CNX Resources (CNX) 10-K 7 Feb 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Jan. 20, 2014	Jun. 30, 2013
Document Information [Abstract]	'	'	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Entity Registrant Name	'CONSOL Energy Inc	'	'
Entity Central Index Key	'0001070412	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Entity Common Stock, Shares Outstanding	'	229,162,591	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Public Float	'	'	$3,294,530,080

Consolidated_Statements_of_Inc

Consolidated Statements of Income (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement [Abstract]	'	'	'
Sales-Outside	$3,015,551	$3,122,550	$3,991,007
Sales-Gas Royalty Interests	63,202	49,405	66,929
Sales-Purchased Gas	6,531	3,316	4,344
Freight-Outside	35,438	107,079	175,633
Other Income	178,963	395,176	139,132
Total Revenue and Other Income	3,299,685	3,677,526	4,377,045
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	2,228,952	2,221,859	2,266,560
Gas Royalty Interests Costs	53,028	38,867	59,331
Purchased Gas Costs	4,837	2,711	3,831
Freight Expense	35,438	107,079	175,444
Selling, General and Administrative Expenses	90,408	90,740	114,643
Depreciation, Depletion and Amortization	461,122	427,115	430,577
Interest Expense	219,198	220,042	248,344
Taxes Other Than Income	160,627	162,426	174,392
Gains (Losses) on Extinguishment of Debt	0	0	16,090
Acquisition and Financing Fees	0	0	14,907
Total Costs	3,253,610	3,270,839	3,504,119
Earnings Before Income Taxes	46,075	406,687	872,926
Income Taxes	-33,189	88,728	191,251
Income (Loss) from Continuing Operations Attributable to Parent	79,264	317,959	681,675
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax	579,792	70,114	-49,178
Net Income (Loss)	659,056	388,073	632,497
Less: Net Loss (Income) Attributable to Noncontrolling Interest	1,386	397	0
Net Income Attributable to CONSOL Energy Inc Shareholders	$660,442	$388,470	$632,497
Earnings per share:	'	'	'
Income (Loss) from Continuing Operations, Per Basic Share	$0.35	$1.40	$3.01
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Basic Share	$2.54	$0.31	($0.22)
Basic	$2.89	$1.71	$2.79
Income (Loss) from Continuing Operations, Per Diluted Share	$0.35	$1.39	$2.98
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Diluted Share	$2.52	$0.31	($0.22)
Dilutive	$2.87	$1.70	$2.76
Weighted Average Number of Common Shares Outstanding:	'	'	'
Weighted Average Number of Shares Outstanding, Basic	228,728,628	227,593,524	226,680,369
Dilutive	230,077,942	229,141,767	229,003,599
Dividends Paid Per Share	$0.38	$0.63	$0.43

Consolidated_Statement_of_Comp

Consolidated Statement of Comprehensive Income (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Statement of Comprehensive Income [Abstract]	'	'	'
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	($79,899)	($189,259)	($95,007)
Net Income (Loss)	659,056	388,073	632,497
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Treasury Rate Lock, Net of Tax	0	0	-96
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	456,493	129,231	-32,813
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	45,631	114,240	200,700
Net Income (Loss)	659,056	388,073	632,497
Other Comprehensive Income (Loss), Net of Tax	422,225	54,212	72,784
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	1,081,281	442,285	705,281
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest	1,386	397	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$1,082,667	$442,682	$705,281

Consolidated_Statement_of_Comp1

Consolidated Statement of Comprehensive Income Parentheticals (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013
Other Comprehensive Income (Loss), Tax	$53,990	$121,484	$60,925
Adjustment For Actuarially Determined Liabilities [Member]	'	'	'
Other Comprehensive Income (Loss), Tax	-276,928	-77,871	1,583
Cash Flow Hedging [Member]	'	'	'
Other Comprehensive Income (Loss), Tax	($29,407)	($73,593)	($129,235)

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current Assets:	'	'
Cash and Cash Equivalents	$327,420	$21,862
Accounts and Notes Receivable:	'	'
Trade	332,574	428,328
Notes, Loans and Financing Receivable, Net, Current	25,861	318,387
Other Receivables, Net, Current	243,973	131,131
Accounts Receivable—Securitized	0	37,846
Inventories	157,914	170,808
Deferred Income Taxes	211,303	84,777
Income Taxes Receivable, Current	10,705	0
Restricted Cash and Cash Equivalents, Current	0	48,294
Prepaid Expenses	135,842	148,431
Assets of Disposal Group, Including Discontinued Operation, Current	0	149,230
Total Current Assets	1,445,592	1,539,094
Property, Plant and Equipment:	'	'
Property, Plant and Equipment, Gross	13,578,509	12,121,557
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	4,136,247	3,613,499
Disposal Group, Including Discontinued Operation, Property, Plant, and Equipment, Net	0	1,682,909
Total Property, Plant and Equipment-Net	9,442,262	10,190,967
Other Assets:	'	'
Restricted Cash	0	20,379
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	291,675	222,830
Notes, Loans and Financing Receivable, Net, Noncurrent	125	25,977
Other	214,013	216,235
Disposal Group, Including Discontinued Operation, Other Assets	0	782,112
Total Other Assets	505,813	1,267,533
Total Assets	11,393,667	12,997,594
Current Liabilities:	'	'
Accounts Payable	514,580	498,515
Current Portion of Long-Term Debt	11,455	12,484
Short-Term Notes Payable	0	25,073
Accrued Income Taxes, Current	0	34,219
Borrowings Under Securitization Facility	0	37,846
Other Accrued Liabilities, Current	122,902	144,352
Liabilities of Disposal Group, Including Discontinued Operation, Current	28,239	233,214
Other Accrued Liabilities	565,697	545,748
Total Current Liabilities	1,119,971	1,387,099
Long-Term Debt:	'	'
Long-Term Debt	3,115,963	3,123,600
Capital Lease Obligations	47,596	49,413
Liabilities of Disposal Group, Including Discontinued Operation	0	1,573
Total Long-Term Debt	3,163,559	3,174,586
Deferred Credits and Other Liabilities	'	'
Deferred Tax Liabilities, Net, Noncurrent	242,643	326,685
Postretirement Benefits Other Than Pensions	961,127	882,600
Pneumoconiosis Benefits	111,971	114,136
Mine Closing	320,723	289,818
Gas Well Closing	175,603	146,002
Workers' Compensation	71,468	60,396
Salary Retirement	48,252	218,004
Reclamation	40,706	47,965
Other	131,355	118,307
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	0	2,278,251
Total Deferred Credits and Other Liabilities	2,103,848	4,482,164
TOTAL LIABILITIES	6,387,378	9,043,849
Stockholders' Equity:	'	'
Common Stock, $.01 Par Value; 500,000,000 Shares Authorized, 228,129,467 Issued and 228,094,712 Outstanding at December 31, 2012; 227,289,426 Issued and 227,056,212 Outstanding at December 31, 2011	2,294	2,284
Capital in Excess of Par Value	2,364,592	2,296,908
Preferred Stock, 15,000,000 shares authorized, None issued and outstanding	0	0
Retained Earnings	2,964,520	2,402,551
Accumulated Other Comprehensive Loss	-325,117	-747,342
Common Stock in Treasury, at Cost—34,755 Shares at December 31, 2012 and 233,214 Shares at December 31, 2011	0	-609
Total CONSOL Energy Inc. Stockholders' Equity	5,006,289	3,953,792
Noncontrolling Interest	0	-47
TOTAL EQUITY	5,006,289	3,953,745
TOTAL LIABILITIES AND EQUITY	$11,393,667	$12,997,594

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets Parentheticals (USD $)	Dec. 31, 2013	Dec. 31, 2012
Common Stock, Shares, Outstanding	229,145,736	228,094,712
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	229,145,736	228,129,467
Common Stock, Shares, Outstanding	229,145,736	228,094,712
Treasury Stock, Shares	0	34,755
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_Sto

Consolidated Statements of Stockholders' Equity (USD $)	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
In Thousands, unless otherwise specified
Balance, Beginning of Period at Dec. 31, 2010	$2,936,013	$2,273	$2,178,604	$1,680,597	($874,338)	($42,659)	$2,944,477	($8,464)
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'
Net Income (Loss)	632,497	0	0	632,497	0	0	632,497	0
Treasury Rate Lock, Net of Tax	-96	0	0	0	-96	0	-96	0
Gas Cash Flow Hedge (Net of tax: $15,983, ($68,310), $47,891)	-105,693	0	0	0	-105,693	0	-105,693	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	-32,813	0	0	0	-32,813	0	-32,813	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	705,281	0	0	632,497	72,784	0	705,281	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	705,281	'	'	'	'	'	'	'
Issuance of Treasury Stock	1,312	0	0	-32,001	0	33,313	1,312	0
Proceeds from Issuance of Common Stock	0	'	'	'	'	'	'	'
Tax Benefit from Stock-Based Compensation	7,329	0	7,329	0	0	0	7,329	0
Amortization of Stock-Based Compensation Awards	48,842	0	48,842	0	0	0	48,842	0
Net Change in Crown Drilling Noncontrolling Interest	8,464	0	0	0	0	0	0	8,464
Dividends	96,356	0	0	96,356	0	0	96,356	0
Balance, End of Period at Dec. 31, 2011	3,610,885	2,273	2,234,775	2,184,737	-801,554	-9,346	3,610,885	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'
Net Income (Loss)	388,073	0	0	388,470	0	0	388,470	-397
Treasury Rate Lock, Net of Tax	0	'	'	'	'	'	'	'
Gas Cash Flow Hedge (Net of tax: $15,983, ($68,310), $47,891)	75,019	0	0	0	75,019	0	75,019	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	129,231	0	0	0	129,231	0	129,231	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	442,682	0	0	388,470	54,212	0	442,682	-397
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	442,285	'	'	'	'	'	'	'
Issuance of Treasury Stock	-19,641	0	0	-28,378	0	8,737	-19,641	0
Proceeds from Issuance of Common Stock	8,278	11	8,267	0	0	0	8,278	0
Tax Benefit from Stock-Based Compensation	6,028	0	6,028	0	0	0	6,028	0
Amortization of Stock-Based Compensation Awards	47,838	0	47,838	0	0	0	47,838	0
Net Change in Crown Drilling Noncontrolling Interest	350	0	0	0	0	0	0	350
Dividends	142,278	0	0	142,278	0	0	142,278	0
Balance, End of Period at Dec. 31, 2012	3,953,745	2,284	2,296,908	2,402,551	-747,342	-609	3,953,792	-47
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'
Net Income (Loss)	659,056	0	0	660,442	0	0	660,442	-1,386
Treasury Rate Lock, Net of Tax	0	'	'	'	'	'	'	'
Gas Cash Flow Hedge (Net of tax: $15,983, ($68,310), $47,891)	34,268	0	0	0	34,268	0	34,268	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	456,493	0	0	0	456,493	0	456,493	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	1,082,667	0	0	660,442	422,225	0	1,082,667	-1,386
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	1,081,281	'	'	'	'	'	'	'
Issuance of Treasury Stock	-12,032	0	0	-12,641	0	609	-12,032	0
Proceeds from Issuance of Common Stock	3,727	10	3,717	0	0	0	3,727	0
Tax Benefit from Stock-Based Compensation	-2,075	0	-2,075	0	0	0	-2,075	0
Amortization of Stock-Based Compensation Awards	66,042	0	66,042	0	0	0	66,042	0
Net Change in Crown Drilling Noncontrolling Interest	1,433	0	0	0	0	0	0	1,433
Dividends	85,832	0	0	85,832	0	0	85,832	0
Balance, End of Period at Dec. 31, 2013	$5,006,289	$2,294	$2,364,592	$2,964,520	($325,117)	$0	$5,006,289	$0

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Activities:	'	'	'
Net Income (Loss)	$659,056	$388,073	$632,497
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	-579,792	-70,114	49,178
Depreciation, Depletion and Amortization	461,122	427,115	430,577
Share-based Compensation	56,987	41,127	42,131
(Gain) Loss on Sale of Assets	67,480	282,006	45,673
Gains (Losses) on Extinguishment of Debt	0	0	16,090
Deferred Income Tax Expense (Benefit)	-36,777	10,899	-2,373
Equity in Earnings of Affiliates	-33,133	-27,048	-24,663
Changes in Operating Assets:	'	'	'
Accounts and Notes Receivable	-135,970	20,218	83,770
Inventories	-12,894	-21,166	-5,509
Prepaid Expenses	3,219	-12,435	-3,047
Changes in Other Assets	-31,146	7,041	-23,534
Changes in Operating Liabilities:	'	'	'
Accounts Payable	-99,944	-23,918	142,843
Other Operating Liabilities	-31,701	-50,790	78,530
Changes in Other Liabilities	5,844	12,876	38,413
Other	-42,597	-24,786	-23,001
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	553,570	457,342	1,328,871
Cash Provided by (Used in) Operating Activities, Discontinued Operations	105,206	270,771	198,735
Net Cash Provided by Operating Activities	658,776	728,113	1,527,606
Investing Activities:	'	'	'
Capital Expenditures	-1,496,056	-1,245,497	-1,178,375
Increase (Decrease) in Restricted Cash	68,673	-48,294	0
Proceeds from Sales of Assets	483,969	645,621	747,285
Net Investment in Equity Affiliates	-35,712	-23,451	55,876
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	-979,126	-671,621	-375,214
Cash Provided by (Used in) Investing Activities, Discontinued Operations	777,145	-328,789	-203,310
Net Cash Used in Investing Activities	-201,981	-1,000,410	-578,524
Financing Activities:	'	'	'
(Payments on) Proceeds from Short-Term Borrowings	0	0	-284,000
Payments on Miscellaneous Borrowings	-31,544	16,195	-11,080
Payments on Securitzation Facility	-37,846	37,846	-200,000
Payments On Long Term Notes Including Redemption Premium	0	0	-265,785
Proceeds from Issuance of Long-Term Notes	0	0	250,000
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities	2,929	8,678	8,281
Dividends Paid	-85,832	-142,278	-96,356
Proceeds from Issuance of Common Stock	3,727	8,278	0
Issuance of Treasury Stock	-2,151	-9,485	9,033
Debt Issuance and Financing Fees	0	-210	-15,686
Net Cash Provided by (Used in) Financing Activities, Continuing Operations	-150,717	-80,976	-605,593
Cash Provided by (Used in) Financing Activities, Discontinued Operations	-520	-601	-547
Net Cash (Used in) Provided by Financing Activities	-151,237	-81,577	-606,140
Net Increase in Cash and Cash Equivalents	305,558	-353,874	342,942
Cash and Cash Equivalents at Beginning of Period	21,862	375,736	'
Cash and Cash Equivalents at End of Period	$327,420	$21,862	$375,736

Discontinued_Operations_Notes

Discontinued Operations (Notes)	12 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]	'
	NOTE 2—DISCONTINUED OPERATIONS:
	In December 2013, CONSOL Energy completed the sale of its Consolidation Coal Company (CCC) subsidiary, which includes all five of its longwall coal mines in West Virginia, to a subsidiary of Murray Energy Corporation (Murray Energy). CONSOL Energy retained overriding royalty interests in certain reserves sold in the agreement. Murray Energy also assumed $2,050,656 of CONSOL Energy's employee benefit obligations valued as of December 5, 2013 and its UMWA 1974 Pension Trust obligations. Murray Energy is primarily liable for all 1993 Coal Act liabilities. Cash proceeds of $825,285 were received related to this transaction, which were net of $24,715 in transaction fees. Proceeds are subject to adjustments related to working capital. A pre-tax gain of $1,035,346 was included in Income from Discontinued Operations on the Consolidated Statement of Income.
	For all periods presented in the accompanying Consolidated Statement of Income, the sale of CCC was classified as discontinued operations. There were no other active businesses classified as discontinued operations in the three-year period ended December 31, 2013.
	In late 2013, CONSOL Energy reclassified CCC to discontinued operations based on the decision to divest the business. The Consolidated Financial Statements for all periods presented were reclassified to reflect the business in discontinued operations. The divestiture of the CCC was completed on December 5, 2013.
	The following table details selected financial information for the divested business included within discontinued operations:
		For the Years Ended December 31,
		2013			2012			2011
	Sales	$	2,598,875		$	1,717,926		$	1,740,196
	Income (Loss) from operations before income taxes	$	969,685		$	90,587		$	(84,972	)
	Income taxes (expense) benefit	(389,893		)	(20,473		)	35,794
	Income (loss) from discontinued operations	$	579,792		$	70,114		$	(49,178	)
	The major classes of assets and liabilities of discontinued operations are as follows:
		31-Dec-13			31-Dec-12
	Assets:
	Inventory	$	—		$	76,958
	Current Deferred Income Tax Asset	—			63,327
	Other Current Assets	—			8,945
	Properties, plants, and equipment	—			1,682,909
	Deferred Income Tax Asset	—			771,270
	Other assets	—			10,842
	Assets of discontinued operations	$	—		$	2,614,251
	Liabilities:
	Current Liabilities	$	28,239		$	233,214
	Long Term Debt	—			1,573
	Postretirement Benefits Other Than Pensions	—			1,949,801
	Pneumoconiosis Benefits	—			60,645
	Workers' Compensation	—			95,252
	Mine Closing	—			156,909
	Other liabilities	—			15,644
	Liabilities of discontinued operations	$	28,239		$	2,513,038

Acquisitions_and_Dispositions

Acquisitions and Dispositions	12 Months Ended
	Dec. 31, 2013
ACQUISITIONS AND DISPOSITIONS: [Abstract]	'
Acquisitions and Dispositions:	'
	ACQUISITIONS AND DISPOSITIONS:
	In December 2013, CONSOL Energy acquired the gas drilling rights to approximately 90,000 contiguous acres from Dominion Transmission, a unit of Dominion Resources. The acreage, which is associated with Dominion’s Fink-Kennedy, Lost Creek, and Racket Newberne gas storage fields in West Virginia, lies in the northern portion of Lewis County and the southern portion of Harrison County. CONSOL anticipates that over one-half of the acres will have wet gas. CONSOL Energy has acquired the gas rights to both the Marcellus Shale and the Upper Devonian formations in the storage fields. Consideration of up to $190 million will be paid by CONSOL Energy in two installments: 50% was paid at closing and the balance is due over time as the acres are drilled.  In addition, CONSOL Energy will pay an overriding royalty to Dominion Resources based on a sliding scale. Finally, CONSOL Energy has committed to be an anchor shipper on Dominion’s transmission system, with the specific terms to be negotiated at a future date. Noble Energy, our joint venture partner, acquired 50% of the acres and accordingly will reimburse CONSOL Energy for 50% of the associated costs. CONSOL Energy paid $91,243 in 2013 related to this transaction.
	In August 2013, CONSOL Energy completed the sale of its 50% interest in the CONSOL Energy/Devon Energy joint venture in Alberta, Canada. The properties and coal leases included were those related to Grassy Mountain, Bellevue, Adanac, and Lynx Creek (Crowsnest Pass). Cash proceeds for the sale were $24,764. A gain of $15,260 was included in Other Income in the Consolidated Statement of Income.
	In June 2013, CONSOL Energy completed the sale of Potomac coal reserves in Grant and Tucker Counties in West Virginia. Cash proceeds for the sale were $25,000. A gain of $24,663 was included in Other Income in the Consolidated Statement of Income.
	In April 2013, the Company and the Commonwealth of Pennsylvania (Commonwealth) entered into a Settlement Agreement and Release settling all of the Commonwealth's claims regarding the Ryerson Park Dam (Dam) and the Ryerson Park Lake (Lake). The Settlement provided, in part, for the payment to the Commonwealth of $36,000 for use to rebuild the Dam and restore the Lake with $13,728 of the settlement amount credited to lease bonus and royalty payments on the Commonwealth's Marcellus gas interests within the Park, subject to the Company's agreement to extract the gas from surface facilities located outside of the boundaries of the Park.  The Settlement also provided, in part, for the conveyance by the Company to the Commonwealth of eight surface parcels containing approximately 506 acres of land adjoining the Park after the parcels are no longer needed for the Company's operations and the conveyance by the Commonwealth to the Company of certain coal and mining rights in an area of the Bailey Mine where a mining permit application is currently pending.
	In March 2013, CNX Gas Company LLC (CNX Gas Company), a wholly owned subsidiary of CONSOL Energy, completed negotiations with the Allegheny County Airport Authority, which operates the Pittsburgh International Airport and the Allegheny County Airport, for the lease of the oil and gas rights on approximately 9.3 thousand acres.  A majority of these contiguous acres are in the liquids area of the Marcellus Shale play.  CNX Gas Company paid $46,315 as an up-front bonus payment at closing.  Approximately 7.6% of the bonus payment was placed into escrow while negotiations continue for a portion of the acres associated with the Allegheny County Airport and other acres that have potentially defective title.  CNX Gas Company must spud a well by February 21, 2015 and proceed with due diligence to complete the well or the lease terminates and CNX Gas Company forgoes the bonus. Our joint venture partner, Noble Energy Inc., has acquired a 50% interest in the acreage and accordingly, reimbursed CNX Gas Company for 50% of the associated costs during the year ended December 31, 2013.
	In January 2013, CONSOL Energy completed a sale-leaseback of longwall shields for the Bailey Mine. Cash proceeds for the sale were $71,166. A loss of $358 was recognized due to transaction fees and was included in Other Income in the Consolidated Statement of Income. The lease has been accounted for as an operating lease. The lease term is five years.
	On December 21, 2012, CONSOL Energy completed the disposition of its non-producing Ram River & Scurry Ram assets in Western Canada which consisted of 36 thousand acres of coal lands. In December 2012, cash proceeds of $51,869 were received related to this transaction. These proceeds were net of $637 in transaction fees. Additionally, a note receivable was recognized in 2012 related to the two additional cash payments to be received in June 2013 and June 2014. Payment of $25,500 was received in June 2013. A note receivable of $24,500 was included in Accounts and Notes Receivables - Notes Receivables in the Consolidated Balance Sheet at December 31, 2013. The gain on the transaction was $89,943 and was included in Other Income in the Consolidated Statement of Income for the year ended December 31, 2012.
	On June 29, 2012, CONSOL Energy completed the disposition of its non-producing Northern Powder River Basin assets in southern Montana and northern Wyoming for cash proceeds of $169,500. The assets consisted of CONSOL Energy's 50% interest in Youngs Creek Mining Company LLC, CONSOL Energy's 50% interest in CX Ranch and related properties in and around Sheridan, Wyoming. The gain on the transaction was $150,677 and is included in Other Income in the Consolidated Statement of Income for the year ended December 31, 2012. Additionally, CONSOL Energy retained an 8% production royalty interest on approximately 200 million tons of permitted fee coal.
	On April 4, 2012, CONSOL Energy completed the disposition of its non-producing Elk Creek property in southern West Virginia, which consisted of 20 thousand acres of coal lands and surface rights, for proceeds of $26,000. The gain on the transaction was $11,235 and is included in Other Income in the Consolidated Statement of Income for the year ended December 31, 2012.
	On February 9, 2012, CONSOL Energy completed the disposition of its Burning Star No. 4 property in Illinois, which consisted of 4.3 thousand acres of coal lands and surface rights, for proceeds of $13,023. The gain on the transaction was $11,261 and is included in Other Income in the Consolidated Statement of Income for the year ended December 31, 2012.
	On September 30 2011, CNX Gas Company and Noble formed CONE Gathering LLC (CONE), a joint venture established to develop and operate each company's gas gathering system needs in the Marcellus Shale play. CNX Gas Company's 50% ownership interest in CONE is accounted for under the equity method of accounting. CNX Gas contributed its existing Marcellus Shale gathering infrastructure which had a net book value of $119,740 and Noble contributed cash of approximately $67,545. CONE made a cash distribution to CNX Gas in the amount of $67,545. The cash proceeds were recorded as cash inflows of $59,870 and $7,675 in Distributions from Equity Affiliates and Proceeds from the Sale of Assets, respectively, on the Consolidated Statements of Cash Flow. The gain on the transaction was $7,161 and was recognized in the Consolidated Statements of Income as Other Income for the year ended December 31, 2011.
	On September 21, 2011, CONSOL Energy entered into an agreement with Antero Resources Appalachian Corp. (Antero), pursuant to which CONSOL Energy assigned to Antero overriding royalty interests (ORRI) of approximately 7% in approximately 116 thousand net acres of Marcellus Shale located in nine counties in southwestern Pennsylvania and north central West Virginia, in exchange for proceeds of $193,000 before transaction fees of $2,619. The net gain on the transaction was $41,057 and was recognized in the Consolidated Statements of Income as Other Income for the year ended December 31, 2011.

Other_Income

Other Income	12 Months Ended
	Dec. 31, 2013
Component of Operating Income [Abstract]	'
Other Income and Other Expense Disclosure [Text Block]	'
	NOTE 4—OTHER INCOME:
		For the Years Ended December 31,
		2013		2012		2011
	Gain on disposition of assets (a)	$	67,480	$	282,006	$	45,673
	Equity in earnings of affiliates	33,133		27,048		24,663
	Royalty income	16,906		16,853		17,969
	Interest income	15,889		28,937		8,919
	Pennsylvania Turnpike Settlement	9,000		—		—
	Right-of-way issuance	4,536		3,966		12,157
	Other	32,019		36,366		29,751
	Total Other Income	$	178,963	$	395,176	$	139,132
	(a) See Note 3 - Acquisitions and Dispositions for additional information.

Interest_Expense

Interest Expense	12 Months Ended
	Dec. 31, 2013
Interest Expense [Abstract]	'
Interest Income and Interest Expense Disclosure [Text Block]	'
	NOTE 5—INTEREST EXPENSE:
		For the Years Ended December 31,
		2013			2012			2011
	Interest on debt	$	260,233		$	256,800		$	264,080
	Interest on other payables	2,682			1,296			(189		)
	Interest capitalized	(43,717		)	(38,054		)	(15,547		)
	Total Interest Expense	$	219,198		$	220,042		$	248,344
	Interest on other payables for the year ended December 31, 2013 includes interest expense of $1,369 related to uncertain tax positions. Interest on other payables for the years ended December 31, 2012 and December 31, 2011 includes a reversal of interest expense of $543 and $3,096, respectively, related to uncertain tax positions. See Note 7–Income Taxes, for further discussion.

Taxes_Other_Than_Income

Taxes Other Than Income	12 Months Ended
	Dec. 31, 2013
TAXES OTHER THAN INCOME [Abstract]	'
taxes other than income [Text Block]	'
	NOTE 6—TAXES OTHER THAN INCOME:
		For the Years Ended December 31,
		2013			2012			2011
	Production taxes	$	84,984		$	77,629		$	99,442
	Property taxes	36,338			43,679			35,495
	Payroll taxes	32,779			32,478			33,155
	Capital stock & franchise tax	6,833			9,013			3,670
	Virginia employment enhancement tax credit	(4,683		)	(4,311		)	(6,109		)
	Other	4,376			3,938			8,739
	Total Taxes Other Than Income	$	160,627		$	162,426		$	174,392

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	INCOME TAXES:
	Income tax (benefit) expense provided on earnings from continuing operations consisted of:
		For The Years Ended December 31,
		2013			2012				2011
	Current:
	U.S. Federal	$	6,728		$	44,727			$	161,474
	U.S. State	(10,903		)	1,508				32,150
	Non-U.S	7,763			31,594				—
		3,588			77,829				193,624
	Deferred:
	U.S. Federal	(32,125		)	23,300				30,034
	U.S. State	(4,652		)	(14,166		)		(32,407		)
	Non-U.S.	—			1,765				—
		(36,777		)	10,899				(2,373		)
	Total Income (Benefit) Expense	$	(33,189	)	$	88,728			$	191,251
	The components of the net deferred tax liabilities are as follows:
		December 31,
		2013			2012
	Deferred Tax Assets:
	Postretirement benefits other than pensions	$	337,836		$	347,584
	Mine closing	37,306			57,370
	Alternative minimum tax	159,933			54,609
	Pneumoconiosis benefits	44,580			46,164
	Workers' compensation	31,008			25,191
	Salary retirement	14,330			83,077
	Net operating loss	168,658			27,277
	Mine subsidence	35,655			20,804
	Reclamation	20,978			26,716
	Capital lease	22,489			23,103
	Other	160,567			149,435
	Total Deferred Tax Assets	1,033,340			861,330
	Valuation Allowance**	(7,532		)	(4,500		)
	Net Deferred Tax Assets	1,025,808			856,830
	Deferred Tax Liabilities:
	Property, plant and equipment	(954,007		)	(976,505		)
	Gas hedge	(27,741		)	(51,006		)
	Advance mining royalties	(38,105		)	(33,950		)
	Other	(37,295		)	(37,277		)
	Total Deferred Tax Liabilities	(1,057,148		)	(1,098,738		)
	Net Deferred Tax Liability	$	(31,340	)	$	(241,908	)
	**Valuation allowance of $(7,532) has been allocated to long-term deferred tax asset for 2013. Valuation allowance of $(4,500) has been allocated to long-term deferred tax asset for 2012.
	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. At December 31, 2013 and 2012, positive evidence considered included financial and tax earnings generated over the past three years for certain subsidiaries, future income projections based on existing fixed price contracts and forecasted expenses, 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 and the inability to achieve forecasted results for those periods. CONSOL Energy continues to report, on an after federal tax basis, a deferred tax asset related to federal operating losses of $116,893 and state operating losses of $51,765 with a related valuation allowance of $7,532 at December 31, 2013. The deferred tax asset related to state operating losses, on an after tax adjusted basis, was $27,277 with a related valuation allowance of $4,500 at December 31, 2012. 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 2018 and 2032.
	The deferred tax assets attributable to 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 $4, after federal tax adjusted basis, has also been recorded for 2013. No valuation allowance was recognized in 2012. No allowances were recognized through other comprehensive income in 2013 or 2012. Management will continue to assess the potential for realizing 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 from continuing operations, of the United States statutory federal income tax rate to CONSOL Energy's effective tax rate:
		For the Years Ended December 31,
		2013						2012						2011
		Amount			Percent			Amount				Percent		Amount			Percent
	Statutory U.S. federal income tax rate	$	16,126		35	%		$	142,340			35	%	$	305,524		35	%
	Excess tax depletion	(51,104		)	(110.9	)		(49,572		)		(12.2	)	(72,577		)	(8.3	)
	Effect of medicare prescription drug, improvement and modernization act of 2003	2,112			4.6			2,112				0.5		2,112			0.2
	Effect of domestic production activities	5,680			12.3			(7,215		)		(1.8	)	(21,938		)	(2.5	)
	Federal and state tax accrual to tax return reconciliation	(1,406		)	(3.1	)		6,004				1.5		2,257			0.3
	IRS and state tax examination settlements	3			—			(925		)		(0.2	)	(5,188		)	(0.6	)
	Net effect of state income taxes	(2,399		)	(5.2	)		(8,737		)		(2.1	)	2,926			0.3
	Effect of releasing valuation allowance	(4,659		)	(10.1	)		—				—		(22,618		)	(2.6	)
	Effect of foreign tax	—			—			1,765				0.4		(1,822		)	(0.2	)
	Other	2,458			5.3			2,956				0.7		2,575			0.3
	Income Tax Expense / Effective Rate	$	(33,189	)	(72.1	)%		$	88,728			21.8	%	$	191,251		21.9	%
	A reconciliation of the beginning and ending gross amounts of unrecognized tax benefits is as follows:
		For the Years Ended
		December 31,
		2013			2012
	Balance at beginning of period	$	34,786		$	37,586
Increase in unrecognized tax benefits resulting from tax positions taken during current period	—			—
Increase (decrease) in unrecognized tax benefits resulting from tax positions taken during prior periods	—			—
Reduction in unrecognized tax benefits as a result of the lapse of the applicable statute of limitations	—			(2,800		)
Reduction of unrecognized tax benefits as a result of a settlement with taxing authorities	—			—
Balance at end of period	$	34,786		$	34,786
If these unrecognized tax benefits were recognized, CONSOL Energy's effective tax rate would be impacted by $2,071 at December 31, 2013 and 2012.
CONSOL Energy and its subsidiaries file income tax returns in the U.S. federal, various states and Canadian jurisdictions. With few exceptions, the Company is no longer subject to U.S. federal, state and local, or non-U.S. income tax examinations by tax authorities for the years before 2008.
In 2013, CONSOL Energy recognized no changes in unrecognized tax benefits. The IRS is continuing its audit of tax years 2008 and 2009 in 2014. During the next year, the statute of limitations for assessing additional income tax deficiencies will expire for certain tax years in several state tax jurisdictions. The expiration of the statute of limitations for these years will have an insignificant impact on CONSOL Energy's net income for the twelve-month period.
CONSOL Energy recognizes interest accrued related to unrecognized tax benefits in its interest expense. At December 31, 2013 and 2012, the Company had an accrued liability of $6,200 and $4,831 respectively, for interest related to uncertain tax positions. The accrued interest liabilities include $1,369 , $(543) and $(3,096) that were recorded in the Company's Consolidated Statements of Income for the years ended December 31, 2013, 2012 and 2011, respectively. During the year ended December 31, 2013, CONSOL Energy paid no interest related to income tax deficiencies.
CONSOL Energy recognizes penalties accrued related to unrecognized tax benefits in its income tax expense. As of December 31, 2013, 2012 and 2011, there were no accrued penalties recognized.

Inventories

Inventories	12 Months Ended
	Dec. 31, 2013
Inventory Disclosure [Abstract]	'
Inventories	'
	INVENTORIES:
	Inventory components consist of the following:
		December 31,
		2013		2012
	Coal	$	31,944	$	53,452
	Merchandise for resale	38,263		35,363
	Supplies	87,707		81,993
	Total Inventories	$	157,914	$	170,808
	Inventories are stated at the lower of cost or market. 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 and amortization, and other related costs.
	Merchandise for resale is valued using the last-in, first-out (LIFO) cost method. The excess of replacement cost of merchandise for resale inventories over carrying LIFO value was $18,836 and $19,700 at December 31, 2013 and December 31, 2012, respectively.

Accounts_Receivable_Securitiza

Accounts Receivable Securitization	12 Months Ended
	Dec. 31, 2013
ACCOUNTS RECEIVABLE SECURITIZATION: [Abstract]	'
Accounts Receivable Securitization	'
	ACCOUNTS RECEIVABLE SECURITIZATION:
	CONSOL Energy and certain of our U.S. subsidiaries are party to a trade accounts receivable facility with financial institutions for the sale on a continuous basis of eligible trade accounts receivable. The facility allows CONSOL Energy to receive, on a revolving basis, up to $200,000. The facility also allows for the issuance of letters of credit against the $200,000 capacity. At December 31, 2013, there were letters of credit outstanding against the facility of $66,055. CONSOL Energy management believes that these guarantees will expire without being funded, and therefore the commitments will not have a material adverse effect on the Company's financial condition. No amounts related to these financial guarantees and letters of credit are recorded as liabilities on the financial statements.
	CNX Funding Corporation, a wholly owned, special purpose, bankruptcy-remote subsidiary, buys and sells eligible trade receivables generated by certain subsidiaries of CONSOL Energy. Under the receivables facility, CONSOL Energy and certain subsidiaries, irrevocably and without recourse, sell all of their eligible trade accounts receivable to CNX Funding Corporation, who in turn sells these receivables to financial institutions and their affiliates, while maintaining a subordinated interest in a portion of the pool of trade receivables. This retained interest, which is included in Accounts and Notes Receivable Trade in the Consolidated Balance Sheets, is recorded at fair value. Due to a short average collection cycle for such receivables, our collection experience history and the composition of the designated pool of trade accounts receivable that are part of this program, the fair value of our retained interest approximates the total amount of the designated pool of accounts receivable. CONSOL Energy will continue to service the sold trade receivables for the financial institutions for a fee based upon market rates for similar services.
	In accordance with the Transfers and Servicing Topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification, CONSOL Energy records transactions under the securitization facility as secured borrowings on the Consolidated Balance Sheets.  The pledge of collateral is reported as Accounts Receivable - Securitized and the borrowings are classified as debt in Borrowings under Securitization Facility.
	The cost of funds under this facility is based upon LIBOR and commercial paper rates, plus a charge for administrative services paid to the financial institutions. Costs associated with the receivables facility totaled $1,737, $1,723 and $1,986 for the years ended December 31, 2013, 2012 and 2011, respectively. These costs have been recorded as financing fees which are included in Cost of Goods Sold and Other Operating Charges in the Consolidated Statements of Income. No servicing asset or liability has been recorded. The receivables facility expires in March 2017 with the underlying liquidity agreement renewing annually each March.
	At December 31, 2013 and December 31, 2012, eligible accounts receivable totaled $115,000 and $200,000, respectively. There was $48,945 in subordinated retained interest at December 31, 2013 and there was no subordinated retained interest at December 31, 2012. There were no borrowings under the securitization facility recorded on the Consolidated Balance Sheets at December 31, 2013 and $37,846 borrowings under the securitization facility recorded on the Consolidated Balance Sheets at December 31, 2012.

Property_Plant_and_Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment	'
	PROPERTY, PLANT AND EQUIPMENT:
		December 31,
		2013				2012
	Coal & Other Plant and Equipment	$	3,681,051			$	3,414,940
	Intangible Drilling Cost	1,937,336				1,550,297
	Proven Properties	1,670,404				1,596,838
	Unproven Properties	1,463,406				1,266,017
	Coal Properties and Surface Lands	1,404,056				1,164,107
	Gathering Equipment	1,058,008				1,006,882
	Wells and Related Equipment	688,548				492,364
	Airshafts	397,466				366,054
	Leased Coal Lands	393,372				529,758
	Coal Advance Mining Royalties	381,348				381,343
	Mine Development	354,607				262,511
	Other Gas Assets	126,239				82,217
	Gas Advance Royalties	22,668				8,229
	Total Property, Plant and Equipment	13,578,509				12,121,557
	Less Accumulated Depreciation, Depletion and Amortization	4,136,247				3,613,499
	Total Net Property, Plant and Equipment	$	9,442,262			$	8,508,058
	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, 2013 and 2012, respectively.
			December 31,
			2013				2012
	Unproven gas properties		$	1,487,166			$	1,266,017
	Coal properties		273,242				317,676
	Mine Development		238,356				145,940
	Leased coal lands		99,506				118,697
	Coal advance mining royalties		48,043				55,749
	Airshafts		38,794				21,866
	Gas advance royalties		22,668				8,229
	Total		$	2,207,775			$	1,934,174
	As of December 31, 2013 and 2012, plant and equipment includes gross assets under capital lease of $96,015 and $93,745, respectively. For the years ended December 31, 2013 and 2012, the Gas segment maintains a capital lease for the Jewell Ridge Pipeline of $66,919, which is included in Gas gathering equipment. For the years ended December 31, 2013 and 2012, the Gas segment also maintains a capital lease for vehicles of $10,652 and $9,248, respectively, which are included in Other gas assets. For the years ended December 31, 2013 and 2012, the All Other segment maintains capital leases for vehicles and computer equipment of $18,444 and $17,578, respectively, which are included in Coal and other plant and equipment. Accumulated amortization for capital leases was $50,371 and $44,726 at December 31, 2013 and 2012, respectively. Amortization expense for capital leases is included in Depreciation, Depletion and Amortization in the Consolidated Statements of Income. See Note 15–Leases for further discussion of capital leases.
	Industry Participation Agreements
	CONSOL Energy has two significant industry participation agreements (referred to as "joint ventures" or "JVs") that provided drilling and completion carries for our retained interests.
	On October 21, 2011, CNX Gas Company, a wholly owned subsidiary of CONSOL Energy, completed a sale to Hess Ohio Developments, LLC (Hess) a 50% interest in nearly 200 thousand net Utica Shale acres in Ohio. Cash proceeds related to this transaction were $54,254, which were net of $5,719 in transaction fees. Additionally, CONSOL Energy and Hess entered into a joint development agreement pursuant to which Hess agreed to pay approximately $534,000 in the form of a 50% drilling carry of certain CONSOL Energy working interest obligations as the acreage is developed. The net gain on the transaction was $53,095 and was recognized in the Consolidated Statements of Income as Other Income for the year ended December 31, 2011. CONSOL Energy and Hess have agreed to focus their development efforts on six core counties in southeastern Ohio, in which the joint venture holds approximately 73,000 mostly fee acres. To this end, the parties have agreed to pursue the sale of approximately 63,000 acres outside of the focus areas. In addition, as previously disclosed, based on title work performed by Hess as part of the title defect process, we believe that there are chain of title issues with respect to approximately 39,000 of the joint venture acres representing approximately $153,000 of carry, most of which likely cannot be cured. These acres, together with another 26,000 acres of allegedly defective acres have been reassigned to CONSOL Energy. CONSOL Energy may elect to cure the alleged defects related to these acres and develop them, or sell the acres for its own account. After taking into account the reassignment of approximately 65,000 acres, the parties have agreed that the total carry remaining after these adjustments is $335,000. The loss of these Utica Shale acres will not have a material impact on the Company's financial statements.
	On September 30, 2011, CNX Gas Company completed a sale to Noble Energy, Inc. (Noble) of 50% of the Company's undivided interest in certain Marcellus Shale oil and gas properties in West Virginia and Pennsylvania covering approximately 628 thousand net acres and 50% of the Company's undivided interest in certain of its existing Marcellus Shale wells and related leases. In September 2011, cash proceeds of $485,464 were received related to this transaction, which were net of $34,998 transaction fees. Additionally, a note receivable was recognized related to the two additional cash payments to be received on the first and second anniversary of the transaction closing date. In September 2013, cash proceeds of $327,964 were received related to the second anniversary note receivable. In September 2012, cash proceeds of $327,964 were received related to the first anniversary note receivable. During December 2011, an additional receivable of $16,703 and a payable of $980 were recorded for closing adjustments and were included in Accounts and Notes Receivable - Other and Accounts Payable, respectively. Adjusted cash proceeds of $15,598 related to the additional receivable were received in April 2012. The net loss on the transaction was $64,142 and was recognized in the Consolidated Statements of Income as Other Income for the year ended December 31, 2011. As part of the transaction, CNX Gas Company also received a commitment from Noble to pay one-third of the Company's working interest share of certain drilling and completion costs, up to approximately $2,100,000 with certain restrictions. These restrictions include the suspension of carry if average Henry Hub natural gas prices are below $4.00 per million British thermal units (MMbtu) for three consecutive months. The carry is currently suspended and will remain suspended until average natural gas prices are above $4.00/MMbtu for three consecutive months. Restrictions also include a $400,000 annual maximum on Noble's carried cost obligation.
	The following unaudited pro forma combined financial statements are based on CONSOL Energy's historical consolidated financial statements and adjusted to give effect to the September 30, 2011 sale of a 50% interest in certain Marcellus Shale assets. The unaudited pro forma results for the periods presented below are prepared as if the transaction occurred as of January 1, 2010 and do not include material, non-recurring charges.
			Year Ended
			December 31,
			2011
	Total Revenue and Other Income		$	6,073,904
	Earnings Before Income Taxes		$	775,807
	Net Income Attributable to CONSOL Energy Inc. Shareholders		$	623,114
	Basic Earnings Per Share		$	2.75
	Dilutive Earnings Per Share		$	2.72
	The pro forma results are not necessarily indicative of what actually would have occurred if the transaction had been completed as of January 1, 2010, nor are they necessarily indicative of future consolidated results.
	Under our joint venture agreement with Noble, Noble had the right to perform due diligence on the title to the oil and gas interests which we conveyed to them and to assert that title to the acreage is defective. CONSOL Energy could then review and respond to the asserted title defects, or cure them, and ultimately, if the claim is not resolved, either party could submit the defect to an arbitrator for resolution. We have completed our review of the title defect notice asserted by Noble, and working in collaboration with them, we have addressed defects with respect to approximately 87,851 gross deal acres, having a carry value of approximately $551,000, and successfully resolved such defects to the satisfaction of both parties. We have conceded defects which have an aggregate value of approximately $216,000 in excess of the applicable deductibles and the carry payable by Noble Energy to CONSOL Energy has been reduced by this amount. The impact of these conceded defects was $23,058 and $3,526 of expense for the years ended December 31, 2013 and 2012, respectively, and is included in Cost of Goods Sold and Other Charges in the Consolidated Statements of Income. The parties have resolved substantially all outstanding asserted defects.
	The following table provides information about our industry participation agreements as of December 31, 2013:
			Industry		Industry
			Participation		Participation		Drilling
	Shale		Agreement		Agreement		Carries
	Play		Partner		Date		Remaining
	Marcellus		Noble		30-Sep-11		$	1,873,785
	Utica		Hess		21-Oct-11		$	230,353

ShortTerm_Notes_Payable

Short-Term Notes Payable	12 Months Ended
	Dec. 31, 2013
Short-term Debt [Abstract]	'
Short-Term Notes Payable:	'
	SHORT-TERM NOTES PAYABLE:
	CONSOL Energy's $1,000,000 Senior Secured Credit Agreement, as amended by Amendment No. 1 dated December 5, 2013, expires April 12, 2016. The amendment reduced the availability from $1,500,000 to $1,000,000 resulting in an acceleration of previously deferred financing charges of $3,195 during the year ended December 31, 2013. The facility is secured by substantially all of the assets of CONSOL Energy and certain of its subsidiaries. CONSOL Energy's credit facility allows for up to $1,000,000 of borrowings and letters of credit. CONSOL Energy can request an additional $250,000 increase in the aggregate borrowing limit amount. Fees and interest rate spreads are based on a ratio of financial covenant debt to twelve-month trailing earnings before interest, taxes, depreciation, depletion and amortization (Adjusted EBITDA), measured quarterly. The facility includes a minimum interest coverage ratio covenant of no less than 1.50 to 1.00, measured quarterly through March 30, 2015 and 2.00 to 1.00 thereafter. The interest coverage ratio was 2.21 to 1.00 at December 31, 2013. The facility also includes a senior secured leverage ratio covenant of not more than 2.00 to 1.00, measured quarterly. The senior secured leverage ratio was less than 1.00 to 1.00 at December 31, 2013. Affirmative and negative covenants in the facility limit our 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. At December 31, 2013, the $1,000,000 facility had no borrowings outstanding and $206,988 of letters of credit outstanding, leaving $793,012 of capacity available for borrowings and the issuance of letters of credit. At December 31, 2012, the former $1,500,000 facility had no borrowings outstanding and $100,292 of letters of credit outstanding, leaving $1,399,708 of capacity available for borrowings and the issuance of letters of credit.
	CNX Gas Corporation's (CNX Gas) $1,000,000 Senior Secured Credit Agreement expires April 12, 2016. The facility is secured by substantially all of the assets of CNX Gas and its subsidiaries. CNX Gas' credit facility allows for up to $1,000,000 of borrowings and letters of credit. CNX Gas can request an additional $250,000 increase in the aggregate borrowing limit amount. Fees and interest rate spreads are based on the percentage of facility utilization, measured quarterly. Covenants in the facility limit CNX Gas' ability to dispose of assets, make investments, pay dividends and merge with another corporation. The credit facility allows investments in joint ventures for the development and operation of gas gathering systems and provides for $600,000 of loans, advances and dividends from CNX Gas to CONSOL Energy. Investments in CONE are unrestricted. The facility includes a maximum leverage ratio covenant of not more than 3.50 to 1.00, measured quarterly. The leverage ratio was 0.61 to 1.00 at December 31, 2013. The facility also includes a minimum interest coverage ratio covenant of no less than 3.00 to 1.00, measured quarterly. This ratio was 25.33 to 1.00 at December 31, 2013. At December 31, 2013, the $1,000,000 facility had no borrowings outstanding and $87,643 of letters of credit outstanding, leaving $912,357 of capacity available for borrowings and the issuance of letters of credit. At December 31, 2012, the $1,000,000 facility had no borrowings outstanding and $70,203 of letters of credit outstanding, leaving $929,797 of capacity available for borrowings and the issuance of letters of credit.
	CONSOL Energy entered into an interim funding arrangement for longwall shields. At December 31, 2012, CONSOL Energy had a note payable of $25,073 related to this funding arrangement. The interim funding arrangement bore a weighted average interest rate of 2.46% as of December 31, 2012. There were no interim funding agreements outstanding at December 31, 2013.

