction, Expenses from Transactions with Related Party | $ 123,020 | 104,291 | 65,365 | ||
Income (Loss) from Equity Method Investments | 31,148,000 | 22,883,000 | 4,286,000 | ||
Distribution Made to Limited Partner, Cash Distributions Paid | (19,066,000) | (16,719,000) | |||
Equity Method Investment, Net Sales Proceeds | 0 | ||||
Equity Method Investment, Change in Basis | (4,996,000) | ||||
CONE [Member] | |||||
Related Party Transaction [Line Items] | |||||
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures | 169,208,000 | 213,617,000 | 99,350,000 | ||
Limited Partners' Contributed Capital | 48,260,000 | 43,799,000 | |||
Additional Paid in Capital | 4,621,000 | 87,187,000 | |||
Due from Related Parties | 5,815,000 | 12,216,000 | |||
Inventory, Raw Materials and Purchased Parts, Net of Reserves | 2,239,000 | ||||
Distribution Made to Limited Partner, Cash Distributions Paid | (27,290,000) | (16,719,000) | |||
Equity Method Investment, Net Sales Proceeds | (70,000,000) | ||||
Equity Method Investment, Change in Basis | 0 | ||||
CNX Coal Resources LP [Member] | |||||
Related Party Transaction [Line Items] | |||||
Proceeds from Issuance Initial Public Offering | 75,000,000 | ||||
Long-term Debt | $ 200,000,000 | ||||
Selling and Direct Administrative Expenses [Member] | |||||
Related Party Transaction [Line Items] | |||||
Related Party Transaction, Expenses from Transactions with Related Party | 3,826,000 | 8,926,000 | 11,384,000 | ||
Operating and Other Costs [Member] | |||||
Related Party Transaction [Line Items] | |||||
Related Party Transaction, Expenses from Transactions with Related Party | $ 4,251,000 | $ 6,793,000 | $ 6,707,000 |
Supplemental Coal Data (Unau118
Supplemental Coal Data (Unaudited) (Details) MMcf in Thousands, $ in Thousands, T in Millions | 12 Months Ended | |||||
Dec. 31, 2016USD ($)TMMcf | Dec. 31, 2015USD ($)TMMcf | Dec. 31, 2014USD ($)TMMcf | Dec. 31, 2013USD ($)T | Dec. 31, 2012USD ($)T | Dec. 31, 2011T | |
Reserve Quantities [Line Items] | ||||||
Proved Oil and Gas Property, Successful Effort Method | $ | $ 2,016,916 | $ 1,922,602 | ||||
Reserve Quantities [Roll Forward] | ||||||
Proved Developed and Undeveloped Reserves, Production | MMcf | 394,387 | 328,657 | 235,714 | |||
Net change due to revisions in quantity estimates | $ | $ (35,502) | $ 408,006 | $ 151,233 | |||
Unproved Oil and Gas Property, Successful Effort Method | $ | $ 1,116,282 | $ 1,421,083 | ||||
Assigned Coal Reserves [Member] | ||||||
Reserve Quantities [Line Items] | ||||||
Coal Reserves | 141 | |||||
Steam [Member] | ||||||
Reserve Quantities [Line Items] | ||||||
Proved Undeveloped Reserve (Mass) | 2,274 | |||||
Coal Segment [Member] | ||||||
Reserve Quantities [Line Items] | ||||||
Proved Undeveloped Reserve (Mass) | 2,361 | 3,047 | 3,238 | 3,032 | 4,229 | 4,314 |
Reserve Quantities [Roll Forward] | ||||||
Purchase of minerals in place (Mass) | 0 | 24 | 0 | 1 | 0 | |
Sales of minerals in place (Mass) | (601) | (43) | (233) | (1,199) | (155) | |
Production of proved reserves (Mass) | (26) | (29) | (32) | (55) | (55) | |
Net change due to revisions in quantity estimates | $ | $ (59,000) | $ (143,000) | $ 471,000 | $ 56,000 | $ 125,000 | |
metallurgical coal [Member] | ||||||
Reserve Quantities [Line Items] | ||||||
Proved Undeveloped Reserve (Mass) | 87 | |||||
Affiliated Entity [Member] | ||||||
Reserve Quantities [Line Items] | ||||||