Other_Accrued_Liabilities

Other Accrued Liabilities	12 Months Ended
	Dec. 31, 2013
Other Liabilities Disclosure [Abstract]	'
Accounts Payable and Accrued Liabilities Disclosure [Text Block]	'
	NOTE 13—OTHER ACCRUED LIABILITIES:
		December 31,
		2013		2012
	Subsidence liability	$	98,573	$	88,939
	Accrued interest	63,600		63,687
	Accrued payroll and benefits	38,953		39,172
	Short-term incentive compensation	30,371		28,744
	Uncertain income tax positions	28,530		2,100
	Accrued other taxes	26,305		35,943
	Other	122,902		144,352
	Current portion of long-term liabilities:
	Postretirement benefits other than pensions	60,847		58,452
	Mine closing	30,320		25,081
	Gas well closing	23,971		9,729
	Workers' compensation	13,628		9,176
	Reclamation	9,552		20,582
	Pneumoconiosis benefits	9,212		8,838
	Salary retirement	4,593		6,937
	Long-term disability	4,340		4,016
	Total Other Accrued Liabilities	$	565,697	$	545,748

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2013
Long-term Debt, Unclassified [Abstract]	'
Long-term Debt	'
	LONG-TERM DEBT:
		December 31,
		2013		2012
	Debt:
	Senior notes due April 2017 at 8.00%, issued at par value	$	1,500,000	$	1,500,000
	Senior notes due April 2020 at 8.25%, issued at par value	1,250,000		1,250,000
	Senior notes due March 2021 at 6.375%, issued at par value	250,000		250,000
	MEDCO revenue bonds in series due September 2025 at 5.75%	102,865		102,865
	Advance royalty commitments (7.93% and 7.43% weighted average interest rate for December 31, 2013 and 2012, respectively)	11,182		19,103
	Other long-term notes maturing at various dates through 2031 (total value of $5,923 and $7,300 less unamortized discount of $1,050 and $1,542 at December 31, 2013 and December 31,2012, respectively).	4,873		5,758
		3,118,920		3,127,726
	Less amounts due in one year *	2,957		4,126
	Long-Term Debt	$	3,115,963	$	3,123,600
	* Excludes current portion of Capital Lease Obligations of $8,498 and $8,358 at December 31, 2013 and December 31, 2012, respectively.
	Annual undiscounted maturities on long-term debt during the next five years are as follows:
	Year ended December 31,	Amount
	2014	$	3,364
	2015	4,276
	2016	3,457
	2017	1,502,484
	2018	1,403
	Thereafter	1,609,159
	Total Long-Term Debt Maturities	$	3,124,143

Leases

Leases	12 Months Ended
	Dec. 31, 2013
Leases [Abstract]	'
Leases of Lessee Disclosure [Text Block]	'
	NOTE 15—LEASES:
	CONSOL Energy uses various leased facilities and equipment in our 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, 2013, are as follows:
			Capital				Operating
			Leases				Leases
	Year Ended December 31,
	2014		$	12,059			$	90,565
	2015		10,984				85,225
	2016		9,842				73,158
	2017		8,758				66,536
	2018		8,128				41,221
	Thereafter		21,272				81,321
	Total minimum lease payments		$	71,043			$	438,026
	Less amount representing interest (0.63% – 7.36%)		14,949
	Present value of minimum lease payments		56,094
	Less amount due in one year		8,498
	Total Long-Term Capital Lease Obligation		$	47,596
	Rental expense under operating leases was $90,128, $83,064, and $75,696 for the years ended December 31, 2013, 2012 and 2011, respectively.
	At December 31, 2013, certain of the above operating leases for mining equipment were subleased to third parties. The following represents the minimum rental payments for those operating subleases:
	2014					2015				2016			2017			2018			Thereafter			Total
	$	33,084				$	33,084			$	33,084		$	26,685		$	26,685		$	13,343		$	165,965
	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 $53,484, with no accumulated depreciation at December 31, 2013.
	At December 31, 2013, scheduled minimum rental payments for operating leases related to this equipment were as follows:
	2014				2015				2016			2017			2018			Thereafter			Total
	$	8,561			$	8,561			$	7,637		$	4,496		$	2,992		$	2,328		$	34,575

Pension_and_OPEB

Pension and OPEB	12 Months Ended
	Dec. 31, 2013
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]	'
Components of Pension and Other Postretirement Benefit Plans:	'
	NOTE 16—PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS:
	CONSOL Energy has non-contributory defined benefit retirement plans covering substantially all salaried employees. The benefits for these plans are based primarily on years of service and employees' pay near retirement. CONSOL Energy's salaried plan allows for lump-sum distributions of benefits earned up until December 31, 2005, at the employees' election. The Restoration Plan was frozen effective December 31, 2006 and was replaced prospectively with the CONSOL Energy Supplemental Retirement Plan. CONSOL Energy's Restoration Plan allows only for lump-sum distributions earned up until December 31, 2006. Effective September 8, 2009, the Supplemental Retirement Plan was amended to include employees of CNX Gas. The Supplemental Retirement Plan was frozen effective December 31, 2011 for certain employees and was replaced prospectively with the CONSOL Energy Defined Contribution Restoration Plan.
	Certain subsidiaries of CONSOL Energy provide medical and life insurance benefits to retired employees not covered by the Coal Industry Retiree Health Benefit Act of 1992. The medical plans contain certain cost sharing and containment features, such as deductibles, coinsurance, health care networks and coordination with Medicare. For salaried or non-represented hourly employees hired before January 1, 2007, the eligibility requirement is either age 55 with 20 years of service or age 62 with 15 years of service. Also, salaried employees and retirees contribute a target of 20% of the medical plan operating costs. Contributions may be higher, dependent on either years of service or a combination of age and years of service at retirement. Prospective annual cost increases of up to 6% will be shared by CONSOL Energy and the participants based on their age and years of service at retirement. Annual cost increases in excess of 6% will be the responsibility of the participants. In 2012, the salaried OPEB plan was amended to reduce medical and prescription drug benefits as of January 1, 2014. The plan amendment calls for a fixed annual retiree medical contribution into a Health Reimbursement Account for eligible employees. The amount of the contribution will be dependent on several factors, and the money in the account can be used to help pay for a commercial medical plan, Medicare Part B or Part D premiums, and other qualified medical expenses. Employees who work or worked in corporate or operational support positions at retirement and who are age 50 or older at December 31, 2013 will receive the revised benefit in lieu of the current retiree medical and prescription drug benefits described above upon meeting the eligibility requirements at retirement. Employees who work or worked in corporate or operational support positions who are under age 50 at December 31, 2013 will receive no retiree medical or prescription drug benefits. In addition, any salaried or non-represented hourly employees that were hired or rehired effective January 1, 2007 or later and do not work in a corporate or operational support position are not eligible for retiree health benefits. In lieu of traditional retiree health coverage, if certain eligibility requirements are met, these employees will receive a retiree medical spending allowance of $2,250 per year for each year of service at retirement.
	On March 31, 2012, the salaried OPEB plan was remeasured to reflect the announced plan amendment, which is described above. The remeasurement reflected the reduction in benefits and the change in discount rate to 4.57% at March 31, 2012 from 4.51% at December 31, 2011. The remeasurement resulted in an $80,571 reduction in the OPEB liability with a corresponding adjustment of $50,276 in other comprehensive income, net of $30,295 in deferred taxes. The change resulted in a $9,425 reduction in OPEB expense compared to what was originally expected to be recognized for the year ended December 31, 2012.
	The OPEB liability includes $3,000 and $12,400 as of December 31, 2013 and 2012, respectively, due to the PPACA reform legislation; in particular, the estimated impact of the potential excise tax beginning in 2018. The estimated liability for the excise tax was calculated using the following assumptions: testing pre-Medicare and Medicare covered retirees on a combined basis; assuming individual participants have an average claim cost and future healthcare trend assumptions equal to those used in the year-end valuation; assuming the 2018 tax threshold amount to increase for inflation in later years. These assumptions may change once additional guidance becomes available. The 2013 and 2012 OPEB liability also includes the estimated impact of PPACA legislation regarding the fees to support the Transitional Reinsurance Program. Due to the fact that the state-based exchanges are expected to incur losses during their first few years of existence, the legislation provides for a temporary fee on health insurance issuers and self-insured group health plans that will be used to support these exchanges. The fee is payable for plan years 2014 through 2016. The fee for 2014 is $63 per covered pre-Medicare person, and is estimated to drop to $42 and $26 per covered pre-65 person in 2015 and 2016, respectively.
	According to the Defined Benefit Plans Topic of the Financial Accounting Standards Board (FASB) Accounting Standards Codification, if the lump sum distributions made for the 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 year ended December 31, 2013. Accordingly, CONSOL Energy recognized expense of $39,482 for the year ended December 31, 2013 in Costs of Goods Sold and Other Operating Charges in the Consolidated Statement of Income. The settlement charges represented a pro rata portion of the net unrecognized loss based on the percentage reduction in the projected benefit obligation due to the lump sum payments. The settlement charges noted above also resulted in remeasurements of the pension plan throughout 2013.
	On December 5, 2013, CONSOL Energy completed the sale of its Consolidation Coal Company and certain other subsidiaries to Murray Energy Corporation. As a result of the sale, the obligations for certain participants of the OPEB Plan are the primary responsibility of Murray Energy. This reduced CONSOL Energy's OPEB liability by $1,891,057 at December 31, 2013. These plan settlements resulted in adjustments of $339,318 in Other Comprehensive Income, net of $203,610 in deferred taxes at December 31, 2013. As the result of corporate staffing reductions associated with the sale, the Pension and OPEB plans also recognized curtailment gains of $374 and $39,650 for the year ended December 31, 2013. The curtailment gains resulted in adjustments of $231 and $24,515 in Other Comprehensive Income, net of $143 and $15,135 in deferred taxes for the Pension Plan and the OPEB plan, respectively, at December 31, 2013.
	The reconciliation of changes in the benefit obligation, plan assets and funded status of these plans at December 31, 2013 and 2012, is as follows:
			Pension Benefits								Other Postretirement Benefits
			at December 31,								at December 31,
			2013				2012				2013				2012
	Change in benefit obligation:
	Benefit obligation at beginning of period		$	953,102			$	857,352			$	3,018,172			$	3,242,200
	Service cost		20,865				20,466				18,680				18,817
	Interest cost		36,829				37,586				111,687				135,695
	Actuarial loss (gain)		(82,718		)		90,502				(73,632		)		(131,150		)
	Plan amendments		—				—				—				(80,570		)
	Plan curtailments		(6,551		)		—				—				—
	Plan settlements		(86,925		)		—				(1,891,057		)		—
	Participant contributions		—				—				6,150				5,651
	Benefits and other payments		(21,958		)		(52,804		)		(168,026		)		(172,471		)
	Benefit obligation at end of period		$	812,644			$	953,102			$	1,021,974			$	3,018,172
	Change in plan assets:
	Fair value of plan assets at beginning of period		$	728,161			$	582,571			$	—			$	—
	Actual return on plan assets		94,084				87,935				—				—
	Company contributions		55,469				110,459				161,876				166,820
	Participant contributions		—				—				6,150				5,651
	Benefits and other payments		(21,958		)		(52,804		)		(168,026		)		(172,471		)
	Plan Settlements		(86,925		)		—				—				—
	Fair value of plan assets at end of period		$	768,831			$	728,161			$	—			$	—
	Funded status:
	Noncurrent assets		$	9,032			$	—			$	—			$	—
	Current liabilities		(4,593		)		(6,937		)		(60,847		)		(58,452		)
	Noncurrent liabilities		(48,252		)		(218,004		)		(961,127		)		(882,600		)
	Liabilities of discontinued operations		—				—				—				(2,077,120		)
	Net obligation recognized		$	(43,813	)		$	(224,941	)		$	(1,021,974	)		$	(3,018,172	)
	Amounts recognized in accumulated other comprehensive income consist of:
	Net actuarial loss		$	286,637			$	495,511			$	433,073			$	1,116,051
	Prior service credit		(4,629		)		(6,614		)		(34,086		)		(104,288		)
	Net amount recognized (before tax effect)		$	282,008			$	488,897			$	398,987			$	1,011,763
	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,
		2013				2012				2011				2013				2012			2011
	Components of net periodic benefit cost:
	Service cost	$	20,865			$	20,466			$	17,457			$	18,680			$	18,817		$	13,677
	Interest cost	36,829				37,586				37,744				111,687				135,695			179,739
	Expected return on plan assets	(51,814		)		(46,157		)		(38,522		)		—				—			—
	Amortization of prior service (credits)	(1,611		)		(1,630		)		(666		)		(30,552		)		(51,828		)	(46,397		)
	Recognized net actuarial loss	37,853				47,834				38,102				66,417				80,875			105,364
	Curtailment gain	(374		)		—				—				(39,650		)		—			—
	Settlement loss (gain)	39,482				—				—				(1,348,129		)		—			—
	Net periodic benefit cost (credit)	$	81,230			$	58,099			$	54,115			$	(1,221,547	)		$	183,559		$	252,383
	Expenses (income) attributable to discontinued operations included in the net periodic cost (credit) above (including settlements and curtailments associated with the sale of CCC and certain subsidiaries to Murray Energy) were $8,231, $11,587, and $10,693 for the years ended December 31, 2013, 2012, and 2011, respectively, for the Pension Plans and were $(1,293,975), $101,418, and $140,524 for the years ended December 31, 2013, 2012, and 2011, respectively, for the Other Postretirement Benefits Plan.
	Amounts included in accumulated other comprehensive loss, expected to be recognized in 2014 net periodic benefit costs:
							Other
			Pension				Postretirement
			Benefits				Benefits
	Prior Service (credit) recognition		$	(1,384	)		$	(8,784	)
	Actuarial loss recognition		$	23,564			$	25,474
	The following table provides information related to pension plans with an accumulated benefit obligation in excess of plan assets:
			As of December 31,
			2013				2012
Projected benefit obligation		$	52,845			$	953,102
Accumulated benefit obligation		$	50,820			$	895,493
Fair value of plan assets		$	—			$	728,161
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,
		2013			2012			2013			2012
Discount rate		4.87	%		4	%		4.88	%		4.05	%
Rate of compensation increase		4.23	%		3.77	%		—			—
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,
		2013			2012			2011			2013			2012			2011
Discount rate		4	%		4.5	%		5.3	%		4.05	%		4.51	%		5.33	%
Expected long-term return on plan assets		7.75	%		8	%		8	%		—			—			—
Rate of compensation increase		3.77	%		3.82	%		3.66	%		—			—			—
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 20-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,
		2013			2012			2011
Health care cost trend rate for next year		6.17	%		6.3	%		6.85	%
Rate to which the cost trend is assumed to decline (ultimate trend rate)		4.5	%		4.5	%		4.5	%
Year that the rate reaches ultimate trend rate		2026			2026			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		$	17,296			$	(14,297	)
Effect on accumulated postretirement benefit obligation		$	123,355			$	(103,788	)
Assumed discount rates also have a significant effect on the amounts reported for both pension and other benefit costs. A one-quarter percentage point change in assumed discount rate would have the following effect on benefit costs:
		0.25 Percentage				0.25 Percentage
		Point Increase				Point Decrease
Pension benefit costs (decrease) increase		$	(1,797	)		$	1,798
Other postemployment benefits costs (decrease) increase		$	(3,690	)		$	3,830
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. The target allocations for plan assets are 31 percent U.S. equity securities, 20 percent non-U.S. equity securities, 9 percent global equity securities, and 40 percent 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 comingled 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.
The fair values of plan assets at December 31, 2013 and 2012 by asset category are as follows:
		Fair Value Measurements at December 31, 2013																Fair Value Measurements at December 31, 2012
						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		$	634			$	634			$	—			$	—			$	610		$	610	$	—	$	—
US Equities (a)		14				14				—				—				11			11		—		—
Mercer Collective Trusts
US Large Cap Growth Equity (b)		56,006				—				56,006				—				63,726			—		63,726		—
US Large Cap Value Equity (c)		56,802				—				56,802				—				64,381			—		64,381		—
US Small/Mid Cap Growth Equity (d)		28,530				—				28,530				—				26,406			—		26,406		—
US Small/Mid Cap Value Equity (e)		28,552				—				28,552				—				26,411			—		26,411		—
US Core Fixed Income (f)		35,533				—				35,533				—				38,045			—		38,045		—
Non-US Core Equity (g)		126,712				—				126,712				—				146,009			—		146,009		—
Emerging Markets Equity (h)		29,778				—				29,778				—				33,541			—		33,541		—
Global Low Volatility Equity (i)		70,138				—				70,138				—				—			—		—		—
US Long Duration Investment Grade Fixed Income (j)		55,593				—				55,593				—				39,925			—		39,925		—
US Long Duration Fixed Income (k)		33,489				—				33,489				—				30,675			—		30,675		—
US Large Cap Passive Equity (l)		75,468				—				75,468				—				81,067			—		81,067		—
US Passive Fixed Income (m)		20,287				—				20,287				—				20,415			—		20,415		—
US Long Duration Passive Fixed Income (n)		34,108				—				34,108				—				29,483			—		29,483		—
US Ultra Long Duration Fixed Income (o)		7,656				—				7,656				—				34,595			—		34,595		—
US Active Long Corporate Investment (p)		105,412				—				105,412				—				92,861			—		92,861		—
Long Strips Fixed Income (q)		2,022				—				2,022				—				—			—		—		—
Opportunistic Fixed Income (r)		2,097				—				2,097				—				—			—		—		—
Total		$	768,831			$	648			$	768,183			$	—			$	728,161		$	621	$	727,540	$	—
__________
(a)	This category includes investments in US common stocks and corporate debt.
(b)	This category invests primarily in common stock of large cap companies in the U.S. with above average earnings growth and revenue expectations. It targets broad diversification across economic sectors and seeks to achieve lower overall portfolio volatility by investing in complementary active managers with varying risk characteristics. Fund selection and allocations within the portfolio are implemented by Mercer’s investment management team. The strategy is benchmarked to the Russell 1000 Growth Index.
(c)	This category invests primarily in U.S. large cap companies that appear to be undervalued relative to their intrinsic value. It targets broad diversification across economic sectors and seeks to achieve lower overall portfolio volatility by investing in complementary active managers with varying risk characteristics. Fund selection and allocations within the portfolio are implemented by Mercer’s investment management team. The strategy is benchmarked to the Russell 1000 Value Index.
(d)	This category invests in small to mid-sized U.S. companies with above average earnings growth and revenue expectations. It targets broad diversification across economic sectors and seeks to achieve lower overall portfolio volatility by investing in complementary active managers with varying risk characteristics. Fund selection and allocations within the portfolio are implemented by Mercer’s investment management team. The smaller cap orientation of the strategy requires the investment team to be cognizant of liquidity and capital constraints, which are monitored on an ongoing basis. The strategy is benchmarked to the Russell 2500 Growth Index.
(e)	This category invests in small to mid-sized U.S. companies that appear to be undervalued relative to their intrinsic value. It targets broad diversification across economic sectors and seeks to achieve lower overall portfolio volatility by investing in complementary active managers with varying risk characteristics. Fund selection and allocations within the portfolio are implemented by Mercer’s investment management team. The smaller cap orientation of the strategy requires the investment team to be cognizant of liquidity and capital constraints, which are monitored on an ongoing basis. The strategy is benchmarked to the Russell 2500 Value Index.
(f)	This category invests primarily in U.S. dollar-denominated investment grade and government securities. It may also invest opportunistically in out-of-benchmark positions including U.S. high yield, non-U.S. bonds, and Treasury Inflation-Protected Securities (TIPs). The strategy seeks to achieve lower overall portfolio volatility by investing in complementary active managers with varying risk characteristics, and total portfolio duration is targeted to be within 20% of the benchmark’s duration. Total exposure to high yield issues is typically less than 10%, inclusive of direct investment in high yield and exposure through other core fixed income funds. Fund selection and allocations within the portfolio are implemented by Mercer’s investment management team. The strategy is benchmarked to the Barclays Capital Aggregate Index.
(g)	This category invests in all cap companies primarily operating in developed non-US markets, with some exposure to emerging markets. The strategy targets broad diversification across economic sectors and seeks to achieve lower overall portfolio volatility by investing in complementary active managers with varying risk characteristics. Total exposure to emerging markets is typically 10-15%, inclusive of direct investment in emerging markets and exposure through other non-U.S. equity funds. Fund selection and allocations within the portfolio are implemented by Mercer’s investment management team. The strategy is benchmarked to the MSCI EAFE Index.
(h)	This category invests in companies operating in non-US emerging markets. The strategy targets broad diversification across economic sectors and seeks to achieve lower overall portfolio volatility by investing in complementary active managers with varying risk characteristics. Fund selection and allocations within the portfolio are implemented by Mercer’s investment management team. The strategy is benchmarked to the MSCI Emerging Markets Index.
(i)	This category invests in companies operating in developed markets, globally. The strategy targets a diversified portfolio of equity securities issued by companies which the investment managers believe will exhibit less volatility in their price performance relative to the broad equity market as described by the MSCI World Index. The strategy is benchmarked to the MSCI World Index.
(j)	This category invests in a passively managed U.S. long duration corporate investment grade portfolio at a 90% weight and a passively managed U.S. Long Treasury portfolio at a 10% weight. It seeks to provide broad exposure to U.S. long duration investment grade credit while allowing for short term liquidity through a strategic allocation to US Treasuries. The strategy is benchmarked 90% to the Barclays Capital U.S. Long Credit Index and 10% to the Barclays Capital Long Treasury.
(k)	This category invests primarily in U.S. dollar denominated investment grade bonds and government securities with durations between 9 and 11 years. It may also invest opportunistically in out-of-benchmark positions including U.S. high yield, non-U.S. bonds, municipal bonds, and TIPs. The strategy seeks to achieve lower overall portfolio volatility by investing in complementary active managers with varying risk characteristics. Fund selection and allocations within the portfolio are implemented by Mercer’s investment management team. The strategy is benchmarked to the Barclays Capital U.S. Long Government/Credit Index.
(l)	This category invests in common stock of U.S. large cap companies. The strategy is benchmarked to the S&P 500 Index.
(m)	This category invests primarily in U.S. dollar-denominated investment grade bonds and government securities. The strategy and its underlying passive investments are benchmarked to the Barclays Capital Aggregate Index.
(n)	This category invests primarily in U.S. dollar-denominated investment grade bonds and government securities with durations between 9 and 11 years. The strategy and its underlying passive investments are benchmarked to the Barclays Capital Long Government/Credit Index.
(o)	This category seeks to reduce the volatility of the plan’s funded status and extend the duration of the assets by investing in a series of ultra long duration portfolios with target durations of up to 35 years. Each underlying portfolio is managed by a sub-advisor and consists of five interest rate swaps with sequential target or maturity dates, with the longest dated portfolio maturing in 2045. The interest rate swaps are fully collateralized, resulting in no leverage. The cash collateral is invested by the sub-advisor in an actively managed cash strategy that seeks to provide a return in excess of 3 month LIBOR. The ultra long duration strategy is used in conjunction with liability driven investing solutions, which seek to align the duration of the assets to the plan’s liabilities. The Strategy is benchmarked to a Custom Liability Benchmark Portfolio.
(p)	This category invests in a U.S. long duration corporate investment grade portfolio at a 90% weight and a U.S. long treasury portfolio at a 10% weight. It seeks to provide broad exposure to U.S. long duration investment grade corporate bonds with an emphasis on reducing default risk through active management while allowing for short term liquidity through a strategic allocation to U.S. Treasuries. The strategy is benchmarked 90% to the Barclays Capital U.S. Long Corporate Index and 10% to the Barclay’s Capital Long Treasury.
(q)	This category invests primarily in long dated US Treasury STRIPS often with maturities greater than 20 years. The strategy and its underlying passive investments are benchmarked to the Barclays Capital U.S. 20+ Year STRIPS Index.
(r)	This category invests primarily in fixed income securities from issuers either located in developing/emerging markets or those rated below investment grade (high yield), globally, The strategy is benchmarked to a blended index of 50% JP Morgan Government Bond Index Emerging Markets Global Diversified and 50% Bank of America/Merrill Lynch Global High Yield Index.
There are no investments in CONSOL Energy stock held by these plans at December 31, 2013 or 2012.
There are no assets in the other postretirement benefit plans at December 31, 2013 or 2012.
Cash Flows:
CONSOL Energy expects to contribute to the pension trust using prudent funding methods. Currently, depending on asset values and asset returns held in the trust, we expect to contribute $25,000 - $35,000 to our pension plan trust in 2014. Pension benefit payments are primarily funded from the trust. CONSOL Energy does not expect to contribute to the other postemployment plan in 2014. We intend 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
2014			$	90,347			$	60,847
2015			$	50,080			$	62,914
2016			$	48,952			$	65,493
2017			$	49,415			$	67,623
2018			$	50,741			$	68,395
Year 2019-2023			$	262,986			$	338,544

CWP_and_Workers_Comp

CWP and Workers Comp	12 Months Ended
	Dec. 31, 2013
Postemployment Benefits [Abstract]	'
Coal Workers' Pneumoconiosis (CWP) and Workers' Compensation:	'
	COAL WORKERS’ PNEUMOCONIOSIS (CWP) AND WORKERS’ COMPENSATION:
	CONSOL Energy is responsible under the Federal Coal Mine Health and Safety Act of 1969, as amended, 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. The calculation is based on assumptions regarding disability incidence, medical costs, indemnity levels, mortality, death benefits, dependents and interest rates. These assumptions are derived from actual company experience and outside sources. Actuarial gains associated with CWP have resulted from numerous legislative changes over many years which have resulted in lower approval rates for filed claims than our assumptions originally reflected. Actuarial gains have also resulted from lower incident rates and lower severity of claims filed than our assumptions originally reflected.
	CONSOL Energy is also responsible to 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 with each state having 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. The assumptions include discount rate, future healthcare trend rate, benefit duration and recurrence of injuries. Actuarial gains associated with workers' compensation have resulted from discount rate changes, several years of favorable claims experience, various favorable state legislation changes and overall lower incident rates than our assumptions.
	On December 5, 2013, CONSOL Energy completed the sale of its Consolidation Coal Company and certain other subsidiaries to Murray Energy Corporation. As a result of the sale, the obligations for certain participants of the CWP and Workers' Compensation plans now belong to Murray Energy. This reduced CONSOL Energy's CWP and Workers' Compensation liabilities by $49,652 and $105,308 respectively at December 31, 2013. These plan settlements resulted in adjustments of $43,892 and $13,768 in Other Comprehensive Income, net of $26,337 and $8,262 in deferred taxes for CWP and Workers' Compensation, respectively, at December 31, 2013. The settlements were included in the results of discontinued operations.
			CWP								Workers' Compensation
			at December 31,								at December 31,
			2013				2012				2013				2012
	Change in benefit obligation:
	Benefit obligation at beginning of period		$	184,079			$	183,580			$	179,589			$	174,069
	State administrative fees and insurance bond premiums		—				—				5,324				6,727
	Service, legal and administrative cost		8,168				7,711				15,943				17,126
	Interest cost		7,031				7,964				6,401				7,113
	Actuarial (gain) loss		(18,020		)		(3,919		)		11,806				6,754
	Benefits paid		(10,423		)		(11,257		)		(28,659		)		(32,200		)
	Settlements		(49,652		)		—				(105,308		)		—
	Benefit obligation at end of period		$	121,183			$	184,079			$	85,096			$	179,589
	Current liabilities		$	(9,212	)		$	(8,838	)		$	(13,628	)		$	(9,176	)
	Noncurrent liabilities		(111,971		)		(114,136		)		(71,468		)		(60,396		)
	Liabilities of discontinued operations		—				(61,105		)		—				(110,017		)
	Net obligation recognized		$	(121,183	)		$	(184,079	)		$	(85,096	)		$	(179,589	)
	Amounts recognized in accumulated other comprehensive income consist of:
	Net actuarial gain		$	(80,363	)		$	(148,955	)		$	(13,569	)		$	(44,535	)
	Net amount recognized (before tax effect)		$	(80,363	)		$	(148,955	)		$	(13,569	)		$	(44,535	)
	The components of the net periodic cost (credit) are as follows:
		CWP												Workers’ Compensation
		For the Years Ended												For the Years Ended
		December 31,												December 31,
		2013				2012				2011				2013				2012			2011
	Service cost	$	8,168			$	7,711			$	7,620			$	15,943			$	17,126		$	20,015
	Interest cost	7,031				7,964				9,330				6,401				7,113			8,238
	Amortization of prior service cost	—				(395		)		(728		)		—				—			—
	Recognized net actuarial gain	(16,384		)		(19,338		)		(21,182		)		(2,630		)		(3,944		)	(3,907		)
	State administrative fees and insurance bond premiums	—				—				—				5,324				6,727			7,035
	Settlement gain	(119,881		)		—				—				(121,838		)		—			—
	Net periodic cost (credit)	$	(121,066	)		$	(4,058	)		$	(4,960	)		$	(96,800	)		$	27,022		$	31,381
	(Income) expenses attributable to discontinued operations included in the net periodic cost (credit) (including settlements and curtailments associated with the sale of CCC and certain subsidiaries to Murray Energy) above were $(120,496), $(2,374), and $(2,887) for the years ended December 31, 2013, 2012, and 2011, respectively, for CWP and $(113,097), $10,132, and $12,722 for the years ended December 31, 2013, 2012, and 2011, respectively, for Workers' Compensation.
	Amounts included in accumulated other comprehensive income, expected to be recognized in 2014 net periodic benefit costs:
							Workers'
			CWP				Compensation
			Benefits				Benefits
	Prior Service benefit recognition		$	—			$	—
	Actuarial gain recognition		$	(6,196	)		$	(382	)
	Assumptions:
	The weighted-average discount rates used to determine benefit obligations and net periodic (benefit) cost are as follows:
			CWP									Workers' Compensation
			For the Years Ended									For the Years Ended
			December 31,									December 31,
			2013			2012			2011			2013			2012			2011
	Benefit obligations		4.75	%		4.03	%		4.46	%		4.57	%		3.95	%		4.4	%
	Net periodic (benefit) cost		4.03	%		4.46	%		5.21	%		3.95	%		4.4	%		5.13	%
	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'.
	Assumed discount rates have a significant effect on the amounts reported for both CWP benefits and Workers' Compensation costs. A one-quarter percentage point change in assumed discount rate would have the following effect on benefit costs:
			0.25 Percentage				0.25 Percentage
			Point Increase				Point Decrease
	CWP benefit increase (decrease)		$	585			$	(530	)
	Workers' Compensation costs (decrease) increase		$	(379	)		$	398
	Cash Flows:
	CONSOL Energy does not intend to make contributions to the CWP or Workers' Compensation plans in 2014. We intend 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
	2014			$	9,211			$	18,635			$	13,628			$	5,007
2015			$	9,204			$	18,479			$	13,347			$	5,132
2016			$	9,185			$	18,602			$	13,341			$	5,261
2017			$	9,163			$	18,815			$	13,423			$	5,392
2018			$	9,156			$	19,000			$	13,473			$	5,527
Year 2019-2023			$	45,090			$	99,249			$	69,471			$	29,778

Other_Employee_Benefits

Other Employee Benefits	12 Months Ended
	Dec. 31, 2013
OTHER EMPLOYEE BENEFIT PLANS: [Abstract]	'
Compensation and Employee Benefit Plans [Text Block]	'
	NOTE 18—OTHER EMPLOYEE BENEFIT PLANS:
	UMWA Benefit Trusts:
	The Coal Industry Retiree Health Benefit Act of 1992 (the 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 1992 Benefit Plan. In connection with the sale of Consolidation Coal Company and certain subsidiaries, CONSOL Energy retained responsibility for the contributions to these two funds. 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 who actually retired between July 20, 1992 and September 30, 1994. The 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 Act. The 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. Total contributions under the Act were $11,435, $12,358, and $13,609 for the years ended December 31, 2013, 2012 and 2011, respectively. Based on available information at December 31, 2013, CONSOL Energy's obligation for the Act is estimated to be approximately $120,394.
	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 2006 Act and the 1992 Benefit Plan, the outstanding letters of credit to secure our obligation were $60,741, $63,614, and $67,349 for years ended December 31, 2013, 2012 and 2011, respectively. The 2013, 2012 and 2011 security amounts were based on the annual cost of providing health care benefits and included a reduction in the number of eligible employees.
	Equity Incentive Plans:
	CONSOL Energy has an equity incentive plan that provides grants of stock-based awards to key employees and to non-employee directors. See Note 19–Stock Based Compensation for further discussion of CONSOL Energy's equity incentive plans.
	Investment Plan:
	CONSOL Energy has an investment plan available to all domestic, non-represented employees. Effective January 1, 2006, the company matching contribution was 6% of eligible compensation contributed for all non-represented employees except for those employees of Fairmont Supply Company, whose contribution remains a match of 50% of the first 12% of eligible compensation contributed by the employee. Total payments and costs were $23,748, $24,127, and $23,394 for the years ended December 31, 2013, 2012 and 2011, 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,
		2013			2012			2011
	Benefit (Credit) Cost	$	(687	)	$	6,122		$	6,439
	Discount rate assumption used to determine net periodic benefit costs	3.04		%	3.62		%	4.04		%
	Expenses attributable to discontinued operations included in the net periodic cost (credit) above were $2,073, $1,816, and $2,048 for the years ended December 31, 2013, 2012, and 2011.
	Long-Term Disability related liabilities are included in Deferred Credits and Other Liabilities–Other and Other Accrued Liabilities and amounted to $20,425 and $24,144 at December 31, 2013 and 2012, respectively. On December 5, 2013, CONSOL Energy completed the sale of its Consolidation Coal Company and certain other subsidiaries to Murray Energy Corporation. As a result of the sale, the obligations for certain participants of the Long-Term Disability plan now belong to Murray Energy. This reduced CONSOL Energy's Long-Term Disability liability by $10,140 at December 31, 2013. These plan settlements resulted in adjustments of $1,338 in Other Comprehensive Income, net of $803 in deferred taxes at December 31, 2013.
	2012 Voluntary Severance Incentive Program (VSIP):
	CONSOL Energy offered a VSIP to active salaried corporate and operation support employees with 30 years of service, or more. Under this program, eligible employees who accepted the offer received a severance payment equal to one year's salary and any 2013 accrued vacation earned as of December 31, 2012. Approximately 100 employees volunteered for the program. Severance and vacation pay costs of $13,304 were accrued for the program at December 31, 2012, and were paid in 2013.

Stock_Based_Compensation

Stock Based Compensation	12 Months Ended
	Dec. 31, 2013
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 on April 7, 1999. The plan provides for grants of stock-based awards to key employees and to non-employee directors. Amendments to the plan have been approved by the Board of Directors since the commencement of the plan. In 2012, the Board of Directors approved an increase in the total number of shares by 8,000,000 bringing the total number of shares of common stock that can be covered by grants to 31,800,000. At December 31, 2013, 6,072,413 shares are available for all awards. The Plan provides that the aggregate number of shares available for issuance under the Plan will be reduced by one share for each share issued in settlement of stock options. The Plan, as amended on May 1, 2012, provides the aggregate number of shares available for issuance under the Plan will be reduced by 1.62 for each share issued in settlement of Performance Share Units (PSUs), Restricted Stock Units (RSUs), or CONSOL Stock Units (CSUs). No award of stock options may be exercised under the plan after the tenth anniversary of the effective date of the award.
	CONSOL Energy recognizes stock-based compensation costs for only those shares expected to vest on a straight-line basis over the requisite service period of the award, which is generally the option vesting term, or to an employee's eligible retirement date, if earlier and applicable. The total stock-based compensation expense recognized was $56,987, $41,127 and $42,131 for the years ended December 31, 2013, 2012 and 2011, respectively. The related deferred tax benefit totaled $21,769, $15,464 and $15,841, for the years ended December 31, 2013, 2012 and 2011, respectively.
	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. CONSOL Energy uses the Black-Scholes option pricing model to value the options for each of the employee populations. The table below presents the weighted average expected term in years of the two employee populations. The expected term computation is based upon historical exercise patterns and post-vesting termination behavior of the 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. There were no options granted in 2013. Total fair value of options granted during the years ended December 31, 2012 and 2011 were $8,515 and $9,913, respectively. The fair value of share-based payment awards was estimated using the Black-Scholes option pricing model with the following assumptions and weighted average fair values:
		December 31,
		2012				2011
	Weighted average fair value of grants	$	14.58			$	20.47
	Risk-free interest rate	0.73		%		1.61		%
	Expected dividend yield	1.18		%		0.82		%
	Expected forfeiture rate	2		%		2		%
	Expected volatility	54.8		%		55.1		%
	Expected term in years	4.4				4.26
	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, 2012	5,111,214			$	36.54
	Granted	—			$	—
	Exercised	(310,376	)		$	11.99
	Forfeited	(23,612	)		$	38.64
	Balance at December 31, 2013	4,777,226			$	38.12			4.2	$	28,398
	Vested and expected to vest	4,765,963			$	38.13			4.19	$	28,398
	Exercisable at December 31, 2013	4,344,749			$	38.45			3.76	$	28,839
	These stock options will expire ten years after the date on which they were granted. The employee stock options, covered by the Equity Incentive Plan adopted April 7, 1999, vest 25% per year, beginning one year after the grant date for awards granted prior to 2007. Employee stock options awarded after December 31, 2006, vest 33% per year, beginning one year after the grant date. There are 4,529,216 stock options outstanding under the Equity Incentive Plan. Additionally, there are 192,934 fully vested employee stock options outstanding which vested under terms ranging from six months to one year. Non-employee director stock options vest 33% per year, beginning one year after the grant date. There are 53,895 stock options outstanding under these grants. The vesting of all options, including performance options, will accelerate in the event of death, disability or retirement and may accelerate upon a change in control of CONSOL Energy.
	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, 2013, 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, 2013. This amount varies based on the fair market value of CONSOL Energy's stock. Total intrinsic value of options exercised for the year ended December 31, 2013, 2012 and 2011 was $6,820, $18,562 and $18,049, respectively.
	Cash received from option exercises for the years ended December 31, 2013, 2012 and 2011 was $3,720, $8,383 and $9,033, respectively. The tax impact from option exercises totaled $2,929, $8,678, and $8,281, for the years ended December 31, 2013, 2012 and 2011, respectively. This excess tax benefit is included in cash flows from financing activities in the Consolidated Statements of Cash Flows.
	Under the Equity Incentive Plan, CONSOL Energy granted certain employees and non-employee directors restricted stock unit awards. These awards entitle the holder to receive shares of common stock as the award vests. Compensation expense is recognized over the vesting period of the units. The total fair value of the restricted stock units granted during the years ended December 31, 2013, 2012 and 2011 was $20,687, $26,426 and $24,882, respectively. The total fair value of shares vested during the years ended December 31, 2013, 2012 and 2011 was $37,002, $23,097 and $16,496, respectively. The following represents the unvested 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, 2012	1,326,953			$40.39
	Granted	654,656			$31.60
	Vested	(930,390	)		$39.77
	Forfeited	(169,649	)		$32.93
	Nonvested at December 31, 2013	881,570			$35.95
	Under the Equity Incentive Plan, CONSOL Energy granted certain employees performance share unit awards. These awards entitle the holder to receive 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. At December 31, 2013, achievement of the market and performance goals is believed to be probable. The total fair value of performance share units granted during the years ended December 31, 2013, 2012 and 2011 was $1,270, $16,794 and $11,648, respectively. The following represents the unvested performance share unit awards 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, 2012	702,194			$50.76
	Granted	40,514			$31.35
	Vested	(159,228	)		$68.45
	Nonvested at December 31, 2013	583,480			$38.19
	Under the Equity Incentive Plan, CONSOL Energy granted certain employees performance stock options. These awards entitle the holder to receive shares of common stock subject to the achievement of certain performance goals. Compensation expense is recognized over the vesting period of the units. The annual performance goals for the performance stock options include a gas cost goal and a gas production goal. Achievement of the gas production goal for the year ended December 31, 2012 did not occur. A reversal of compensation expense of $1,671 was recognized in Cost of Goods Sold and Other Operating Charges for the year ended December 31, 2012. The achievement of all goals is believed to be probable at December 31, 2013. The total fair value of performance share options vested during the year ended December 31, 2013, 2012, 2011 was $1,650, $6,599, $3,299. The following represents the unvested performance options 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, 2012	401,392			$16.44
	Vested	(100,349	)		$16.44
	Nonvested at December 31, 2013	301,063			$16.44
	Under the Equity Incentive Plan, CONSOL Energy granted certain employees CONSOL Stock Unit Awards. These awards entitle the holder to receive 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. At December 31, 2013, the achievement of the market and performance goals is believed to be probable. The total fair value of CONSOL Stock Units granted during the year ended December 31, 2013 was $28,381. The following represents the unvested CONSOL Stock Unit awards and their corresponding fair value (based upon the closing share price) at the date of the grant:
		Number of			Weighted Average
		Shares			Grant Date Fair Value
	Nonvested at December 31, 2012	—			—
	Granted	842,167			$33.70
	Forfeited	(8,614	)		$33.39
	Nonvested at December 31, 2013	833,553			$33.70
	As of December 31, 2013, $20,508 of total unrecognized compensation cost related to all unvested stock-based awards is expected to be recognized over a weighted-average period of 1.79 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.

Supplemental_Cash_Flow

Supplemental Cash Flow	12 Months Ended
	Dec. 31, 2013
Supplemental Cash Flow Information [Abstract]	'
Cash Flow, Supplemental Disclosures [Text Block]	'
	NOTE 20—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, 2013, 2012 and 2011, CONSOL Energy entered into non-cash capital lease arrangements of $4,178, $3,583, and $4,649, respectively.
	As of December 31, 2013, 2012 and 2011, CONSOL Energy purchased goods and services related to capital projects in the amount of $175,371, $63,051 and $61,690, respectively, that are included in accounts payable.
	During the year ended December 31, 2012, CONSOL Energy entered into a promissory note for $6,236 with the lessor of its former headquarters to replace the existing operating lease.
	The following table shows cash paid during the year for:
		For the Years Ended December 31,
		2013		2012		2011
	Interest (Net of Amounts Capitalized)	$	209,580	$	212,364	$	242,587
	Income Taxes	$	35,079	$	121,245	$	144,405

Concentrations_of_Credit_Risk

Concentrations of Credit Risk	12 Months Ended
	Dec. 31, 2013
CONCENTRATION OF CREDIT RISK AND MAJOR CUSTOMERS: [Abstract]	'
Concentration Risk Disclosure [Text Block]	'
	NOTE 21—CONCENTRATION OF CREDIT RISK AND MAJOR CUSTOMERS:
	CONSOL Energy markets natural gas primarily to gas wholesalers, thermal coal, principally to electric utilities in the United States, Canada and Western Europe and metallurgical coal to steel and coke producers worldwide.
	Concentration of credit risk is summarized below:
		December 31,
		2013		2012
	Thermal coal utilities	$	154,738	$	247,955
	Steel and coke producers	10,963		47,203
	Coal brokers and distributors	52,233		65,057
	Gas wholesalers	71,441		51,718
	Various other	43,199		16,395
	Total Accounts Receivable Trade (including Accounts Receivable—Securitized)	$	332,574	$	428,328
	Accounts receivable from thermal coal utilities and steel and coke producers include amounts sold under the accounts receivable securitization facility. See Note 10–Accounts Receivable Securitization for further discussion. Credit is extended based on an evaluation of the customer's financial condition, and generally collateral is not required. Credit losses have been consistently minimal.
	For the year ended December 31, 2013, Xcoal Energy Resources and Duke Energy Carolinas each comprised over 10% of our revenues from continuing operations. Coal sales to Xcoal Energy Resources were $495,242 and coal sales to Duke Energy Carolinas were $346,424 during 2013. For the year ended December 31, 2012 and 2011, coal sales to Xcoal Energy Resources comprised over 10% of our revenues from continuing operations. Coal sales to Xcoal Energy Resources were $382,843 and $655,596 for the year ended December 31, 2012 and 2011, respectively.

Fair_Value_of_Financial_Instru

Fair Value of Financial Instruments	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value of Financial Instruments	'
	FAIR VALUE OF FINANCIAL INSTRUMENTS:
	The financial instruments measured at fair value on a recurring basis are summarized below:
		Fair Value Measurements at December 31, 2013									Fair Value Measurements at December 31, 2012
	Description	Quoted Prices in			Significant			Significant			Quoted Prices in			Significant		Significant
		Active Markets			Other			Unobservable			Active Markets			Other		Unobservable
		for Identical			Observable			Inputs			for Identical			Observable		Inputs
		Liabilities			Inputs			(Level 3)			Liabilities			Inputs		(Level 3)
		(Level 1)			(Level 2)						(Level 1)			(Level 2)
	Gas Cash Flow Hedges (Note 23)	$	—		$	65,449		$	—		$	—		$	128,945	$	—
	The following methods and assumptions were used to estimate the fair value for which the fair value option was not elected:
	Cash and cash equivalents: The carrying amount reported in the balance sheets for cash and cash equivalents approximates its fair value due to the short-term maturity of these instruments.
	Restricted cash: The carrying amounts reported in the balance sheets for restricted cash, both current and long-term approximates its fair value.
	Short-term notes payable: The carrying amount reported in the balance sheets for short-term notes payable approximates its fair value due to the short-term maturity of these instruments.
	Borrowings under Securitization Facility: The carrying amount reported in the balance sheets for borrowings under the securitization facility approximates its fair value due to the short-term maturity of these instruments.
	Long-term debt: The fair value of long-term debt is measured using unadjusted quoted market prices or estimated using discounted cash flow analyses. The discounted cash flow analyses are based on current market rates for instruments with similar cash flows.
	The carrying amounts and fair values of financial instruments for which the fair value option was not elected are as follows:
		December 31, 2013						December 31, 2012
		Carrying			Fair			Carrying			Fair
		Amount			Value			Amount			Value
	Cash and cash equivalents	$	327,420		$	327,420		$	21,862		$	21,862
	Restricted cash (a)	$	—		$	—		$	68,673		$	68,673
	Short-term notes payable	$	—		$	—		$	(25,073	)	$	(25,073	)
	Borrowings under securitization facility	$	—		$	—		$	(37,846	)	$	(37,846	)
	Long-term debt	$	(3,118,920	)	$	(3,299,875	)	$	(3,127,726	)	$	(3,376,767	)

Derivatives

Derivatives	12 Months Ended
	Dec. 31, 2013
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 our exposure to commodity price volatility. The fair value of CONSOL Energy's derivatives (natural gas price swaps) are based on intra-bank pricing models which utilize inputs that are either readily available in the public market, such as natural gas forward curves, or can be corroborated from active markets or broker quotes. These values are then compared to the values given by our counterparties for reasonableness. Changes in the fair value of the derivatives are recorded currently in earnings unless special hedge accounting criteria are met. For derivatives designated as fair value hedges, the changes in fair value of both the derivative instrument and the hedged item are recorded in earnings. For derivatives designated as cash flow hedges, the effective portions of changes in the fair value of the derivatives are reported in Other Comprehensive Income or Loss (OCI) on the Consolidated Balance Sheets and reclassified into Outside Sales on the Consolidated Statements of Income in the same period or periods which the forecasted transaction affects earnings. The ineffective portions of hedges are recognized in earnings in the current period. CONSOL Energy currently utilizes only cash flow hedges that are considered highly effective.
	CONSOL Energy formally assesses both at inception of the hedge and on an ongoing basis whether each derivative is highly effective in offsetting changes in the fair values or the cash flows of the hedged item. If it is determined that a derivative is not highly effective as a hedge or if a derivative ceases to be a highly effective hedge, CONSOL Energy will discontinue hedge accounting prospectively.
	CONSOL Energy is exposed to credit risk in the event of nonperformance 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 our counterparty master agreements 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 have to post collateral for hedges in a liabilities position in excess of defined thresholds. All of our 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.
	CONSOL Energy has entered into swap contracts for natural gas to manage the price risk associated with the forecasted natural gas revenues. The objective of these hedges is to reduce the variability of the cash flows associated with the forecasted sales from the underlying commodity. As of December 31, 2013, the total notional amount of the Company’s outstanding natural gas swap contracts was 279.3 billion cubic feet. These swap contracts are forecasted to settle through December 31, 2016 and meet the criteria for cash flow hedge accounting. As these contracts settle, the cash received and/or paid will be shown on the Consolidated Statements of Cash Flows as Changes in Prepaid Expenses, Changes in Other Assets, Changes in Other Operating Liabilities and/or Changes in Other Liabilities. Assuming no changes in price during the next twelve months, $30,333 of unrealized gain is expected to be reclassified from Other Comprehensive Income on the Consolidated Balance Sheets and into Outside Sales on the Consolidated Statements of Income, as a result of the gross settlement of cash flow hedges. No gains or losses have been reclassified into earnings as a result of the discontinuance of cash flow hedges.
	The gross fair value at December 31, 2013 of CONSOL Energy's derivative instruments, which were all natural gas swaps and qualify as cash flow hedges, was an asset of $83,661 and a liability of $18,212. The total asset is comprised of $59,605 and $24,056 which were included in Prepaid Expense and Other Assets, respectively, on the Consolidated Balance Sheets. The total liability is comprised of $12,327 and $5,885 which were included in Other Accrued Liabilities and Other Liabilities, respectively, on the Consolidated Balance Sheets.
	The gross fair value at December 31, 2012 of CONSOL Energy's derivative instruments, which were all natural gas swaps and qualify as cash flow hedges, was an asset of $135,969 and a liability of $7,024. The total asset is comprised of $80,057 and $55,912 which were included in Prepaid Expense and Other Assets, respectively, on the Consolidated Balance Sheets. The total liability is comprised of $970 and $6,054 which were included in Other Accrued Liabilities and Other Liabilities, respectively, on the Consolidated Balance Sheets.
	The effect of derivative instruments in cash flow hedging relationships on the Consolidated Statements of Income and the Consolidated Statements of Stockholders' Equity net of tax were as follows:
		Year Ended December 31,
		2013			2012		2011
	Natural Gas Price Swaps
	Beginning Balance – Accumulated OCI	$	76,761		$	151,780	$	46,087
	Gain recognized in Accumulated OCI	$	45,631		$	114,240	$	200,700
	Less: Gain reclassified from Accumulated OCI into Outside Sales	$	79,899		$	189,259	$	95,007
	Ending Balance – Accumulated OCI	$	42,493		$	76,761	$	151,780
	Gain recognized in Outside Sales for ineffectiveness	$	(4,645	)	$	579	$	1,034
	There were no amounts recognized in earnings related to the amount excluded from the assessment of hedge effectiveness in 2013, 2012 or 2011.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	NOTE 24—COMMITMENTS AND CONTINGENGENT 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. We accrue the estimated loss for these lawsuits and claims when the loss is probable and can be estimated. Our 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 $318,786.
	The following lawsuits and claims include those for which a loss is probable and an accrual has been recognized.
	Asbestos-Related Litigation: One of our subsidiaries, Fairmont Supply Company (Fairmont), which distributes industrial supplies, currently is named as a defendant in approximately 6,900 asbestos-related claims in state courts in Pennsylvania, Ohio, West Virginia, Maryland, Texas and Illinois. Because a very small percentage of products manufactured by third parties and supplied by Fairmont in the past may have contained asbestos and many of the pending claims are part of mass complaints filed by hundreds of plaintiffs against a hundred or more defendants, it has been difficult for Fairmont to determine how many of the cases actually involve valid claims or plaintiffs who were actually exposed to asbestos-containing products supplied by Fairmont. In addition, while Fairmont may be entitled to indemnity or contribution in certain jurisdictions from manufacturers of identified products, the availability of such indemnity or contribution is unclear at this time, and in recent years, some of the manufacturers named as defendants in these actions have sought protection from these claims under bankruptcy laws. Fairmont has no insurance coverage with respect to these asbestos cases. Based on over 15 years of experience with this litigation, we have established an accrual to cover our estimated liability for these cases. This accrual is immaterial to the overall financial position of CONSOL Energy and was included in Other Accrued Liabilities on the Consolidated Balance Sheet. Past payments by Fairmont with respect to asbestos cases have not been material.
	Hale Litigation: A purported class action lawsuit was filed on September 23, 2010 in the U.S. District Court in Abingdon, Virginia styled Hale v. CNX Gas Company, et. al. The lawsuit alleges that the plaintiff class consists of forced-pooled unleased gas owners whose gas ownership is in conflict, the Virginia Supreme Court and General Assembly have decided that coalbed methane (CBM) belongs to the owner of the gas estate, the Virginia Gas and Oil Act of 1990 unconstitutionally provides only a 1/8 net proceeds royalty to CBM owners for gas produced under the forced-pooled orders, and CNX Gas Company relied upon control of only the coal estate in force pooling the CBM notwithstanding decisions by the Virginia Supreme Court. The lawsuit seeks a judicial declaration of ownership of the CBM and that the entire net proceeds of CBM production (that is, the 1/8 royalty and the 7/8 of net revenues since production began) be distributed to the class members. The lawsuit also alleges 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. The Magistrate Judge issued a Report and Recommendation in which she recommended that the District Judge decide that the deemed lease provision of the Gas and Oil Act is constitutional as is the 1/8 royalty. The Magistrate Judge recommended against the dismissal of certain other claims. The District Judge affirmed the Magistrate Judge's recommendations in their entirety. An amended complaint was filed, which added additional allegations that include gas hedging receipts should have been used as the basis for royalty payments, severance tax should not be allowed as a post-production deduction from royalties, and damages incurred because gas was produced prior to the entry of pooling orders. A motion to dismiss the Amended Complaint was filed and denied. The Magistrate Judge issued a Report & Recommendation on June 5, 2013, recommending that the District Judge grant plaintiffs' Motion for Class Certification. CNX Gas Company filed its extensive Objections to the Report & Recommendation on July 3, 2013. The District Judge heard argument on the Objections on September 12, 2013, and on September 30, 2013, entered an Order overruling the Objections, adopting the Report & Recommendation and certifying the class with a modified class definition. CNX Gas believes this case cannot properly proceed as a class action and filed a Petition asking the U.S. Court of Appeals for the Fourth Circuit to review the class certification Order. On November 13, 2013, the Fourth Circuit entered an Order deferring a ruling on the Petition; assigning the case to a merits panel; and, requesting full briefing of the class certification challenge. At the same time, Plaintiffs have filed Motions for Summary Judgment on the issue of “ownership” of the gas royalty escrow accounts and seeking an accounting. The Fourth Circuit denied a Motion to Stay the trial court proceedings while it considers the class certification issues, and the District Judge held argument on the summary judgment motions for January 6, 2014. CONSOL Energy believes that the case has meritorious defenses and intends to defend it vigorously. We have established an accrual to cover our 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 Sheet.
	Addison Litigation: A purported class action lawsuit was filed on April 28, 2010 in the United States District Court in Abingdon, Virginia styled Addison v. CNX Gas Company, et al.  The lawsuit alleges that the plaintiff class consists of gas lessors whose gas ownership is in conflict. The lawsuit alleges that the Virginia Supreme Court and General Assembly have decided that the plaintiff owns the gas and is entitled to royalties held in escrow by the Commonwealth of Virginia or CNX Gas Company. The lawsuit also alleges CNX Gas Company failed to either pay royalties due 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. Plaintiff seeks a declaratory judgment regarding ownership, an accounting and compensatory and punitive damages for breach of contract; conversion; negligence (voluntary undertaking) for improperly asserting that conflicting ownership exists, negligence (breach of duties as an operator); breach of fiduciary duties; and unjust enrichment. The Magistrate Judge issued a Report and Recommendation recommending dismissing some claims and allowing others to proceed. The District Judge affirmed the Magistrate Judge's recommendations in their entirety. An Amended Complaint was filed which added an additional allegation that gas hedging receipts should have been used as the basis for royalty payments. A motion to dismiss those claims was filed and was denied. The Magistrate Judge issued a Report & Recommendation on June 5, 2013, recommending that the District Judge grant plaintiffs' Motion for Class Certification. CNX Gas Company filed its extensive Objections to the Report & Recommendation on July 3, 2013. The District Judge heard argument on the Objections on September 12, 2013, and on September 30, 2013, entered an Order overruling the Objections, adopting the Report & Recommendation and certifying the class with a modified class definition. CNX Gas believes this case cannot properly proceed as a class action and filed a Petition asking the U.S. Court of Appeals for the Fourth Circuit to review the class certification Order. On November 13, 2013, the Fourth Circuit entered an Order deferring a ruling on the Petition; assigning the case to a merits panel; and, requesting full briefing of the class certification challenge. At the same time, Plaintiffs have filed Motions for Summary Judgment on the issue of “ownership” of the gas royalty escrow accounts and seeking an accounting. The Fourth Circuit denied a Motion to Stay the trial court proceedings while it considers the class certification issues, and the District Judge held argument on the summary judgment motions for January 6, 2014. CONSOL Energy believes that the case has meritorious defenses and intends to defend it vigorously. We have established an accrual to cover our estimated liability for this case. This accrual is immaterial to the overall financial position of CONSOL Energy and was included in Other Accrued Liabilities on the Consolidated Balance Sheet.
	The following royalty and land right lawsuits and claims include those for which a loss is reasonably possible, but not probable, and accordingly, no accrual has 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 are 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.
	Ratliff Litigation: On March 22, 2012, the Company was served with four complaints filed on May 31, 2011 by four individuals against Consolidation Coal Company (CCC), Island Creek Coal Company (ICCC), CNX Gas Company, subsidiaries of CONSOL Energy, as well as CONSOL Energy itself in the Circuit Court of Russell County, Virginia. The complaints seek damages and injunctive relief in connection with the deposit of water from mining activities at CCC's Buchanan Mine into nearby void spaces at some of the mines of ICCC. The suits allege damage to coal and coalbed methane and seek recovery in tort, contract and assumpsit (quasi-contract). The cases were removed to federal court, motions to dismiss were filed by CCC, and then were voluntarily dismissed by the plaintiffs. On January 30, 2013, the four plaintiffs filed a single consolidated complaint against the same defendants in the United States District Court for the Western District of Virginia, alleging the same damage and theories of recovery for storage of water in the mine voids ostensibly underlying their property. The suit seeks damages ranging from $4,000 to $8,000 plus punitive damages. The defendants have asserted Virginia's Mine Void Statute as a defense to plaintiffs claims and the plaintiffs have challenged the constitutionality of that statute. Based on Plaintiffs’ challenge, the Court on August 1, 2013, entered a Certificate pursuant to 28 USC Section 2304 notifying the Virginia Attorney General that the Mine Void Statute had been called into question and advising the Commonwealth of its right to intervene in the proceedings for the limited purpose of addressing the constitutionality of the statute. To date, the Virginia Attorney General has not responded. CONSOL Energy intends to vigorously defend the suit.
	Kennedy Litigation: The Company is a party to a case filed on March 26, 2008 captioned Earl Kennedy (and others) v. CNX Gas Company and CONSOL Energy in the Court of Common Pleas of Greene County, Pennsylvania. The lawsuit alleges that CNX Gas Company and CONSOL Energy trespassed and converted gas and other minerals allegedly belonging to the plaintiffs in connection with wells drilled by CNX Gas Company. The complaint, as amended, seeks injunctive relief, including removing CNX Gas Company from the property, and compensatory damages of $20,000. The suit also sought to overturn existing law as to the ownership of coalbed methane in Pennsylvania, but that claim was dismissed by the court; the plaintiffs are seeking to appeal that dismissal. The suit also seeks a determination that the Pittsburgh 8 coal seam does not include the “roof/rider” coal. The court denied the plaintiff's summary judgment motion on that issue. The court held a bench trial on the “roof/rider” coal issue in November 2011 and ruled for CNX Gas Company and CONSOL Energy, holding that the “roof/rider” coal is included in the Pittsburgh 8 coal seam. The plaintiffs have indicated that they intend to appeal that decision. A Motion for Summary Judgment on all remaining counts was argued on January 10, 2014, and remains pending. Should the Motion be denied, a trial on the issue of whether a drilling that deviates from the coal seam results in damage to the gas owner is anticipated for first quarter 2014. CNX Gas Company and CONSOL Energy believe this lawsuit to be without merit and intends to vigorously defend it. Consequently, we have not recognized any liability related to these actions.
	Rowland Litigation: Rowland Land Company filed a complaint in May 2011 against CONSOL Energy, CNX Gas Company, Dominion Resources Inc., and EQT Production Company (EQT) in Raleigh County Circuit Court, West Virginia. Rowland is the lessor on a 33,000 acre oil and gas lease in southern West Virginia. EQT was the original lessee, but farmed out the development of the lease to Dominion Resources in exchange for an overriding royalty. Dominion Resources sold the indirect subsidiary that held the lease to a subsidiary of CONSOL Energy on April 30, 2010. Subsequent to that acquisition, the subsidiary that held the lease was merged into CNX Gas Company as part of an internal reorganization. Rowland alleges that (i) Dominion Resources' sale of the subsidiary to CONSOL Energy was a change in control that required its consent under the terms of the farmout agreement and lease, and/or (ii) the subsequent merger of the subsidiary into CNX Gas Company was an assignment that required its consent under the lease. Rowland has recently been permitted to file its Third Amended Complaint to include additional allegations that CONSOL Energy has slandered Rowland's title. A motion to dismiss will be filed. Initial mediation efforts have been unsuccessful. CONSOL Energy believes that the case is without merit and intends to defend it vigorously. Consequently, we have not recognized any liability related to these actions.
	At December 31, 2013, 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 total of future payments that we 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. 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		Less Than		1-3 Years		3-5 Years		Beyond
		Amounts		1  Year						5  Years
		Committed
	Letters of Credit:
	Employee-Related	$	190,358	$	164,852	$	25,506	$	—	$	—
	Environmental	56,293		23,075		33,218		—		—
	Other	114,106		76,460		37,646		—		—
	Total Letters of Credit	360,757		264,387		96,370		—		—
	Surety Bonds:
	Employee-Related	204,884		204,884		—		—		—
	Environmental	610,209		610,209		—		—		—
	Other	32,492		32,481		10		—		1
	Total Surety Bonds	847,585		847,574		10		—		1
	Gurantees:
	Coal	333,460		200,400		133,060		—		—
	Other	70,523		35,611		10,846		9,718		14,348
	Total Guarantees	403,983		236,011		143,906		9,718		14,348
	Total Commitments	$	1,612,325	$	1,347,972	$	240,286	$	9,718	$	14,349
	Included in the above table are commitments and guarantees entered into in conjunction with the sale of Consolidation Coal Company (CCC) 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), CONSOL Energy has guaranteed certain equipment lease obligations and coal sales agreement that are being 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, such as certain Murray Energy collateral and/or Murray Energy indemnifications. At December 31, 2013, the fair value of these guarantees was $3,000 and are included in Other Accrued Liabilities on the Consolidated Balance Sheet. 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 cried 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.
	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 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 Sheet. As of December 31, 2013, the purchase obligations for each of the next five years and beyond were as follows:
	Obligations Due	Amount
	Less than 1 year	$	240,870
	1 - 3 years	260,218
	3 - 5 years	199,144
	More than 5 years	583,333
	Total Purchase Obligations	$	1,283,565
	Costs related to these purchase obligations include:
		For The Years Ended December 31,
		2013		2012		2011
	Gas drilling obligations	$	109,609	$	110,975	$	108,167
	Firm transportation expense	126,766		78,475		59,606
	Major equipment purchases	12,668		101,367		34,219
	Other	—		492		891
	Total costs related to purchase obligations	$	249,043	$	291,309	$	202,883

Segment_Information

Segment Information	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Segment Reporting Disclosure [Text Block]	'
	SEGMENT INFORMATION:
	CONSOL Energy has two principal business divisions: Gas and Coal. The principal activity of the Gas division is to produce pipeline quality natural gas for sale primarily to gas wholesalers. The Gas division includes four reportable segments. These reportable segments are Marcellus, Coalbed Methane, Shallow Oil and Gas and Other Gas. The Other Gas segment includes our purchased gas activities, general and administrative activities as well as various other activities assigned to the Gas division but not allocated to each individual well type. The principal activities of the Coal division are mining, preparation and marketing of thermal coal, sold primarily to power generators, and metallurgical coal, sold to metal and coke producers. The Coal division includes four reportable segments. These reportable segments are Thermal, Low Volatile Metallurgical, High Volatile Metallurgical and Other Coal. Each of these reportable segments includes a number of operating segments (mines or type of coal sold). For the twelve months ended December 31, 2013, the Thermal aggregated segment includes the following mines: Bailey, Enlow Fork, Fola Complex, and Miller Creek Complex. For the twelve months ended December 31, 2013, the Low Volatile Metallurgical aggregated segment includes the Buchanan Mine and Amonate Complex. For the twelve months ended December 31, 2013, the High Volatile Metallurgical aggregated segment includes: Bailey, Enlow Fork, and Fola Complex coal sales. The Other Coal segment includes our purchased coal activities, idled mine activities, general and administrative activities as well as various other activities assigned to the Coal division but not allocated to each individual mine. CONSOL Energy’s All Other segment includes industrial supplies, coal terminal operations and various other corporate activities that are not allocated to the gas or coal segment. 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 only (coal, gas and other) and are not allocated between each individual segment. This presentation is consistent with the information regularly reviewed by the chief operating decision maker. The assets are not allocated to each individual segment due to the diverse asset base controlled by CONSOL Energy where 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,
			2013				2012				2011
	Total segment sales and freight from external customers		$	3,120,722			$	3,282,350			$	4,237,913
	Other income not allocated to segments (Note 4)		178,963				395,176				139,132
	Total Consolidated Revenue and Other Income		$	3,299,685			$	3,677,526			$	4,377,045
	Earnings Before Income Taxes:
			For the Years Ended December 31,
			2013				2012				2011
	Segment Earnings Before Income Taxes for total reportable business segments		$	334,910			$	631,078			$	1,162,481
	Segment Earnings Before Income Taxes for all other businesses		(47,468		)		10,997				3,408
	Interest income (expense), net and other non-operating activity (I)		(226,199		)		(228,804		)		(258,308		)
	Transaction and Financing Fees (I)		—				—				(14,907		)
	Evaluation fees for non-core asset dispositions (I)		(15,168		)		(6,584		)		(5,780		)
	Loss on debt extinguishment		—				—				(16,090		)
	Lease Settlement		—				—				2,122
	Earnings Before Income Taxes		$	46,075			$	406,687			$	872,926
	Total Assets:		December 31,
			2013				2012
	Segment assets for total reportable business segments		$	10,521,753			$	9,873,863
	Segment assets for all other businesses		293,486				363,676
	Items excluded from segment assets:
	Cash and other investments (I)		321,992				19,252
	Recoverable income taxes		10,705				—
	Deferred tax assets		211,303				84,777
	Bond issuance costs		34,428				41,775
	Discontinued Operations		—				2,614,251
	Total Consolidated Assets		$	11,393,667			$	12,997,594
	_________________________
	(I) Excludes amounts specifically related to the gas segment.
	Enterprise-Wide Disclosures:
	CONSOL Energy's Revenues by geographical location (J):
			For the Years Ended December 31,
			2013				2012				2011
	United States (K)		$	2,999,674			$	2,898,341			$	3,460,871
	Europe		83,878				187,313				366,384
	South America		29,787				169,591				400,307
	Canada		3,575				5,692				10,351
	Other		3,808				21,413				—
	Total Revenues and Freight from External Customers (K)		$	3,120,722			$	3,282,350			$	4,237,913
	_________________________
	(J) CONSOL Energy attributes revenue to individual countries based on the location of the customer.
	(K) CONSOL Energy has contractual relationships with certain U.S. based customers who distribute coal to international markets.
	CONSOL Energy's Property, Plant and Equipment by geographical location are:
			December 31,
			2013				2012
	United States		$	9,431,238			$	8,487,614
	Canada		11,024				20,444
	Discontinued Operations		—				1,682,909
	Total Property, Plant and Equipment, net		$	9,442,262			$	10,190,967
Segment Information	'
	Industry segment results for the year ended December 31, 2013 are:
		Marcellus				Coalbed				Shallow Oil and Gas				Other			Total			Thermal		Low Volatile		High Volatile		Other			Total Coal		All			Corporate,			Consolidated
		Shale				Methane								Gas			Gas					Metallurgical		Metallurgical		Coal					Other			Adjustments
																																		&
																																		Eliminations
	Sales—outside	$	251,846			$	335,730			$	131,135			$	18,990		$	737,701		$	1,388,005	$	447,417	$	159,888	$	22,757		$	2,018,067	$	259,783		$	—		$	3,015,551	(A)
	Sales—purchased gas	—				—				—				6,531			6,531			—		—		—		—			—		—			—			6,531
	Sales—gas royalty interests	—				—				—				63,202			63,202			—		—		—		—			—		—			—			63,202
	Freight—outside	—				—				—				—			—			—		—		—		35,438			35,438		—			—			35,438
	Intersegment transfers	—				—				—				3,167			3,167			—		—		—		—			—		127,553			(130,720		)	—
	Total Sales and Freight	$	251,846			$	335,730			$	131,135			$	91,890		$	810,601		$	1,388,005	$	447,417	$	159,888	$	58,195		$	2,053,505	$	387,336		$	(130,720	)	$	3,120,722
	Earnings (Loss) Before Income Taxes	$	79,439			$	81,392			$	(17,829	)		$	(144,616	)	$	(1,614	)	$	375,787	$	121,285	$	40,500	$	(201,048	)	$	336,524	$	(47,468	)	$	(241,367	)	$	46,075	(B)
	Segment assets																$	6,334,468											$	4,187,285	$	293,486		$	578,428		$	11,393,667	(C)
	Depreciation, depletion and amortization																$	229,562											$	218,414	$	13,146		$	—		$	461,122
	Capital expenditures																$	968,607											$	458,653	$	68,796		$	—		$	1,496,056
	(A)	Included in the Coal segment are sales of $495,242 to Xcoal Energy & Resources and $346,424 to Duke Energy each comprising over 10% of sales.
	(B)	Includes equity in earnings of unconsolidated affiliates of $17,346, $14,684 and $1,102 for Coal, Gas and All Other, respectively.
	(C)	Includes investments in unconsolidated equity affiliates of $20,512, $206,060 and $65,103 for Coal, Gas and All Other, respectively.
	Industry segment results for the year ended December 31, 2012 are:
		Marcellus				Coalbed				Shallow Oil and Gas				Other			Total			Thermal		Low Volatile		High Volatile		Other			Total Coal		All			Corporate,			Consolidated
		Shale				Methane								Gas			Gas					Metallurgical		Metallurgical		Coal					Other			Adjustments
																																		&
																																		Eliminations
	Sales—outside	$	134,080			$	379,595			$	135,412			$	9,733		$	658,820		$	1,430,912	$	505,670	$	210,153	$	22,890		$	2,169,625	$	294,105		$	—		$	3,122,550	(D)
	Sales—purchased gas	—				—				—				3,316			3,316			—		—		—		—			—		—			—			3,316
	Sales—gas royalty interests	—				—				—				49,405			49,405			—		—		—		—			—		—			—			49,405
	Freight—outside	—				—				—				—			—			—		—		—		107,079			107,079		—			—			107,079
	Intersegment transfers	—				—				—				1,622			1,622			—		—		—		—			—		142,014			(143,636		)	—
	Total Sales and Freight	$	134,080			$	379,595			$	135,412			$	64,076		$	713,163		$	1,430,912	$	505,670	$	210,153	$	129,969		$	2,276,704	$	436,119		$	(143,636	)	$	3,282,350
	Earnings (Loss) Before Income Taxes	$	29,546			$	125,970			$	(13,390	)		$	(102,675	)	$	39,451		$	396,748	$	210,133	$	57,163	$	(72,417	)	$	591,627	$	10,997		$	(235,388	)	$	406,687	(E)
	Segment assets																$	5,768,882											$	4,104,981	$	363,676		$	2,760,055		$	12,997,594	(F)
	Depreciation, depletion and amortization																$	202,956											$	211,831	$	12,328		$	—		$	427,115
	Capital expenditures																$	532,636											$	662,888	$	49,973		$	—		$	1,245,497
	(D)	Included in the Coal segment are sales of $382,843 to Xcoal Energy & Resources comprising over 10% of sales.
	(E)	Includes equity in earnings of unconsolidated affiliates of $17,318, $9,562 and $168 for Coal, Gas and All Other, respectively.
	(F)	Includes investments in unconsolidated equity affiliates of $19,517, $143,876 and $59,437 for Coal, Gas and All Other, respectively.
	Industry segment results for the year ended December 31, 2011 are:
		Marcellus				Coalbed				Shallow Oil and Gas				Other			Total			Thermal		Low Volatile		High Volatile		Other			Total Coal		All			Corporate,			Consolidated
		Shale				Methane								Gas			Gas					Metallurgical		Metallurgical		Coal					Other			Adjustments
																																		&
																																		Eliminations
	Sales—outside	$	118,973			$	462,677			$	155,444			$	11,370		$	748,464		$	1,495,480	$	1,071,570	$	324,377	$	66,333		$	2,957,760	$	284,783		$	—		$	3,991,007	(G)
	Sales—purchased gas	—				—				—				4,344			4,344			—		—		—		—			—		—			—			4,344
	Sales—gas royalty interests	—				—				—				66,929			66,929			—		—		—		—			—		—			—			66,929
	Freight—outside	—				—				—				—			—			—		—		—		175,633			175,633		—			—			175,633
	Intersegment transfers	—				—				—				3,303			3,303			—		—		—		—			—		194,857			(198,160		)	—
	Total Sales and Freight	$	118,973			$	462,677			$	155,444			$	85,946		$	823,040		$	1,495,480	$	1,071,570	$	324,377	$	241,966		$	3,133,393	$	479,640		$	(198,160	)	$	4,237,913
	Earnings (Loss) Before Income Taxes	$	41,566			$	185,761			$	(14,732	)		$	(82,811	)	$	129,784		$	421,683	$	692,249	$	129,119	$	(210,354	)	$	1,032,697	$	3,408		$	(292,963	)	$	872,926	(H)
	Depreciation, depletion and amortization																$	206,821											$	214,285	$	9,471		$	—		$	430,577
	Capital expenditures																$	664,612											$	472,591	$	41,172		$	—		$	1,178,375
	(G) Included in the Coal segment are sales of $655,596 to Xcoal Energy & Resources comprising over 10% of sales.
	(H)     Includes equity in earnings of unconsolidated affiliates of $19,629, $4,231 and $803 for Coal, Gas and All Other, respectively.