Proved Undeveloped Reserve (Mass) | 0 | 0 | 55 | 57 | 41 |
Supplemental Gas Data Capitaliz
Supplemental Gas Data Capitalized Costs (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items] | ||
Proved Oil and Gas Property, Successful Effort Method | $ 2,016,916 | $ 1,922,602 |
Unproved Oil and Gas Property, Successful Effort Method | 1,116,282 | 1,421,083 |
Drilling Cost | 3,583,565 | 3,452,989 |
Wells and related equipment | 791,996 | 785,744 |
Gathering assets | 1,138,299 | 1,147,173 |
Oil and Gas Reclamation Liability, Noncurrent | 176,961 | 115,121 |
Total Property, Plant and Equipment | 8,824,019 | 8,844,712 |
Accumulated Depreciation, Depletion and Amortization | (3,099,622) | (2,691,005) |
Net Capitalized Costs | 5,724,397 | 6,153,707 |
Gas Segment [Member] | ||
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items] | ||
Proved Oil and Gas Property, Successful Effort Method | 1,922,602 | |
Unproved Oil and Gas Property, Successful Effort Method | 1,421,083 | |
Drilling Cost | $ 3,583,565 | $ 3,452,989 |
Supplemental Gas Data Oil and G
Supplemental Gas Data Oil and Gas Expenditures (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items] | |||
Proven properties | $ 0 | $ 0 | $ 0 |
Unproven properties | 1,537 | 76,676 | 119,597 |
Development | 138,813 | 666,315 | 952,733 |
Exploration | 32,259 | 95,371 | 45,006 |
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities | $ 172,609 | $ 838,362 | $ 1,117,336 |
Supplemental Gas Data Results o
Supplemental Gas Data Results of Operations (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items] | |||
Production Revenue | $ 793,673 | $ 728,458 | $ 1,007,381 |
Gain (Loss) on Hedging Activity | (141,021) | 392,942 | 23,193 |
Gas Royalty Interests and Purchased Gas Sales | 43,256 | 14,450 | 8,999 |
Total Revenue | 695,908 | 1,135,850 | 1,039,573 |
Lifting Costs | 96,434 | 121,847 | 139,242 |
Production Tax Expense | 31,049 | 30,438 | 39,418 |
Gathering Costs | 374,350 | 343,403 | 239,591 |
E&P Direct Administration and Selling | 14,519 | 10,120 | 22,718 |
Other Costs | 370,374 | 323,600 | |
Impairment of Oil and Gas Properties | 0 | 828,905 | 0 |
DD&A | 976,922 | 1,715,808 | 771,820 |
Total Costs | (281,014) | (579,958) | 267,753 |
Pre-tax Operating Income | (69,308) | (250,220) | 45,162 |
Income Taxes | (211,706) | (329,738) | 222,591 |
Cnx Gas Guarantor [Member] | |||
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items] | |||
Gain (Loss) on Hedging Activity | (141,021) | 392,942 | 23,193 |
Gas Royalty Interests and Purchased Gas Sales | 43,256 | 14,450 | 8,999 |
Production Tax Expense | 31,049 | 30,438 | 39,418 |
Gain (Loss) on Sale of Assets | 42,717 | 10,721 | 7,251 |
Other Costs | 417,853 | ||
Impairment of Oil and Gas Properties | $ 0 | $ 828,905 | $ 0 |
Supplemental Gas Data Average U
Supplemental Gas Data Average Unit Prices (Details) | 12 Months Ended | |||
Dec. 31, 2016USD ($)MMcf | Dec. 31, 2015USD ($)MMcf | Dec. 31, 2014USD ($)MMcf | Dec. 31, 2013MMcf | |
Average Sales Price and Production Costs Per Unit of Production [Line Items] | ||||
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place | (870,884,000) | |||
Oil and Gas Delivery Commitments and Contracts, Remaining Contractual Volume | 431.4 | |||
Proved Developed and Undeveloped Reserves, Production | 394,387,000 | 328,657,000 | 235,714,000 | |
Proved Developed and Undeveloped Reserves, Purchases of Minerals in Place | 1,443,642,000 | |||