Guarantor_Subsidiaries_Financi

Guarantor Subsidiaries Financial Information	12 Months Ended
	Dec. 31, 2013
Guarantor Subsidiaries Financial Information [Abstract]	'
Additional Financial Information Disclosure [Text Block]	'
	NOTE 26—GUARANTOR SUBSIDIARIES FINANCIAL INFORMATION:
	The payment obligations under the $1,500,000, 8.000% per annum senior notes due April 1, 2017, the $1,250,000, 8.250% per annum senior notes due April 1, 2020, and the $250,000, 6.375% per annum senior notes due March 1, 2021 issued by CONSOL Energy are jointly and severally, and also fully and unconditionally guaranteed by substantially all 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, the remaining guarantor subsidiaries and the 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.
	Income Statement for the Year Ended December 31, 2013:
		Parent			CNX Gas			Other			Non-			Elimination			Consolidated
		Issuer			Guarantor			Subsidiary			Guarantors
								Guarantors
	Sales—Outside	$	—		$	740,869		$	2,061,652		$	216,419		$	(3,389	)	$	3,015,551
	Sales—Gas Royalty Interests	—			63,202			—			—			—			63,202
	Sales—Purchased Gas	—			6,531			—			—			—			6,531
	Freight—Outside	—			—			35,438			—			—			35,438
	Other Income	930,481			57,592			100,757			20,614			(930,481		)	178,963
	Total Revenue and Other Income	930,481			868,194			2,197,847			237,033			(933,870		)	3,299,685
	Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	170,702			493,416			1,313,601			219,450			31,783			2,228,952
	Gas Royalty Interests Costs	—			53,069			—			—			(41		)	53,028
	Purchased Gas Costs	—			4,837			—			—			—			4,837
	Related Party Activity	35,678			—			(112,626		)	1,767			75,181			—
	Freight Expense	—			—			35,438			—			—			35,438
	Selling, General and Administrative Expenses	—			44,733			44,357			1,318			—			90,408
	Depreciation, Depletion and Amortization	12,857			229,562			216,726			1,977			—			461,122
	Interest Expense	211,449			8,605			(423		)	47			(480		)	219,198
	Taxes Other Than Income	3,669			35,176			118,675			3,107			—			160,627
	Total Costs	434,355			869,398			1,615,748			227,666			106,443			3,253,610
	Earnings (Loss) Before Income Taxes	496,126			(1,204		)	582,099			9,367			(1,040,313		)	46,075
	Income Tax (Benefit) Expense	(164,316		)	1,420			126,164			3,543			—			(33,189		)
	Income (Loss) from Continuing Operations	660,442			(2,624		)	455,935			5,824			(1,040,313		)	79,264
	Income from Discontinued Operations, net of tax	—			—			—			579,792			—			579,792
	Net Income (Loss)	660,442			(2,624		)	455,935			585,616			(1,040,313		)	659,056
	Less: Net Loss Attributable to Noncontrolling Interest	—			1,386			—			—			—			1,386
	Net Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	660,442		$	(1,238	)	$	455,935		$	585,616		$	(1,040,313	)	$	660,442
	Balance Sheet for December 31, 2013:
		Parent			CNX Gas			Other			Non-			Elimination			Consolidated
		Issuer			Guarantor			Subsidiary			Guarantors
								Guarantors
	Assets:
	Current Assets:
	Cash and Cash Equivalents	$	320,473		$	6,238		$	—		$	709		$	—		$	327,420
	Accounts and Notes Receivable:
	Trade	—			71,911			—			260,663			—			332,574
	Notes Receivable	1,238			—			24,623			—			—			25,861
	Other Receivables	17,657			207,128			14,969			4,219			—			243,973
	Inventories	—			15,185			99,320			43,409			—			157,914
	Deferred Income Taxes	219,566			(8,263		)	—			—			—			211,303
	Recoverable Income Taxes	(16,262		)	26,967			—			—			—			10,705
	Prepaid Expenses	43,698			65,701			24,915			1,528			—			135,842
	Total Current Assets	586,370			384,867			163,827			310,528			—			1,445,592
	Property, Plant and Equipment:
	Property, Plant and Equipment	220,355			6,919,972			6,412,378			25,804			—			13,578,509
	Less-Accumulated Depreciation, Depletion and Amortization	145,754			1,188,464			2,783,043			18,986			—			4,136,247
	Total Property, Plant and Equipment-Net	74,601			5,731,508			3,629,335			6,818			—			9,442,262
	Other Assets:
	Investment in Affiliates	11,965,054			206,060			70,222			—			(11,949,661		)	291,675
	Notes Receivable	125			—			—			—			—			125
	Other	145,401			30,728			28,831			9,053			—			214,013
	Total Other Assets	12,110,580			236,788			99,053			9,053			(11,949,661		)	505,813
	Total Assets	$	12,771,551		$	6,353,163		$	3,892,215		$	326,399		$	(11,949,661	)	$	11,393,667
	Liabilities and Equity:
	Current Liabilities:
	Accounts Payable	$	180,261		$	324,226		$	493		$	9,600		$	—		$	514,580
	Accounts Payable (Recoverable)—Related Parties	4,563,327			23,287			(5,055,923		)	136,822			332,487			—
	Current Portion Long-Term Debt	1,029			6,258			3,372			796			—			11,455
	Short-Term Notes Payable	—			332,487			—			—			(332,487		)	—
	Other Accrued Liabilities	144,612			89,080			322,606			9,399			—			565,697
	Current Liabilities of Discontinued Operations	—			—			—			28,239			—			28,239
Total Current Liabilities	4,889,229			775,338			(4,729,452		)	184,856			—			1,119,971
Long-Term Debt:
Long-Term Debt	3,004,213			—			111,750			—			—			3,115,963
Capital Lease Obligations	1,245			42,852			1,724			1,775			—			47,596
Total Long-Term Debt	3,005,458			42,852			113,474			1,775			—			3,163,559
Deferred Credits and Other Liabilities
Deferred Income Taxes	(232,904		)	475,547			—			—			—			242,643
Postretirement Benefits Other Than Pensions	—			—			961,127			—			—			961,127
Pneumoconiosis Benefits	—			—			111,971			—			—			111,971
Mine Closing	—			—			320,723			—			—			320,723
Gas Well Closing	—			119,429			56,174			—			—			175,603
Workers’ Compensation	—			—			71,136			332			—			71,468
Salary Retirement	48,252			—			—			—			—			48,252
Reclamation	—			—			40,706			—			—			40,706
Other	55,227			61,190			14,938			—			—			131,355
Total Deferred Credits and Other Liabilities	(129,425		)	656,166			1,576,775			332			—			2,103,848
Total CONSOL Energy Inc. Stockholders’ Equity	5,006,289			4,878,807			6,931,418			139,436			(11,949,661		)	5,006,289
Total Liabilities and Equity	$	12,771,551		$	6,353,163		$	3,892,215		$	326,399		$	(11,949,661	)	$	11,393,667
Condensed Statement of Cash Flows For the Year Ended December 31, 2013:
	Parent			CNX Gas			Other Subsidiary Guarantors			Non-			Elimination			Consolidated
				Guarantor						Guarantors
Net Cash Provided by (Used in) Continuing Operations	$	51,093		$	440,763		$	572,683		$	(843,456	)	$	332,487		$	553,570
Net Cash Provided by Discontinued Operating Activities	—			—			—			105,206			—			105,206
Net Cash Provided by (Used in) Operating Activities	$	51,093		$	440,763		$	572,683		$	(738,250	)	$	332,487		$	658,776
Cash Flows from Investing Activities:
Capital Expenditures	$	(68,796	)	$	(968,607	)	$	(458,653	)	$	—		$	—		$	(1,496,056	)
Change in Restricted Cash	—			—			68,673			—			—			68,673
Proceeds From Sales of Assets	327,964			350,975			(195,082		)	112			—			483,969
(Investments in), net of Distributions from, Equity Affiliates	—			(47,500		)	11,788			—			—			(35,712		)
Net Cash (Used in) Provided by Continuing Operations	259,168			(665,132		)	(573,274		)	112			—			(979,126		)
Net Cash Provided by Discontinued Investing Activities	—			—			—			777,145			—			777,145
Net Cash (Used in) Provided by Investing Activities	$	259,168		$	(665,132	)	$	(573,274	)	$	777,257		$	—		$	(201,981	)
Cash Flows from Financing Activities:
Dividends (Paid)	$	14,168		$	(100,000	)	$	—		$	—		$	—		$	(85,832	)
Payments on Short-Term Borrowings	—			332,487			—			—			(332,487		)	—
Payments on Miscellaneous Borrowings	(25,952		)	—			(4,800		)	(792		)	—			(31,544		)
Proceeds from Securitization Facility	—			—			—			(37,846		)	—			(37,846		)
Proceeds from Issuance of Common Stock	3,727			—			—			—			—			3,727
Other Financing Activities	778			(5,232		)	5,232			—			—			778
Net Cash (Used in) Provided by Continuing Operations	(7,279		)	227,255			432			(38,638		)	(332,487		)	(150,717		)
Net Cash Used in Discontinued Financing Activities	—			—			—			(520		)	—			(520		)
Net Cash (Used in) Provided by Financing Activities	$	(7,279	)	$	227,255		$	432		$	(39,158	)	$	(332,487	)	$	(151,237	)
Income Statement for the Year Ended December 31, 2012:
	Parent			CNX Gas			Other			Non-			Elimination			Consolidated
	Issuer			Guarantor			Subsidiary			Guarantors
							Guarantors
Sales—Outside	$	—		$	660,442		$	2,221,421		$	243,059		$	(2,372	)	$	3,122,550
Sales—Gas Royalty Interests	—			49,405			—			—			—			49,405
Sales—Purchased Gas	—			3,316			—			—			—			3,316
Freight—Outside	—			—			107,079			—			—			107,079
Other Income	613,340			56,946			316,592			21,639			(613,341		)	395,176
Total Revenue and Other Income	613,340			770,109			2,645,092			264,698			(615,713		)	3,677,526
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	127,372			407,045			1,417,519			239,502			30,421			2,221,859
Gas Royalty Interests Costs	—			38,922			—			—			(55		)	38,867
Purchased Gas Costs	—			2,711			—			—			—			2,711
Related Party Activity	12,865			—			(22,466		)	1,814			7,787			—
Freight Expense	—			—			107,079			—			—			107,079
Selling, General and Administrative Expenses	—			40,101			49,222			1,417			—			90,740
Depreciation, Depletion and Amortization	12,172			202,956			209,923			2,064			—			427,115
Interest Expense	208,894			5,098			6,470			44			(464		)	220,042
Taxes Other Than Income	401			33,892			125,288			2,845			—			162,426
Total Costs	361,704			730,725			1,893,035			247,686			37,689			3,270,839
Earnings (Loss) Before Income Taxes	251,636			39,384			752,057			17,012			(653,402		)	406,687
Income Tax Expense (Benefit)	(136,834		)	15,021			204,105			6,436			—			88,728
Income (Loss) from Continuing Operations	388,470			24,363			547,952			10,576			(653,402		)	317,959
Income from Discontinued Operations, net of tax	—			—			—			70,114			—			70,114
Net Income (Loss)	388,470			24,363			547,952			80,690			(653,402		)	388,073
Less: Net Loss Attributable to Noncontrolling Interest	—			397			—			—			—			397
Net Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	388,470		$	24,760		$	547,952		$	80,690		$	(653,402	)	$	388,470
Balance Sheet for December 31, 2012:
	Parent			CNX Gas			Other			Non-			Elimination			Consolidated
	Issuer			Guarantor			Subsidiary			Guarantors
							Guarantors
Assets:
Current Assets:
Cash and Cash Equivalents	$	17,491		$	3,352		$	159		$	860		$	—		$	21,862
Accounts and Notes Receivable:
Trade	—			58,126			—			370,202			—			428,328
Securitized	—			—			—			37,846			—			37,846
Notes Receivable	154			315,730			2,503			—			—			318,387
Other Receivables	6,335			214,748			33,289			5,159			(128,400		)	131,131
Inventories	—			14,133			121,311			35,364			—			170,808
Deferred Income Taxes	174,176			(26,072		)	(63,327		)	—			—			84,777
Restricted Cash	—			—			48,294			—			—			48,294
Prepaid Expenses	29,589			86,186			31,286			1,370			—			148,431
Current Assets of Discontinued Operations	—			—			—			149,230			—			149,230
Total Current Assets	227,745			666,203			173,515			600,031			(128,400		)	1,539,094
Property, Plant and Equipment:
Property, Plant and Equipment	216,448			5,956,207			5,923,723			25,179			—			12,121,557
Less-Accumulated Depreciation, Depletion and Amortization	126,048			960,613			2,508,769			18,069			—			3,613,499
Property, Plant and Equipment of Discontinued Operations, net	—			—			—			1,682,909			—			1,682,909
Total Property, Plant and Equipment-Net	90,400			4,995,594			3,414,954			1,690,019			—			10,190,967
Other Assets:
Restricted Cash	—			—			20,379			—			—			20,379
Investment in Affiliates	9,917,050			143,876			769,058			—			(10,607,154		)	222,830
Notes Receivable	239			—			25,738			—			—			25,977
Other	118,938			65,935			21,174			10,188			—			216,235
Other Assets of Discontinued Operations	—			—			—			782,112			—			782,112
Total Other Assets	10,036,227			209,811			836,349			792,300			(10,607,154		)	1,267,533
Total Assets	$	10,354,372		$	5,871,608		$	4,424,818		$	3,082,350		$	(10,735,554	)	$	12,997,594
Balance Sheet for December 31, 2012 (Continued):
	Parent			CNX Gas			Other			Non-			Elimination			Consolidated
	Issuer			Guarantor			Subsidiary			Guarantors
							Guarantors
Liabilities and Equity:
Current Liabilities:
Accounts Payable	$	177,734		$	166,182		$	145,469		$	9,130		$	—		$	498,515
Accounts Payable (Recoverable)-Related Parties	3,599,216			23,981			(3,749,584		)	254,787			(128,400		)	—
Short-Term Notes Payable	25,073			—			—			—			—			25,073
Current Portion of Long-Term Debt	1,554			5,953			4,221			756			—			12,484
Accrued Income Taxes	20,488			13,731			—			—			—			34,219
Borrowings under Securitization Facility	—			—			—			37,846			—			37,846
Other Accrued Liabilities	135,407			57,074			343,739			9,528			—			545,748
Current Liabilities of Discontinued Operations	—			—			—			233,214			—			233,214
Total Current Liabilities	3,959,472			266,921			(3,256,155		)	545,261			(128,400		)	1,387,099
Long-Term Debt:
Long-Term Debt	3,004,798			—			118,802			—			—			3,123,600
Capital Lease Obligations	717			46,081			1,148			1,467			—			49,413
Long-Term Debt of Discontinued Operations	—			—			—			1,573			—			1,573
Total Long-Term Debt	3,005,515			46,081			119,950			3,040			—			3,174,586
Deferred Credits and Other Liabilities:
Deferred Income Taxes	(884,310		)	439,725			771,270			—			—			326,685
Postretirement Benefits Other Than Pensions	—			—			882,600			—			—			882,600
Pneumoconiosis Benefits	—			—			114,136			—			—			114,136
Mine Closing	—			—			289,818			—			—			289,818
Gas Well Closing	—			80,097			65,905			—			—			146,002
Workers’ Compensation	—			—			60,090			306			—			60,396
Salary Retirement	218,004			—			—			—			—			218,004
Reclamation	—			—			47,965			—			—			47,965
Other	101,899			24,518			(8,110		)	—			—			118,307
Deferred Credits and Other Liabilities of Discontinued Operations	—			—			—			2,278,251			—			2,278,251
Total Deferred Credits and Other Liabilities	(564,407		)	544,340			2,223,674			2,278,557			—			4,482,164
Total CONSOL Energy Inc. Stockholders’ Equity	3,953,792			5,014,313			5,337,349			255,492			(10,607,154		)	3,953,792
Noncontrolling Interest	—			(47		)	—			—			—			(47		)
Total Liabilities and Equity	$	10,354,372		$	5,871,608		$	4,424,818		$	3,082,350		$	(10,735,554	)	$	12,997,594
Condensed Statement of Cash Flows For the Year Ended December 31, 2012:
	Parent			CNX Gas			Other Subsidiary Guarantors			Non-			Elimination			Consolidated
				Guarantor						Guarantors
Net Cash Provided by (Used in) Continuing Operations	$	(58,410	)	$	82,036		$	412,293		$	21,423		$	—		$	457,342
Net Cash Provided by Discontinued Operating Activities	—			—			—			270,771			—			270,771
Net Cash Provided by (Used in) Operating Activities	$	(58,410	)	$	82,036		$	412,293		$	292,194		$	—		$	728,113
Cash Flows from Investing Activities:
Capital Expenditures	$	(49,973	)	$	(532,636	)	$	(662,888	)	$	—		$	—		$	(1,245,497	)
Change in Restricted Cash	—			—			(48,294		)	—			—			(48,294		)
Proceeds From Sales of Assets	—			360,129			285,238			254			—			645,621
(Investments in), net of Distributions from, Equity Affiliates	200,000			(37,400		)	13,949			—			(200,000		)	(23,451		)
Net Cash (Used in) Provided by Continuning Operations	$	150,027		$	(209,907	)	$	(411,995	)	$	254		$	(200,000	)	$	(671,621	)
Net Cash Used in Discontinued Investing Activities	—			—			—			(328,789		)	—			(328,789		)
Net Cash (Used in) Provided by Investing Activities	$	150,027		$	(209,907	)	$	(411,995	)	$	(328,535	)	$	(200,000	)	$	(1,000,410	)
Cash Flows from Financing Activities:
Dividends (Paid)	$	(142,278	)	$	(200,000	)	$	—		$	—		$	200,000		$	(142,278	)
Proceeds from Issuance of Common Stock	8,278			—			—			—			—			8,278
Other Financing Activities	22,532			(5,504		)	(1,408		)	37,404			—			53,024
Net Cash (Used in) Provided by Continuing Operations	$	(111,468	)	$	(205,504	)	$	(1,408	)	$	37,404		$	200,000		$	(80,976	)
Net Cash Used in Discontinued Financing Activities	—			—			—			(601		)	—			(601		)
Net Cash (Used in) Provided by Financing Activities	$	(111,468	)	$	(205,504	)	$	(1,408	)	$	36,803		$	200,000		$	(81,577	)
Income Statement for the Year Ended December 31, 2011:
	Parent			CNX Gas			Other			Non-			Elimination			Consolidated
	Issuer			Guarantor			Subsidiary			Guarantors
							Guarantors
Sales—Outside	$	—		$	751,767		$	3,009,104		$	234,998		$	(4,862	)	$	3,991,007
Sales—Gas Royalty Interests	—			66,929			—			—			—			66,929
Sales—Purchased Gas	$	—		$	4,344		$	—		$	—		$	—		$	4,344
Freight—Outside	—			—			175,633			—			—			175,633
Other Income	876,233			58,923			48,673			26,309			(871,006		)	139,132
Total Revenue and Other Income	876,233			881,963			3,233,410			261,307			(875,868		)	4,377,045
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion, and amortization shown below)	108,681			388,507			1,443,472			228,291			97,609			2,266,560
Gas Royalty Interests Costs	—			59,377			—			—			(46		)	59,331
Purchased Gas Costs	—			3,831			—			—			—			3,831
Related Party Activity	4,767			—			(25,720		)	1,986			18,967			—
Freight Expense	—			—			175,444			—			—			175,444
Selling, General and Administrative Expenses	—			50,429			62,729			1,485			—			114,643
Depreciation, Depletion and Amortization	12,194			206,821			209,159			2,403			—			430,577
Interest Expense	235,370			9,398			3,911			53			(388		)	248,344
Taxes Other Than Income	950			34,023			136,382			3,037			—			174,392
Transaction and Financing Fees	14,907			—			—			—			—			14,907
Loss on Debt Extinguishment	16,090			—			—			—			—			16,090
Total Costs	392,959			752,386			2,005,377			237,255			116,142			3,504,119
Earnings (Loss) Before Income Taxes	483,274			129,577			1,228,033			24,052			(992,010		)	872,926
Income Tax Expense (Benefit)	(149,223		)	51,876			279,500			9,098			—			191,251
Income (Loss) from Continuing Operations	632,497			77,701			948,533			14,954			(992,010		)	681,675
Loss from Discontinued Operations, net of tax	—			—			—			(49,178		)	—			(49,178		)
Net Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	632,497		$	77,701		$	948,533		$	(34,224	)	$	(992,010	)	$	632,497
Condensed Statement of Cash Flows For the Year Ended December 31, 2011:
	Parent			CNX Gas			Other Subsidiary Guarantors			Non-			Elimination			Consolidated
				Guarantor						Guarantors
Net Cash Provided by (Used in) Continuing Operations	$	530,444		$	329,360		$	465,847		$	3,220		$	—		$	1,328,871
Net Cash Provided by Discontinued Operating Activities	$	—		$	—		$	—		$	198,735		$	—		198,735
Net Cash Provided by (Used in) Operating Activities	$	530,444		$	329,360		$	465,847		$	201,955		$	—		$	1,527,606
Cash Flows from Investing Activities:
Capital Expenditures	$	(41,172	)	$	(664,612	)	$	(472,591	)	$	—		$	—		$	(1,178,375	)
Proceeds From Sales of Assets	10			746,956			(1,155		)	1,474			—			747,285
Distributions from, net of Investments in, Equity Affiliates	—			50,626			5,250			—			—			55,876
Net Cash (Used in) Provided by Continuing Operations	$	(41,162	)	$	132,970		$	(468,496	)	$	1,474		$	—		$	(375,214	)
Net Cash Used in Discontinued Investing Activities	—			—			—			(203,310		)	—			(203,310		)
Net Cash (Used in) Provided by Investing Activities	$	(41,162	)	$	132,970		$	(468,496	)	$	(201,836	)	$	—		$	(578,524	)
Cash Flows from Financing Activities:
Dividends Paid	$	(96,356	)	$	—		$	—		$	—		$	—		$	(96,356	)
Payments on Short-Term Borrowings	(155,000		)	(129,000		)	—			—			—			(284,000		)
Payments on Securitization Facility	(200,000		)	—			—			—			—			(200,000		)
Proceeds from Long-Term Notes	250,000			—			—			—			—			250,000
Payments on Long Term Notes, including Redemption Premium	(265,785		)	—			—			—			—			(265,785		)
Other Financing Activities	5,749			(13,162		)	(1,246		)	(793		)	—			(9,452		)
Net Cash Used in Continuing Operations	$	(461,392	)	$	(142,162	)	$	(1,246	)	$	(793	)	$	—		$	(605,593	)
Net Cash Used in Discontinued Financing Activities	—			—			—			(547		)	—			(547		)
Net Cash Used in Financing Activities	$	(461,392	)	$	(142,162	)	$	(1,246	)	$	(1,340	)	$	—		$	(606,140	)
Statement of Comprehensive Income for the Year Ended December 31, 2013:
	Parent			CNX Gas			Other			Non-			Elimination			Consolidated
				Guarantor			Subsidiary			Guarantors
							Guarantors
Net Income (Loss)	$	660,442		$	(2,624	)	$	455,935		$	585,616		$	(1,040,313	)	$	659,056
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	456,493			—			456,493			—			(456,493		)	456,493
Net Increase (Decrease) in the Value of Cash Flow Hedge	45,631			45,631			—			—			(45,631		)	45,631
Reclassification of Cash Flow Hedge from OCI to Earnings	(79,899		)	(79,899		)	—			—			79,899			(79,899		)
Other Comprehensive Income (Loss):	$	422,225		$	(34,268	)	$	456,493		$	—		$	(422,225	)	$	422,225
Comprehensive Income (Loss)	1,082,667			(36,892		)	912,428			585,616			(1,462,538		)	1,081,281
Less: Comprehensive Loss Attributable to Noncontrolling Interest	—			1,386			—			—			—			1,386
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	1,082,667		$	(35,506	)	$	912,428		$	585,616		$	(1,462,538	)	$	1,082,667
Statement of Comprehensive Income for the Year Ended December 31, 2012:
	Parent			CNX Gas			Other			Non-Guarantors			Elimination			Consolidated
				Guarantor			Subsidiary
							Guarantors
Net Income (Loss)	$	388,470		$	24,363		$	547,952		$	80,690		$	(653,402	)	$	388,073
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	129,231			—			129,231			—			(129,231		)	129,231
Net Increase (Decrease) in the Value of Cash Flow Hedge	114,240			114,240			—			—			(114,240		)	114,240
Reclassification of Cash Flow Hedge from OCI to Earnings	(189,259		)	(189,259		)	—			—			189,259			(189,259		)
Other Comprehensive Income (Loss):	$	54,212		$	(75,019	)	$	129,231		$	—		$	(54,212	)	$	54,212
Comprehensive Income (Loss)	$	442,682		$	(50,656	)	$	677,183		$	80,690		$	(707,614	)	$	442,285
Less: Comprehensive Income Attributable to Noncontrolling Interest	—			397			—			—			—			397
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	442,682		$	(50,259	)	$	677,183		$	80,690		$	(707,614	)	$	442,682
Statement of Comprehensive Income for the Year Ended December 31, 2011:
	Parent			CNX Gas			Other			Non-			Elimination			Consolidated
				Guarantor			Subsidiary			Guarantors
							Guarantors
Net Income (Loss)	$	632,497		$	77,701		$	948,533		$	(34,224	)	$	(992,010	)	$	632,497
Other Comprehensive Income (Loss):
Treasury Rate Lock	(96		)	—			—			—			—			(96		)
Actuarially Determined Long-Term Liability Adjustments	(32,813		)	—			(32,813		)	—			32,813			(32,813		)
Net Increase (Decrease) in the Value of Cash Flow Hedge	200,700			200,700			—			—			(200,700		)	200,700
Reclassification of Cash Flow Hedge from OCI to Earnings	(95,007		)	(95,007		)	—			—			95,007			(95,007		)
Other Comprehensive Income (Loss):	$	72,784		$	105,693		$	(32,813	)	$	—		$	(72,880	)	$	72,784
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	705,281		$	183,394		$	915,720		$	(34,224	)	$	(1,064,890	)	$	705,281

Related_Party

Related Party	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions Disclosure [Text Block]	'
	NOTE 27—RELATED PARTY TRANSACTIONS
	CONE Gathering LLC Related Party Transactions
	During the years ended December 31, 2013, 2012 and 2011, CONE Gathering LLC (CONE) a 50% owned affiliate, provided CNX Gas Company LLC (CNX Gas Company) gathering services in the ordinary course of business. Gathering services received from CONE were $34,062, $20,408 and $4,267 in the years ended December 31, 2013, 2012 and 2011 respectively, which were included in Cost of Goods Sold on the Consolidated Statements of Income.
	As of December 31, 2013 and 2012, CONSOL Energy and CNX Gas had a net payable of $5,448 and $3,142, respectively, due to CONE which is comprised of the following items:
		December 31,			December 31,
		2013			2012			Location on Balance Sheet
	Reimbursement for CONE Expenses	$	(2,168	)	$	(1,336	)	Accounts Receivable–Other
	Reimbursement for Services Provided to CONE	(265		)	(341		)	Accounts Receivable–Other
	CONE Gathering Capital Reimbursement	—			(18		)	Accounts Receivable–Other
	CONE Gathering Fee Payable	7,881			4,837			Accounts Payable
	Net Payable due CONE	$	5,448		$	3,142

Supplemental_Coal_Data_Unaudit

Supplemental Coal Data (Unaudited)	12 Months Ended
	Dec. 31, 2013
SUPPLEMENTAL COAL DATA [Abstract]	'
Mineral Industries Disclosures [Text Block]	'
	Supplemental Coal Data (unaudited)
		Millions of Tons
		For the Year Ended December 31,
		2013		2012		2011		2010		2009
	Proved and probable reserves at beginning of period	4,229		4,314		4,229		4,350		4,372
	Purchased reserves	1		—		6		4		5
	Reserves sold in place	(1,199	)	(155	)	—		(41	)	(3	)
	Production	(55	)	(55	)	(62	)	(62	)	(58	)
	Revisions and other changes	56		125		141		(22	)	34
	Consolidated proved and probable reserves at end of period*	3,032		4,229		4,314		4,229		4,350
	Proportionate share of proved and probable reserves of unconsolidated equity affiliates*	57		41		145		172		170
	______________
	*    Proved 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. Proved and probable reserves of unconsolidated equity affiliates are included in this number.
	CONSOL Energy's coal reserves are located in nearly every major coal-producing region in North America. At December 31, 2013, 382 million tons were assigned to mines either in production, temporarily idle, or under development. The proved and probable reserves at December 31, 2013 include 2,511 million tons of steam coal reserves, of which approximately 5 percent has a sulfur content equivalent to less than 1.2 pounds sulfur dioxide per million British thermal unit (Btu), 18 percent has a sulfur content equivalent to between 1.2 and 2.5 pounds sulfur dioxide per million Btu and an additional 77 percent has a sulfur content equivalent to greater than 2.5 pounds sulfur dioxide per million Btu. The reserves also include 521 million tons of metallurgical coal in consolidated reserves, of which approximately 49 percent has a sulfur content equivalent to less than 1.2 pounds sulfur dioxide per million Btu and an additional 51 percent has a sulfur content equivalent to between 1.2 and 2.5 pounds sulfur dioxide per million Btu. A significant portion of this metallurgical coal can also serve the steam coal market.

Supplemental_Gas_Data

Supplemental Gas Data	12 Months Ended
	Dec. 31, 2013
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 Financial Accounting Standards Board's Accounting Standards Update No. 2010-03, “Extractive Activities-Oil and Gas (Topic 932).”
	Capitalized Costs:
			As of December 31,
			2013				2012
	Proven properties		$	1,670,404			$	1,596,838
	Unproven properties		1,463,406				1,266,017
	Intangible drilling costs		1,937,336				1,550,297
	Wells and related equipment		688,548				492,364
	Gathering assets		1,058,008				1,006,882
	Gas Well Plugging		113,481				70,753
	Total Property, Plant and Equipment		6,931,183				5,983,151
	Accumulated Depreciation, Depletion and Amortization		(1,187,409		)		(959,291		)
	Net Capitalized Costs		$	5,743,774			$	5,023,860
	Costs incurred for property acquisition, exploration and development (*):
			For the Years Ended December 31,
			2013				2012				2011
	Property acquisitions
	Proven properties		$	—			$	50,005			$	6,673
	Unproven properties		260,477				28,634				58,731
	Development		629,100				339,608				463,401
	Exploration		95,413				130,312				131,419
	Total		$	984,990			$	548,559			$	660,224
	__________
	(*)	Includes costs incurred whether capitalized or expensed.
	Results of Operations for Producing Activities:
			For the Years Ended December 31,
			2013				2012				2011
	Production Revenue		$	740,869			$	660,442			$	751,767
	Royalty Interest Gas Revenue		63,202				49,405				66,929
	Purchased Gas Revenue		6,531				3,316				4,344
	Total Revenue		810,602				713,163				823,040
	Lifting Costs		96,600				90,835				106,477
	Ad Valorem, Severance & Other Taxes		28,677				26,145				26,261
	Gathering Costs		201,023				160,575				142,339
	Royalty Interest Gas Costs		53,069				38,922				59,377
	Direct Administrative, Selling & Other Costs		49,092				47,567				60,355
	Other Costs		61,119				39,029				18,095
	Purchased Gas Costs		4,837				2,711				3,831
	DD&A		229,562				202,956				206,821
	Total Costs		723,979				608,740				623,556
	Pre-tax Operating Income		86,623				104,423				199,484
	Income Taxes		32,917				39,827				79,873
	Results of Operations for Producing Activities excluding Corporate and Interest Costs		$	53,706			$	64,596			$	119,611
	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,
			2013				2012				2011
	Production (MMcfe)		172,380				156,325				153,504
	Average gas sales price before effects of financial settlements (per Mcf)		$	3.85			$	3			$	4.27
	Average effects of financial settlements (per Mcf)		$	0.45			$	1.22			$	0.63
	Average gas sales price including effects of financial settlements (per Mcf)		$	4.3			$	4.22			$	4.9
	Average lifting costs, excluding ad valorem and severance taxes (per Mcf)		$	0.56			$	0.58			$	0.68
	During the years ended December 31, 2013, 2012 and 2011, we drilled 139.8, 95.5, and 254.9 net development wells, respectively. There were no net dry development wells in 2013, 2012, or 2011.
	During the years ended December 31, 2013, 2012 and 2011, we drilled 5.5, 22.0, and 69.5 net exploratory wells, respectively. There were zero net dry exploratory wells in 2013, seven net dry exploratory wells in 2012 and two net dry exploratory wells in 2011.
	At December 31, 2013, there were 31.0 net development wells in the process of being drilled.
	At December 31, 2013, there were 1.0 net exploratory wells in the process of being drilled.
	CONSOL Energy is committed to provide 60.3 bcf of gas under existing sales contracts or agreements over the course of the next four years. CONSOL Energy expects 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, 2013, the number of producing wells, developed acreage and undeveloped acreage:
			Gross			Net(1)
	Producing Wells (including gob wells)		15,063			12,874
	Proved Developed Acreage		542,388			527,693
	Proved Undeveloped Acreage		105,019			59,346
	Unproved Acreage		5,396,659			4,212,030
Total Acreage		6,044,066			4,799,069
____________
-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 our 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 2013 gas reserves results, which are reported in the Supplemental Gas Data year ended December 31, 2013 Form 10-K, were audited by Netherland Sewell. 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
		(MMcfe)			(Mbbls)			(Mbbls)			(MMcfe)
Balance December 31, 2010		3,724,361			—			1,206			3,731,597
Revisions (a)		(76,486	)		25			416			(73,837	)
Price Changes		(9,976	)		—			—			(9,976	)
Extensions and Discoveries (c)		517,023			—			27			517,178
Production		(152,940	)		—			(94	)		(153,504	)
Sales of Reserves In-Place		(531,431	)		—			—			(531,431	)
Balance December 31, 2011 (d)		3,470,551			25			1,555			3,480,027
Revisions (b)		243,442			469			(710	)		241,989
Price Changes		(526,608	)		—			(1	)		(526,611	)
Extensions and Discoveries (c)		873,104			12,992			553			954,378
Production		(155,052	)		(111	)		(100	)		(156,325	)
Sales of Reserves In-Place		—			—			—			—
Balance December 31, 2012 (d)		3,905,437			13,375			1,297			3,993,458
Revisions (b)		176,045			(1,017	)		336			171,953
Price Changes		104,728			4			1			104,757
Extensions and Discoveries (c)		1,567,634			9,623			1,343			1,633,426
Production		(168,737	)		(438	)		(170	)		(172,380	)
Sales of Reserves In-Place		—			—			—			—
Balance December 31, 2013 (d)		5,585,107			21,547			2,807			5,731,214
Proved developed reserves:
31-Dec-11		2,126,330			—			1,579			2,135,805
31-Dec-12		2,149,912			1,717			878			2,165,483
31-Dec-13		2,470,412			5,939			1,375			2,514,294
Proved undeveloped reserves:
31-Dec-11		1,344,222			—			—			1,344,222
31-Dec-12		1,755,525			12,075			—			1,827,975
31-Dec-13		3,114,695			15,607			1,431			3,216,920
__________
(a)	Revisions are primarily due corporate planning changes that affect the number of wells (5-Years) forecasted to be drilled in our various areas and reservoirs. These changes were partially offset by upward revisions attributable to efficiencies in operations and well performance and had the total affect of a negative revision for 2011.
(b)	Revisions are primarily due to corporate planning changes that affect the number of wells (5-Years) forecasted to be drilled in our various areas and reservoirs. These changes along with upward revisions attributable to efficiencies in operations and well performance and had the total affect of the positive revisions for 2013 and 2012.
(c)	Extensions and Discoveries are primarily due to the addition of wells on our Marcellus Shale acreage more than one offset location away with reliable technology.
(d)	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 those reserves expected to be recovered through existing wells, with existing equipment and operating methods.
		For the Year
		Ended
		December 31,
		2013
Proved Undeveloped Reserves (MMcfe)
Beginning proved undeveloped reserves		1,827,975
Undeveloped reserves transferred to developed(a)		(230,333	)
Price Changes		11,410
Plan and other revisions (b)		88,187
Extension and discoveries (c)		1,519,681
Ending proved undeveloped reserves(d)		3,216,920
_________
(a)	During 2013, various exploration and development drilling and evaluations were completed. Approximately, $202,066 of capital was spent in the year ended December 31, 2013 related to undeveloped reserves that were transferred to developed.
(b) Plan and other revisions are due to corporate planning changes that affect the number of wells forecasted to be drilled in our various areas and reservoirs. 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 include approximately 683 Bcfe which were initially classified as unproved related to the DTI and Airport lease acquisitions.  These reserves were subsequently reclassified to proved undeveloped reserves utilizing reliable technologies which include wire line open hole log data, performance data, log cross sections, core data, and statistical analysis.  The statistical method utilized production performance from Consol Energy's and competitors' wells.  Geophysical data include data from Consol's wells, published documents, state data-sites and were used to confirm continuity of the formation.
(d)	Included in proved undeveloped reserves at December 31, 2013 are approximately 226,063 MMcfe of reserves that have been reported for more than five years. These reserves specifically relate to CONSOL Energy's Buchanan Mine, more specifically, 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. Evidence also exists that supports the continual operation of the mine beyond the current plan, unless there was an extreme circumstance which resulted from an external factor. These reasons constitute that specific circumstances exist to continue recognizing these reserves for CONSOL Energy.
The following table represents the capitalized exploratory well cost activity as indicated:
		December 31,
		2013
Costs pending the determination of proved reserves at December 31, 2013
For a period one year or less		$	17,728
For a period greater than one year but less than five years		—
For a period greater than five years		—
Total		$	17,728
		December 31,
		2013				2012				2011
Costs reclassified to wells, equipment and facilities based on the determination of proved reserves		$	12,140			$	14,447			$	189
Costs expensed due to determination of dry hole or abandonment of project		$	8,596			$	3,320			$	5,108
CONSOL Energy's proved gas reserves are located in the United States.

Supplemental_Quarterly_Info_Un

Supplemental Quarterly Info (Unaudited)	12 Months Ended
	Dec. 31, 2013
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,
		2013			2013			2013			2013
	Sales	$	799,997		$	759,948		$	753,080		$	772,258
	Freight Revenue	$	14,061		$	10,125		$	11,563		$	3,946
	Cost of Goods Sold and Other Operating Charges (including Gas Royalty Interests' Costs and Purchased Gas Costs)	$	612,000		$	552,126		$	560,247		$	562,386
	Freight Expense	$	14,061		$	10,125		$	11,563		$	3,946
	(Loss) Income from Continuing Operations	$	(3,725	)	$	8,562		$	(72,169	)	$	146,595
	Income (Loss) from Discontinued Operations	$	1,904		$	(21,375	)	$	8,120		$	591,144
	Net (Loss) Income Attributable to CONSOL Energy Inc Shareholders	$	(1,564	)	$	(12,526	)	$	(63,651	)	$	738,183
	Earnings Per Share
	Basic:
	(Loss) Income from Continuing Operations	$	(0.02	)	$	0.04		$	(0.31	)	$	0.64
	Income (Loss) from Discontinued Operations	$	0.01		$	(0.09	)	$	0.03		$	2.58
	Net (Loss) Income	$	(0.01	)	$	(0.05	)	$	(0.28	)	$	3.22
	Dilutive:
	(Loss) Income from Continuing Operations	$	(0.02	)	$	0.04		$	(0.31	)	$	0.64
	Income (Loss) from Discontinued Operations	$	0.01		$	(0.09	)	$	0.03		$	2.56
	Net (Loss) Income	$	(0.01	)	$	(0.05	)	$	(0.28	)	$	3.2
		Three Months Ended
		March 31,			June 30,			September 30,			December 31,
		2012			2012			2012			2012
	Sales	$	878,118		$	807,198		$	681,717		$	808,238
	Freight Revenue	$	49,293		$	49,472		$	27,430		$	13,426
	Cost of Goods Sold and Other Operating Charges (including Gas Royalty Interests' Costs and Purchased Gas Costs)	$	601,723		$	565,601		$	543,158		$	557,094
	Freight Expense	$	49,293		$	49,472		$	27,430		$	13,426
	Income (Loss) from Continuing Operations	$	80,906		$	155,789		$	(26,316	)	$	107,580
	Income (Loss) from Discontinued Operations	$	16,290		$	(3,050	)	$	14,814		$	42,060
	Net Income (Loss) Attributable to CONSOL Energy Inc Shareholders	$	97,196		$	152,739		$	(11,368	)	$	149,903
	Earnings Per Share
	Basic:
	Income (Loss) from Continuing Operations	$	0.36		$	0.68		$	(0.12	)	$	0.47
	Income (Loss) from Discontinued Operations	$	0.07		$	(0.01	)	$	0.07		$	0.19
	Net Income (Loss)	$	0.43		$	0.67		$	(0.05	)	$	0.66
	Dilutive:
	Income (Loss) from Continuing Operations	$	0.35		$	0.68		$	(0.12	)	$	0.47
	Income (Loss) from Discontinued Operations	$	0.07		$	(0.01	)	$	0.07		$	0.18
	Net Income (Loss)	$	0.42		$	0.67		$	(0.05	)	$	0.65

Significant_Accounting_Policy_

Significant Accounting Policy (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Consolidation, Policy [Policy Text Block]	'
	Basis of Consolidation:
	The Consolidated Financial Statements include the accounts of majority-owned and controlled subsidiaries. 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. Investments in oil and gas producing entities are accounted for under the proportionate consolidation method. The accounts of variable interest entities, where CONSOL Energy is the primary beneficiary, are included in the Consolidated Financial Statements. All significant intercompany transactions and accounts have been eliminated in consolidation.
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, and various disclosures. Actual results could differ from those estimates. The most significant estimates included in the preparation of the financial statements are related to business combinations, 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 coal and gas reserves value.
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 uncollectible amounts were not material in the periods presented. There were no material financing receivables with a contractual maturity greater than one year.
Inventory, Policy [Policy Text Block]	'
	Inventories:
	Inventories are stated at the lower of cost or market. 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 merchandise for resale is determined by the last-in, first-out (LIFO) method and includes industrial maintenance, repair and operating supplies for sale to third parties. The cost of supplies inventory is determined by the average cost method and includes operating and maintenance supplies to be used in our coal and gas operations.
Property, Plant and Equipment, Policy [Policy Text Block]	'
	Property, Plant and Equipment:
	CONSOL Energy uses the successful efforts method of accounting for 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 amortized on a units-of-production method. Units-of-production amortization rates are revised when events and circumstances indicate an adjustment is necessary, or at a minimum once a year; those 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. Costs of developing the first pit within a permitted area of a surface mine are capitalized. A surface mine is defined as the permitted mining area which includes various adjacent pits that share common infrastructure, processing equipment and a common ore body. Surface mine development costs include construction costs for entry roads, drilling, blasting and removal of overburden in developing the first cut for mountain stripping or box cuts for surface stripping. Stripping costs incurred during the production phase of a mine are expensed as incurred.
	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. We employ 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 a 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 generally are extended automatically to 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. We also make advance payments (advanced mining royalties) to lessors under certain lease agreements that are recoupable against future production, and we make payments that are generally based upon a specified rate per ton or a percentage of gross realization from the sale of the coal. We evaluate our properties periodically for impairment issues or whenever events or circumstances indicate that the carrying amount may not be recoverable.
	Advance mining royalties are advance payments made to lessors under terms of mineral lease agreements that are recoupable against future production using the units-of-production method. Depletion of leased coal interests is computed using the units-of-production method over proven and probable coal reserves. Advance mining royalties and leased coal interests are evaluated periodically, or at a minimum once a 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.
	When properties are retired or otherwise disposed, the related cost and accumulated depreciation are removed from the respective accounts and any profit or loss on disposition is recognized as gain or loss in other income.
	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 reserve tons assigned and accessible to the mine. Proven and probable coal reserves exclude non-recoverable coal reserves and anticipated processing losses. 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 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, 2013 and 2012, 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. There was no impairment expense recognized for the years ended December 31, 2013, 2012, and 201
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, an evaluation to determine the largest amount of benefit, determined on a cumulative probability basis that is more likely than not to be realized upon ultimate settlement, is determined. A previously recognized tax position is derecognized 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 we believe 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.
Cash and Cash Equivalents, Restricted Cash and Cash Equivalents, Policy [Policy Text Block]	'
	Restricted Cash:
	For the year ended December 31, 2012, restricted cash included a $48,294 deposit into escrow associated with the Ram River Asset sale. The deposit was released upon CONSOL Energy's filing of all Canadian tax returns associated with the transaction. For the year ended December 31, 2012, restricted cash also included a $20,379 deposit into escrow as security to perfect CONSOL Energy's appeal to the Pennsylvania Environmental Hearing Board under the applicable statute related to the Ryerson dam litigation .
Pension and Other Postretirement Plans, Nonpension Benefits, Policy [Policy Text Block]	'
	Postretirement Benefits Other Than Pensions:
	Postretirement benefits other than pensions, except for those established pursuant to the Coal Industry Retiree Health Benefit Act of 1992 (the Health Benefit 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. Postretirement benefit obligations established by the Health Benefit Act are treated as a multi-employer plan which requires expense to be recorded for the associated obligations as payments are made.
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]	'
	Mine Closing, Reclamation and Gas Well Closing Costs:
	CONSOL Energy accrues for mine closing costs, reclamation costs, perpetual water care costs and dismantling and removing costs of gas related facilities 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. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. Depreciation 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 Cost of Goods Sold and Other Operating Charges on the Consolidated Statements of Income. Asset retirement obligations primarily relate to the closure of mines and gas wells, which includes treatment of water and the reclamation of land upon exhaustion of gas and coal reserves.
	Accrued mine closing costs, perpetual care costs, reclamation and costs of dismantling and removing gas related facilities are regularly reviewed by management and are revised for changes in future estimated costs and regulatory requirements.
	CONSOL Energy accrues for reclamation, mine closing costs, perpetual water care costs and dismantling and removing costs of gas related facilities 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, net of the associated accumulated depreciation. The obligation for asset retirements is included in Mine Closing, Reclamation, Gas Well Closing and Other Accrued Liabilities on the Consolidated Balance Sheets.
Pension and Other Postretirement Plans, Pensions, Policy [Policy Text Block]	'
	Retirement Plans:
	CONSOL Energy has non-contributory defined benefit retirement plans covering substantially all salaried employees. 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 period. 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, Policy [Policy Text Block]	'
	Revenue Recognition:
	Revenues are recognized when title passes to the customers. For gas sales, this occurs at the contractual point of delivery. For domestic coal sales, this generally occurs when coal is loaded at mine or offsite storage locations. For export coal sales, this generally occurs when coal is loaded onto marine vessels at terminal locations. For industrial supplies and equipment sales, this generally occurs when the products are delivered. For terminal, land and research and development, revenue is recognized generally as the service is provided to the customer.
	CONSOL Energy has operational gas-balancing agreements with various interstate pipelines. 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 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 which qualify for netting under the Nonmonetary Transactions Topic of the FASB Accounting Standards Codification and are therefore reflected net on the income statement in Cost of Goods Sold and Other Operating Charges.
	CONSOL Energy purchases gas produced by third parties at market prices less a fee. The gas purchased from third party producers is then resold to end users or gas marketers at current market prices. These revenues and expenses are recorded gross as Purchased Gas Revenue and Purchased Gas Costs in the Consolidated Statements of Income. Purchased gas revenue is recognized when title passes to the customer. Purchased gas costs are recognized when title passes to CONSOL Energy from the third party producer.
	Royalty Interest Gas Sales represent the revenues related to the portion of production belonging to royalty interest owners sold by CONSOL Energy.
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 Revenue and Freight Expense, respectively.
Revenue Recognition, Services, Royalty Fees [Policy Text Block]	'
	Royalty Recognition:
	Royalty expenses for gas rights are included in Gas Royalty Interest Costs when the related revenue for the gas sale is recognized. Royalty expenses for coal rights are included in Cost of Goods Sold and Other Operating Charges when the related revenue for the coal sale is recognized. These royalty expenses are paid in cash in accordance with the terms of each agreement. Revenues for gas and coal sold related to production under royalty contracts, versus owned by CONSOL Energy, are recorded on a gross basis.
Commitments and Contingencies, Policy [Policy Text Block]	'
	Contingencies:
	CONSOL Energy, or our subsidiaries, from time to time 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 managements 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.
Stockholders' Equity, Policy [Policy Text Block]	'
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 19–Stock Based Compensation for further discussio
Earnings Per Share, Policy [Policy Text Block]	'
	Earnings per Share:
	Basic earnings per share are computed by dividing net income 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 the assumed exercise of stock options and performance stock options and the assumed vesting of restricted and performance stock 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 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:
	CONSOL Energy accounts for derivative instruments in accordance with the Derivatives and Hedging Topic of the FASB Accounting Standards Codification. This requires CONSOL Energy to measure every derivative instrument (including certain derivative instruments embedded in other contracts) at fair value and record them in the balance sheet as either an asset or liability. Changes in fair value of derivatives are recorded currently in earnings unless special hedge accounting criteria are met. For derivatives designated as cash flow hedges, the effective portions of changes in fair value of the derivative are reported in other comprehensive income. The ineffective portions of hedges are recognized in earnings in the current period.
	CONSOL Energy formally assesses, both at inception of the hedge and on an ongoing basis, whether each derivative is highly effective in offsetting changes in fair values or cash flows of the hedged item. If it is determined that a derivative is not highly effective as a hedge, or if a derivative ceases to be a highly effective hedge, CONSOL Energy will discontinue hedge accounting prospectively.
Business Combinations Policy [Policy Text Block]	'
	Accounting for Business Combinations:
	CONSOL Energy accounts for its business acquisitions under the acquisition method of accounting consistent with the requirements of the Business Combination Topic of the FASB Accounting Standards Codification. The total cost of acquisitions is allocated to the underlying identifiable net assets, based on their respective estimated fair values. Determining the fair value of assets acquired and liabilities assumed requires management's judgment and often involves the use of significant estimates and assumptions with respect to future cash inflows and outflows, discount rates and asset lives, among other items.
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 majority-owned and controlled subsidiaries. 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. Investments in oil and gas producing entities are accounted for under the proportionate consolidation method. The accounts of variable interest entities, where CONSOL Energy is the primary beneficiary, are included in the Consolidated Financial Statements. All significant intercompany transactions and accounts have been eliminated in consolidation.
	Discontinued Operations
	Businesses to be divested are classified in the Consolidated Financial Statements as either discontinued operations or held for sale. 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 Sheet and to discontinued operations on the Consolidated Statements of Income and Cash Flows, respectively, for all periods presented. The gains or losses associated with these divested businesses are recorded in discontinued operations the Consolidated Statements of Income. Additionally, the accompanying notes, including segment information do not include the assets, liabilities, or operating results of businesses classified as discontinued operations for all periods presented. Management does not expect any significant continuing involvement with these businesses following their divestiture, and these businesses are expected to be disposed of within one year.
	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, and various disclosures. Actual results could differ from those estimates. The most significant estimates included in the preparation of the financial statements are related to business combinations, 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 coal and gas reserves value.
	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 uncollectible amounts were not material in the periods presented. There were no material financing receivables with a contractual maturity greater than one year.
	Inventories:
	Inventories are stated at the lower of cost or market. 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 merchandise for resale is determined by the last-in, first-out (LIFO) method and includes industrial maintenance, repair and operating supplies for sale to third parties. The cost of supplies inventory is determined by the average cost method and includes operating and maintenance supplies to be used in our coal and gas operations.
	Property, Plant and Equipment:
	CONSOL Energy uses the successful efforts method of accounting for 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 amortized on a units-of-production method. Units-of-production amortization rates are revised when events and circumstances indicate an adjustment is necessary, or at a minimum once a year; those 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. Costs of developing the first pit within a permitted area of a surface mine are capitalized. A surface mine is defined as the permitted mining area which includes various adjacent pits that share common infrastructure, processing equipment and a common ore body. Surface mine development costs include construction costs for entry roads, drilling, blasting and removal of overburden in developing the first cut for mountain stripping or box cuts for surface stripping. Stripping costs incurred during the production phase of a mine are expensed as incurred.
	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. We employ 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 a 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 generally are extended automatically to 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. We also make advance payments (advanced mining royalties) to lessors under certain lease agreements that are recoupable against future production, and we make payments that are generally based upon a specified rate per ton or a percentage of gross realization from the sale of the coal. We evaluate our properties periodically for impairment issues or whenever events or circumstances indicate that the carrying amount may not be recoverable.
	Advance mining royalties are advance payments made to lessors under terms of mineral lease agreements that are recoupable against future production using the units-of-production method. Depletion of leased coal interests is computed using the units-of-production method over proven and probable coal reserves. Advance mining royalties and leased coal interests are evaluated periodically, or at a minimum once a 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.
	When properties are retired or otherwise disposed, the related cost and accumulated depreciation are removed from the respective accounts and any profit or loss on disposition is recognized as gain or loss in other income.
	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 reserve tons assigned and accessible to the mine. Proven and probable coal reserves exclude non-recoverable coal reserves and anticipated processing losses. 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 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.
	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. There was no impairment expense recognized for the years ended December 31, 2013, 2012, and 2011.
	Capitalized costs of unproved gas properties are evaluated for recoverability on a prospect 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. Exploration expense was $61,119, $39,029 and $18,095 for the years ended December 31, 2013, 2012 and 2011, respectively, which was primarily related to lease expirations.
	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, an evaluation to determine the largest amount of benefit, determined on a cumulative probability basis that is more likely than not to be realized upon ultimate settlement, is determined. A previously recognized tax position is derecognized 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 we believe 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.
	Restricted Cash:
	For the year ended December 31, 2012, restricted cash included a $48,294 deposit into escrow associated with the Ram River Asset sale. The deposit was released upon CONSOL Energy's filing of all Canadian tax returns associated with the transaction. For the year ended December 31, 2012, restricted cash also included a $20,379 deposit into escrow as security to perfect CONSOL Energy's appeal to the Pennsylvania Environmental Hearing Board under the applicable statute related to the Ryerson dam litigation . Both escrow accounts were released in the year ended December 31, 2013 and are reflected in the Change in Restricted Cash line included in Net Cash Used in Investing Activities of the Consolidated Statement of Cash Flows.
	Postretirement Benefits Other Than Pensions:
	Postretirement benefits other than pensions, except for those established pursuant to the Coal Industry Retiree Health Benefit Act of 1992 (the Health Benefit 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. Postretirement benefit obligations established by the Health Benefit Act are treated as a multi-employer plan which requires expense to be recorded for the associated obligations as payments are made. 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.
	Mine Closing, Reclamation and Gas Well Closing Costs:
	CONSOL Energy accrues for mine closing costs, reclamation costs, perpetual water care costs and dismantling and removing costs of gas related facilities 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. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. Depreciation 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 Cost of Goods Sold and Other Operating Charges on the Consolidated Statements of Income. Asset retirement obligations primarily relate to the closure of mines and gas wells, which includes treatment of water and the reclamation of land upon exhaustion of gas and coal reserves.
	Accrued mine closing costs, perpetual care costs, reclamation and costs of dismantling and removing gas related facilities are regularly reviewed by management and are revised for changes in future estimated costs and regulatory requirements.
	Retirement Plans:
	CONSOL Energy has non-contributory defined benefit retirement plans covering substantially all salaried employees. 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 period. 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 gas sales, this occurs at the contractual point of delivery. For domestic coal sales, this generally occurs when coal is loaded at mine or offsite storage locations. For export coal sales, this generally occurs when coal is loaded onto marine vessels at terminal locations. For industrial supplies and equipment sales, this generally occurs when the products are delivered. For terminal, land and research and development, revenue is recognized generally as the service is provided to the customer.
	CONSOL Energy has operational gas-balancing agreements with various interstate pipelines. 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 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 which qualify for netting under the Nonmonetary Transactions Topic of the FASB Accounting Standards Codification and are therefore reflected net on the income statement in Cost of Goods Sold and Other Operating Charges.
	CONSOL Energy purchases gas produced by third parties at market prices less a fee. The gas purchased from third party producers is then resold to end users or gas marketers at current market prices. These revenues and expenses are recorded gross as Purchased Gas Revenue and Purchased Gas Costs in the Consolidated Statements of Income. Purchased gas revenue is recognized when title passes to the customer. Purchased gas costs are recognized when title passes to CONSOL Energy from the third party producer.
	Royalty Interest Gas Sales represent the revenues related to the portion of production belonging to royalty interest owners sold by CONSOL Energy.
	Freight Revenue and Expense:
	Shipping and handling costs invoiced to coal customers and paid to third-party carriers are recorded as Freight Revenue and Freight Expense, respectively.
	Royalty Recognition:
	Royalty expenses for gas rights are included in Gas Royalty Interest Costs when the related revenue for the gas sale is recognized. Royalty expenses for coal rights are included in Cost of Goods Sold and Other Operating Charges when the related revenue for the coal sale is recognized. These royalty expenses are paid in cash in accordance with the terms of each agreement. Revenues for gas and coal sold related to production under royalty contracts, versus owned by CONSOL Energy, are recorded on a gross basis.
	Contingencies:
	CONSOL Energy, or our subsidiaries, from time to time 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 managements 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 19–Stock Based Compensation for further discussion.
	Earnings per Share:
	Basic earnings per share are computed by dividing net income 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 the assumed exercise of stock options and performance stock options and the assumed vesting of restricted and performance stock 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 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,
	2013		2012			2011
Anti-Dilutive Options	1,976,549		2,411,963			1,156,018
Anti-Dilutive Restricted Stock Units	282,230		8,822			—
Anti-Dilutive Performance Share Units	—		445,847			—
Anti-Dilutive Performance Share Options	802,804		501,744			—
	3,061,583		3,368,376			1,156,018
The computations for basic and dilutive earnings per share are as follows:
	For the Years Ended
	December 31,
	2013			2012				2011
Income from Continuing Operations	79,264			317,959				681,675
Income (Loss) from Discontinuing Operations	579,792			70,114				(49,178		)
Less: Net Loss Attributable to Noncontrolling Interest	1,386			397				—
Net income attributable to CONSOL Energy Inc. shareholders	$	660,442		$	388,470			$	632,497
Weighted average shares of common stock outstanding:
Basic	228,728,628			227,593,524				226,680,369
Effect of stock-based compensation awards	1,349,314			1,548,243				2,323,230
Dilutive	230,077,942			229,141,767				229,003,599
Earnings per share:
Basic (Continuing Operations)	$	0.35		$	1.4			$	3.01
Basic (Discontinuing Operations)	2.54			0.31				(0.22		)
Total Basic	$	2.89		$	1.71			$	2.79
Dilutive (Continuing Operations)	$	0.35		$	1.39			$	2.98
Dilutive (Discontinuing Operations)	2.52			0.31				(0.22		)
Total Dilutive	$	2.87		$	1.7			$	2.76
Shares of common stock outstanding were as follows:
		2013		2012			2011
Balance, beginning of year		228,094,712		227,056,212			226,162,133
Issuance related to Stock-Based Compensation(1)		1,051,024		1,038,500			894,079
Balance, end of year		229,145,736		228,094,712			227,056,212
(1) See Note 19–Stock-Based Compensation for additional information.
Other Comprehensive Income (Loss):
Changes in Accumulated Other Comprehensive Income / (Loss) by component, net of tax, were as follows:
	Gains and Losses on Cash Flow Hedges					Postretirement Benefits					Total
Balance at December 31, 2012	$	76,761				$	(824,103			)	$	(747,342	)
Other comprehensive income before reclassifications	45,631					140,250					185,881
Amounts reclassified from accumulated other comprehensive income	(79,899			)		316,243					236,344
Other comprehensive income	(34,268			)		456,493					422,225
Balance at December 31, 2013	$	42,493				$	(367,610			)	$	(325,117	)
The following table shows the reclassification of adjustments out of Accumulated Other Comprehensive Loss:
	For the Years Ended December 31,
	2013					2012					2011
Derivative Instruments (Note 23)
Natural gas price swaps	$	(133,889		)		$	(310,743			)	$	(155,932	)
Tax benefit	53,990					121,484					60,925
Net of tax	$	(79,899		)		$	(189,259			)	$	(95,007	)
Actuarially Determined Long-Term Liability Adjustments*(Note 16 and Note 17)
Amortization of prior service costs	$	(32,164		)		$	(53,853			)	$	(47,792	)
Recognized net actuarial loss	86,481					106,299					119,262
Settlement loss	39,482					—					—
Total	93,799					52,446					71,470
Tax expense	(35,806			)		(19,720				)	(27,416		)
Net of tax	$	57,993				$	32,726				$	44,054
*Excludes amounts related to the remeasurement of the Actuarially Determined Long-Term Liabilities for the years ended December 31, 2013, December 31, 2012 and December 31, 2011. Excludes $258,250, net of tax, of reclassifications of adjustments out of accumulated other comprehensive income related to discontinued operations for the year ended December 31, 2013.
Accounting for Derivative Instruments:
CONSOL Energy accounts for derivative instruments in accordance with the Derivatives and Hedging Topic of the FASB Accounting Standards Codification. This requires CONSOL Energy to measure every derivative instrument (including certain derivative instruments embedded in other contracts) at fair value and record them in the balance sheet as either an asset or liability. Changes in fair value of derivatives are recorded currently in earnings unless special hedge accounting criteria are met. For derivatives designated as cash flow hedges, the effective portions of changes in fair value of the derivative are reported in other comprehensive income. The ineffective portions of hedges are recognized in earnings in the current period.
CONSOL Energy formally assesses, both at inception of the hedge and on an ongoing basis, whether each derivative is highly effective in offsetting changes in fair values or cash flows of the hedged item. If it is determined that a derivative is not highly effective as a hedge, or if a derivative ceases to be a highly effective hedge, CONSOL Energy will discontinue hedge accounting prospectively.
Accounting for Business Combinations:
CONSOL Energy accounts for its business acquisitions under the acquisition method of accounting consistent with the requirements of the Business Combination Topic of the FASB Accounting Standards Codification. The total cost of acquisitions is allocated to the underlying identifiable net assets, based on their respective estimated fair values. Determining the fair value of assets acquired and liabilities assumed requires management's judgment and often involves the use of significant estimates and assumptions with respect to future cash inflows and outflows, discount rates and asset lives, among other items.
Recent Accounting Pronouncements:
In February 2013, the Financial Accounting Standards Board issued Update 2013-04 - Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date. The objective of the amendments in this update is to provide guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of this guidance is fixed at the reporting date, except for obligations addressed within existing guidance in U.S. generally accepted accounting principles (GAAP). The guidance in this update requires an entity to measure obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of this guidance is fixed at the reporting date, as the sum of the following: (a.) The amount the reporting entity agreed to pay on the basis of its arrangement amount with its co-obligors, and (b.) Any additional amount the reporting entity expects to pay on behalf of its co-obligors. The guidance in this update also requires an entity to disclose the nature and amount of the obligation as well as other information about those obligations. The amendments in this update are effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The amendments in this update should be applied retrospectively to all prior periods presented for those obligations resulting from joint and several liability arrangements within the update's scope that exist at the beginning of an entity's fiscal year of adoption. We believe adoption of this new guidance will not have a material impact on CONSOL Energy's financial statements.
Reclassifications:
Certain amounts in prior periods have been reclassified to conform with the report classifications of the years ended December 31, 2013, 2012 and 2011, respectively, with no effect on previously reported net income or stockholders' equity.
Subsequent Events:
We have evaluated all subsequent events through the date the financial statements were issued. No material recognized or non-recognizable subsequent events were identified.