Beginning reserves | 6,251,648,000 | 5,642,989,000 | 6,827,616,000 | 5,731,214,000 |
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates | (99,849,000) | 1,368,909,000 | 218,168,000 | |
Proved Developed and Undeveloped Reserves, Improved Recovery | 190,009,000 | (3,159,421,000) | 15,512,000 | |
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 720,146,000 | 934,542,000 | 1,098,436,000 | |
Plan and Other Revisions [Member] | ||||
Average Sales Price and Production Costs Per Unit of Production [Line Items] | ||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 4,906,000 | |||
Natural Gas [Member] | ||||
Average Sales Price and Production Costs Per Unit of Production [Line Items] | ||||
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place | (711,155,000) | |||
Proved Developed and Undeveloped Reserves, Production | 358,474,000 | 285,041,000 | 216,260,000 | |
Proved Developed and Undeveloped Reserves, Purchases of Minerals in Place | 1,352,759,000 | |||
Beginning reserves | 5,828,398,000 | 5,060,214,000 | 6,317,600,000 | 5,585,107,000 |
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates | 21,280,000 | 1,052,978,000 | (46,560,000) | |
Proved Developed and Undeveloped Reserves, Improved Recovery | 179,914,000 | (2,866,123,000) | 15,512,000 | |
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 643,688,000 | 840,800,000 | ||
Natural Gas [Member] | Plan and Other Revisions [Member] | ||||
Average Sales Price and Production Costs Per Unit of Production [Line Items] | ||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 979,801,000 | |||
Natural Gas, Per Thousand Cubic Feet [Member] | ||||
Average Sales Price and Production Costs Per Unit of Production [Line Items] | ||||
Average Gas Sales Price before effects of financial settlements | $ | $ 2.01 | $ 2.22 | $ 4.27 | |
Average effects of financial settlements (per thousand cubic feet) | $ | 0.62 | 0.60 | 0.10 | |
Average gas sales price including effects of financial settlements (per thousand cubic feet) | $ | $ 2.63 | $ 2.82 | $ 4.37 | |
Average lifting costs, excluding ad valorem and severance taxes (per thousand cubic feet) | .24 | .37 | .59 | |
Natural Gas Liquids [Member] | ||||
Average Sales Price and Production Costs Per Unit of Production [Line Items] | ||||
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place | (22,382,000) | |||
Proved Developed and Undeveloped Reserves, Production | 5,119,000 | 5,812,000 | 2,578,000 | |
Proved Developed and Undeveloped Reserves, Purchases of Minerals in Place | 13,177,000 | |||
Beginning reserves | 60,532,000 | 86,212,000 | 77,790,000 | 21,546,000 |
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates | (20,669,000) | 45,993,000 | 40,363,000 | |
Proved Developed and Undeveloped Reserves, Improved Recovery | 1,647,000 | (45,675,000) | 0 | |
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 10,960,000 | 13,916,000 | ||
Natural Gas Liquids [Member] | Plan and Other Revisions [Member] | ||||
Average Sales Price and Production Costs Per Unit of Production [Line Items] | ||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 18,459,000 | |||
Crude Oil [Member] | ||||
Average Sales Price and Production Costs Per Unit of Production [Line Items] | ||||
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place | (4,240,000) | |||
Proved Developed and Undeveloped Reserves, Production | 867,000 | 1,458,000 | 664,000 | |