Mine_Closing_Reclamation_and_G

Mine Closing, Reclamation, and Gas Well Closing ARO Accounting Policy (Policies)	12 Months Ended
	Dec. 31, 2013
MINE CLOSING, RECLAMATION & GAS WELL CLOSING [Abstract]	'
Asset Retirement Obligation Disclosure [Text Block]	'
	NOTE 8—MINE CLOSING, RECLAMATION & GAS WELL CLOSING:
	CONSOL Energy accrues for reclamation, mine closing costs, perpetual water care costs and dismantling and removing costs of gas related facilities 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, net of the associated accumulated depreciation. The obligation for asset retirements is included in Mine Closing, Reclamation, Gas Well Closing and Other Accrued Liabilities on the Consolidated Balance Sheets.
	The reconciliation of changes in the asset retirement obligations at December 31, 2013 and 2012 is as follows:
		As of December 31,
		2013			2012
	Balance at beginning of period	$	539,177		$	500,648
	Accretion expense	41,909			37,922
	Payments	(38,198		)	(36,086		)
	Revisions in estimated cash flows	42,558			40,832
	Other	15,429			(4,139		)
	Balance at end of period	$	600,875		$	539,177
	For the year ended December 31, 2013, Other includes $15,429 related to a contractual agreement between CONSOL Energy and Murray Energy whereas CONSOL Energy will retain the obligation of water treatment at sixteen locations sold to Murray Energy.
	For the year ended December 31, 2012, Other includes $(4,139) related to the disposition of the non-producing Elk Creek property. See Note 3 - Acquisitions and Dispositions for additional details.
Asset Retirement Obligations, Policy [Policy Text Block]	'
	Mine Closing, Reclamation and Gas Well Closing Costs:
	CONSOL Energy accrues for mine closing costs, reclamation costs, perpetual water care costs and dismantling and removing costs of gas related facilities 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. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. Depreciation 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 Cost of Goods Sold and Other Operating Charges on the Consolidated Statements of Income. Asset retirement obligations primarily relate to the closure of mines and gas wells, which includes treatment of water and the reclamation of land upon exhaustion of gas and coal reserves.
	Accrued mine closing costs, perpetual care costs, reclamation and costs of dismantling and removing gas related facilities are regularly reviewed by management and are revised for changes in future estimated costs and regulatory requirements.
	CONSOL Energy accrues for reclamation, mine closing costs, perpetual water care costs and dismantling and removing costs of gas related facilities 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, net of the associated accumulated depreciation. The obligation for asset retirements is included in Mine Closing, Reclamation, Gas Well 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, 2013
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 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 amortized on a units-of-production method. Units-of-production amortization rates are revised when events and circumstances indicate an adjustment is necessary, or at a minimum once a year; those 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. Costs of developing the first pit within a permitted area of a surface mine are capitalized. A surface mine is defined as the permitted mining area which includes various adjacent pits that share common infrastructure, processing equipment and a common ore body. Surface mine development costs include construction costs for entry roads, drilling, blasting and removal of overburden in developing the first cut for mountain stripping or box cuts for surface stripping. Stripping costs incurred during the production phase of a mine are expensed as incurred.
	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. We employ 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 a 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 generally are extended automatically to 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. We also make advance payments (advanced mining royalties) to lessors under certain lease agreements that are recoupable against future production, and we make payments that are generally based upon a specified rate per ton or a percentage of gross realization from the sale of the coal. We evaluate our properties periodically for impairment issues or whenever events or circumstances indicate that the carrying amount may not be recoverable.
	Advance mining royalties are advance payments made to lessors under terms of mineral lease agreements that are recoupable against future production using the units-of-production method. Depletion of leased coal interests is computed using the units-of-production method over proven and probable coal reserves. Advance mining royalties and leased coal interests are evaluated periodically, or at a minimum once a 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.
	When properties are retired or otherwise disposed, the related cost and accumulated depreciation are removed from the respective accounts and any profit or loss on disposition is recognized as gain or loss in other income.
	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 reserve tons assigned and accessible to the mine. Proven and probable coal reserves exclude non-recoverable coal reserves and anticipated processing losses. 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 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, 2013 and 2012, respectively.

Derivatives_Derivatives_Policy

Derivatives Derivatives Policy (Policies)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivatives, Reporting of Derivative Activity [Policy Text Block]	'
	CONSOL Energy formally assesses both at inception of the hedge and on an ongoing basis whether each derivative is highly effective in offsetting changes in the fair values or the cash flows of the hedged item. If it is determined that a derivative is not highly effective as a hedge or if a derivative ceases to be a highly effective hedge, CONSOL Energy will discontinue hedge accounting prospectively.

Significant_Accounting_Policy_1

Significant Accounting Policy (Tables)	12 Months Ended
	Dec. 31, 2013
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,
		2013		2012			2011
	Anti-Dilutive Options	1,976,549		2,411,963			1,156,018
	Anti-Dilutive Restricted Stock Units	282,230		8,822			—
	Anti-Dilutive Performance Share Units	—		445,847			—
	Anti-Dilutive Performance Share Options	802,804		501,744			—
		3,061,583		3,368,376			1,156,018
Schedule of Basic and Dilutive Earnings Per Share [Text Block]	'
		For the Years Ended
		December 31,
		2013			2012				2011
	Income from Continuing Operations	79,264			317,959				681,675
	Income (Loss) from Discontinuing Operations	579,792			70,114				(49,178		)
	Less: Net Loss Attributable to Noncontrolling Interest	1,386			397				—
	Net income attributable to CONSOL Energy Inc. shareholders	$	660,442		$	388,470			$	632,497
	Weighted average shares of common stock outstanding:
	Basic	228,728,628			227,593,524				226,680,369
	Effect of stock-based compensation awards	1,349,314			1,548,243				2,323,230
	Dilutive	230,077,942			229,141,767				229,003,599
	Earnings per share:
	Basic (Continuing Operations)	$	0.35		$	1.4			$	3.01
	Basic (Discontinuing Operations)	2.54			0.31				(0.22		)
	Total Basic	$	2.89		$	1.71			$	2.79
	Dilutive (Continuing Operations)	$	0.35		$	1.39			$	2.98
	Dilutive (Discontinuing Operations)	2.52			0.31				(0.22		)
	Total Dilutive	$	2.87		$	1.7			$	2.76
Schedule of Stock by Class [Table Text Block]	'
	Shares of common stock outstanding were as follows:
			2013		2012			2011
	Balance, beginning of year		228,094,712		227,056,212			226,162,133
	Issuance related to Stock-Based Compensation(1)		1,051,024		1,038,500			894,079
	Balance, end of year		229,145,736		228,094,712			227,056,212
	(1) See Note 19–Stock-Based Compensation for additional information.

Discontinued_Operations_Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	'
		For the Years Ended December 31,
		2013			2012			2011
	Sales	$	2,598,875		$	1,717,926		$	1,740,196
	Income (Loss) from operations before income taxes	$	969,685		$	90,587		$	(84,972	)
	Income taxes (expense) benefit	(389,893		)	(20,473		)	35,794
	Income (loss) from discontinued operations	$	579,792		$	70,114		$	(49,178	)
	The major classes of assets and liabilities of discontinued operations are as follows:
		31-Dec-13			31-Dec-12
	Assets:
	Inventory	$	—		$	76,958
	Current Deferred Income Tax Asset	—			63,327
	Other Current Assets	—			8,945
	Properties, plants, and equipment	—			1,682,909
	Deferred Income Tax Asset	—			771,270
	Other assets	—			10,842
	Assets of discontinued operations	$	—		$	2,614,251
	Liabilities:
	Current Liabilities	$	28,239		$	233,214
	Long Term Debt	—			1,573
	Postretirement Benefits Other Than Pensions	—			1,949,801
	Pneumoconiosis Benefits	—			60,645
	Workers' Compensation	—			95,252
	Mine Closing	—			156,909
	Other liabilities	—			15,644
	Liabilities of discontinued operations	$	28,239		$	2,513,038

Acquisitions_and_Dispositions_

Acquisitions and Dispositions (Tables)	12 Months Ended
	Dec. 31, 2013
Noble JV [Member]	'
Business Acquisition [Line Items]	'
Business Acquisition, Pro Forma Information	'
Dominion Acquisition Member	'
Business Acquisition [Line Items]	'
Business Acquisition, Pro Forma Information	'
	.

Other_Income_Tables

Other Income (Tables)	12 Months Ended
	Dec. 31, 2013
Component of Operating Income [Abstract]	'
Schedule of Other Nonoperating Income, by Component [Table Text Block]	'
		For the Years Ended December 31,
		2013		2012		2011
	Gain on disposition of assets (a)	$	67,480	$	282,006	$	45,673
	Equity in earnings of affiliates	33,133		27,048		24,663
	Royalty income	16,906		16,853		17,969
	Interest income	15,889		28,937		8,919
	Pennsylvania Turnpike Settlement	9,000		—		—
	Right-of-way issuance	4,536		3,966		12,157
	Other	32,019		36,366		29,751
	Total Other Income	$	178,963	$	395,176	$	139,132
	(a) See Note 3 - Acquisitions and Dispositions for additional information.

Interest_Expense_Tables

Interest Expense (Tables)	12 Months Ended
	Dec. 31, 2013
Interest Expense [Abstract]	'
Schedule of Other Nonoperating Expense, by Component [Table Text Block]	'
		For the Years Ended December 31,
		2013			2012			2011
	Interest on debt	$	260,233		$	256,800		$	264,080
	Interest on other payables	2,682			1,296			(189		)
	Interest capitalized	(43,717		)	(38,054		)	(15,547		)
	Total Interest Expense	$	219,198		$	220,042		$	248,344

Taxes_Other_Than_Income_Tables

Taxes Other Than Income (Tables)	12 Months Ended
	Dec. 31, 2013
TAXES OTHER THAN INCOME [Abstract]	'
Taxes Other Than Income [Table Text Block]	'
		For the Years Ended December 31,
		2013			2012			2011
	Production taxes	$	84,984		$	77,629		$	99,442
	Property taxes	36,338			43,679			35,495
	Payroll taxes	32,779			32,478			33,155
	Capital stock & franchise tax	6,833			9,013			3,670
	Virginia employment enhancement tax credit	(4,683		)	(4,311		)	(6,109		)
	Other	4,376			3,938			8,739
	Total Taxes Other Than Income	$	160,627		$	162,426		$	174,392

Mine_Closing_Reclamation_and_G1

Mine Closing, Reclamation, and Gas Well Closing (Tables)	12 Months Ended
	Dec. 31, 2013
MINE CLOSING, RECLAMATION & GAS WELL CLOSING [Abstract]	'
Schedule of Change in Asset Retirement Obligation [Table Text Block]	'
		As of December 31,
		2013			2012
	Balance at beginning of period	$	539,177		$	500,648
	Accretion expense	41,909			37,922
	Payments	(38,198		)	(36,086		)
	Revisions in estimated cash flows	42,558			40,832
	Other	15,429			(4,139		)
	Balance at end of period	$	600,875		$	539,177

Inventories_Tables

Inventories (Tables)	12 Months Ended
	Dec. 31, 2013
Inventory Disclosure [Abstract]	'
Schedule of Inventory, Current [Table Text Block]	'
		December 31,
		2013		2012
	Coal	$	31,944	$	53,452
	Merchandise for resale	38,263		35,363
	Supplies	87,707		81,993
	Total Inventories	$	157,914	$	170,808

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment	'
		December 31,
		2013				2012
	Coal & Other Plant and Equipment	$	3,681,051			$	3,414,940
	Intangible Drilling Cost	1,937,336				1,550,297
	Proven Properties	1,670,404				1,596,838
	Unproven Properties	1,463,406				1,266,017
	Coal Properties and Surface Lands	1,404,056				1,164,107
	Gathering Equipment	1,058,008				1,006,882
	Wells and Related Equipment	688,548				492,364
	Airshafts	397,466				366,054
	Leased Coal Lands	393,372				529,758
	Coal Advance Mining Royalties	381,348				381,343
	Mine Development	354,607				262,511
	Other Gas Assets	126,239				82,217
	Gas Advance Royalties	22,668				8,229
	Total Property, Plant and Equipment	13,578,509				12,121,557
	Less Accumulated Depreciation, Depletion and Amortization	4,136,247				3,613,499
	Total Net Property, Plant and Equipment	$	9,442,262			$	8,508,058
Schedule of Amortization Expense Per Unit of Production [Table Text Block]	'
			December 31,
			2013				2012
	Unproven gas properties		$	1,487,166			$	1,266,017
	Coal properties		273,242				317,676
	Mine Development		238,356				145,940
	Leased coal lands		99,506				118,697
	Coal advance mining royalties		48,043				55,749
	Airshafts		38,794				21,866
	Gas advance royalties		22,668				8,229
	Total		$	2,207,775			$	1,934,174
Collaborative Arrangement Disclosure [Text Block]	'
			Industry		Industry
			Participation		Participation		Drilling
	Shale		Agreement		Agreement		Carries
	Play		Partner		Date		Remaining
	Marcellus		Noble		30-Sep-11		$	1,873,785
	Utica		Hess		21-Oct-11		$	230,353

Other_Accrued_Liabilities_Tabl

Other Accrued Liabilities (Tables)	12 Months Ended
	Dec. 31, 2013
Other Liabilities Disclosure [Abstract]	'
Schedule of Accrued Liabilities [Table Text Block]	'
		December 31,
		2013		2012
	Subsidence liability	$	98,573	$	88,939
	Accrued interest	63,600		63,687
	Accrued payroll and benefits	38,953		39,172
	Short-term incentive compensation	30,371		28,744
	Uncertain income tax positions	28,530		2,100
	Accrued other taxes	26,305		35,943
	Other	122,902		144,352
	Current portion of long-term liabilities:
	Postretirement benefits other than pensions	60,847		58,452
	Mine closing	30,320		25,081
	Gas well closing	23,971		9,729
	Workers' compensation	13,628		9,176
	Reclamation	9,552		20,582
	Pneumoconiosis benefits	9,212		8,838
	Salary retirement	4,593		6,937
	Long-term disability	4,340		4,016
	Total Other Accrued Liabilities	$	565,697	$	545,748

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Long-term Debt, Unclassified [Abstract]	'
Schedule of Long-term Debt	'
		December 31,
		2013		2012
	Debt:
	Senior notes due April 2017 at 8.00%, issued at par value	$	1,500,000	$	1,500,000
	Senior notes due April 2020 at 8.25%, issued at par value	1,250,000		1,250,000
	Senior notes due March 2021 at 6.375%, issued at par value	250,000		250,000
	MEDCO revenue bonds in series due September 2025 at 5.75%	102,865		102,865
	Advance royalty commitments (7.93% and 7.43% weighted average interest rate for December 31, 2013 and 2012, respectively)	11,182		19,103
	Other long-term notes maturing at various dates through 2031 (total value of $5,923 and $7,300 less unamortized discount of $1,050 and $1,542 at December 31, 2013 and December 31,2012, respectively).	4,873		5,758
		3,118,920		3,127,726
	Less amounts due in one year *	2,957		4,126
	Long-Term Debt	$	3,115,963	$	3,123,600
Schedule of Maturities of Long-term Debt [Table Text Block]	'
	Annual undiscounted maturities on long-term debt during the next five years are as follows:
	Year ended December 31,	Amount
	2014	$	3,364
	2015	4,276
	2016	3,457
	2017	1,502,484
	2018	1,403
	Thereafter	1,609,159
	Total Long-Term Debt Maturities	$	3,124,143

Leases_Tables

Leases (Tables)	12 Months Ended
	Dec. 31, 2013
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,
	2014		$	12,059			$	90,565
	2015		10,984				85,225
	2016		9,842				73,158
	2017		8,758				66,536
	2018		8,128				41,221
	Thereafter		21,272				81,321
	Total minimum lease payments		$	71,043			$	438,026
	Less amount representing interest (0.63% – 7.36%)		14,949
	Present value of minimum lease payments		56,094
	Less amount due in one year		8,498
	Total Long-Term Capital Lease Obligation		$	47,596
333131 Mining Machinery and Equipment Manufacturing [Member]	'
Sale Leaseback Transaction [Line Items]	'
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	'
	2014					2015				2016			2017			2018			Thereafter			Total
	$	33,084				$	33,084			$	33,084		$	26,685		$	26,685		$	13,343		$	165,965
Discontinued Operations [Member]	'
Sale Leaseback Transaction [Line Items]	'
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	'
	2014				2015				2016			2017			2018			Thereafter			Total
	$	8,561			$	8,561			$	7,637		$	4,496		$	2,992		$	2,328		$	34,575

Pension_and_OPEB_Tables

Pension and OPEB (Tables)	12 Months Ended
	Dec. 31, 2013
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,
			2013				2012				2013				2012
	Change in benefit obligation:
	Benefit obligation at beginning of period		$	953,102			$	857,352			$	3,018,172			$	3,242,200
	Service cost		20,865				20,466				18,680				18,817
	Interest cost		36,829				37,586				111,687				135,695
	Actuarial loss (gain)		(82,718		)		90,502				(73,632		)		(131,150		)
	Plan amendments		—				—				—				(80,570		)
	Plan curtailments		(6,551		)		—				—				—
	Plan settlements		(86,925		)		—				(1,891,057		)		—
	Participant contributions		—				—				6,150				5,651
	Benefits and other payments		(21,958		)		(52,804		)		(168,026		)		(172,471		)
	Benefit obligation at end of period		$	812,644			$	953,102			$	1,021,974			$	3,018,172
	Change in plan assets:
	Fair value of plan assets at beginning of period		$	728,161			$	582,571			$	—			$	—
	Actual return on plan assets		94,084				87,935				—				—
	Company contributions		55,469				110,459				161,876				166,820
	Participant contributions		—				—				6,150				5,651
	Benefits and other payments		(21,958		)		(52,804		)		(168,026		)		(172,471		)
	Plan Settlements		(86,925		)		—				—				—
	Fair value of plan assets at end of period		$	768,831			$	728,161			$	—			$	—
	Funded status:
	Noncurrent assets		$	9,032			$	—			$	—			$	—
	Current liabilities		(4,593		)		(6,937		)		(60,847		)		(58,452		)
	Noncurrent liabilities		(48,252		)		(218,004		)		(961,127		)		(882,600		)
	Liabilities of discontinued operations		—				—				—				(2,077,120		)
	Net obligation recognized		$	(43,813	)		$	(224,941	)		$	(1,021,974	)		$	(3,018,172	)
	Amounts recognized in accumulated other comprehensive income consist of:
	Net actuarial loss		$	286,637			$	495,511			$	433,073			$	1,116,051
	Prior service credit		(4,629		)		(6,614		)		(34,086		)		(104,288		)
	Net amount recognized (before tax effect)		$	282,008			$	488,897			$	398,987			$	1,011,763
Schedule of Defined Benefit Plans Disclosures [Table Text Block]	'
	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,
		2013				2012				2011				2013				2012			2011
	Components of net periodic benefit cost:
	Service cost	$	20,865			$	20,466			$	17,457			$	18,680			$	18,817		$	13,677
	Interest cost	36,829				37,586				37,744				111,687				135,695			179,739
	Expected return on plan assets	(51,814		)		(46,157		)		(38,522		)		—				—			—
	Amortization of prior service (credits)	(1,611		)		(1,630		)		(666		)		(30,552		)		(51,828		)	(46,397		)
	Recognized net actuarial loss	37,853				47,834				38,102				66,417				80,875			105,364
	Curtailment gain	(374		)		—				—				(39,650		)		—			—
	Settlement loss (gain)	39,482				—				—				(1,348,129		)		—			—
	Net periodic benefit cost (credit)	$	81,230			$	58,099			$	54,115			$	(1,221,547	)		$	183,559		$	252,383
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		$	(1,384	)		$	(8,784	)
	Actuarial loss recognition		$	23,564			$	25,474
Schedule of Accumulated Benefit Obligations in Excess of Fair Value of Plan Assets [Table Text Block]	'
			As of December 31,
			2013				2012
	Projected benefit obligation		$	52,845			$	953,102
	Accumulated benefit obligation		$	50,820			$	895,493
	Fair value of plan assets		$	—			$	728,161
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,
			2013			2012			2013			2012
	Discount rate		4.87	%		4	%		4.88	%		4.05	%
	Rate of compensation increase		4.23	%		3.77	%		—			—
	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,
			2013			2012			2011			2013			2012			2011
	Discount rate		4	%		4.5	%		5.3	%		4.05	%		4.51	%		5.33	%
	Expected long-term return on plan assets		7.75	%		8	%		8	%		—			—			—
	Rate of compensation increase		3.77	%		3.82	%		3.66	%		—			—			—
Schedule of Health Care Cost Trend Rates [Table Text Block]	'
	The assumed health care cost trend rates are as follows:
			At December 31,
			2013			2012			2011
	Health care cost trend rate for next year		6.17	%		6.3	%		6.85	%
	Rate to which the cost trend is assumed to decline (ultimate trend rate)		4.5	%		4.5	%		4.5	%
	Year that the rate reaches ultimate trend rate		2026			2026			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		$	17,296			$	(14,297	)
	Effect on accumulated postretirement benefit obligation		$	123,355			$	(103,788	)
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets [Table Text Block]	'
	Assumed discount rates also have a significant effect on the amounts reported for both pension and other benefit costs. A one-quarter percentage point change in assumed discount rate would have the following effect on benefit costs:
			0.25 Percentage				0.25 Percentage
			Point Increase				Point Decrease
	Pension benefit costs (decrease) increase		$	(1,797	)		$	1,798
	Other postemployment benefits costs (decrease) increase		$	(3,690	)		$	3,830
Schedule of Allocation of Plan Assets [Table Text Block]	'
	The fair values of plan assets at December 31, 2013 and 2012 by asset category are as follows:
			Fair Value Measurements at December 31, 2013																Fair Value Measurements at December 31, 2012
							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		$	634			$	634			$	—			$	—			$	610		$	610	$	—	$	—
	US Equities (a)		14				14				—				—				11			11		—		—
	Mercer Collective Trusts
	US Large Cap Growth Equity (b)		56,006				—				56,006				—				63,726			—		63,726		—
	US Large Cap Value Equity (c)		56,802				—				56,802				—				64,381			—		64,381		—
	US Small/Mid Cap Growth Equity (d)		28,530				—				28,530				—				26,406			—		26,406		—
	US Small/Mid Cap Value Equity (e)		28,552				—				28,552				—				26,411			—		26,411		—
	US Core Fixed Income (f)		35,533				—				35,533				—				38,045			—		38,045		—
	Non-US Core Equity (g)		126,712				—				126,712				—				146,009			—		146,009		—
	Emerging Markets Equity (h)		29,778				—				29,778				—				33,541			—		33,541		—
	Global Low Volatility Equity (i)		70,138				—				70,138				—				—			—		—		—
	US Long Duration Investment Grade Fixed Income (j)		55,593				—				55,593				—				39,925			—		39,925		—
	US Long Duration Fixed Income (k)		33,489				—				33,489				—				30,675			—		30,675		—
	US Large Cap Passive Equity (l)		75,468				—				75,468				—				81,067			—		81,067		—
	US Passive Fixed Income (m)		20,287				—				20,287				—				20,415			—		20,415		—
	US Long Duration Passive Fixed Income (n)		34,108				—				34,108				—				29,483			—		29,483		—
	US Ultra Long Duration Fixed Income (o)		7,656				—				7,656				—				34,595			—		34,595		—
	US Active Long Corporate Investment (p)		105,412				—				105,412				—				92,861			—		92,861		—
	Long Strips Fixed Income (q)		2,022				—				2,022				—				—			—		—		—
	Opportunistic Fixed Income (r)		2,097				—				2,097				—				—			—		—		—
	Total		$	768,831			$	648			$	768,183			$	—			$	728,161		$	621	$	727,540	$	—
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, 2013
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		$	(1,384	)		$	(8,784	)
	Actuarial loss recognition		$	23,564			$	25,474
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,
			2013			2012			2013			2012
	Discount rate		4.87	%		4	%		4.88	%		4.05	%
	Rate of compensation increase		4.23	%		3.77	%		—			—
	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,
			2013			2012			2011			2013			2012			2011
	Discount rate		4	%		4.5	%		5.3	%		4.05	%		4.51	%		5.33	%
	Expected long-term return on plan assets		7.75	%		8	%		8	%		—			—			—
	Rate of compensation increase		3.77	%		3.82	%		3.66	%		—			—			—
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets [Table Text Block]	'
	Assumed discount rates also have a significant effect on the amounts reported for both pension and other benefit costs. A one-quarter percentage point change in assumed discount rate would have the following effect on benefit costs:
			0.25 Percentage				0.25 Percentage
			Point Increase				Point Decrease
	Pension benefit costs (decrease) increase		$	(1,797	)		$	1,798
	Other postemployment benefits costs (decrease) increase		$	(3,690	)		$	3,830
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 Accumulated and Projected Benefit Obligations [Table Text Block]	'
			CWP								Workers' Compensation
			at December 31,								at December 31,
			2013				2012				2013				2012
	Change in benefit obligation:
	Benefit obligation at beginning of period		$	184,079			$	183,580			$	179,589			$	174,069
	State administrative fees and insurance bond premiums		—				—				5,324				6,727
	Service, legal and administrative cost		8,168				7,711				15,943				17,126
	Interest cost		7,031				7,964				6,401				7,113
	Actuarial (gain) loss		(18,020		)		(3,919		)		11,806				6,754
	Benefits paid		(10,423		)		(11,257		)		(28,659		)		(32,200		)
	Settlements		(49,652		)		—				(105,308		)		—
	Benefit obligation at end of period		$	121,183			$	184,079			$	85,096			$	179,589
	Current liabilities		$	(9,212	)		$	(8,838	)		$	(13,628	)		$	(9,176	)
	Noncurrent liabilities		(111,971		)		(114,136		)		(71,468		)		(60,396		)
	Liabilities of discontinued operations		—				(61,105		)		—				(110,017		)
	Net obligation recognized		$	(121,183	)		$	(184,079	)		$	(85,096	)		$	(179,589	)
	Amounts recognized in accumulated other comprehensive income consist of:
	Net actuarial gain		$	(80,363	)		$	(148,955	)		$	(13,569	)		$	(44,535	)
	Net amount recognized (before tax effect)		$	(80,363	)		$	(148,955	)		$	(13,569	)		$	(44,535	)
Schedule of Net Benefit Costs [Table Text Block]	'
	The components of the net periodic cost (credit) are as follows:
		CWP												Workers’ Compensation
		For the Years Ended												For the Years Ended
		December 31,												December 31,
		2013				2012				2011				2013				2012			2011
	Service cost	$	8,168			$	7,711			$	7,620			$	15,943			$	17,126		$	20,015
	Interest cost	7,031				7,964				9,330				6,401				7,113			8,238
	Amortization of prior service cost	—				(395		)		(728		)		—				—			—
	Recognized net actuarial gain	(16,384		)		(19,338		)		(21,182		)		(2,630		)		(3,944		)	(3,907		)
	State administrative fees and insurance bond premiums	—				—				—				5,324				6,727			7,035
	Settlement gain	(119,881		)		—				—				(121,838		)		—			—
	Net periodic cost (credit)	$	(121,066	)		$	(4,058	)		$	(4,960	)		$	(96,800	)		$	27,022		$	31,381
Schedule of Amounts in Accumulated Other Comprehensive Income (Loss) to be Recognized over Next Fiscal Year [Table Text Block]	'
	Amounts included in accumulated other comprehensive income, expected to be recognized in 2014 net periodic benefit costs:
							Workers'
			CWP				Compensation
			Benefits				Benefits
	Prior Service benefit recognition		$	—			$	—
	Actuarial gain recognition		$	(6,196	)		$	(382	)
Schedule of Assumptions Used [Table Text Block]	'
	Assumptions:
	The weighted-average discount rates used to determine benefit obligations and net periodic (benefit) cost are as follows:
			CWP									Workers' Compensation
			For the Years Ended									For the Years Ended
			December 31,									December 31,
			2013			2012			2011			2013			2012			2011
	Benefit obligations		4.75	%		4.03	%		4.46	%		4.57	%		3.95	%		4.4	%
	Net periodic (benefit) cost		4.03	%		4.46	%		5.21	%		3.95	%		4.4	%		5.13	%
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets [Table Text Block]	'
	Assumed discount rates have a significant effect on the amounts reported for both CWP benefits and Workers' Compensation costs. A one-quarter percentage point change in assumed discount rate would have the following effect on benefit costs:
			0.25 Percentage				0.25 Percentage
			Point Increase				Point Decrease
	CWP benefit increase (decrease)		$	585			$	(530	)
	Workers' Compensation costs (decrease) increase		$	(379	)		$	398
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
	2014			$	9,211			$	18,635			$	13,628			$	5,007
	2015			$	9,204			$	18,479			$	13,347			$	5,132
	2016			$	9,185			$	18,602			$	13,341			$	5,261
	2017			$	9,163			$	18,815			$	13,423			$	5,392
	2018			$	9,156			$	19,000			$	13,473			$	5,527
	Year 2019-2023			$	45,090			$	99,249			$	69,471			$	29,778

Other_Employee_Benefits_Tables

Other Employee Benefits (Tables)	12 Months Ended
	Dec. 31, 2013
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:
		Pension Benefits												Other Postretirement Benefits
		For the Years Ended December 31,												For the Years Ended December 31,
		2013				2012				2011				2013			2012			2011
	Components of net periodic benefit cost:
	Service cost	$	20,865			$	20,466			$	17,457			$	18,680		$	18,817		$	13,677
	Interest cost	36,829				37,586				37,744				111,687			135,695			179,739
	Expected return on plan assets	(51,814		)		(46,157		)		(38,522		)		—			—			—
	Amortization of prior service (credits)	(1,611		)		(1,630		)		(666		)		(30,552		)	(51,828		)	(46,397		)
	Recognized net actuarial loss	37,853				47,834				38,102				66,417			80,875			105,364
	Curtailment gain	(374		)		—				—				(39,650		)	—			—
	Settlement loss (gain)	39,482				—				—				(1,348,129		)	—			—
	Net periodic benefit cost (credit)	$	81,230			$	58,099			$	54,115			$	(1,221,547	)	$	183,559		$	252,383
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,
			2013				2012				2011
	Benefit (Credit) Cost		$	(687	)		$	6,122			$	6,439
	Discount rate assumption used to determine net periodic benefit costs		3.04		%		3.62		%		4.04		%

Stock_Based_Compensation_Table

Stock Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2013
Share-based Compensation [Abstract]	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value [Table Text Block]	'
	he fair value of share-based payment awards was estimated using the Black-Scholes option pricing model with the following assumptions and weighted average fair values:
		December 31,
		2012				2011
	Weighted average fair value of grants	$	14.58			$	20.47
	Risk-free interest rate	0.73		%		1.61		%
	Expected dividend yield	1.18		%		0.82		%
	Expected forfeiture rate	2		%		2		%
	Expected volatility	54.8		%		55.1		%
	Expected term in years	4.4				4.26
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, 2012	5,111,214			$	36.54
	Granted	—			$	—
	Exercised	(310,376	)		$	11.99
	Forfeited	(23,612	)		$	38.64
	Balance at December 31, 2013	4,777,226			$	38.12			4.2	$	28,398
	Vested and expected to vest	4,765,963			$	38.13			4.19	$	28,398
	Exercisable at December 31, 2013	4,344,749			$	38.45			3.76	$	28,839
Schedule of Nonvested Restricted Stock Units Activity [Table Text Block]	'
		Number of			Weighted Average
		Shares			Grant Date Fair Value
	Nonvested at December 31, 2012	1,326,953			$40.39
	Granted	654,656			$31.60
	Vested	(930,390	)		$39.77
	Forfeited	(169,649	)		$32.93
	Nonvested at December 31, 2013	881,570			$35.95
Schedule of Nonvested Performance-based Units Activity [Table Text Block]	'
	The following represents the unvested performance share unit awards 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, 2012	702,194			$50.76
	Granted	40,514			$31.35
	Vested	(159,228	)		$68.45
	Nonvested at December 31, 2013	583,480			$38.19
Schedule of Other Share-based Compensation, Activity [Table Text Block]	'
	The following represents the unvested performance options 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, 2012	401,392			$16.44
	Vested	(100,349	)		$16.44
	Nonvested at December 31, 2013	301,063			$16.44

Supplemental_Cash_Flow_Tables

Supplemental Cash Flow (Tables)	12 Months Ended
	Dec. 31, 2013
Supplemental Cash Flow Information [Abstract]	'
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	'
		For the Years Ended December 31,
		2013		2012		2011
	Interest (Net of Amounts Capitalized)	$	209,580	$	212,364	$	242,587
	Income Taxes	$	35,079	$	121,245	$	144,405

Fair_Value_of_Financial_Instru1

Fair Value of Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2013
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 December 31, 2013									Fair Value Measurements at December 31, 2012
	Description	Quoted Prices in			Significant			Significant			Quoted Prices in			Significant		Significant
		Active Markets			Other			Unobservable			Active Markets			Other		Unobservable
		for Identical			Observable			Inputs			for Identical			Observable		Inputs
		Liabilities			Inputs			(Level 3)			Liabilities			Inputs		(Level 3)
		(Level 1)			(Level 2)						(Level 1)			(Level 2)
	Gas Cash Flow Hedges (Note 23)	$	—		$	65,449		$	—		$	—		$	128,945	$	—
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Table Text Block]	'
	The carrying amounts and fair values of financial instruments for which the fair value option was not elected are as follows:
		December 31, 2013						December 31, 2012
		Carrying			Fair			Carrying			Fair
		Amount			Value			Amount			Value
	Cash and cash equivalents	$	327,420		$	327,420		$	21,862		$	21,862
	Restricted cash (a)	$	—		$	—		$	68,673		$	68,673
	Short-term notes payable	$	—		$	—		$	(25,073	)	$	(25,073	)
	Borrowings under securitization facility	$	—		$	—		$	(37,846	)	$	(37,846	)
	Long-term debt	$	(3,118,920	)	$	(3,299,875	)	$	(3,127,726	)	$	(3,376,767	)

Derivatives_Tables

Derivatives (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance [Table Text Block]	'
	The effect of derivative instruments in cash flow hedging relationships on the Consolidated Statements of Income and the Consolidated Statements of Stockholders' Equity net of tax were as follows:
		Year Ended December 31,
		2013			2012		2011
	Natural Gas Price Swaps
	Beginning Balance – Accumulated OCI	$	76,761		$	151,780	$	46,087
	Gain recognized in Accumulated OCI	$	45,631		$	114,240	$	200,700
	Less: Gain reclassified from Accumulated OCI into Outside Sales	$	79,899		$	189,259	$	95,007
	Ending Balance – Accumulated OCI	$	42,493		$	76,761	$	151,780
	Gain recognized in Outside Sales for ineffectiveness	$	(4,645	)	$	579	$	1,034

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Long-term Purchase Commitment [Table Text Block]	'
	t December 31, 2013, 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 total of future payments that we 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. 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		Less Than		1-3 Years		3-5 Years		Beyond
		Amounts		1  Year						5  Years
		Committed
	Letters of Credit:
	Employee-Related	$	190,358	$	164,852	$	25,506	$	—	$	—
	Environmental	56,293		23,075		33,218		—		—
	Other	114,106		76,460		37,646		—		—
	Total Letters of Credit	360,757		264,387		96,370		—		—
	Surety Bonds:
	Employee-Related	204,884		204,884		—		—		—
	Environmental	610,209		610,209		—		—		—
	Other	32,492		32,481		10		—		1
	Total Surety Bonds	847,585		847,574		10		—		1
	Gurantees:
	Coal	333,460		200,400		133,060		—		—
	Other	70,523		35,611		10,846		9,718		14,348
	Total Guarantees	403,983		236,011		143,906		9,718		14,348
	Total Commitments	$	1,612,325	$	1,347,972	$	240,286	$	9,718	$	14,349
Unrecorded Unconditional Purchase Obligations Disclosure	'
	. These purchase obligations are not recorded on the Consolidated Balance Sheet. As of December 31, 2013, the purchase obligations for each of the next five years and beyond were as follows:
	Obligations Due	Amount
	Less than 1 year	$	240,870
	1 - 3 years	260,218
	3 - 5 years	199,144
	More than 5 years	583,333
	Total Purchase Obligations	$	1,283,565
Supply Commitment [Table Text Block]	'
	osts related to these purchase obligations include:
		For The Years Ended December 31,
		2013		2012		2011
	Gas drilling obligations	$	109,609	$	110,975	$	108,167
	Firm transportation expense	126,766		78,475		59,606
	Major equipment purchases	12,668		101,367		34,219
	Other	—		492		891
	Total costs related to purchase obligations	$	249,043	$	291,309	$	202,883

Segment_Information_Tables

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2013																																							Dec. 31, 2012																																Dec. 31, 2011
Segment Reporting [Abstract]	'																																							'																																'
Industry segment results	'																																							'																																'
	Industry segment results for the year ended December 31, 2013 are:																																							Industry segment results for the year ended December 31, 2012 are:																																Industry segment results for the year ended December 31, 2011 are:
																																									Marcellus		Coalbed		Shallow Oil and Gas			Other			Total		Thermal		Low Volatile		High Volatile		Other			Total Coal		All		Corporate,			Consolidated				Marcellus		Coalbed		Shallow Oil and Gas			Other			Total		Thermal		Low Volatile		High Volatile		Other			Total Coal		All		Corporate,			Consolidated
		Marcellus				Coalbed				Shallow Oil and Gas				Other			Total			Thermal		Low Volatile		High Volatile		Other			Total Coal		All			Corporate,			Consolidated				Shale		Methane					Gas			Gas				Metallurgical		Metallurgical		Coal					Other		Adjustments							Shale		Methane					Gas			Gas				Metallurgical		Metallurgical		Coal					Other		Adjustments
		Shale				Methane								Gas			Gas					Metallurgical		Metallurgical		Coal					Other			Adjustments																																&																																&
																																		&																																Eliminations																																Eliminations
																																		Eliminations						Sales—outside	$	134,080	$	379,595	$	135,412		$	9,733		$	658,820	$	1,430,912	$	505,670	$	210,153	$	22,890		$	2,169,625	$	294,105	$	—		$	3,122,550	(D)	Sales—outside	$	118,973	$	462,677	$	155,444		$	11,370		$	748,464	$	1,495,480	$	1,071,570	$	324,377	$	66,333		$	2,957,760	$	284,783	$	—		$	3,991,007	(G)
	Sales—outside	$	251,846			$	335,730			$	131,135			$	18,990		$	737,701		$	1,388,005	$	447,417	$	159,888	$	22,757		$	2,018,067	$	259,783		$	—		$	3,015,551	(A)
																																								Sales—purchased gas	—		—		—			3,316			3,316		—		—		—		—			—		—		—			3,316			Sales—purchased gas	—		—		—			4,344			4,344		—		—		—		—			—		—		—			4,344
	Sales—purchased gas	—				—				—				6,531			6,531			—		—		—		—			—		—			—			6,531
																																								Sales—gas royalty interests	—		—		—			49,405			49,405		—		—		—		—			—		—		—			49,405			Sales—gas royalty interests	—		—		—			66,929			66,929		—		—		—		—			—		—		—			66,929
	Sales—gas royalty interests	—				—				—				63,202			63,202			—		—		—		—			—		—			—			63,202
																																								Freight—outside	—		—		—			—			—		—		—		—		107,079			107,079		—		—			107,079			Freight—outside	—		—		—			—			—		—		—		—		175,633			175,633		—		—			175,633
	Freight—outside	—				—				—				—			—			—		—		—		35,438			35,438		—			—			35,438
																																								Intersegment transfers	—		—		—			1,622			1,622		—		—		—		—			—		142,014		(143,636		)	—			Intersegment transfers	—		—		—			3,303			3,303		—		—		—		—			—		194,857		(198,160		)	—
	Intersegment transfers	—				—				—				3,167			3,167			—		—		—		—			—		127,553			(130,720		)	—
																																								Total Sales and Freight	$	134,080	$	379,595	$	135,412		$	64,076		$	713,163	$	1,430,912	$	505,670	$	210,153	$	129,969		$	2,276,704	$	436,119	$	(143,636	)	$	3,282,350		Total Sales and Freight	$	118,973	$	462,677	$	155,444		$	85,946		$	823,040	$	1,495,480	$	1,071,570	$	324,377	$	241,966		$	3,133,393	$	479,640	$	(198,160	)	$	4,237,913
	Total Sales and Freight	$	251,846			$	335,730			$	131,135			$	91,890		$	810,601		$	1,388,005	$	447,417	$	159,888	$	58,195		$	2,053,505	$	387,336		$	(130,720	)	$	3,120,722
																																								Earnings (Loss) Before Income Taxes	$	29,546	$	125,970	$	(13,390	)	$	(102,675	)	$	39,451	$	396,748	$	210,133	$	57,163	$	(72,417	)	$	591,627	$	10,997	$	(235,388	)	$	406,687	(E)	Earnings (Loss) Before Income Taxes	$	41,566	$	185,761	$	(14,732	)	$	(82,811	)	$	129,784	$	421,683	$	692,249	$	129,119	$	(210,354	)	$	1,032,697	$	3,408	$	(292,963	)	$	872,926	(H)
	Earnings (Loss) Before Income Taxes	$	79,439			$	81,392			$	(17,829	)		$	(144,616	)	$	(1,614	)	$	375,787	$	121,285	$	40,500	$	(201,048	)	$	336,524	$	(47,468	)	$	(241,367	)	$	46,075	(B)
																																								Segment assets											$	5,768,882										$	4,104,981	$	363,676	$	2,760,055		$	12,997,594	(F)	Depreciation, depletion and amortization											$	206,821										$	214,285	$	9,471	$	—		$	430,577
	Segment assets																$	6,334,468											$	4,187,285	$	293,486		$	578,428		$	11,393,667	(C)
																																								Depreciation, depletion and amortization											$	202,956										$	211,831	$	12,328	$	—		$	427,115		Capital expenditures											$	664,612										$	472,591	$	41,172	$	—		$	1,178,375
	Depreciation, depletion and amortization																$	229,562											$	218,414	$	13,146		$	—		$	461,122
																																								Capital expenditures											$	532,636										$	662,888	$	49,973	$	—		$	1,245,497
	Capital expenditures																$	968,607											$	458,653	$	68,796		$	—		$	1,496,056																																		(G) Included in the Coal segment are sales of $655,596 to Xcoal Energy & Resources comprising over 10% of sales.
																																																																								(H)     Includes equity in earnings of unconsolidated affiliates of $19,629, $4,231 and $803 for Coal, Gas and All Other, respectively.
																																								(D)	Included in the Coal segment are sales of $382,843 to Xcoal Energy & Resources comprising over 10% of sales.
	(A)	Included in the Coal segment are sales of $495,242 to Xcoal Energy & Resources and $346,424 to Duke Energy each comprising over 10% of sales.
																																								(E)	Includes equity in earnings of unconsolidated affiliates of $17,318, $9,562 and $168 for Coal, Gas and All Other, respectively.
	(B)	Includes equity in earnings of unconsolidated affiliates of $17,346, $14,684 and $1,102 for Coal, Gas and All Other, respectively.
																																								(F)	Includes investments in unconsolidated equity affiliates of $19,517, $143,876 and $59,437 for Coal, Gas and All Other, respectively.
	(C)	Includes investments in unconsolidated equity affiliates of $20,512, $206,060 and $65,103 for Coal, Gas and All Other, respectively.
Segment Reporting, Revenue Reconciling Item [Line Items]	'																																							'																																'
Reconciliation of Operating Profit (Loss) from Segments to Consolidated [Table Text Block]	'																																							'																																'
	Earnings Before Income Taxes:
			For the Years Ended December 31,
			2013				2012				2011
	Segment Earnings Before Income Taxes for total reportable business segments		$	334,910			$	631,078			$	1,162,481
	Segment Earnings Before Income Taxes for all other businesses		(47,468		)		10,997				3,408
	Interest income (expense), net and other non-operating activity (I)		(226,199		)		(228,804		)		(258,308		)
	Transaction and Financing Fees (I)		—				—				(14,907		)
	Evaluation fees for non-core asset dispositions (I)		(15,168		)		(6,584		)		(5,780		)
	Loss on debt extinguishment		—				—				(16,090		)
	Lease Settlement		—				—				2,122
	Earnings Before Income Taxes		$	46,075			$	406,687			$	872,926
Reconciliation of Revenue from Segments to Consolidated [Table Text Block]	'																																							'																																'
	Revenue and Other Income:
			For the Years Ended December 31,
			2013				2012				2011
	Total segment sales and freight from external customers		$	3,120,722			$	3,282,350			$	4,237,913
	Other income not allocated to segments (Note 4)		178,963				395,176				139,132
	Total Consolidated Revenue and Other Income		$	3,299,685			$	3,677,526			$	4,377,045
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 (J):
			For the Years Ended December 31,
			2013				2012				2011
	United States (K)		$	2,999,674			$	2,898,341			$	3,460,871
	Europe		83,878				187,313				366,384
	South America		29,787				169,591				400,307
	Canada		3,575				5,692				10,351
	Other		3,808				21,413				—
	Total Revenues and Freight from External Customers (K)		$	3,120,722			$	3,282,350			$	4,237,913
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 are:
			December 31,
			2013				2012
	United States		$	9,431,238			$	8,487,614
	Canada		11,024				20,444
	Discontinued Operations		—				1,682,909
	Total Property, Plant and Equipment, net		$	9,442,262			$	10,190,967
Reconciliation of Assets and Liabilities from Segment to Consolidated	'																																							'																																'
	Total Assets:		December 31,
			2013				2012
	Segment assets for total reportable business segments		$	10,521,753			$	9,873,863
	Segment assets for all other businesses		293,486				363,676
	Items excluded from segment assets:
	Cash and other investments (I)		321,992				19,252
	Recoverable income taxes		10,705				—
	Deferred tax assets		211,303				84,777
	Bond issuance costs		34,428				41,775
	Discontinued Operations		—				2,614,251
	Total Consolidated Assets		$	11,393,667			$	12,997,594
	_________________________
	(I) Excludes amounts specifically related to the gas segment.

Guarantor_Subsidiaries_Financi1

Guarantor Subsidiaries Financial Information (Tables)	12 Months Ended
	Dec. 31, 2013																			Dec. 31, 2012																			Dec. 31, 2011
Guarantor Subsidiaries Financial Information [Abstract]	'																			'																			'
Guarantor Income Statements [Table Text Block]	'																			'																			'
	Income Statement for the Year Ended December 31, 2013:																			ncome Statement for the Year Ended December 31, 2012:																			Income Statement for the Year Ended December 31, 2011:
		Parent			CNX Gas			Other			Non-			Elimination			Consolidated				Parent			CNX Gas			Other			Non-			Elimination			Consolidated				Parent			CNX Gas			Other			Non-			Elimination			Consolidated
		Issuer			Guarantor			Subsidiary			Guarantors										Issuer			Guarantor			Subsidiary			Guarantors										Issuer			Guarantor			Subsidiary			Guarantors
								Guarantors																			Guarantors																			Guarantors
	Sales—Outside	$	—		$	740,869		$	2,061,652		$	216,419		$	(3,389	)	$	3,015,551		Sales—Outside	$	—		$	660,442		$	2,221,421		$	243,059		$	(2,372	)	$	3,122,550		Sales—Outside	$	—		$	751,767		$	3,009,104		$	234,998		$	(4,862	)	$	3,991,007
	Sales—Gas Royalty Interests	—			63,202			—			—			—			63,202			Sales—Gas Royalty Interests	—			49,405			—			—			—			49,405			Sales—Gas Royalty Interests	—			66,929			—			—			—			66,929
	Sales—Purchased Gas	—			6,531			—			—			—			6,531			Sales—Purchased Gas	—			3,316			—			—			—			3,316			Sales—Purchased Gas	$	—		$	4,344		$	—		$	—		$	—		$	4,344
	Freight—Outside	—			—			35,438			—			—			35,438			Freight—Outside	—			—			107,079			—			—			107,079			Freight—Outside	—			—			175,633			—			—			175,633
	Other Income	930,481			57,592			100,757			20,614			(930,481		)	178,963			Other Income	613,340			56,946			316,592			21,639			(613,341		)	395,176			Other Income	876,233			58,923			48,673			26,309			(871,006		)	139,132
	Total Revenue and Other Income	930,481			868,194			2,197,847			237,033			(933,870		)	3,299,685			Total Revenue and Other Income	613,340			770,109			2,645,092			264,698			(615,713		)	3,677,526			Total Revenue and Other Income	876,233			881,963			3,233,410			261,307			(875,868		)	4,377,045
	Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	170,702			493,416			1,313,601			219,450			31,783			2,228,952			Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	127,372			407,045			1,417,519			239,502			30,421			2,221,859			Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion, and amortization shown below)	108,681			388,507			1,443,472			228,291			97,609			2,266,560
	Gas Royalty Interests Costs	—			53,069			—			—			(41		)	53,028			Gas Royalty Interests Costs	—			38,922			—			—			(55		)	38,867			Gas Royalty Interests Costs	—			59,377			—			—			(46		)	59,331
	Purchased Gas Costs	—			4,837			—			—			—			4,837			Purchased Gas Costs	—			2,711			—			—			—			2,711			Purchased Gas Costs	—			3,831			—			—			—			3,831
	Related Party Activity	35,678			—			(112,626		)	1,767			75,181			—			Related Party Activity	12,865			—			(22,466		)	1,814			7,787			—			Related Party Activity	4,767			—			(25,720		)	1,986			18,967			—
	Freight Expense	—			—			35,438			—			—			35,438			Freight Expense	—			—			107,079			—			—			107,079			Freight Expense	—			—			175,444			—			—			175,444
	Selling, General and Administrative Expenses	—			44,733			44,357			1,318			—			90,408			Selling, General and Administrative Expenses	—			40,101			49,222			1,417			—			90,740			Selling, General and Administrative Expenses	—			50,429			62,729			1,485			—			114,643
	Depreciation, Depletion and Amortization	12,857			229,562			216,726			1,977			—			461,122			Depreciation, Depletion and Amortization	12,172			202,956			209,923			2,064			—			427,115			Depreciation, Depletion and Amortization	12,194			206,821			209,159			2,403			—			430,577
	Interest Expense	211,449			8,605			(423		)	47			(480		)	219,198			Interest Expense	208,894			5,098			6,470			44			(464		)	220,042			Interest Expense	235,370			9,398			3,911			53			(388		)	248,344
	Taxes Other Than Income	3,669			35,176			118,675			3,107			—			160,627			Taxes Other Than Income	401			33,892			125,288			2,845			—			162,426			Taxes Other Than Income	950			34,023			136,382			3,037			—			174,392
	Total Costs	434,355			869,398			1,615,748			227,666			106,443			3,253,610			Total Costs	361,704			730,725			1,893,035			247,686			37,689			3,270,839			Transaction and Financing Fees	14,907			—			—			—			—			14,907
	Earnings (Loss) Before Income Taxes	496,126			(1,204		)	582,099			9,367			(1,040,313		)	46,075			Earnings (Loss) Before Income Taxes	251,636			39,384			752,057			17,012			(653,402		)	406,687			Loss on Debt Extinguishment	16,090			—			—			—			—			16,090
	Income Tax (Benefit) Expense	(164,316		)	1,420			126,164			3,543			—			(33,189		)	Income Tax Expense (Benefit)	(136,834		)	15,021			204,105			6,436			—			88,728			Total Costs	392,959			752,386			2,005,377			237,255			116,142			3,504,119
	Income (Loss) from Continuing Operations	660,442			(2,624		)	455,935			5,824			(1,040,313		)	79,264			Income (Loss) from Continuing Operations	388,470			24,363			547,952			10,576			(653,402		)	317,959			Earnings (Loss) Before Income Taxes	483,274			129,577			1,228,033			24,052			(992,010		)	872,926
	Income from Discontinued Operations, net of tax	—			—			—			579,792			—			579,792			Income from Discontinued Operations, net of tax	—			—			—			70,114			—			70,114			Income Tax Expense (Benefit)	(149,223		)	51,876			279,500			9,098			—			191,251
	Net Income (Loss)	660,442			(2,624		)	455,935			585,616			(1,040,313		)	659,056			Net Income (Loss)	388,470			24,363			547,952			80,690			(653,402		)	388,073			Income (Loss) from Continuing Operations	632,497			77,701			948,533			14,954			(992,010		)	681,675
	Less: Net Loss Attributable to Noncontrolling Interest	—			1,386			—			—			—			1,386			Less: Net Loss Attributable to Noncontrolling Interest	—			397			—			—			—			397			Loss from Discontinued Operations, net of tax	—			—			—			(49,178		)	—			(49,178		)
	Net Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	660,442		$	(1,238	)	$	455,935		$	585,616		$	(1,040,313	)	$	660,442		Net Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	388,470		$	24,760		$	547,952		$	80,690		$	(653,402	)	$	388,470		Net Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	632,497		$	77,701		$	948,533		$	(34,224	)	$	(992,010	)	$	632,497
Guarantor Balance Sheet [Table Text Block]	'																			'																			'
	Balance Sheet for December 31, 2013:																			Balance Sheet for December 31, 2012:
		Parent			CNX Gas			Other			Non-			Elimination			Consolidated				Parent			CNX Gas			Other			Non-			Elimination			Consolidated
		Issuer			Guarantor			Subsidiary			Guarantors										Issuer			Guarantor			Subsidiary			Guarantors
								Guarantors																			Guarantors
	Assets:																			Assets:
	Current Assets:																			Current Assets:
	Cash and Cash Equivalents	$	320,473		$	6,238		$	—		$	709		$	—		$	327,420		Cash and Cash Equivalents	$	17,491		$	3,352		$	159		$	860		$	—		$	21,862
	Accounts and Notes Receivable:																			Accounts and Notes Receivable:
	Trade	—			71,911			—			260,663			—			332,574			Trade	—			58,126			—			370,202			—			428,328
	Notes Receivable	1,238			—			24,623			—			—			25,861			Securitized	—			—			—			37,846			—			37,846
	Other Receivables	17,657			207,128			14,969			4,219			—			243,973			Notes Receivable	154			315,730			2,503			—			—			318,387
	Inventories	—			15,185			99,320			43,409			—			157,914			Other Receivables	6,335			214,748			33,289			5,159			(128,400		)	131,131
	Deferred Income Taxes	219,566			(8,263		)	—			—			—			211,303			Inventories	—			14,133			121,311			35,364			—			170,808
	Recoverable Income Taxes	(16,262		)	26,967			—			—			—			10,705			Deferred Income Taxes	174,176			(26,072		)	(63,327		)	—			—			84,777
	Prepaid Expenses	43,698			65,701			24,915			1,528			—			135,842			Restricted Cash	—			—			48,294			—			—			48,294
	Total Current Assets	586,370			384,867			163,827			310,528			—			1,445,592			Prepaid Expenses	29,589			86,186			31,286			1,370			—			148,431
	Property, Plant and Equipment:																			Current Assets of Discontinued Operations	—			—			—			149,230			—			149,230
	Property, Plant and Equipment	220,355			6,919,972			6,412,378			25,804			—			13,578,509
																				Total Current Assets	227,745			666,203			173,515			600,031			(128,400		)	1,539,094
	Less-Accumulated Depreciation, Depletion and Amortization	145,754			1,188,464			2,783,043			18,986			—			4,136,247
																				Property, Plant and Equipment:
	Total Property, Plant and Equipment-Net	74,601			5,731,508			3,629,335			6,818			—			9,442,262			Property, Plant and Equipment	216,448			5,956,207			5,923,723			25,179			—			12,121,557
	Other Assets:																			Less-Accumulated Depreciation, Depletion and Amortization	126,048			960,613			2,508,769			18,069			—			3,613,499
	Investment in Affiliates	11,965,054			206,060			70,222			—			(11,949,661		)	291,675
																				Property, Plant and Equipment of Discontinued Operations, net	—			—			—			1,682,909			—			1,682,909
	Notes Receivable	125			—			—			—			—			125
																				Total Property, Plant and Equipment-Net	90,400			4,995,594			3,414,954			1,690,019			—			10,190,967
	Other	145,401			30,728			28,831			9,053			—			214,013
																				Other Assets:
	Total Other Assets	12,110,580			236,788			99,053			9,053			(11,949,661		)	505,813			Restricted Cash	—			—			20,379			—			—			20,379
	Total Assets	$	12,771,551		$	6,353,163		$	3,892,215		$	326,399		$	(11,949,661	)	$	11,393,667		Investment in Affiliates	9,917,050			143,876			769,058			—			(10,607,154		)	222,830
	Liabilities and Equity:																			Notes Receivable	239			—			25,738			—			—			25,977
	Current Liabilities:
	Accounts Payable	$	180,261		$	324,226		$	493		$	9,600		$	—		$	514,580		Other	118,938			65,935			21,174			10,188			—			216,235
	Accounts Payable (Recoverable)—Related Parties	4,563,327			23,287			(5,055,923		)	136,822			332,487			—			Other Assets of Discontinued Operations	—			—			—			782,112			—			782,112
	Current Portion Long-Term Debt	1,029			6,258			3,372			796			—			11,455			Total Other Assets	10,036,227			209,811			836,349			792,300			(10,607,154		)	1,267,533
	Short-Term Notes Payable	—			332,487			—			—			(332,487		)	—			Total Assets	$	10,354,372		$	5,871,608		$	4,424,818		$	3,082,350		$	(10,735,554	)	$	12,997,594
	Other Accrued Liabilities	144,612			89,080			322,606			9,399			—			565,697
	Current Liabilities of Discontinued Operations	—			—			—			28,239			—			28,239
	Total Current Liabilities	4,889,229			775,338			(4,729,452		)	184,856			—			1,119,971
	Long-Term Debt:
	Long-Term Debt	3,004,213			—			111,750			—			—			3,115,963
	Capital Lease Obligations	1,245			42,852			1,724			1,775			—			47,596
	Total Long-Term Debt	3,005,458			42,852			113,474			1,775			—			3,163,559
	Deferred Credits and Other Liabilities
	Deferred Income Taxes	(232,904		)	475,547			—			—			—			242,643
	Postretirement Benefits Other Than Pensions	—			—			961,127			—			—			961,127
	Pneumoconiosis Benefits	—			—			111,971			—			—			111,971
	Mine Closing	—			—			320,723			—			—			320,723
	Gas Well Closing	—			119,429			56,174			—			—			175,603
	Workers’ Compensation	—			—			71,136			332			—			71,468
	Salary Retirement	48,252			—			—			—			—			48,252
	Reclamation	—			—			40,706			—			—			40,706
	Other	55,227			61,190			14,938			—			—			131,355
	Total Deferred Credits and Other Liabilities	(129,425		)	656,166			1,576,775			332			—			2,103,848
	Total CONSOL Energy Inc. Stockholders’ Equity	5,006,289			4,878,807			6,931,418			139,436			(11,949,661		)	5,006,289
	Total Liabilities and Equity	$	12,771,551		$	6,353,163		$	3,892,215		$	326,399		$	(11,949,661	)	$	11,393,667
Guarantor Condensed Cash Flow [Table Text Block]	'																			'																			'
	Condensed Statement of Cash Flows For the Year Ended December 31, 2013:																			Condensed Statement of Cash Flows For the Year Ended December 31, 2012:																			Condensed Statement of Cash Flows For the Year Ended December 31, 2011:
		Parent			CNX Gas			Other Subsidiary Guarantors			Non-			Elimination			Consolidated				Parent			CNX Gas			Other Subsidiary Guarantors			Non-			Elimination			Consolidated				Parent			CNX Gas			Other Subsidiary Guarantors			Non-			Elimination			Consolidated
					Guarantor						Guarantors													Guarantor						Guarantors													Guarantor						Guarantors
	Net Cash Provided by (Used in) Continuing Operations	$	51,093		$	440,763		$	572,683		$	(843,456	)	$	332,487		$	553,570		Net Cash Provided by (Used in) Continuing Operations	$	(58,410	)	$	82,036		$	412,293		$	21,423		$	—		$	457,342		Net Cash Provided by (Used in) Continuing Operations	$	530,444		$	329,360		$	465,847		$	3,220		$	—		$	1,328,871
	Net Cash Provided by Discontinued Operating Activities	—			—			—			105,206			—			105,206			Net Cash Provided by Discontinued Operating Activities	—			—			—			270,771			—			270,771			Net Cash Provided by Discontinued Operating Activities	$	—		$	—		$	—		$	198,735		$	—		198,735
	Net Cash Provided by (Used in) Operating Activities	$	51,093		$	440,763		$	572,683		$	(738,250	)	$	332,487		$	658,776		Net Cash Provided by (Used in) Operating Activities	$	(58,410	)	$	82,036		$	412,293		$	292,194		$	—		$	728,113		Net Cash Provided by (Used in) Operating Activities	$	530,444		$	329,360		$	465,847		$	201,955		$	—		$	1,527,606
	Cash Flows from Investing Activities:																			Cash Flows from Investing Activities:																			Cash Flows from Investing Activities:
																																							Capital Expenditures	$	(41,172	)	$	(664,612	)	$	(472,591	)	$	—		$	—		$	(1,178,375	)
	Capital Expenditures	$	(68,796	)	$	(968,607	)	$	(458,653	)	$	—		$	—		$	(1,496,056	)	Capital Expenditures	$	(49,973	)	$	(532,636	)	$	(662,888	)	$	—		$	—		$	(1,245,497	)
																																							Proceeds From Sales of Assets	10			746,956			(1,155		)	1,474			—			747,285
	Change in Restricted Cash	—			—			68,673			—			—			68,673			Change in Restricted Cash	—			—			(48,294		)	—			—			(48,294		)
																																							Distributions from, net of Investments in, Equity Affiliates	—			50,626			5,250			—			—			55,876
	Proceeds From Sales of Assets	327,964			350,975			(195,082		)	112			—			483,969			Proceeds From Sales of Assets	—			360,129			285,238			254			—			645,621
																																							Net Cash (Used in) Provided by Continuing Operations	$	(41,162	)	$	132,970		$	(468,496	)	$	1,474		$	—		$	(375,214	)
	(Investments in), net of Distributions from, Equity Affiliates	—			(47,500		)	11,788			—			—			(35,712		)	(Investments in), net of Distributions from, Equity Affiliates	200,000			(37,400		)	13,949			—			(200,000		)	(23,451		)
																																							Net Cash Used in Discontinued Investing Activities	—			—			—			(203,310		)	—			(203,310		)
	Net Cash (Used in) Provided by Continuing Operations	259,168			(665,132		)	(573,274		)	112			—			(979,126		)	Net Cash (Used in) Provided by Continuning Operations	$	150,027		$	(209,907	)	$	(411,995	)	$	254		$	(200,000	)	$	(671,621	)
																																							Net Cash (Used in) Provided by Investing Activities	$	(41,162	)	$	132,970		$	(468,496	)	$	(201,836	)	$	—		$	(578,524	)
	Net Cash Provided by Discontinued Investing Activities	—			—			—			777,145			—			777,145			Net Cash Used in Discontinued Investing Activities	—			—			—			(328,789		)	—			(328,789		)
																																							Cash Flows from Financing Activities:
	Net Cash (Used in) Provided by Investing Activities	$	259,168		$	(665,132	)	$	(573,274	)	$	777,257		$	—		$	(201,981	)	Net Cash (Used in) Provided by Investing Activities	$	150,027		$	(209,907	)	$	(411,995	)	$	(328,535	)	$	(200,000	)	$	(1,000,410	)	Dividends Paid	$	(96,356	)	$	—		$	—		$	—		$	—		$	(96,356	)
	Cash Flows from Financing Activities:																			Cash Flows from Financing Activities:																			Payments on Short-Term Borrowings	(155,000		)	(129,000		)	—			—			—			(284,000		)
	Dividends (Paid)	$	14,168		$	(100,000	)	$	—		$	—		$	—		$	(85,832	)	Dividends (Paid)	$	(142,278	)	$	(200,000	)	$	—		$	—		$	200,000		$	(142,278	)
																																							Payments on Securitization Facility	(200,000		)	—			—			—			—			(200,000		)
	Payments on Short-Term Borrowings	—			332,487			—			—			(332,487		)	—			Proceeds from Issuance of Common Stock	8,278			—			—			—			—			8,278
																																							Proceeds from Long-Term Notes	250,000			—			—			—			—			250,000
	Payments on Miscellaneous Borrowings	(25,952		)	—			(4,800		)	(792		)	—			(31,544		)	Other Financing Activities	22,532			(5,504		)	(1,408		)	37,404			—			53,024
																																							Payments on Long Term Notes, including Redemption Premium	(265,785		)	—			—			—			—			(265,785		)
	Proceeds from Securitization Facility	—			—			—			(37,846		)	—			(37,846		)	Net Cash (Used in) Provided by Continuing Operations	$	(111,468	)	$	(205,504	)	$	(1,408	)	$	37,404		$	200,000		$	(80,976	)
																																							Other Financing Activities	5,749			(13,162		)	(1,246		)	(793		)	—			(9,452		)
	Proceeds from Issuance of Common Stock	3,727			—			—			—			—			3,727			Net Cash Used in Discontinued Financing Activities	—			—			—			(601		)	—			(601		)
																																							Net Cash Used in Continuing Operations	$	(461,392	)	$	(142,162	)	$	(1,246	)	$	(793	)	$	—		$	(605,593	)
	Other Financing Activities	778			(5,232		)	5,232			—			—			778			Net Cash (Used in) Provided by Financing Activities	$	(111,468	)	$	(205,504	)	$	(1,408	)	$	36,803		$	200,000		$	(81,577	)
																																							Net Cash Used in Discontinued Financing Activities	—			—			—			(547		)	—			(547		)
	Net Cash (Used in) Provided by Continuing Operations	(7,279		)	227,255			432			(38,638		)	(332,487		)	(150,717		)
																																							Net Cash Used in Financing Activities	$	(461,392	)	$	(142,162	)	$	(1,246	)	$	(1,340	)	$	—		$	(606,140	)
	Net Cash Used in Discontinued Financing Activities	—			—			—			(520		)	—			(520		)
	Net Cash (Used in) Provided by Financing Activities	$	(7,279	)	$	227,255		$	432		$	(39,158	)	$	(332,487	)	$	(151,237	)
Guarantor Comprehensive Income Statement [Table Text Block]	'																			'																			'
	Statement of Comprehensive Income for the Year Ended December 31, 2013:																			Statement of Comprehensive Income for the Year Ended December 31, 2012:																			Statement of Comprehensive Income for the Year Ended December 31, 2011:
		Parent			CNX Gas			Other			Non-			Elimination			Consolidated				Parent			CNX Gas			Other			Non-Guarantors			Elimination			Consolidated				Parent			CNX Gas			Other			Non-			Elimination			Consolidated
					Guarantor			Subsidiary			Guarantors													Guarantor			Subsidiary																Guarantor			Subsidiary			Guarantors
								Guarantors																			Guarantors																			Guarantors
	Net Income (Loss)	$	660,442		$	(2,624	)	$	455,935		$	585,616		$	(1,040,313	)	$	659,056		Net Income (Loss)	$	388,470		$	24,363		$	547,952		$	80,690		$	(653,402	)	$	388,073		Net Income (Loss)	$	632,497		$	77,701		$	948,533		$	(34,224	)	$	(992,010	)	$	632,497
	Other Comprehensive Income (Loss):																			Other Comprehensive Income (Loss):																			Other Comprehensive Income (Loss):
	Actuarially Determined Long-Term Liability Adjustments	456,493			—			456,493			—			(456,493		)	456,493			Actuarially Determined Long-Term Liability Adjustments	129,231			—			129,231			—			(129,231		)	129,231			Treasury Rate Lock	(96		)	—			—			—			—			(96		)
	Net Increase (Decrease) in the Value of Cash Flow Hedge	45,631			45,631			—			—			(45,631		)	45,631			Net Increase (Decrease) in the Value of Cash Flow Hedge	114,240			114,240			—			—			(114,240		)	114,240			Actuarially Determined Long-Term Liability Adjustments	(32,813		)	—			(32,813		)	—			32,813			(32,813		)
	Reclassification of Cash Flow Hedge from OCI to Earnings	(79,899		)	(79,899		)	—			—			79,899			(79,899		)	Reclassification of Cash Flow Hedge from OCI to Earnings	(189,259		)	(189,259		)	—			—			189,259			(189,259		)	Net Increase (Decrease) in the Value of Cash Flow Hedge	200,700			200,700			—			—			(200,700		)	200,700
	Other Comprehensive Income (Loss):	$	422,225		$	(34,268	)	$	456,493		$	—		$	(422,225	)	$	422,225		Other Comprehensive Income (Loss):	$	54,212		$	(75,019	)	$	129,231		$	—		$	(54,212	)	$	54,212		Reclassification of Cash Flow Hedge from OCI to Earnings	(95,007		)	(95,007		)	—			—			95,007			(95,007		)
	Comprehensive Income (Loss)	1,082,667			(36,892		)	912,428			585,616			(1,462,538		)	1,081,281			Comprehensive Income (Loss)	$	442,682		$	(50,656	)	$	677,183		$	80,690		$	(707,614	)	$	442,285		Other Comprehensive Income (Loss):	$	72,784		$	105,693		$	(32,813	)	$	—		$	(72,880	)	$	72,784
	Less: Comprehensive Loss Attributable to Noncontrolling Interest	—			1,386			—			—			—			1,386			Less: Comprehensive Income Attributable to Noncontrolling Interest	—			397			—			—			—			397			Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	705,281		$	183,394		$	915,720		$	(34,224	)	$	(1,064,890	)	$	705,281
	Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	1,082,667		$	(35,506	)	$	912,428		$	585,616		$	(1,462,538	)	$	1,082,667		Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	442,682		$	(50,259	)	$	677,183		$	80,690		$	(707,614	)	$	442,682

Related_Party_Tables

Related Party (Tables)	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Receivables Payables [Table Text Block]	'
		December 31,			December 31,
		2013			2012			Location on Balance Sheet
	Reimbursement for CONE Expenses	$	(2,168	)	$	(1,336	)	Accounts Receivable–Other
	Reimbursement for Services Provided to CONE	(265		)	(341		)	Accounts Receivable–Other
	CONE Gathering Capital Reimbursement	—			(18		)	Accounts Receivable–Other
	CONE Gathering Fee Payable	7,881			4,837			Accounts Payable
	Net Payable due CONE	$	5,448		$	3,142

Supplemental_Coal_Data_Unaudit1

Supplemental Coal Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
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,
		2013		2012		2011		2010		2009
	Proved and probable reserves at beginning of period	4,229		4,314		4,229		4,350		4,372
	Purchased reserves	1		—		6		4		5
	Reserves sold in place	(1,199	)	(155	)	—		(41	)	(3	)
	Production	(55	)	(55	)	(62	)	(62	)	(58	)
	Revisions and other changes	56		125		141		(22	)	34
	Consolidated proved and probable reserves at end of period*	3,032		4,229		4,314		4,229		4,350
	Proportionate share of proved and probable reserves of unconsolidated equity affiliates*	57		41		145		172		170
	______________
	*    Proved 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, 2013
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,
			2013				2012				2011
	Future Cash Flows:
	Revenues		$	21,602,594			$	11,777,550			$	14,804,398
	Production costs		(7,105,962		)		(4,823,670		)		(5,262,635		)
	Development costs		(3,902,875		)		(2,450,589		)		(1,674,829		)
	Income tax expense		(4,025,626		)		(1,711,251		)		(2,989,435		)
	Future Net Cash Flows		6,568,131				2,792,040				4,877,499
	Discounted to present value at a 10% annual rate		(4,887,320		)		(2,055,834		)		(3,130,318		)
	Total standardized measure of discounted net cash flows		$	1,680,811			$	736,206			$	1,747,181
	The following are the principal sources of change in the standardized measure of discounted future net cash flows for consolidated operations during:
			December 31,
			2013				2012				2011
	Balance at beginning of period		$	736,206			$	1,747,181			$	1,660,821
	Net changes in sales prices and production costs		1,295,956				(1,480,573		)		(339,098		)
	Sales net of production costs		(365,477		)		(104,518		)		(217,186		)
	Net change due to revisions in quantity estimates		132,900				(104,158		)		(83,580		)
	Net change due to extensions, discoveries and improved recovery		383,308				14,645				324,755
	Net change due to (divestiture) acquisition		—				—				(559,132		)
	Development costs incurred during the period		625,824				333,640				463,401
	Difference in previously estimated development costs compared to actual costs incurred during the period		(123,976		)		(96,749		)		154,137
	Changes in estimated future development costs		(486,518		)		(153,104		)		155,619
	Net change in future income taxes		(578,951		)		619,045				130,746
	Accretion of discount and other		61,539				(39,203		)		56,698
	Total discounted cash flow at end of period		$	1,680,811			$	736,206			$	1,747,181
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]	'
	Capitalized Costs:
			As of December 31,
			2013				2012
	Proven properties		$	1,670,404			$	1,596,838
	Unproven properties		1,463,406				1,266,017
	Intangible drilling costs		1,937,336				1,550,297
	Wells and related equipment		688,548				492,364
	Gathering assets		1,058,008				1,006,882
	Gas Well Plugging		113,481				70,753
	Total Property, Plant and Equipment		6,931,183				5,983,151
	Accumulated Depreciation, Depletion and Amortization		(1,187,409		)		(959,291		)
	Net Capitalized Costs		$	5,743,774			$	5,023,860
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,
			2013				2012				2011
	Property acquisitions
	Proven properties		$	—			$	50,005			$	6,673
	Unproven properties		260,477				28,634				58,731
	Development		629,100				339,608				463,401
	Exploration		95,413				130,312				131,419
	Total		$	984,990			$	548,559			$	660,224
	__________
	(*)	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,
			2013				2012				2011
	Production Revenue		$	740,869			$	660,442			$	751,767
	Royalty Interest Gas Revenue		63,202				49,405				66,929
	Purchased Gas Revenue		6,531				3,316				4,344
	Total Revenue		810,602				713,163				823,040
	Lifting Costs		96,600				90,835				106,477
	Ad Valorem, Severance & Other Taxes		28,677				26,145				26,261
	Gathering Costs		201,023				160,575				142,339
	Royalty Interest Gas Costs		53,069				38,922				59,377
	Direct Administrative, Selling & Other Costs		49,092				47,567				60,355
	Other Costs		61,119				39,029				18,095
	Purchased Gas Costs		4,837				2,711				3,831
	DD&A		229,562				202,956				206,821
	Total Costs		723,979				608,740				623,556
	Pre-tax Operating Income		86,623				104,423				199,484
	Income Taxes		32,917				39,827				79,873
	Results of Operations for Producing Activities excluding Corporate and Interest Costs		$	53,706			$	64,596			$	119,611
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,
			2013				2012				2011
	Production (MMcfe)		172,380				156,325				153,504
	Average gas sales price before effects of financial settlements (per Mcf)		$	3.85			$	3			$	4.27
	Average effects of financial settlements (per Mcf)		$	0.45			$	1.22			$	0.63
	Average gas sales price including effects of financial settlements (per Mcf)		$	4.3			$	4.22			$	4.9
	Average lifting costs, excluding ad valorem and severance taxes (per Mcf)		$	0.56			$	0.58			$	0.68
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, 2013, the number of producing wells, developed acreage and undeveloped acreage:
			Gross			Net(1)
	Producing Wells (including gob wells)		15,063			12,874
	Proved Developed Acreage		542,388			527,693
	Proved Undeveloped Acreage		105,019			59,346
	Unproved Acreage		5,396,659			4,212,030
	Total Acreage		6,044,066			4,799,069
	____________
	-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
			(MMcfe)			(Mbbls)			(Mbbls)			(MMcfe)
	Balance December 31, 2010		3,724,361			—			1,206			3,731,597
	Revisions (a)		(76,486	)		25			416			(73,837	)
	Price Changes		(9,976	)		—			—			(9,976	)
	Extensions and Discoveries (c)		517,023			—			27			517,178
	Production		(152,940	)		—			(94	)		(153,504	)
	Sales of Reserves In-Place		(531,431	)		—			—			(531,431	)
	Balance December 31, 2011 (d)		3,470,551			25			1,555			3,480,027
	Revisions (b)		243,442			469			(710	)		241,989
	Price Changes		(526,608	)		—			(1	)		(526,611	)
	Extensions and Discoveries (c)		873,104			12,992			553			954,378
	Production		(155,052	)		(111	)		(100	)		(156,325	)
	Sales of Reserves In-Place		—			—			—			—
	Balance December 31, 2012 (d)		3,905,437			13,375			1,297			3,993,458
	Revisions (b)		176,045			(1,017	)		336			171,953
	Price Changes		104,728			4			1			104,757
	Extensions and Discoveries (c)		1,567,634			9,623			1,343			1,633,426
	Production		(168,737	)		(438	)		(170	)		(172,380	)
	Sales of Reserves In-Place		—			—			—			—
	Balance December 31, 2013 (d)		5,585,107			21,547			2,807			5,731,214
	Proved developed reserves:
	31-Dec-11		2,126,330			—			1,579			2,135,805
	31-Dec-12		2,149,912			1,717			878			2,165,483
	31-Dec-13		2,470,412			5,939			1,375			2,514,294
	Proved undeveloped reserves:
	31-Dec-11		1,344,222			—			—			1,344,222
	31-Dec-12		1,755,525			12,075			—			1,827,975
	31-Dec-13		3,114,695			15,607			1,431			3,216,920
	__________
	(a)	Revisions are primarily due corporate planning changes that affect the number of wells (5-Years) forecasted to be drilled in our various areas and reservoirs. These changes were partially offset by upward revisions attributable to efficiencies in operations and well performance and had the total affect of a negative revision for 2011.
	(b)	Revisions are primarily due to corporate planning changes that affect the number of wells (5-Years) forecasted to be drilled in our various areas and reservoirs. These changes along with upward revisions attributable to efficiencies in operations and well performance and had the total affect of the positive revisions for 2013 and 2012.
	(c)	Extensions and Discoveries are primarily due to the addition of wells on our Marcellus Shale acreage more than one offset location away with reliable technology.
	(d)	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,
			2013
	Costs pending the determination of proved reserves at December 31, 2013
	For a period one year or less		$	17,728
	For a period greater than one year but less than five years		—
	For a period greater than five years		—
	Total		$	17,728
Capitalized Exploratory Well Costs, Roll Forward [Table Text Block]	'
			December 31,
			2013				2012				2011
	Costs reclassified to wells, equipment and facilities based on the determination of proved reserves		$	12,140			$	14,447			$	189
	Costs expensed due to determination of dry hole or abandonment of project		$	8,596			$	3,320			$	5,108