Proved Developed and Undeveloped Reserves, Purchases of Minerals in Place | 1,970,000 | |||
Beginning reserves | 10,007,000 | 10,915,000 | 7,212,000 | 2,806,000 |
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates | 481,000 | 6,662,000 | 3,756,000 | |
Proved Developed and Undeveloped Reserves, Improved Recovery | 35,000 | (3,208,000) | 0 | |
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 1,783,000 | 1,707,000 | ||
Crude Oil [Member] | Plan and Other Revisions [Member] | ||||
Average Sales Price and Production Costs Per Unit of Production [Line Items] | ||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 1,314,000 |
Supplemental Gas Data Acreages
Supplemental Gas Data Acreages (Details) number in Thousands, a in Thousands, $ in Thousands | Dec. 31, 2016USD ($)a | Dec. 31, 2015USD ($) |
Gas and Oil Acreage [Line Items] | ||
Unproved Oil and Gas Property, Successful Effort Method | $ | $ 1,116,282 | $ 1,421,083 |
Proved Oil and Gas Property, Successful Effort Method | $ | $ 2,016,916 | $ 1,922,602 |
Productive Gas Wells, Number of Wells, Gross | 17,314 | |
Gas and Oil Acreage, Undeveloped, Net | 30,038 | |
unproved acreage gross | 4,804,804 | |
Gas and Oil Acreage, Unproved, Net | 3,745,533 | |
Total Acreage - Gross | 5,389,087 | |
Total Acreage - Net | 4,316,853 | |
Productive Gas Wells, Number of Wells, Net | 12,846 | |
Productive Oil Wells, Number of Wells, Gross | 189 | |
Productive Oil Wells, Number of Wells, Net | 30 | |
Gas and Oil Area, Developed, Gross | 549,816 | |
Gas and Oil Area, Developed, Net | 541,282 | |
Gas and Oil Area, Undeveloped, Gross | 34,467 |
Supplemental Gas Data Explorata
Supplemental Gas Data Exploratary Wells (Details) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016USD ($) | Dec. 31, 2015USD ($) | Dec. 31, 2014USD ($) | |
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items] | |||
Development Wells Drilled, Net Productive | 36 | 133 | 180 |
Costs expensed due to determination of dry hole or abandonment of project | $ 0 | $ 0 | $ 2,041 |
Costs reclassified to wells, equipment and facilities based on the determination of proved reserves | $ 40,917 | $ 17,179 | $ 27,453 |
Exploratory Wells Drilled, Net Productive | 3 | 9 |
Supplemental Gas Data PV-10 (De
Supplemental Gas Data PV-10 (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | Dec. 31, 2013 |
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items] | ||||
Revenues | $ 11,303,409 | $ 11,837,732 | $ 28,502,852 | |
Production costs | 5,850,941 | 6,584,947 | 10,100,868 | |
Development costs | 1,550,294 | 1,220,010 | 3,368,621 | |
Income tax expense | 1,482,826 | 1,532,454 | 5,711,989 | |
Future Net Cash Flows | 2,419,348 | 2,500,321 | 9,321,374 | |
Discounted to present value at a 10% annual rate | 1,464,231 | 1,481,017 | 6,337,216 | |
Total standardized measure of discounted net cash flows | $ 955,117 | $ 1,019,304 | $ 2,984,158 | $ 1,680,811 |
Supplemental Gas Data PV-10 Rec
Supplemental Gas Data PV-10 Reconciliation (Details) MMcf in Thousands, $ in Thousands | 12 Months Ended | |||
Dec. 31, 2016USD ($)MMcf | Dec. 31, 2015USD ($)MMcf | Dec. 31, 2014USD ($)MMcf | Dec. 31, 2013USD ($)MMcf | |
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items] | ||||
Beginning reserves | MMcf | 6,251,648 | 5,642,989 | 6,827,616 | 5,731,214 |
Revenues | $ 11,303,409 | $ 11,837,732 | $ 28,502,852 | |
Net changes in sales prices and production costs | (172,812) | (4,151,684) | 517,731 | |
Net changes in sales prices and production costs | (150,819) | (589,533) | (559,563) | |
Net change due to revisions in quantity estimates | (35,502) | 408,006 | 151,233 | |
Net change due to extensions, discoveries and improved recovery | (54,628) | 157,016 | 418,775 | |
Development costs incurred during the period | 138,813 | 666,315 | 952,733 | |
Difference in previously estimated development costs compared to actual costs incurred during the period | (39,821) | 8,911 | (102,949) | |
Increase Due to Purchases of Minerals in Place | 238,819 | 0 | 0 | |
Decrease Due to Sales of Minerals in Place | (137,998) | 0 | ||
Changes in estimated future development costs | (158,000) | 374,982 | 595,221 | |
Net change in future income taxes | 36,513 | 1,259,744 | (798,470) | |
Accretion of discount and other | 271,248 | (98,611) | 128,636 | |
Total standardized measure of discounted net cash flows | 955,117 | 1,019,304 | 2,984,158 | $ 1,680,811 |
Production costs | (5,850,941) | (6,584,947) | (10,100,868) | |
Development costs | (1,550,294) | (1,220,010) | (3,368,621) | |
Income tax expense | (1,482,826) | (1,532,454) | (5,711,989) | |
Future Net Cash Flows | 2,419,348 | 2,500,321 | 9,321,374 | |
Discounted to present value at a 10% annual rate | $ (1,464,231) | $ (1,481,017) | $ (6,337,216) | |
Natural Gas [Member] | ||||
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items] | ||||
Beginning reserves | MMcf | 5,828,398 | 5,060,214 | 6,317,600 | 5,585,107 |
Supplemental Gas Data Proved Un
Supplemental Gas Data Proved Undeveloped Reserves (Details) MMcf in Thousands | 12 Months Ended | ||||
Dec. 31, 2016USD ($)MMcf | Dec. 31, 2015USD ($)MMcf | Dec. 31, 2014USD ($)MMcf | Dec. 31, 2013MMcf | Jan. 02, 2013MMcf | |
Reserve Quantities [Line Items] | |||||
Payments to Acquire Property, Plant, and Equipment | $ | $ 226,820,000 | $ 982,934,000 | $ 1,459,452,000 | ||
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place | (870,884) | ||||
Proved Developed and Undeveloped Reserves, Purchases of Minerals in Place | 1,443,642 | ||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 720,146 | 934,542 | 1,098,436 | ||
Proved Developed and Undeveloped Reserves, Production | 394,387 | 328,657 | 235,714 | ||
Beginning reserves | 6,251,648 | 5,642,989 | 6,827,616 | 5,731,214 | |
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates | (99,849) | 1,368,909 | 218,168 | ||
Proved Developed and Undeveloped Reserves, Improved Recovery | 190,009 | (3,159,421) | 15,512 | ||
proved undeveloped [Member] | |||||
Reserve Quantities [Line Items] | |||||
Payments to Acquire Property, Plant, and Equipment | $ | $ 58,694 | ||||
Proved Undeveloped Reserve (Volume) | 2,568,346 | 1,945,837 | |||
undeveloped reserves transferred to developed | (211,876) | ||||
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place | (199,401) | ||||
Proved Developed and Undeveloped Reserves, Purchases of Minerals in Place | 547,680 | ||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 669,266 | ||||
Beginning reserves | 2,568,346 | 1,945,837 | 3,628,910 | ||
Price Changes [Member] | |||||
Reserve Quantities [Line Items] | |||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 188,066 | ||||
Plan and Other Revisions [Member] | |||||
Reserve Quantities [Line Items] | |||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 4,906 | ||||