Supplemental_Quarterly_Info_Un1

Supplemental Quarterly Info (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
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,
		2013			2013			2013			2013
	Sales	$	799,997		$	759,948		$	753,080		$	772,258
	Freight Revenue	$	14,061		$	10,125		$	11,563		$	3,946
	Cost of Goods Sold and Other Operating Charges (including Gas Royalty Interests' Costs and Purchased Gas Costs)	$	612,000		$	552,126		$	560,247		$	562,386
	Freight Expense	$	14,061		$	10,125		$	11,563		$	3,946
	(Loss) Income from Continuing Operations	$	(3,725	)	$	8,562		$	(72,169	)	$	146,595
	Income (Loss) from Discontinued Operations	$	1,904		$	(21,375	)	$	8,120		$	591,144
	Net (Loss) Income Attributable to CONSOL Energy Inc Shareholders	$	(1,564	)	$	(12,526	)	$	(63,651	)	$	738,183
	Earnings Per Share
	Basic:
	(Loss) Income from Continuing Operations	$	(0.02	)	$	0.04		$	(0.31	)	$	0.64
	Income (Loss) from Discontinued Operations	$	0.01		$	(0.09	)	$	0.03		$	2.58
	Net (Loss) Income	$	(0.01	)	$	(0.05	)	$	(0.28	)	$	3.22
	Dilutive:
	(Loss) Income from Continuing Operations	$	(0.02	)	$	0.04		$	(0.31	)	$	0.64
	Income (Loss) from Discontinued Operations	$	0.01		$	(0.09	)	$	0.03		$	2.56
	Net (Loss) Income	$	(0.01	)	$	(0.05	)	$	(0.28	)	$	3.2
		Three Months Ended
		March 31,			June 30,			September 30,			December 31,
		2012			2012			2012			2012
	Sales	$	878,118		$	807,198		$	681,717		$	808,238
	Freight Revenue	$	49,293		$	49,472		$	27,430		$	13,426
	Cost of Goods Sold and Other Operating Charges (including Gas Royalty Interests' Costs and Purchased Gas Costs)	$	601,723		$	565,601		$	543,158		$	557,094
	Freight Expense	$	49,293		$	49,472		$	27,430		$	13,426
	Income (Loss) from Continuing Operations	$	80,906		$	155,789		$	(26,316	)	$	107,580
	Income (Loss) from Discontinued Operations	$	16,290		$	(3,050	)	$	14,814		$	42,060
	Net Income (Loss) Attributable to CONSOL Energy Inc Shareholders	$	97,196		$	152,739		$	(11,368	)	$	149,903
	Earnings Per Share
	Basic:
	Income (Loss) from Continuing Operations	$	0.36		$	0.68		$	(0.12	)	$	0.47
	Income (Loss) from Discontinued Operations	$	0.07		$	(0.01	)	$	0.07		$	0.19
	Net Income (Loss)	$	0.43		$	0.67		$	(0.05	)	$	0.66
	Dilutive:
	Income (Loss) from Continuing Operations	$	0.35		$	0.68		$	(0.12	)	$	0.47
	Income (Loss) from Discontinued Operations	$	0.07		$	(0.01	)	$	0.07		$	0.18
	Net Income (Loss)	$	0.42		$	0.67		$	(0.05	)	$	0.65

Significant_Accounting_Policy_2

Significant Accounting Policy Anit-Dilutive Securities (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	3,061,583	3,368,376	1,156,018
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	1,976,549	2,411,963	1,156,018
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	282,230	8,822	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	0	445,847	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	501,744	0

Significant_Accounting_Policy_3

Significant Accounting Policy Earnings Per Share (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012	Jun. 30, 2012	Mar. 31, 2012	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Income (Loss) from Continuing Operations Attributable to Parent	$146,595	($72,169)	$107,580	$8,562	($3,725)	($26,316)	$155,789	$80,906	$79,264	$317,959	$681,675
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax	591,144	8,120	42,060	-21,375	1,904	14,814	-3,050	16,290	579,792	70,114	-49,178
Less: Net Loss (Income) Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	1,386	397	0
Net Income Attributable to CONSOL Energy Inc Shareholders	$738,183	($63,651)	$149,903	($12,526)	($1,564)	($11,368)	$152,739	$97,196	$660,442	$388,470	$632,497
Weighted Average Number of Shares Outstanding, Basic	'	'	'	'	'	'	'	'	228,728,628	227,593,524	226,680,369
Effect of stock-based compensation awards	'	'	'	'	'	'	'	'	1,349,314	1,548,243	2,323,230
Weighted Average Number of Shares Outstanding, Diluted	'	'	'	'	'	'	'	'	230,077,942	229,141,767	229,003,599
Earnings Per Share, Basic	$3.22	($0.28)	$0.66	($0.05)	($0.01)	($0.05)	$0.67	$0.43	$2.89	$1.71	$2.79
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Basic Share	$2.58	$0.03	$0.19	($0.09)	$0.01	$0.07	($0.01)	$0.07	$2.54	$0.31	($0.22)
Income (Loss) from Continuing Operations, Per Basic Share	$0.64	($0.31)	$0.47	$0.04	($0.02)	($0.12)	$0.68	$0.36	$0.35	$1.40	$3.01
Earnings Per Share, Diluted	$3.20	($0.28)	$0.65	($0.05)	($0.01)	($0.05)	$0.67	$0.42	$2.87	$1.70	$2.76
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Diluted Share	$2.56	$0.03	$0.18	($0.09)	$0.01	$0.07	($0.01)	$0.07	$2.52	$0.31	($0.22)
Income (Loss) from Continuing Operations, Per Diluted Share	$0.64	($0.31)	$0.47	$0.04	($0.02)	($0.12)	$0.68	$0.35	$0.35	$1.39	$2.98

Significant_Accounting_Policy_4

Significant Accounting Policy Common Stock Rollforward (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Common Stock [Roll Forward]	'	'	'
Common Stock, Shares, Outstanding	228,094,712	227,056,212	226,162,133
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures	1,051,024	1,038,500	894,079
Common Stock, Shares, Outstanding	229,145,736	228,094,712	227,056,212

Significant_Accounting_Policy_5

Significant Accounting Policy Other (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Commonwealth Park Property [Member]	'
Restricted Cash and Cash Equivalents	$20,379
plaza escrow [Domain]	'
Restricted Cash and Cash Equivalents	$48,294

Significant_Accounting_Policy_6

Significant Accounting Policy Other Comprehensive Income (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	($325,117)	($747,342)	'
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	-367,610	-824,103	'
Other Comprehensive Income (Loss), Net of Tax	422,225	54,212	72,784
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	42,493	76,761	'
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	185,881	'	'
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	236,344	'	'
Postretirement Benefit Costs [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Other Comprehensive Income (Loss), Net of Tax	456,493	'	'
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	140,250	'	'
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	316,243	'	'
Cash Flow Hedging [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Other Comprehensive Income (Loss), Net of Tax	-34,268	'	'
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	45,631	'	'
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	($79,899)	'	'

Significant_Accounting_Policy_7

Significant Accounting Policy Accumulated Other Comprehensive Income (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Reclassifications, net of tax, related to discontinued operations	$258,250	'	'
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	42,493,000	76,761,000	'
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, before Tax	-133,889,000	-310,743,000	-155,932,000
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax	53,990,000	121,484,000	60,925,000
Defined Benefit Plan, Actuarial Net (Gains) Losses	86,481,000	106,299,000	119,262,000
Net periodic (benefit) cost	93,799,000	52,446,000	71,470,000
Actuarially Determined Long-Term Liability Tax Expense	-35,806,000	-19,720,000	-27,416,000
Defined Benefit Plan, Service Cost	-32,164,000	-53,853,000	-47,792,000
Actuarially Long-Term Liabilities Net of Tax	57,993,000	32,726,000	44,054,000
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	-367,610,000	-824,103,000	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	-325,117,000	-747,342,000	'
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	185,881,000	'	'
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	236,344,000	'	'
Other Comprehensive Income (Loss), Net of Tax	422,225,000	54,212,000	72,784,000
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	-79,899,000	-189,259,000	-95,007,000
Pension Plan, Defined Benefit [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Defined Benefit Plan, Actuarial Net (Gains) Losses	-82,718,000	90,502,000	'
Defined Benefit Plan, Net Periodic Benefit Cost	39,482,000	0	0
Net periodic (benefit) cost	81,230,000	58,099,000	54,115,000
Defined Benefit Plan, Service Cost	-1,611,000	-1,630,000	-666,000
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	282,008,000	488,897,000	'
Postretirement Benefit Costs [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	140,250,000	'	'
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	316,243,000	'	'
Other Comprehensive Income (Loss), Net of Tax	456,493,000	'	'
Cash Flow Hedging [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	45,631,000	'	'
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	-79,899,000	'	'
Other Comprehensive Income (Loss), Net of Tax	($34,268,000)	'	'

Discontinued_Operations_Detail

Discontinued Operations (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Gain (Loss) on Sale of Property Plant Equipment	$67,480,000	$282,006,000	$45,673,000
Benefit Obligations Assumed By Murray Energy	2,050,656,000	'	'
Discontinued Operations [Member]	'	'	'
Gain (Loss) on Sale of Property Plant Equipment	1,035,346,000	'	'
Proceeds from Sale of Property, Plant, and Equipment	825,285,000	'	'
Restructuring Costs	$24,715,000	'	'

Discontinued_Operations_Income

Discontinued Operations Income (Loss) from Discontinued Operations (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012	Jun. 30, 2012	Mar. 31, 2012	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Disposal Group, Including Discontinued Operation, Revenue	'	'	'	'	'	'	'	'	$2,598,875	$1,717,926	$1,740,196
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	'	'	'	'	'	'	'	'	969,685	90,587	-84,972
Discontinued Operation, Tax Effect of Discontinued Operation	'	'	'	'	'	'	'	'	-389,893	-20,473	35,794
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax	$591,144	$8,120	$42,060	($21,375)	$1,904	$14,814	($3,050)	$16,290	$579,792	$70,114	($49,178)

Discontinued_Operations_Balanc

Discontinued Operations Balance Sheet (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'
Disposal Group, Including Discontinued Operation, Inventory	$0	$76,958,000
Disposal Group, Including Discontinued Operation, Deferred Tax Assets, Noncurrent	0	771,270,000
Disposal Group, Including Discontinued Operation, Deferred Tax Assets	0	63,327,000
Disposal Group, Including Discontinued Operation, Other Current Assets	0	8,945,000
Disposal Group, Including Discontinued Operation, Property, Plant, and Equipment, Net	0	1,682,909,000
Disposal Group, Including Discontinued Operation, Other Noncurrent Assets	0	10,842,000
Assets of Disposal Group, Including Discontinued Operation	0	2,614,251,000
Liabilities of Disposal Group, Including Discontinued Operation, Current	28,239,000	233,214,000
Disposal Group, Discontinued Operations, Long-Term Debt	0	1,573,000
Disposal Group, Including Discontinued Operation, Postretirement Plan Benefit Obligation	0	1,949,801,000
Disposal Group, Discontinued Operations, Pneumoconiosis Benefits	0	60,645,000
Disposal Group, Discontinued Operations, Workers' Compensation	0	95,252,000
Disposal Group, including discontinued operations, Mine Closing	0	156,909,000
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	0	2,278,251,000
Disposal Group, Including Discontinued Operation, Other Liabilities	'	15,644,000
Disposal Group, Including Discontinued Operation, Accounts Payable and Accrued Liabilities	$28,239,000	$2,513,038,000

Acquisitions_Details

Acquisitions (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Sep. 30, 2012
	acre			Allegheny County Airport Lease [Member]	Dominion Acquisition Member	Ryerson Park Lake and Dam [Member]	Ryerson Park Lake and Dam [Member]	Potomac coal reserves [Member]	Antero [Member]	Antero [Member]
				acre			acre			acre
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'	'
Business Combination, Contingent Consideration Arrangements, Change in Range of Outcomes, Contingent Consideration, Liability, Value, High	'	'	'	'	$190,000,000	$36,000,000	'	'	'	'
Reimbursement From JV Partner	'	'	'	0.5	'	'	'	'	'	'
Bonus Payment	'	'	'	'	'	13,728,000	'	'	'	'
Coal Lands and or Surface Rights	'	'	'	'	'	'	506,000	'	'	'
Gas and Oil Area, Undeveloped, Gross	105,019,000	'	'	9,000	'	'	'	'	'	'
Acquisition Costs, Period Cost	'	'	'	'	91,243,000	'	'	'	'	'
Proceeds from Sale of Property, Plant, and Equipment	'	'	'	'	'	'	'	25,000,000	193,000	'
Gas and Oil Acreage, Unproved, Net	4,212,030,000	'	'	'	'	'	'	'	'	116
Business Acquisition, Cost of Acquired Entity, Transaction Costs	'	'	'	46,315,000	'	'	'	'	2,619	'
Escrow Deposit	'	'	'	0.076	'	'	'	'	'	'
Acquisition and Financing Fees	$0	$0	$14,907,000	'	'	'	'	'	'	'

Dispositions_Details

Dispositions (Details) (USD $)

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Jun. 30, 2012

Dec. 31, 2012

Mar. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Sep. 30, 2012

acre

Crowsnest Pass Sale [Member]

Crowsnest Pass Sale [Member]

Potomac coal reserves [Member]

Bailey Long-wall shields [Member]

Ram River [Member]

Ram River [Member]

Youngs Creek [Member]

Elk Creek [Member]

Elk Creek [Member]

Burning Start No.4 [Member]

Burning Start No.4 [Member]

CONE [Member]

Antero [Member]

Antero [Member]

acre

acre

acre

acre

acre

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Coal Lands and or Surface Rights

'

'

'

'

'

'

'

'

36

200,000,000

'

20

'

4.3

'

'

'

Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$119,740,000

'

'

Gas and Oil Acreage, Unproved, Net

4,212,030,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

116

Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds

'

'

'

'

'

'

'

'

'

'

'

'

'

'

67,545,000

'

'

Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures

291,675,000

222,830,000

'

'

'

'

'

'

'

'

'

'

'

'

59,870,000

'

'

Proceeds from Sale of Property, Plant, and Equipment

'

'

'

24,764,000

'

25,000,000

71,166,000

'

51,869

169,500

26,000

'

13,023

'

7,675

193,000

'

Interest in property sold

'

'

'

'

1

'

'

'

'

50

'

'

'

'

'

'

'

Note Receivable 1 year - PPE Sale

'

'

'

'

'

'

'

25,500

'

'

'

'

'

'

'

'

'

Note Receivable 2 year - PPE Sale

'

'

'

'

'

'

'

24,500

'

'

'

'

'

'

'

'

'

Business Acquisition, Cost of Acquired Entity, Transaction Costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,619

'

Acquisition and Financing Fees

0

0

14,907,000

'

'

'

'

637

'

'

'

'

'

'

'

'

'

Significant Acquisitions and Disposals, Gain (Loss) on Sale or Disposal, Pretax

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,161,000

'

'

Gain (Loss) on Disposition of Property

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

41,057

'

Gain (Loss) on Sale of Property Plant Equipment

67,480,000

282,006,000

45,673,000

15,260,000

'

24,663,000

358,000

89,943

'

150,677

11,235

'

11,261

'

'

'

'

Royalty Interest Retained

'

'

'

'

'

'

'

'

'

$8

'

'

'

'

'

'

'

Other_Income_Details

Other Income (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Component of Operating Income [Abstract]	'	'	'
Gain (Loss) on Sale of Property Plant Equipment	$67,480	$282,006	$45,673
Interest Income (Expense), Net	15,889	28,937	8,919
Pennsylvania Turnpike Settlement	9,000	0	0
Equity in Earnings of Affiliates	-33,133	-27,048	-24,663
Royalty Revenue	16,906	16,853	17,969
Right of Way Issuance	4,536	3,966	12,157
Other Nonoperating Income (Expense)	32,019	36,366	29,751
Other Income	$178,963	$395,176	$139,132

Interest_Expense_Details

Interest Expense (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Interest Expense [Abstract]	'	'	'
Interest Expense, Debt	$260,233	$256,800	$264,080
Interest Expense, Other	2,682	1,296	-189
Interest Costs Incurred, Capitalized	-43,717	-38,054	-15,547
Interest Expense	219,198	220,042	248,344
Unrecognized Tax Benefits, Interest on Income Taxes Expense	$1,369	$543	$3,096

Taxes_Other_Than_Income_Detail

Taxes Other Than Income (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Taxes, Other	$160,627	$162,426	$174,392
Production Taxes [Member]	'	'	'
Taxes, Other	84,984	77,629	99,442
Real Estate Properties [Domain]	'	'	'
Taxes, Other	36,338	43,679	35,495
Payroll Taxes [Member]	'	'	'
Taxes, Other	32,779	32,478	33,155
Capital Stock and Franchise Tax [Member]	'	'	'
Taxes, Other	6,833	9,013	3,670
Virginia employment enhancement tax credit [Member]	'	'	'
Taxes, Other	-4,683	-4,311	-6,109
Other taxes [Member]	'	'	'
Taxes, Other	$4,376	$3,938	$8,739

Income_Taxes_Income_Tax_Compon

Income Taxes Income Tax Components (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	Rate	Rate	Rate
Income Tax Contingency [Line Items]	'	'	'
Valuation Allowance, Deferred Tax Asset, Change in Amount	$4	'	'
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	-2,399	-8,737	2,926
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Depletion, Amount	($51,104)	($49,572)	($72,577)

Income_Taxes_Effective_Tax_Rat

Income Taxes Effective Tax Rate Reconciliation (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	Rate	Rate	Rate
Effective Tax Rate Reconciliation [Abstract]	'	'	'
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount	$16,126	$142,340	$305,524
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	-51,104	-49,572	-72,577
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Depletion, Percent	-110.90%	-12.20%	-8.30%
Effective Income Tax Rate Reconciliation, Deduction, Medicare Prescription Drug Benefit, Amount	2,112	2,112	2,112
Effective Income Tax Rate Reconciliation, Deduction, Medicare Prescription Drug Benefit, Percent	4.60%	0.50%	0.20%
Effective Income Tax Rate Reconciliation, Deduction, Qualified Production Activity, Amount	5,680	-7,215	-21,938
Effective Income Tax Rate Reconciliation, Deduction, Qualified Production Activity, Percent	12.30%	-1.80%	-2.50%
Effective Income Tax Rate Reconciliation, Tax Contingency, Amount	-1,406	6,004	2,257
Effective Income Tax Rate Reconciliation, Tax Contingency, Percent	-3.10%	1.50%	0.30%
Effective Income Tax Rate Reconciliation, Tax Settlement, Amount	3	-925	-5,188
Effective Income Tax Rate Reconciliation, Tax Settlement, Percent	0.00%	-0.20%	-0.60%
Effective Income Tax Rate Reconciliation, Tax Settlement, State and Local, Amount	-2,399	-8,737	2,926
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	-5.20%	-2.10%	0.30%
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	-4,659	0	-22,618
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Percent	-10.10%	0.00%	-2.60%
Effective Income Tax Rate Reconciliation, Tax Credit, Foreign, Amount	0	1,765	-1,822
Effective Income Tax Rate Reconciliation, Tax Credit, Foreign, Percent	0.00%	0.40%	-0.20%
Effective Income Tax Rate Reconciliation, Deduction, Other, Amount	2,458	2,956	2,575
Effective Income Tax Rate Reconciliation, Deduction, Other, Percent	5.30%	0.70%	0.30%
Income Tax Expense (Benefit)	($33,189)	$88,728	$191,251
Effective Income Tax Rate Reconciliation, Percent	-72.10%	21.80%	21.90%

Income_Taxes_Income_Taxes_Deta

Income Taxes Income Taxes (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Tax Disclosure [Abstract]	'	'	'
Deferred Tax Assets, Operating Loss Carryforwards, Foreign	$116,893	'	'
Current Federal Tax Expense (Benefit)	6,728,000	44,727,000	161,474,000
Current State and Local Tax Expense (Benefit)	-10,903,000	1,508,000	32,150,000
Current Foreign Tax Expense (Benefit)	7,763,000	31,594,000	0
Current Income Tax Expense (Benefit)	3,588,000	77,829,000	193,624,000
Deferred Federal Income Tax Expense (Benefit)	-32,125,000	23,300,000	30,034,000
Deferred State and Local Income Tax Expense (Benefit)	-4,652,000	-14,166,000	-32,407,000
Deferred Foreign Income Tax Expense (Benefit)	0	1,765,000	0
Deferred Income Tax Expense (Benefit)	-36,777,000	10,899,000	-2,373,000
Income Tax Expense (Benefit)	($33,189,000)	$88,728,000	$191,251,000

Income_Taxes_Net_Deferred_Tax_

Income Taxes Net Deferred Tax assets/Liabilities (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]	'	'
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Postretirement Benefits	$337,836,000	$347,584,000
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Asset Retirement Obligations	37,306,000	57,370,000
Deferred Tax Assets, Property, Plant and Equipment	22,489,000	23,103,000
Deferred Tax Assets, Tax Credit Carryforwards, Alternative Minimum Tax	159,933,000	54,609,000
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits	44,580,000	46,164,000
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Other	31,008,000	25,191,000
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Pensions	14,330,000	83,077,000
Deferred Tax Assets, Operating Loss Carryforwards	168,658,000	27,277,000
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Accrued Liabilities	35,655,000	20,804,000
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals	20,978,000	26,716,000
Deferred Tax Assets, Other	160,567,000	149,435,000
Deferred Tax Assets, Gross	1,033,340,000	861,330,000
Deferred Tax Assets, Valuation Allowance	7,532,000	4,500,000
Deferred Tax Assets	1,025,808,000	856,830,000
Deferred Tax Liabilities, Property, Plant and Equipment	-954,007,000	-976,505,000
Deferred Tax Liabilities, Derivatives	-27,741,000	-51,006,000
Deferred Tax Liabilities, Leasing Arrangements	-38,105,000	-33,950,000
Deferred Tax Liabilities, Other	-37,295,000	-37,277,000
Deferred Tax Liabilities, Gross	-1,057,148,000	-1,098,738,000
Deferred Tax Liabilities, Net	-31,340,000	-241,908,000
Deferred Federal Income Tax Expense (Benefit)	51,765	27,277
Valuation Allowance, Deferred Tax Asset, Change in Amount	$4,000	'

Income_Taxes_Unrecognized_tax_

Income Taxes Unrecognized tax benefits (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Tax Disclosure [Abstract]	'	'	'
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	$2,071	'	'
Unrecognized Tax Benefits	34,786	34,786	37,586
Unrecognized Tax Benefits, Increase Resulting from Current Period Tax Positions	0	0	'
Unrecognized Tax Benefits, Increase Resulting from Prior Period Tax Positions	0	0	'
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations	0	-2,800	'
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities	0	0	'
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued	6,200	4,831	'
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	$1,369	($543)	($3,096)

Mine_Closing_Reclamation_and_G2

Mine Closing, Reclamation, and Gas Well Closing (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligation [Roll Forward]	'	'
Asset Retirement Obligation, Beginning of Period	$539,177	$500,648
Accretion Expense	41,909	37,922
Asset Retirement Obligation, Cash Paid to Settle	-38,198	-36,086
Asset Retirement Obligation, Revision of Estimate	42,558	40,832
Asset Retirement Obligation, Other Change	15,429	-4,139
Asset Retirement Obligation, End of Period	$600,875	$539,177

Inventory_Components_Details

Inventory Components (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Coal	$31,944	$53,452
Merchandise for resale	38,263	35,363
Supplies	87,707	81,993
Total Inventories	157,914	170,808
Excess of replacement cost of merchandise for resl inventories over carrying LIFO value	$18,836	$19,700

Accounts_Receivable_Securitiza1

Accounts Receivable Securitization (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Letters of credit, maximum borrowing capacity	$200,000,000	'	'
Current borrowing capacity of receivable facility	200,000,000	'	'
Letters of Credit Outstanding, Amount	66,055,000	'	'
Costs associated with the receivables facility	-1,737,000	-1,723,000	-1,986,000
Eligible accounts receivable	115,000,000	200,000,000	'
Subordinated Debt	48,945	'	'
Borrowings Under Securitization Facility	0	37,846,000	'
Accounts Receivable—Securitized	0	37,846,000	'
Decrease in the accounts receivable securitization program	($37,846,000)	$37,846,000	($200,000,000)
AR securitization facility [Member]	'	'	'
Expiration date of receivables facility	30-Mar-17	'	'

Property_Plant_and_Equipment_P1

Property, Plant and Equipment PROPERTY PLANT AND EQUIPMENT (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Thousands, except Per Share data, unless otherwise specified			Noble JV[Member] [Member]
Property, Plant and Equipment [Line Items]	'	'	'
Business Acquisition, Pro Forma Revenue	'	'	$6,073,904
Business Acquisition, Pro Forma Income (Loss) before Income Taxes	'	'	775,807
Business Acquisition, Pro Forma Net Income (Loss)	'	'	623,114
Basic Earnings Per Share, Pro Forma	'	'	$2.75
Business Acquisition, Pro Forma Earnings Per Share, Diluted	'	'	$2.72
Coal and other plant and equipment	3,681,051	3,414,940	'
Proved Oil and Gas Property, Successful Effort Method	1,670,404	1,596,838	'
Drilling Cost	1,937,336	1,550,297	'
Coal Properties And Surface Lands	1,404,056	1,164,107	'
Unproved Oil and Gas Property, Successful Effort Method	1,463,406	1,266,017	'
Gas Gathering Systems Net	1,058,008	1,006,882	'
Airshafts	397,466	366,054	'
Mine development	354,607	262,511	'
Property Subject to or Available for Operating Lease, Gross	393,372	529,758	'
Gas wells and related equipment	688,548	492,364	'
Prepaid Royalties	381,348	381,343	'
Other gas assets	126,239	82,217	'
Advances for Gas Exploration, Development and Production Amount	22,668	8,229	'
Property, Plant and Equipment, Gross	13,578,509	12,121,557	'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	4,136,247	3,613,499	'
Total Property, Plant and Equipment-Net	9,442,262	10,190,967	'
Property, Plant and Equipment, Other, Net	'	$8,508,058	'

Property_Plant_and_Equipment_A

Property, Plant and Equipment Assets Amortized by Units of Production (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Assets Amortized By Units of Production [Line Items]	'	'
Unproved Oil and Gas Property, Successful Effort Method	$1,463,406	$1,266,017
Coal Properties And Surface Lands	1,404,056	1,164,107
Mine development	354,607	262,511
Property Subject to or Available for Operating Lease, Gross	393,372	529,758
Prepaid Royalties	381,348	381,343
Airshafts	397,466	366,054
Advances for Gas Exploration, Development and Production Amount	22,668	8,229
Property, Plant and Equipment, Gross	13,578,509	12,121,557
Assets amortized by units of production [Member]	'	'
Assets Amortized By Units of Production [Line Items]	'	'
Unproved Oil and Gas Property, Successful Effort Method	1,487,166	1,266,017
Coal Properties And Surface Lands	273,242	317,676
Mine development	238,356	145,940
Property Subject to or Available for Operating Lease, Gross	99,506	118,697
Prepaid Royalties	48,043	55,749
Airshafts	38,794	21,866
Advances for Gas Exploration, Development and Production Amount	22,668	8,229
Property, Plant and Equipment, Gross	$2,207,775	$1,934,174

Property_Plant_and_Equipment_C

Property, Plant and Equipment Capital Leases (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Capital Leased Assets [Line Items]	'	'
Capital Lease Obligations	$96,015	$93,745
Capital Leases, Lessee Balance Sheet, Assets by Major Class, Accumulated Depreciation	50,371	44,726
jewell ridge pipeline [Member]	'	'
Capital Leased Assets [Line Items]	'	'
Capital Lease Obligations	66,919	'
Vehicles [Member]	'	'
Capital Leased Assets [Line Items]	'	'
Capital Lease Obligations	10,652	9,248
Computer Equipment [Member]	'	'
Capital Leased Assets [Line Items]	'	'
Capital Lease Obligations	$18,444	$17,578

Property_Plant_and_Equipment_J

Property, Plant and Equipment Joint Participation Agreements (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Acquisition and Financing Fees	$0	$0	$14,907,000
Gain (Loss) on Sale of Property Plant Equipment	67,480,000	282,006,000	45,673,000
Hess [Member]	'	'	'
Proceeds from Sale of Property, Plant, and Equipment	'	'	54,254
drill carry remaining	230,353,000	'	'
Acquisition and Financing Fees	'	'	5,719
Drilling Commitment Carry Amount	'	'	534,000
Gain (Loss) on Sale of Property Plant Equipment	'	'	53,095
Carry Value of Acres W/ Asserted Title Defects	'	'	153,000
Drilling Commitment Carry Amount After Adjustments	'	'	335,000
Expense Related to Conceded Title Defects	23,058	3,526	'
Noble JV[Member] [Member]	'	'	'
Proceeds from Sale of Property, Plant, and Equipment	327,964	327,964	485,464
Oil and Gas Joint Interest Billing Receivables	'	'	16,703
Due to Joint Venture	'	'	980
Cash proceeds Related to Receivable	'	'	15,598
drill carry remaining	1,873,785,000	'	'
Acquisition and Financing Fees	'	'	34,998
Drilling Commitment Carry Amount	'	'	2,100,000
Gain (Loss) on Sale of Property Plant Equipment	'	'	64,142
Carry Value of Acres W/ Asserted Title Defects	'	'	551,000
Maximum Drilling Commitment Carry	'	'	400,000
Interest in property sold	'	'	50
Acres With Asserted Title Defects	87,851,000	'	'
Carry Value of Conceded Acres	'	'	$216,000

ShortTerm_Notes_Payable_Detail

Short-Term Notes Payable (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Senior Secured Credit Facility April122016 Member [Member]	'	'
Short-term Debt [Line Items]	'	'
Credit facility, face amount	$1,000,000	$1,500,000
Additional Capacity Available On Credit Lines At Request	250,000	'
Minimum interest coverage ratio	1.5	'
Interest coverage ratio	2.21	'
Senior secured leverage ratio, maximum	2	'
Letters of credit outstanding	206,988	100,292
Borrowings and issuance of letters of credit remaining capacity	793,012	1,399,708
CNX Gas Senior Secured Credit Facility April122016 Member [Member]	'	'
Short-term Debt [Line Items]	'	'
Credit facility, face amount	1,000,000	1,000,000
Additional Capacity Available On Credit Lines At Request	250,000	'
Minimum interest coverage ratio	3	'
Interest coverage ratio	25.33	'
Maximum leverage ratio	3.5	'
Current maximum leverage ratio	0.61	'
Letters of credit outstanding	87,643	70,203
Borrowings and issuance of letters of credit remaining capacity	912,357	929,797
Interim Funding for Longwall Shields [Member]	'	'
Short-term Debt [Line Items]	'	'
Notes Payable, Current	$25,073	'
Short-term Debt, Weighted Average Interest Rate	2.46%	'

Other_Accrued_Liabilities_Deta

Other Accrued Liabilities (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Other Liabilities Disclosure [Abstract]	'	'
Subsidence Liability	$98,573	$88,939
Accrued Salaries, Current	38,953	39,172
Interest Payable, Current	63,600	63,687
Accrual for Taxes Other than Income Taxes, Current	26,305	35,943
Accrued Bonuses, Current	30,371	28,744
Liability for Uncertain Tax Positions, Current	28,530	2,100
Other Accrued Liabilities, Current	122,902	144,352
Other Postretirement Benefits Payable	60,847	58,452
Accrued Reclamation Costs, Current	9,552	20,582
Pneumoconiosis Liability, Current	9,212	8,838
Defined Benefit Pension Plan Liabilities, Current	4,593	6,937
Long Term Disability, Current	4,340	4,016
Mine closing liability, current	13,628	9,176
Gas well closing liability, current	23,971	9,729
Workers' Compensation Liability, Current	$30,320	$25,081

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Debt Instrument [Line Items]	'	'	'
Interest Expense	$219,198	$220,042	$248,344
Gains (Losses) on Extinguishment of Debt	0	0	16,090
Long-term Debt	3,118,920	3,127,726	'
Less amounts due in one year	-2,957	-4,126	'
Long-Term Debt	3,115,963	3,123,600	'
Senior Notes Due April 2017 at 8.00%	'	'	'
Debt Instrument [Line Items]	'	'	'
Long-term Debt	1,500,000	1,500,000	'
Interest rate stated percentage	8.00%	'	'
Debt Instrument, Face Amount	1,500,000	'	'
Senior notes due April 2020 at 8.25%	'	'	'
Debt Instrument [Line Items]	'	'	'
Long-term Debt	1,250,000	1,250,000	'
Interest rate stated percentage	8.25%	'	'
Debt Instrument, Face Amount	1,250,000	'	'
Senior notes due March 2021 at 6.375%	'	'	'
Debt Instrument [Line Items]	'	'	'
Long-term Debt	250,000	250,000	'
Interest rate stated percentage	6.38%	'	'
Debt Instrument, Face Amount	250,000	'	'
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	11,182	19,103	'
Note due through December 2012 at 6.10%	'	'	'
Debt Instrument [Line Items]	'	'	'
Long-term Debt	$4,873	$5,758	'

LongTerm_Debt_Debt_Maturity_Sc

Long-Term Debt Debt Maturity Schedule (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Long-term Debt, Unclassified [Abstract]	'
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$3,364
Long-term Debt, Maturities, Repayments of Principal in Year Two	4,276
Long-term Debt, Maturities, Repayments of Principal in Year Three	3,457
Long-term Debt, Maturities, Repayments of Principal in Year Four	1,502,484
Long-term Debt, Maturities, Repayments of Principal in Year Five	1,403
Long-term Debt, Maturities, Repayments of Principal after Year Five	1,609,159
Long-term Debt	$3,124,143

Leases_Operating_Leases_Detail

Leases Operating Leases (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Leased Assets [Line Items]	'	'	'
Operating Leases, Rent Expense	$90,128	$83,064	$75,696
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]	'	'	'
Operating Leases, Future Minimum Payments Due, Current	90,565	'	'
Operating Leases, Future Minimum Payments, Due in Two Years	85,225	'	'
Operating Leases, Future Minimum Payments, Due in Three Years	73,158	'	'
Operating Leases, Future Minimum Payments, Due in Four Years	66,536	'	'
Operating Leases, Future Minimum Payments, Due in Five Years	41,221	'	'
Operating Leases, Future Minimum Payments, Due Thereafter	81,321	'	'
Operating Leases, Future Minimum Payments Due	438,026	'	'
Discontinued Operations [Member]	'	'	'
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]	'	'	'
Operating Leases, Future Minimum Payments Due, Current	8,561	'	'
Operating Leases, Future Minimum Payments, Due in Two Years	8,561	'	'
Operating Leases, Future Minimum Payments, Due in Three Years	7,637	'	'
Operating Leases, Future Minimum Payments, Due in Four Years	4,496	'	'
Operating Leases, Future Minimum Payments, Due in Five Years	2,992	'	'
Operating Leases, Future Minimum Payments, Due Thereafter	2,328	'	'
Operating Leases, Future Minimum Payments Due	34,575	'	'
333131 Mining Machinery and Equipment Manufacturing [Member]	'	'	'
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]	'	'	'
Operating Leases, Future Minimum Payments Due, Current	33,084	'	'
Operating Leases, Future Minimum Payments, Due in Two Years	33,084	'	'
Operating Leases, Future Minimum Payments, Due in Three Years	33,084	'	'
Operating Leases, Future Minimum Payments, Due in Four Years	26,685	'	'
Operating Leases, Future Minimum Payments, Due in Five Years	26,685	'	'
Operating Leases, Future Minimum Payments, Due Thereafter	13,343	'	'
Operating Leases, Future Minimum Payments Due	$165,965	'	'

Leases_Capital_Leases_Details

Leases Capital Leases (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Capital Leased Assets [Line Items]	'	'
Capital Leases, Future Minimum Payments, Interest Included in Payments	$14,949	'
Capital Lease Obligations	47,596	49,413
Capital Leases, Future Minimum Payments Due	71,043	'
Capital Leases, Future Minimum Payments, Net Minimum Payments, Fiscal Year Maturity [Abstract]	'	'
Capital Leases, Future Minimum Payments Due, Current	12,059	'
Capital Leases, Future Minimum Payments Due in Two Years	10,984	'
Capital Leases, Future Minimum Payments Due in Three Years	9,842	'
Capital Leases, Future Minimum Payments Due in Four Years	8,758	'
Capital Leases, Future Minimum Payments Due in Five Years	8,128	'
Capital Leases, Future Minimum Payments Due Thereafter	21,272	'
Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments	56,094	'
Capital Lease Obligations, Current	$8,498	'

Pension_and_OPEB_Pension_and_O

Pension and OPEB Pension and OPEB Liability Disclosures (Details) (USD $)	3 Months Ended	12 Months Ended
	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'	'	'
Defined Benefit Plan, Service Cost	'	($32,164,000)	($53,853,000)	($47,792,000)
Net periodic (benefit) cost	'	93,799,000	52,446,000	71,470,000
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'	'
Defined Benefit Plan, Actuarial Net (Gains) Losses	'	86,481,000	106,299,000	119,262,000
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss) [Abstract]	'	'	'	'
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	'	-367,610,000	-824,103,000	'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]	'	'	'	'
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.57%	'	4.51%	'
Pension Plan, Defined Benefit [Member]	'	'	'	'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'	'	'
Service cost	'	20,865,000	20,466,000	17,457,000
Interest cost	'	36,829,000	37,586,000	37,744,000
Expected return on plan assets	'	-51,814,000	-46,157,000	-38,522,000
Defined Benefit Plan, Service Cost	'	-1,611,000	-1,630,000	-666,000
Amortization of actuarial gain	'	37,853,000	47,834,000	38,102,000
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Curtailments	'	-374,000	0	0
Defined Benefit Plan, Net Periodic Benefit Cost	'	39,482,000	0	0
Net periodic (benefit) cost	'	81,230,000	58,099,000	54,115,000
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'	'
Defined Benefit Plan, Benefit Obligation	'	812,644,000	953,102,000	857,352,000
service cost - prior year	'	'	20,466,000	'
Defined Benefit Plan, Plan Amendments	'	0	0	'
Defined Benefit Plan, Curtailments	'	-6,551,000	0	'
Defined Benefit Plan, Settlements, Benefit Obligation	'	86,925,000	0	'
Defined Benefit Plan, Contributions by Plan Participants	'	0	0	'
Defined Benefit Plan, Benefits Paid	'	-21,958,000	-52,804,000	'
Defined Benefit Plan, Actuarial Net (Gains) Losses	'	-82,718,000	90,502,000	'
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	'	231,000	'	'
Deferred Income Taxes and Tax Credits	'	143,000	'	'
Defined Benefit Plan, Settlements, Plan Assets	'	-86,925,000	0	'
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]	'	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	'	768,831,000	728,161,000	582,571,000
Defined Benefit Plan, Actual Return on Plan Assets	'	94,084,000	87,935,000	'
Defined Benefit Plan, Contributions by Employer	'	55,469,000	110,459,000	'
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent	'	9,032,000	0	'
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]	'	'	'	'
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	'	-48,252,000	-218,004,000	'
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	'	-4,593,000	-6,937,000	'
Defined Benefit Plan, Amounts Recognized in Balance Sheet	'	-43,813,000	-224,941,000	'
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	'	286,637,000	495,511,000	'
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax	'	-4,629,000	-6,614,000	'
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	'	282,008,000	488,897,000	'
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)	'	-1,384,000	'	'
Defined Benefit Plan, Amortization of Net Gains (Losses)	'	23,564,000	'	'
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	'	50,820,000	895,493,000	'
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Projected Benefit Obligation	'	52,845,000	953,102,000	'
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets	'	0	728,161,000	'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]	'	'	'	'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	'	4.87%	4.00%	'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase	'	4.23%	3.77%	'
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	'	7.75%	8.00%	8.00%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	'	3.77%	3.82%	3.66%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	'	4.00%	4.50%	5.30%
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]	'	'	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Two	'	50,080,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Three	'	48,952,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Four	'	49,415,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Five	'	50,741,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter	'	262,986,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year One	'	90,347,000	'	'
Other Postretirement Benefit Plan, Defined Benefit [Member]	'	'	'	'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'	'	'
Service cost	'	18,680,000	18,817,000	13,677,000
Interest cost	'	111,687,000	135,695,000	179,739,000
Expected return on plan assets	'	0	0	0
Defined Benefit Plan, Service Cost	'	-30,552,000	-51,828,000	-46,397,000
Amortization of actuarial gain	'	66,417,000	80,875,000	105,364,000
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Curtailments	'	-39,650,000	0	0
Defined Benefit Plan, Net Periodic Benefit Cost	'	-1,348,129,000	0	0
Net periodic (benefit) cost	'	-1,221,547,000	183,559,000	252,383,000
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'	'
Defined Benefit Plan, Benefit Obligation	'	1,021,974,000	3,018,172,000	3,242,200,000
Defined Benefit Plan, Plan Amendments	'	0	-80,570,000	'
Defined Benefit Plan, Curtailments	'	0	0	'
Defined Benefit Plan, Settlements, Benefit Obligation	'	1,891,057,000	0	'
Defined Benefit Plan, Contributions by Plan Participants	'	6,150,000	5,651,000	'
Defined Benefit Plan, Benefits Paid	'	-168,026,000	-172,471,000	'
Defined Benefit Plan, Actuarial Net (Gains) Losses	'	-73,632,000	-131,150,000	'
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	'	339,318,000	'	'
Deferred Income Taxes and Tax Credits	'	203,610,000	'	'
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	'	161,876,000	166,820,000	'
Defined Benefit Plan, Assets for Plan Benefits, Noncurrent	'	0	0	'
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]	'	'	'	'
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	'	-961,127,000	-882,600,000	'
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	'	-60,847,000	-58,452,000	'
Defined Benefit Plan, Amounts Recognized in Balance Sheet	'	-1,021,974,000	-3,018,172,000	'
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	'	433,073,000	1,116,051,000	'
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), Net Prior Service Cost (Credit), before Tax	'	-34,086,000	-104,288,000	'
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	'	398,987,000	1,011,763,000	'
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)	'	-8,784,000	'	'
Defined Benefit Plan, Amortization of Net Gains (Losses)	'	25,474,000	'	'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]	'	'	'	'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	'	4.88%	4.05%	'
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	'	4.05%	4.51%	5.33%
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract]	'	'	'	'
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	'	6.17%	6.30%	6.85%
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	'	'2026	'2026	'2026
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	'	17,296,000	'	'
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components	'	-14,297,000	'	'
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	'	123,355,000	'	'
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	'	-103,788,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]	'	'	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Two	'	62,914,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Three	'	65,493,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Four	'	67,623,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Five	'	68,395,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter	'	338,544,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year One	'	60,847,000	'	'
Other Postretirement Benefit Plan, Defined Benefit [Member] | remeasurent and assumption changes [Member]	'	'	'	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'	'
Defined Benefit Plan, Plan Amendments	'	'	80,571,000	'
Other Postretirement Benefit Plan, Defined Benefit [Member] | PPACA Legislation [Member]	'	'	'	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'	'
Defined Benefit Plan, Plan Amendments	'	12,400	3,000,000	'
Comprehensive Income [Member] | remeasurent and assumption changes [Member]	'	'	'	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'	'
Defined Benefit Plan, Plan Amendments	'	'	50,276,000	'
Deferred Tax Asset [Domain] | remeasurent and assumption changes [Member]	'	'	'	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'	'
Defined Benefit Plan, Plan Amendments	'	'	30,295,000	'
Other Expense [Member] | remeasurent and assumption changes [Member]	'	'	'	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'	'
Defined Benefit Plan, Plan Amendments	'	'	9,425,000	'
Other Postretirement Benefit Plan, Defined Benefit [Member] | Other Postretirement Benefit Plan, Defined Benefit [Member]	'	'	'	'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'	'	'
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Curtailments	'	-24,515,000	'	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'	'
Deferred Income Taxes and Tax Credits	'	$15,135,000	'	'