Proved Developed [Member] | |||||
Reserve Quantities [Line Items] | |||||
Beginning reserves | 3,683,302 | 3,697,152 | 3,198,706 | ||
Natural Gas [Member] | |||||
Reserve Quantities [Line Items] | |||||
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place | (711,155) | ||||
Proved Developed and Undeveloped Reserves, Purchases of Minerals in Place | 1,352,759 | ||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 643,688 | 840,800 | |||
Proved Developed and Undeveloped Reserves, Production | 358,474 | 285,041 | 216,260 | ||
Beginning reserves | 5,828,398 | 5,060,214 | 6,317,600 | 5,585,107 | |
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates | 21,280 | 1,052,978 | (46,560) | ||
Proved Developed and Undeveloped Reserves, Improved Recovery | 179,914 | (2,866,123) | 15,512 | ||
Natural Gas [Member] | proved undeveloped [Member] | |||||
Reserve Quantities [Line Items] | |||||
Beginning reserves | 2,349,934 | 1,749,320 | 3,337,694 | ||
Natural Gas [Member] | Plan and Other Revisions [Member] | |||||
Reserve Quantities [Line Items] | |||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 979,801 | ||||
Natural Gas [Member] | Proved Developed [Member] | |||||
Reserve Quantities [Line Items] | |||||
Beginning reserves | 3,478,464 | 3,310,894 | 2,979,906 | ||
Natural Gas Liquids [Member] | |||||
Reserve Quantities [Line Items] | |||||
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place | (22,382) | ||||
Proved Developed and Undeveloped Reserves, Purchases of Minerals in Place | 13,177 | ||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 10,960 | 13,916 | |||
Proved Developed and Undeveloped Reserves, Production | 5,119 | 5,812 | 2,578 | ||
Beginning reserves | 60,532 | 86,212 | 77,790 | 21,546 | |
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates | (20,669) | 45,993 | 40,363 | ||
Proved Developed and Undeveloped Reserves, Improved Recovery | 1,647 | (45,675) | 0 | ||
Natural Gas Liquids [Member] | proved undeveloped [Member] | |||||
Reserve Quantities [Line Items] | |||||
Beginning reserves | 29,866 | 27,016 | 45,385 | ||
Natural Gas Liquids [Member] | Plan and Other Revisions [Member] | |||||
Reserve Quantities [Line Items] | |||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 18,459 | ||||
Natural Gas Liquids [Member] | Proved Developed [Member] | |||||
Reserve Quantities [Line Items] | |||||
Beginning reserves | 30,666 | 59,196 | 32,405 | ||
Crude Oil [Member] | |||||
Reserve Quantities [Line Items] | |||||
Proved Developed and Undeveloped Reserves, Sales of Minerals in Place | (4,240) | ||||
Proved Developed and Undeveloped Reserves, Purchases of Minerals in Place | 1,970 | ||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 1,783 | 1,707 | |||
Proved Developed and Undeveloped Reserves, Production | 867 | 1,458 | 664 | ||
Beginning reserves | 10,007 | 10,915 | 7,212 | 2,806 | |
Proved Developed and Undeveloped Reserves, Revisions of Previous Estimates | 481 | 6,662 | 3,756 | ||
Proved Developed and Undeveloped Reserves, Improved Recovery | 35 | (3,208) | 0 | ||
Crude Oil [Member] | proved undeveloped [Member] | |||||
Reserve Quantities [Line Items] | |||||
Beginning reserves | 6,536 | 5,736 | 3,151 | ||
Crude Oil [Member] | Plan and Other Revisions [Member] | |||||
Reserve Quantities [Line Items] | |||||
Proved Developed and Undeveloped Reserves, Extensions, Discoveries, and Additions | 1,314 | ||||
Crude Oil [Member] | Proved Developed [Member] | |||||
Reserve Quantities [Line Items] | |||||
Beginning reserves | 3,474 | 5,180 | 4,061 |
Supplemental Quarterly Info 128
Supplemental Quarterly Info (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Thousands | 3 Months Ended | 12 Months Ended | |||||||||
Dec. 31, 2016 | Sep. 30, 2016 | Dec. 31, 2015 | Jun. 30, 2015 | Mar. 31, 2015 | Sep. 30, 2014 | Jun. 30, 2014 | Mar. 31, 2014 | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 2014 | |
Impairment of Oil and Gas Properties | $ 0 | $ 828,905 | $ 0 | ||||||||
Sales | $ 390,398 | $ 688,590 | $ 602,772 | $ 235,251 | $ 478,864 | $ 631,979 | $ 503,825 | $ 715,740 | 2,026,375 | 2,693,339 | 3,204,023 |
Freight-Outside | 12,519 | 9,392 | 10,295 | 11,447 | 13,110 | 2,436 | 2,750 | 5,018 | 46,468 | 20,499 | 23,133 |
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below) | 415,224 | 361,551 | 243,267 | 369,392 | 329,071 | 267,826 | 351,200 | 399,281 | |||
Freight Expense | 12,519 | 9,392 | 10,295 | 11,447 | 13,110 | 2,436 | 2,750 | 5,018 | 46,468 | 20,499 | 23,133 |
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax | 19,564 | (34,975) | (11,017) | (234,605) | (53,167) | (3,842) | (25,417) | 26,067 | (303,183) | (14,209) | (1,857) |
Income (Loss) from Continuing Operations Attributable to Parent | (321,198) | 62,568 | 45,342 | (234,044) | (43,291) | 129,312 | (577,884) | 52,964 | (544,919) | (360,676) | 164,947 |
Net Income Attributable to CONSOL Energy Inc Shareholders | $ (306,047) | $ 25,345 | $ 30,405 | $ (469,828) | $ (97,572) | $ 118,980 | $ (603,301) | $ 79,031 | $ (848,102) | $ (374,885) | $ 163,090 |
Basic | $ (1.33) | $ 0.11 | $ 0.13 | $ (2.05) | $ (0.43) | $ 0.52 | $ (2.64) | $ 0.34 | $ (3.70) | $ (1.64) | $ 0.71 |
Income (Loss) from Continuing Operations, Per Diluted Share | (1.42) | 0.26 | 0.18 | (1.03) | (0.19) | 0.54 | (2.52) | 0.23 | (2.38) | (1.57) | 0.71 |
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Diluted Share | 0.09 | (0.15) | (0.05) | (1.02) | (0.24) | (0.02) | (0.12) | 0.11 | (1.32) | (0.07) | (0.01) |
Income (Loss) from Continuing Operations, Per Basic Share | (1.42) | 0.26 | 0.18 | (1.03) | (0.19) | 0.54 | (2.52) | 0.23 | (2.38) | (1.57) | 0.72 |
Diluted | (1.33) | 0.11 | 0.13 | (2.05) | (0.43) | 0.52 | (2.64) | 0.34 | (3.70) | (1.64) | 0.70 |
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Basic Share | $ 0.09 | $ (0.15) | $ (0.05) | $ (1.02) | $ (0.24) | $ (0.02) | $ (0.12) | $ 0.11 | $ (1.32) | $ (0.07) | $ (0.01) |
Uncategorized Items - cnx-20161
Label | Element | Value |
Noncontrolling Interest [Member] | ||
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | us-gaap_ProfitLoss | $ 8,954,000 |
Common Stock [Member] | ||
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | us-gaap_ProfitLoss | 0 |
AOCI Attributable to Parent [Member] | ||
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | us-gaap_ProfitLoss | 0 |
Treasury Stock [Member] | ||
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | us-gaap_ProfitLoss | 0 |
Additional Paid-in Capital [Member] | ||
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | us-gaap_ProfitLoss | 0 |
Retained Earnings [Member] | ||
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | us-gaap_ProfitLoss | (848,102,000) |
Parent [Member] | ||
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest | us-gaap_ProfitLoss | $ (848,102,000) |