Pension_and_OPEB_Pension_Plan_

Pension and OPEB Pension Plan Assets Fair Value (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
US Active Long Corporate Investment [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	$105,412	$92,861	'
US Active Long Corporate Investment [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	'	0	'
US Active Long Corporate Investment [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	105,412	92,861	'
US Active Long Corporate Investment [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Other Postretirement Benefit Plan, Defined Benefit [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Net Periodic Benefit Cost	-1,348,129	0	0
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components	-1,797	'	'
Defined Benefit Plan, Effect of .25% Decrease on Pension Benefit Costs	1,798	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	0
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	-3,690	'	'
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	3,830	'	'
Pension Plan, Defined Benefit [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Net Periodic Benefit Cost	39,482	0	0
Defined Benefit Plan, Fair Value of Plan Assets	768,831	728,161	582,571
Pension Plan, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	648	621	'
Pension Plan, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	768,183	727,540	'
Pension Plan, Defined Benefit [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, Defined Benefit [Member] | Cash and Cash Equivalents [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	634	610	'
Pension Plan, Defined Benefit [Member] | 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	634	610	'
Pension Plan, Defined Benefit [Member] | 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	'
Pension Plan, Defined Benefit [Member] | 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	'
Pension Plan, Defined Benefit [Member] | Equity Securities [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	14	11	'
Pension Plan, Defined Benefit [Member] | Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	14	11	'
Pension Plan, Defined Benefit [Member] | 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	'
Pension Plan, Defined Benefit [Member] | 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	'
Pension Plan, Defined Benefit [Member] | Large Cap Growth [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	56,006	63,726	'
Pension Plan, Defined Benefit [Member] | Large Cap Growth [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | Large Cap Growth [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	56,006	63,726	'
Pension Plan, Defined Benefit [Member] | Large Cap Growth [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, Defined Benefit [Member] | Large Cap Value [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	56,802	64,381	'
Pension Plan, Defined Benefit [Member] | Large Cap Value [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | Large Cap Value [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	56,802	64,381	'
Pension Plan, Defined Benefit [Member] | Large Cap Value [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, Defined Benefit [Member] | Small/Mid Cap Growth [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	28,530	26,406	'
Pension Plan, Defined Benefit [Member] | Small/Mid Cap Growth [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | Small/Mid Cap Growth [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	28,530	26,406	'
Pension Plan, Defined Benefit [Member] | Small/Mid Cap Growth [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, Defined Benefit [Member] | Small/Mid Cap Value [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	28,552	26,411	'
Pension Plan, Defined Benefit [Member] | Small/Mid Cap Value [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | Small/Mid Cap Value [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	28,552	26,411	'
Pension Plan, Defined Benefit [Member] | Small/Mid Cap Value [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, Defined Benefit [Member] | US Core Fixed Income [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	35,533	38,045	'
Pension Plan, Defined Benefit [Member] | US Core Fixed Income [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | US Core Fixed Income [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	35,533	38,045	'
Pension Plan, Defined Benefit [Member] | US Core Fixed Income [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, Defined Benefit [Member] | Non-US Core Equity [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	126,712	146,009	'
Pension Plan, Defined Benefit [Member] | Non-US Core Equity [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | Non-US Core Equity [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	126,712	146,009	'
Pension Plan, Defined Benefit [Member] | Non-US Core Equity [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, Defined Benefit [Member] | emerging markets equity [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	29,778	33,541	'
Pension Plan, Defined Benefit [Member] | emerging markets equity [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | emerging markets equity [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	29,778	33,541	'
Pension Plan, Defined Benefit [Member] | emerging markets equity [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, Defined Benefit [Member] | Global Low Volatility Equity [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	70,138	0	'
Pension Plan, Defined Benefit [Member] | Global Low Volatility Equity [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | Global Low Volatility Equity [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	70,138	0	'
Pension Plan, Defined Benefit [Member] | Global Low Volatility Equity [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, Defined Benefit [Member] | US Long Duration Investment Grade Fixed Income [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	55,593	39,925	'
Pension Plan, Defined Benefit [Member] | US Long Duration Investment Grade Fixed Income [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | US Long Duration Investment Grade Fixed Income [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	55,593	39,925	'
Pension Plan, Defined Benefit [Member] | US Long Duration Investment Grade Fixed Income [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, Defined Benefit [Member] | US Long Duration Fixed Income [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	33,489	30,675	'
Pension Plan, Defined Benefit [Member] | US Long Duration Fixed Income [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | US Long Duration Fixed Income [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	33,489	30,675	'
Pension Plan, Defined Benefit [Member] | US Long Duration Fixed Income [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, Defined Benefit [Member] | US Ultra Long Duration Fixed Income [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	7,656	34,595	'
Pension Plan, Defined Benefit [Member] | US Ultra Long Duration Fixed Income [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | US Ultra Long Duration Fixed Income [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	7,656	34,595	'
Pension Plan, Defined Benefit [Member] | US Ultra Long Duration Fixed Income [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, Defined Benefit [Member] | US Large Cap Passive Equity [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	75,468	81,067	'
Pension Plan, Defined Benefit [Member] | US Large Cap Passive Equity [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | US Large Cap Passive Equity [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	75,468	81,067	'
Pension Plan, Defined Benefit [Member] | US Large Cap Passive Equity [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, Defined Benefit [Member] | us passive fixed income [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	20,287	20,415	'
Pension Plan, Defined Benefit [Member] | us passive fixed income [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | us passive fixed income [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	20,287	20,415	'
Pension Plan, Defined Benefit [Member] | us passive fixed income [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, Defined Benefit [Member] | US Long Duration Passive Fixed Income [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	34,108	29,483	'
Pension Plan, Defined Benefit [Member] | US Long Duration Passive Fixed Income [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | US Long Duration Passive Fixed Income [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	34,108	29,483	'
Pension Plan, Defined Benefit [Member] | US Long Duration Passive Fixed Income [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, Defined Benefit [Member] | US Active Long Corporate Investment [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	'	'
Pension Plan, Defined Benefit [Member] | Long Strips Fixed Income [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	2,022	0	'
Pension Plan, Defined Benefit [Member] | Long Strips Fixed Income [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | Long Strips Fixed Income [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	2,022	0	'
Pension Plan, Defined Benefit [Member] | Long Strips Fixed Income [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, Defined Benefit [Member] | Opportunistic Fixed Income [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	2,097	0	'
Pension Plan, Defined Benefit [Member] | Opportunistic Fixed Income [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Pension Plan, Defined Benefit [Member] | Opportunistic Fixed Income [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	2,097	0	'
Pension Plan, Defined Benefit [Member] | Opportunistic Fixed Income [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Minimum [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year	25,000	'	'
Maximum [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year	$35,000	'	'

CWP_and_Workers_Comp_Details

CWP and Workers Comp (Details) (USD $)	3 Months Ended	12 Months Ended
	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'	'	'
Net periodic (benefit) cost	'	$93,799,000	$52,446,000	$71,470,000
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'	'
Defined Benefit Plan, Actuarial Net (Gains) Losses	'	86,481,000	106,299,000	119,262,000
Defined Benefit Plan, Amounts Recognized in Other Comprehensive Income (Loss) [Abstract]	'	'	'	'
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	'	-367,610,000	-824,103,000	'
Defined Benefit Plan, Assumptions Used in Calculations [Abstract]	'	'	'	'
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.57%	'	4.51%	'
Coal Workers Pneumoconiosis [Member]	'	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'	'
Defined Benefit Plan, Curtailments	'	49,652,000	'	'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'	'	'
Service cost	'	8,168,000	7,711,000	7,620,000
Interest cost	'	7,031,000	7,964,000	9,330,000
Amortization of actuarial gain	'	16,384,000	19,338,000	21,182,000
State administrative fees and insurance bond premiums	'	0	0	0
Defined Benefit Plan, Net Periodic Benefit Cost	'	-119,881,000	0	0
Legal and administrative costs	'	8,168,000	7,711,000	'
Net periodic (benefit) cost	'	-121,066,000	-4,058,000	-4,960,000
Legal and administrative costs	'	8,168,000	7,711,000	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'	'
Defined Benefit Plan, Benefit Obligation	'	121,183,000	184,079,000	183,580,000
Defined Benefit Plan, Actuarial Net (Gains) Losses	'	-18,020,000	-3,919,000	'
Defined Benefit Plan, Benefits Paid	'	-10,423,000	-11,257,000	'
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]	'	'	'	'
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	'	111,971,000	-114,136,000	'
Defined Benefit Plan, Amounts Recognized in Balance Sheet	'	-121,183,000	-184,079,000	'
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	'	-9,212,000	-8,838,000	'
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	'	-80,363,000	-148,955,000	'
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	'	-80,363,000	-148,955,000	'
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)	'	-6,196,000	'	'
Defined Benefit Plan, Amortization of Net Prior Service Cost (Credit)	'	0	-395,000	-728,000
Defined Benefit Plan, Assumptions Used in Calculations [Abstract]	'	'	'	'
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	'	4.03%	4.46%	5.21%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	'	4.75%	4.03%	4.46%
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]	'	'	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year One	'	9,211,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Two	'	9,204,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Three	'	9,185,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Four	'	9,163,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Five	'	9,156,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter	'	45,090,000	'	'
Defined Benefit Plan, Effect of .25% Increase on OPEB costs	'	-379,000	'	'
defined benefit plan, effect of .25% decrease on OPEB expense	'	398,000	'	'
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	'	43,892,000	'	'
Deferred Income Taxes and Tax Credits	'	26,337,000	'	'
Workers Compensation [Member]	'	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'	'
Defined Benefit Plan, Curtailments	'	105,308,000	'	'
Defined Benefit Plan, Effect of .25% increase on Pension Benefit Costs	'	585,000	'	'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'	'	'
Service cost	'	15,943,000	17,126,000	20,015,000
Interest cost	'	6,401,000	7,113,000	8,238,000
Amortization of actuarial gain	'	2,630,000	3,944,000	3,907,000
State administrative fees and insurance bond premiums	'	5,324,000	6,727,000	7,035,000
Defined Benefit Plan, Net Periodic Benefit Cost	'	-121,838,000	0	0
Legal and administrative costs	'	15,943,000	17,126,000	'
Net periodic (benefit) cost	'	-96,800,000	27,022,000	31,381,000
Legal and administrative costs	'	15,943,000	17,126,000	'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'	'	'
Defined Benefit Plan, Benefit Obligation	'	85,096,000	179,589,000	174,069,000
Defined Benefit Plan, Actuarial Net (Gains) Losses	'	11,806,000	6,754,000	'
Defined Benefit Plan, Benefits Paid	'	-28,659,000	-32,200,000	'
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]	'	'	'	'
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	'	71,468,000	-60,396,000	'
Defined Benefit Plan, Amounts Recognized in Balance Sheet	'	-85,096,000	-179,589,000	'
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	'	-13,628,000	-9,176,000	'
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	'	-13,569,000	-44,535,000	'
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	'	-13,569,000	-44,535,000	'
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)	'	-382,000	'	'
Defined Benefit Plan, Amortization of Net Prior Service Cost (Credit)	'	0	0	0
Defined Benefit Plan, Assumptions Used in Calculations [Abstract]	'	'	'	'
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	'	3.95%	4.40%	5.13%
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	'	4.57%	3.95%	4.40%
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]	'	'	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year One	'	18,635,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Two	'	18,479,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Three	'	18,602,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Four	'	18,815,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Five	'	19,000,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter	'	99,249,000	'	'
Defined Benefit Plan, Effect of .25% Decrease on Pension Benefit Costs	'	-530,000	'	'
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	'	13,768,000	'	'
Deferred Income Taxes and Tax Credits	'	8,262,000	'	'
Workers Compensation [Member] | Actuarial Benefits [Member]	'	'	'	'
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]	'	'	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year One	'	13,628,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Two	'	13,347,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Three	'	13,341,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Four	'	13,423,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Five	'	13,473,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter	'	69,471,000	'	'
Workers Compensation [Member] | 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	'	5,007,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Two	'	5,132,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Three	'	5,261,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Four	'	5,392,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Year Five	'	5,527,000	'	'
Defined Benefit Plan, Expected Future Benefit Payments in Five Fiscal Years Thereafter	'	29,778,000	'	'
Discontinued Operations [Member] | Coal Workers Pneumoconiosis [Member]	'	'	'	'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'	'	'
Defined Benefit Plan, Net Periodic Benefit Cost	'	'	'	-2,887,000
Net periodic (benefit) cost	'	-120,496,000	-2,374,000	'
Discontinued Operations [Member] | Workers Compensation [Member]	'	'	'	'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'	'	'
Net periodic (benefit) cost	'	($113,097,000)	$10,132,000	$12,722,000

Other_Employee_Benefits_LongTe

Other Employee Benefits Long-Term Disability (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Net Periodic Benefit Cost	$93,799,000	$52,446,000	$71,470,000
Long term disability [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Net Periodic Benefit Cost	-687	6,122	6,439
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	3.04%	3.62%	4.04%
Defined Benefit Plan, Benefit Obligation	20,425	24,144	'
Defined Benefit Plan, Curtailments	10,140,000	'	'
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	1,338,000	'	'
Deferred Income Taxes and Tax Credits	$803,000	'	'

Other_Employee_Benefits_MultiE

Other Employee Benefits MultiEmployer Plans (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Letters of Credit Outstanding, Amount	$66,055,000	'	'
Allocated Share-based Compensation Expense	56,987	41,127	42,131
Share-based Compensation	56,987,000	41,127,000	42,131,000
Voluntary Severance Incentive Program	'	13,304,000	'
Non-Pension Multiemployer Plans [Domain]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Letters of Credit Outstanding, Amount	60,741	63,614	67,349
Retiree Health Benefit Act of 1992 [Domain]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Multiemployer Plan, Period Contributions	11,435	12,358	13,609
Multiemployer Plan, Withdrawal Obligation	120,394	'	'
401k Defined Contribution [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'
Defined Contribution Plan, Cost Recognized	$23,748	$24,127	$23,394

Stock_Based_Compensation_Detai

Stock Based Compensation (Details) (USD $)	6 Months Ended	12 Months Ended
	Jun. 30, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period	1,671	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	'	31,800,000	'	'
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	'	$20,508	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant	'	6,072,413	'	'
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense	'	21,769	15,464	15,841
Allocated Share-based Compensation Expense	'	56,987	41,127	42,131
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	'	1,650	6,599	3,299
Employee Stock Option [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Stock Issued During Period, Value, Share-based Compensation, Net of Forfeitures	'	'	$8,515	$9,913

Stock_Based_Compensation_Weigh

Stock Based Compensation Weighted Average Fair Value of Grants (Details) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013
			Stock Options [Member]	Stock Options [Member]	Six to Twelve months [Domain]
					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	'	'	$3.76	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Remaining Contractual Te	'	'	4.19	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual TER	'	'	4.2	'	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Number of Outstanding Options	'	'	4,777,226	5,111,214	192,934
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value	$14.58	$20.47	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	0.73%	1.61%	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate	1.18%	0.82%	'	'	'
Share Based Comp expected forfeiture rate	2.00%	2.00%	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate	54.80%	55.10%	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	'	4.26	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Te	$4.40	'	'	'	'

Stock_Based_Compensation_Stock

Stock Based Compensation Stock Option Rollforward (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
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	$1.79	'	'
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities	2,929,000	8,678,000	8,281,000
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures	1,051,024	1,038,500	894,079
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	20,687	26,426	24,882
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value	37,002	23,097	16,496
Stock Options [Member]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]	'	'	'
Proceeds from Stock Options Exercised	3,720	8,383	9,033
Excess Tax Benefit (Tax Deficiency) from Share-based Compensation, Financing Activities	2,929	8,678	8,281
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Number of Outstanding Options	4,777,226	5,111,214	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period, Total Intrinsic Value	6,820	18,562	18,049
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price	$38.12	$36.54	'
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	-310,376	'	'
Share Based Comp, Exercises, Weighted Average Exercise Price	$11.99	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures in Period	-23,612	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price	$38.64	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Number	4,765,963	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value	28,398	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Exercise Price	$38.13	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Aggregate Intrinsic Value	28,398	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Intrinsic Value	28,839	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Number	4,344,749	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Exercise Price	$38.45	'	'
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	301,063	401,392	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$16.44	$16.44	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	-100,349	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$16.44	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value	$1,650	$6,599	$3,299
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	583,480	702,194	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$38.19	$50.76	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	40,514	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$31.35	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	-159,228	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$68.45	'	'
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	881,570	1,326,953	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$35.95	$40.39	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	654,656	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$31.60	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	-930,390	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$39.77	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	-169,649	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	$32.93	'	'
Directors - thirty three percent per year [Member] | Stock 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	53,895	'	'
thirty three percent per year [Member] | Stock 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	4,529,216	'	'

Stock_Based_Compensation_Restr

Stock Based Compensation Restricted and Performance Stock Unit Rollforward (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
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	6,072,413	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value	'	$14.58	$20.47
Stock Options [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	4,777,226	5,111,214	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures in Period	-23,612	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price	$38.64	'	'
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	$1,270	$16,794	$11,648
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	881,570	1,326,953	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$35.95	$40.39	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	654,656	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$31.60	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	-930,390	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$39.77	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	$32.93	'	'
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	$28,381	'	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Number of Outstanding Options	833,553	0	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$33.70	$0	'
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant	842,167	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value	$33.70	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures in Period	-8,614	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price	$33.39	'	'
Six to Twelve months [Domain] | Stock Options [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	192,934	'	'

Supplemental_Cash_Flow_Supplem

Supplemental Cash Flow Supplemental Cash Flow (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Supplemental Cash Flow Information [Abstract]	'	'	'
Income Taxes Paid	$35,079,000	$121,245,000	$144,405,000
Interest Paid, Net	209,580,000	212,364,000	242,587,000
Capital Lease Obligations [Member]	'	'	'
Other Significant Noncash Transactions [Line Items]	'	'	'
Noncash or Part Noncash Acquisition, Value of Liabilities Assumed	4,178	3,583	4,649
Notes Received from Property Sales [Member]	'	'	'
Other Significant Noncash Transactions [Line Items]	'	'	'
Other Significant Noncash Transaction, Value of Consideration Received	175,371	63,051	61,690
Commercial Paper [Member]	'	'	'
Other Significant Noncash Transactions [Line Items]	'	'	'
Other Significant Noncash Transaction, Value of Consideration Received	$6,236	'	'

Concentrations_of_Credit_Risk_

Concentrations of Credit Risk (Details) (Customer Concentration Risk [Member])	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accounts Receivable [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Customer	'332574	'428328	'
Accounts Receivable [Member] | Steam Coal Utilities [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Customer	'154738	'247955	'
Accounts Receivable [Member] | Steel and Coke Producers [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Customer	'10963	'47203	'
Accounts Receivable [Member] | Coal Brokers and Distributors [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Customer	'52233	'65057	'
Accounts Receivable [Member] | Gas Customers [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Customer	'71441	'51718	'
Accounts Receivable [Member] | All Other [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Customer	'43199	'16395	'
Sales Revenue, Goods, Net [Member] | Duke Energy [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Customer	'346424	'	'
Sales Revenue, Goods, Net [Member] | XCoal Energy and Resources [Member]	'	'	'
Concentration Risk [Line Items]	'	'	'
Concentration Risk, Customer	'495242	'382843	'655596

Financial_Instruments_Measured

Financial Instruments Measured at Fair Value on a Recurring Basis (Details) (USD $)	Dec. 31, 2013	Jan. 02, 2013	Dec. 31, 2012	Jan. 02, 2012	Dec. 31, 2011	Jan. 02, 2011
In Thousands, unless otherwise specified
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]	'	'	'	'	'	'
Cash and Cash Equivalents	$327,420	$21,862	$21,862	$375,736	$375,736	$32,794
Short-term Non-bank Loans and Notes Payable	0	'	25,073	'	'	'
Borrowings Under Securitization Facility	0	'	37,846	'	'	'
Long-term Debt	3,118,920	'	3,127,726	'	'	'
Quoted Prices in Active Markets for Identical Liabilities (Level 1)	'	'	'	'	'	'
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]	'	'	'	'	'	'
Gas Cash Flow hedges	0	'	0	'	'	'
Significant Other Observable Inputs (Level 2)	'	'	'	'	'	'
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]	'	'	'	'	'	'
Gas Cash Flow hedges	65,449	'	128,945	'	'	'
Significant Unobservable Inputs (Level 3)	'	'	'	'	'	'
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]	'	'	'	'	'	'
Gas Cash Flow hedges	0	'	0	'	'	'
Other Assets [Member]	'	'	'	'	'	'
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]	'	'	'	'	'	'
Restricted Cash and Investments	20,379	'	'	'	'	'
Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'	'	'	'	'
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]	'	'	'	'	'	'
Cash and Cash Equivalents	327,420	'	21,862	'	'	'
Restricted Cash and Cash Equivalents	0	'	68,673	'	'	'
Short-term Non-bank Loans and Notes Payable	0	'	25,073	'	'	'
Borrowings Under Securitization Facility	0	'	37,846	'	'	'
Long-term Debt	3,118,920	'	3,127,726	'	'	'
Fair Value	'	'	'	'	'	'
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]	'	'	'	'	'	'
Cash and Cash Equivalents	327,420	'	21,862	'	'	'
Restricted Cash and Cash Equivalents	0	'	68,673	'	'	'
Short-term Non-bank Loans and Notes Payable	0	'	25,073	'	'	'
Borrowings Under Securitization Facility	0	'	37,846	'	'	'
Long-term Debt	$3,299,875	'	$3,376,767	'	'	'

Carrying_Amounts_and_Fair_Valu

Carrying Amounts and Fair Values of Financial Instruments for Which the Fair Value Option Was Not Elected (Details) (USD $)	Dec. 31, 2013	Jan. 02, 2013	Dec. 31, 2012	Jan. 02, 2012	Dec. 31, 2011	Jan. 02, 2011
In Thousands, unless otherwise specified
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]	'	'	'	'	'	'
Cash and Cash Equivalents	$327,420	$21,862	$21,862	$375,736	$375,736	$32,794
Short-term Non-bank Loans and Notes Payable	0	'	25,073	'	'	'
Borrowings under Securitization Facility	0	'	-37,846	'	'	'
Long-term debt	-3,118,920	'	-3,127,726	'	'	'
Carrying (Reported) Amount, Fair Value Disclosure [Member]	'	'	'	'	'	'
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]	'	'	'	'	'	'
Cash and Cash Equivalents	327,420	'	21,862	'	'	'
Restricted cash	0	'	68,673	'	'	'
Short-term Non-bank Loans and Notes Payable	0	'	25,073	'	'	'
Borrowings under Securitization Facility	0	'	-37,846	'	'	'
Long-term debt	-3,118,920	'	-3,127,726	'	'	'
Fair Value	'	'	'	'	'	'
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]	'	'	'	'	'	'
Cash and Cash Equivalents	327,420	'	21,862	'	'	'
Restricted cash	0	'	68,673	'	'	'
Short-term Non-bank Loans and Notes Payable	0	'	25,073	'	'	'
Borrowings under Securitization Facility	0	'	-37,846	'	'	'
Long-term debt	-3,299,875	'	-3,376,767	'	'	'
Other Current Assets [Member]	'	'	'	'	'	'
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]	'	'	'	'	'	'
Restricted Cash and Investments	48,294	'	'	'	'	'
Other Assets [Member]	'	'	'	'	'	'
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]	'	'	'	'	'	'
Restricted Cash and Investments	$20,379	'	'	'	'	'

Derivatives_Derivates_Impact_o

Derivatives Derivates Impact on Income (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accumulated Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Roll Forward]	'	'	'
Price Risk Cash Flow Hedge Unrealized Gain (Loss) to be Reclassified During Next 12 Months	$30,333	'	'
Commodity Contract [Member] | Cash Flow Hedging [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Roll Forward]	'	'	'
Derivative Instruments, Gain Reclassified from Accumulated OCI into Income, Effective Portion	-79,899,000	-189,259,000	-95,007,000
Commodity Contract [Member] | Sales [Member] | Cash Flow Hedging [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Roll Forward]	'	'	'
Derivative, Net Hedge Ineffectiveness Gain (Loss)	-4,645,000	579,000	1,034,000
Accumulated Other Comprehensive Income (Loss) | Commodity Contract [Member] | Cash Flow Hedging [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Roll Forward]	'	'	'
Derivative Component Of Accumulated Other Comprehensive Income (Loss), Beginning of Period	76,761,000	151,780,000	46,087,000
Derivative Instruments, Gain Recognized in Other Comprehensive Income (Loss), Effective Portion	45,631,000	114,240,000	200,700,000
Derivative Instruments, Gain Reclassified from Accumulated OCI into Income, Effective Portion	79,899,000	189,259,000	95,007,000
Derivative Component Of Accumulated Other Comprehensive Income (Loss), End of Period	$42,493,000	$76,761,000	$151,780,000

Derivatives_Derivatives_by_Bal

Derivatives Derivatives by Balance Sheet Location (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Notional Disclosures [Abstract]	'	'
Derivative, Nonmonetary Notional Amount (billion cubic feet)	279.3	'
Commodity Contract [Member] | Cash Flow Hedging [Member] | Assets, Total [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$83,661	$135,969
Derivative Liability, Fair Value, Gross Liability	'	7,024
Commodity Contract [Member] | Cash Flow Hedging [Member] | Prepaid Expenses [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Assets, Current	59,605	80,057
Commodity Contract [Member] | Cash Flow Hedging [Member] | Other Assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Assets, Noncurrent	24,056	55,912
Commodity Contract [Member] | Cash Flow Hedging [Member] | Other Current Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Current	'	970
Commodity Contract [Member] | Cash Flow Hedging [Member] | Liabilities, Total [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	18,212	'
Commodity Contract [Member] | Cash Flow Hedging [Member] | Accrued Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Current	12,327	'
Commodity Contract [Member] | Cash Flow Hedging [Member] | Other Liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Liabilities, Noncurrent	$5,885	$6,054

Commitments_and_Contingencies_1

Commitments and Contingencies Additional Information (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Commitments and Contingencies Disclosure [Line Items]	'
Loss Contingency, Range of Possible Loss, Portion Not Accrued	318,786
Asbestos Issue [Member]	'
Commitments and Contingencies Disclosure [Line Items]	'
Commitments and Contingent, number of asbestos claims	6,900,000
Earl Kennedy [Member]	'
Commitments and Contingencies Disclosure [Line Items]	'
Loss Contingency, Damages Sought	'20000
Minimum [Member] | Ratliff [Member]	'
Commitments and Contingencies Disclosure [Line Items]	'
Loss Contingency, Damages Sought	'4000
Maximum [Member] | Ratliff [Member]	'
Commitments and Contingencies Disclosure [Line Items]	'
Loss Contingency, Damages Sought	'8000

Maximum_Potential_Total_of_Fut

Maximum Potential Total of Future Payments Under Commitment Instruments (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	$1,612,325
Surety Bond [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	360,757
Surety Bond [Member] | Employee-Related	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	190,358
Surety Bond [Member] | Environmental	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	56,293
Surety Bond [Member] | Other Commitments	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	114,106
Surety Bonds:	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	847,585
Surety Bonds: | Employee-Related	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	204,884
Surety Bonds: | Environmental	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	610,209
Surety Bonds: | Other Commitments	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	32,492
Guarantees [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	403,983
Guarantees [Member] | Other Commitments	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	70,523
Guarantees [Member] | Coal Segment [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	333,460
Balance on First Anniversary [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	1,347,972
Balance on First Anniversary [Member] | Surety Bond [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	264,387
Balance on First Anniversary [Member] | Surety Bond [Member] | Employee-Related	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	164,852
Balance on First Anniversary [Member] | Surety Bond [Member] | Environmental	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	23,075
Balance on First Anniversary [Member] | Surety Bond [Member] | Other Commitments	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	76,460
Balance on First Anniversary [Member] | Surety Bonds:	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	847,574
Balance on First Anniversary [Member] | Surety Bonds: | Employee-Related	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	204,884
Balance on First Anniversary [Member] | Surety Bonds: | Environmental	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	610,209
Balance on First Anniversary [Member] | Surety Bonds: | Other Commitments	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	32,481
Balance on First Anniversary [Member] | Guarantees [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	236,011
Balance on First Anniversary [Member] | Guarantees [Member] | Other Commitments	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	35,611
Balance on First Anniversary [Member] | Guarantees [Member] | Coal Segment [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	200,400
More Than One And Within Three Years From Balance Sheet Date [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	240,286
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	96,370
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	25,506
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	33,218
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	37,646
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	10
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	0
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	0
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	10
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	143,906
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	10,846
More Than One And Within Three Years From Balance Sheet Date [Member] | Guarantees [Member] | Coal Segment [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	133,060
More Than Three And Within Five Years From Balance Sheet Date [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	9,718
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	0
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	0
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	9,718
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	9,718
More Than Three And Within Five Years From Balance Sheet Date [Member] | Guarantees [Member] | Coal Segment [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	0
Beyond Five Years of Balance Sheet Date [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	14,349
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	1
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	1
Beyond Five Years of Balance Sheet Date [Member] | Guarantees [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	14,348
Beyond Five Years of Balance Sheet Date [Member] | Guarantees [Member] | Other Commitments	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	14,348
Beyond Five Years of Balance Sheet Date [Member] | Guarantees [Member] | Coal Segment [Member]	'
Loss Contingencies [Line Items]	'
Maximum potential total of future payments under commitments	$0

Unrecorded_Unconditional_Purch

Unrecorded Unconditional Purchase Obligation (Details) (Purchase Commitment [Member], USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Purchase Commitment [Member]	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'
Less than 1 year	$240,870
1 - 3 years	260,218
3 - 5 years	199,144
More than 5 years	583,333
Total Purchase Obligations	$1,283,565

Costs_Related_to_Purchase_Obli

Costs Related to Purchase Obligations (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Schedule of Costs Related to Purchase Obligations [Line Items]	'	'	'
Unrecorded Unconditional Purchase Obligation, Purchases	$249,043	$291,309	$202,883
Major equipment purchases	'	'	'
Schedule of Costs Related to Purchase Obligations [Line Items]	'	'	'
Unrecorded Unconditional Purchase Obligation, Purchases	12,668	101,367	34,219
Firm transportation expense	'	'	'
Schedule of Costs Related to Purchase Obligations [Line Items]	'	'	'
Unrecorded Unconditional Purchase Obligation, Purchases	126,766	78,475	59,606
Gas drilling obligations	'	'	'
Schedule of Costs Related to Purchase Obligations [Line Items]	'	'	'
Unrecorded Unconditional Purchase Obligation, Purchases	109,609	110,975	108,167
Other Obligations	'	'	'
Schedule of Costs Related to Purchase Obligations [Line Items]	'	'	'
Unrecorded Unconditional Purchase Obligation, Purchases	$0	$492	$891

Segment_Information_Industry_S

Segment Information Industry Segment Results (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012	Jun. 30, 2012	Mar. 31, 2012	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	$3,015,551	$3,122,550	$3,991,007
Sales-Purchased Gas	'	'	'	'	'	'	'	'	6,531	3,316	4,344
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	63,202	49,405	66,929
Freight-Outside	3,946	11,563	13,426	10,125	14,061	27,430	49,472	49,293	35,438	107,079	175,633
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	0	0	0
Total Revenue and Other Income	'	'	'	'	'	'	'	'	3,299,685	3,677,526	4,377,045
Revenue From External Customers	'	'	'	'	'	'	'	'	3,120,722	3,282,350	4,237,913
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	46,075	406,687	872,926
Total Assets	11,393,667	'	12,997,594	'	'	'	'	'	11,393,667	12,997,594	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	461,122	427,115	430,577
Segment Reporting - Capital Expenditures	'	'	'	'	'	'	'	'	1,496,056	1,245,497	1,178,375
Equity in Earnings of Affiliates	'	'	'	'	'	'	'	'	-33,133	-27,048	-24,663
Investments in Unconsolidated Equity Affiliates	291,675	'	222,830	'	'	'	'	'	291,675	222,830	'
Total Reportable Business Segments	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	334,910	631,078	1,162,481
Total Assets	10,521,753	'	9,873,863	'	'	'	'	'	10,521,753	9,873,863	'
Coal Segment [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	2,018,067	2,169,625	2,957,760
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	35,438	107,079	175,633
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	0	0	0
Total Revenue and Other Income	'	'	'	'	'	'	'	'	2,053,505	2,276,704	3,133,393
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	336,524	591,627	1,032,697
Total Assets	4,187,285	'	4,104,981	'	'	'	'	'	4,187,285	4,104,981	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	218,414	211,831	214,285
Segment Reporting - Capital Expenditures	'	'	'	'	'	'	'	'	458,653	662,888	472,591
Equity in Earnings of Affiliates	'	'	'	'	'	'	'	'	-17,346	-17,318	-19,629
Investments in Unconsolidated Equity Affiliates	20,512	'	19,517	'	'	'	'	'	20,512	19,517	'
Gas	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	737,701	658,820	748,464
Sales-Purchased Gas	'	'	'	'	'	'	'	'	6,531	3,316	4,344
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	63,202	49,405	66,929
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	-3,167	1,622	-3,303
Total Revenue and Other Income	'	'	'	'	'	'	'	'	810,601	713,163	823,040
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	-1,614	39,451	129,784
Total Assets	6,334,468	'	5,768,882	'	'	'	'	'	6,334,468	5,768,882	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	229,562	202,956	206,821
Segment Reporting - Capital Expenditures	'	'	'	'	'	'	'	'	968,607	532,636	664,612
Equity in Earnings of Affiliates	'	'	'	'	'	'	'	'	-14,684	-9,562	-4,231
Investments in Unconsolidated Equity Affiliates	206,060	'	143,876	'	'	'	'	'	206,060	143,876	'
Other Segments [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	259,783	294,105	284,783
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	-127,553	-142,014	-194,857
Total Revenue and Other Income	'	'	'	'	'	'	'	'	387,336	436,119	479,640
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	-47,468	10,997	3,408
Total Assets	293,486	'	363,676	'	'	'	'	'	293,486	363,676	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	13,146	12,328	9,471
Segment Reporting - Capital Expenditures	'	'	'	'	'	'	'	'	68,796	49,973	41,172
Equity in Earnings of Affiliates	'	'	'	'	'	'	'	'	-1,102	-168	'
Intersegment Eliminations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	0	0	0
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	130,720	143,636	198,160
Total Revenue and Other Income	'	'	'	'	'	'	'	'	-130,720	-143,636	-198,160
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	-241,367	-235,388	-292,963
Total Assets	578,428	'	2,760,055	'	'	'	'	'	578,428	2,760,055	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting - Capital Expenditures	'	'	'	'	'	'	'	'	0	0	0
All Other [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Equity in Earnings of Affiliates	'	'	'	'	'	'	'	'	'	'	-803
Investments in Unconsolidated Equity Affiliates	65,103	'	59,437	'	'	'	'	'	65,103	59,437	'
Steam [Member] | Coal Segment [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	1,388,005	1,430,912	1,495,480
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	0	0	0
Total Revenue and Other Income	'	'	'	'	'	'	'	'	1,388,005	1,430,912	1,495,480
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	375,787	396,748	421,683
Low Volatile Metallurgical | Coal Segment [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	447,417	505,670	1,071,570
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	0	0	0
Total Revenue and Other Income	'	'	'	'	'	'	'	'	447,417	505,670	1,071,570
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	121,285	210,133	692,249
High Volatile Metallurgical | Coal Segment [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	159,888	210,153	324,377
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	0	0	0
Total Revenue and Other Income	'	'	'	'	'	'	'	'	159,888	210,153	324,377
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	40,500	57,163	129,119
Other Coal | Coal Segment [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	22,757	22,890	66,333
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	35,438	107,079	175,633
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	0	0	0
Total Revenue and Other Income	'	'	'	'	'	'	'	'	58,195	129,969	241,966
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	-201,048	-72,417	-210,354
Coalbed Methane | Gas	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	335,730	379,595	462,677
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	0	0	0
Total Revenue and Other Income	'	'	'	'	'	'	'	'	335,730	379,595	462,677
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	81,392	125,970	185,761
Marcellus Shale | Gas	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	251,846	134,080	118,973
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	0	0	0
Total Revenue and Other Income	'	'	'	'	'	'	'	'	251,846	134,080	118,973
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	79,439	29,546	41,566
Conventional Gas | Gas	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	131,135	135,412	155,444
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	0	0	0
Total Revenue and Other Income	'	'	'	'	'	'	'	'	131,135	135,412	155,444
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	-17,829	-13,390	-14,732
Other Gas | Gas	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	18,990	9,733	11,370
Sales-Purchased Gas	'	'	'	'	'	'	'	'	6,531	3,316	4,344
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	63,202	49,405	66,929
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Segment Reporting - Intersegment Transfers	'	'	'	'	'	'	'	'	-3,167	-1,622	-3,303
Total Revenue and Other Income	'	'	'	'	'	'	'	'	91,890	64,076	85,946
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	-144,616	-102,675	-82,811
XCoal Energy and Resources [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Total Revenue and Other Income	'	'	'	'	'	'	'	'	495,242	382,843	655,596
Duke Energy [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Total Revenue and Other Income	'	'	'	'	'	'	'	'	$346,424	'	'

Reconciliation_of_Segment_Info

Reconciliation of Segment Information, Revenue and Other Income (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'
Total Revenue and Other Income	$3,299,685,000	$3,677,526,000	$4,377,045,000
Revenue From External Customers	3,120,722,000	3,282,350,000	4,237,913,000
Earnings Before Income Taxes:	'	'	'
Earnings Before Income Taxes	46,075,000	406,687,000	872,926,000
Acquisition and Financing Fees	0	0	-14,907,000
Other Income	178,963,000	395,176,000	139,132,000
Total Reportable Business Segments	'	'	'
Earnings Before Income Taxes:	'	'	'
Earnings Before Income Taxes	334,910,000	631,078,000	1,162,481,000
Coal Segment [Member]	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'
Total Revenue and Other Income	2,053,505,000	2,276,704,000	3,133,393,000
Earnings Before Income Taxes:	'	'	'
Earnings Before Income Taxes	336,524,000	591,627,000	1,032,697,000
Gas	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'
Total Revenue and Other Income	810,601,000	713,163,000	823,040,000
Earnings Before Income Taxes:	'	'	'
Earnings Before Income Taxes	-1,614,000	39,451,000	129,784,000
Other Segments [Member]	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'
Total Revenue and Other Income	387,336,000	436,119,000	479,640,000
Earnings Before Income Taxes:	'	'	'
Earnings Before Income Taxes	-47,468,000	10,997,000	3,408,000
Excludes Gas Segment [Member]	'	'	'
Earnings Before Income Taxes:	'	'	'
Interest Income (Expense), Net and Other Non-operating Activity	-226,199,000	-228,804,000	-258,308,000
Acquisition and Financing Fees	0	0	14,907,000
Fees for Disposing Non-core Assets	-15,168,000	-6,584,000	5,780,000
Corporate Adjustments And Eliminations [Member]	'	'	'
Earnings Before Income Taxes:	'	'	'
Gain (Loss) Estimates on Extinguishment of Debt	0	0	-16,090,000
Intersegment Eliminations [Member]	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'
Total Revenue and Other Income	-130,720,000	-143,636,000	-198,160,000
Earnings Before Income Taxes:	'	'	'
Earnings Before Income Taxes	-241,367,000	-235,388,000	-292,963,000
Segment Lease Settlement	0	0	2,122,000
UNITED STATES	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'
Total Revenue and Other Income	2,999,674,000	2,898,341,000	3,460,871,000
Europe [Member]	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'
Total Revenue and Other Income	83,878,000	187,313,000	366,384,000
South America [Member]	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'
Total Revenue and Other Income	29,787,000	169,591,000	400,307,000
CANADA	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'
Total Revenue and Other Income	3,575,000	5,692,000	10,351,000
Other Credit Derivatives [Member]	'	'	'
Segment Reporting, Revenue Reconciling Item [Line Items]	'	'	'
Total Revenue and Other Income	$3,808,000	$21,413,000	$0

Reconciliation_of_Segment_Info1

Reconciliation of Segment Information, Total Assets (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Assets:	'	'
Assets	$11,393,667,000	$12,997,594,000
Items excluded from segment assets:	'	'
Income Taxes Receivable, Current	10,705,000	0
Deferred Tax Assets	1,025,808,000	856,830,000
Assets of Disposal Group, Including Discontinued Operation	0	2,614,251,000
Total Property, Plant and Equipment-Net	9,442,262,000	10,190,967,000
Total Reportable Business Segments	'	'
Assets:	'	'
Assets	10,521,753,000	9,873,863,000
Coal Segment [Member]	'	'
Assets:	'	'
Assets	4,187,285,000	4,104,981,000
Gas	'	'
Assets:	'	'
Assets	6,334,468,000	5,768,882,000
Other Segments [Member]	'	'
Assets:	'	'
Assets	293,486,000	363,676,000
Excludes Gas Segment [Member]	'	'
Items excluded from segment assets:	'	'
Cash and Other Investments	321,992,000	19,252,000
Intersegment Eliminations [Member]	'	'
Assets:	'	'
Assets	578,428,000	2,760,055,000
Items excluded from segment assets:	'	'
Income Taxes Receivable, Current	10,705,000	0
Deferred Tax Assets	211,303,000	84,777,000
Bond Issuance Costs	34,428,000	41,775,000
Assets of Disposal Group, Including Discontinued Operation	0	2,614,251,000
UNITED STATES	'	'
Segment Reporting, Asset Reconciling Item [Line Items]	'	'
Disclosure of Long-Live Assets by Geographic Region	9,431,238,000	8,487,614,000
CANADA	'	'
Segment Reporting, Asset Reconciling Item [Line Items]	'	'
Disclosure of Long-Live Assets by Geographic Region	11,024,000	20,444,000
Discontinued Operations [Member]	'	'
Segment Reporting, Asset Reconciling Item [Line Items]	'	'
Disclosure of Long-Live Assets by Geographic Region	$0	$1,682,909,000

Guarantor_Subsidiaries_Financi2

Guarantor Subsidiaries Financial Information Additional Information (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Senior Notes Due April 2017 at 8.00%	'
Condensed Financial Statements, Captions [Line Items]	'
Debt Instrument, Face Amount	$1,500,000
Interest rate stated percentage	8.00%
Senior notes due April 2020 at 8.25%	'
Condensed Financial Statements, Captions [Line Items]	'
Debt Instrument, Face Amount	1,250,000
Interest rate stated percentage	8.25%
Senior notes due March 2021 at 6.375%	'
Condensed Financial Statements, Captions [Line Items]	'
Debt Instrument, Face Amount	$250,000
Interest rate stated percentage	6.38%

Guarantor_Subsidiaries_Income_

Guarantor Subsidiaries Income Statement (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012	Jun. 30, 2012	Mar. 31, 2012	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Schedule of Condensed Consolidating Statement of Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	$3,015,551,000	$3,122,550,000	$3,991,007,000
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	63,202,000	49,405,000	66,929,000
Sales-Purchased Gas	'	'	'	'	'	'	'	'	6,531,000	3,316,000	4,344,000
Freight-Outside	3,946,000	11,563,000	13,426,000	10,125,000	14,061,000	27,430,000	49,472,000	49,293,000	35,438,000	107,079,000	175,633,000
Other Income	'	'	'	'	'	'	'	'	178,963,000	395,176,000	139,132,000
Total Revenue and Other Income	'	'	'	'	'	'	'	'	3,299,685,000	3,677,526,000	4,377,045,000
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	562,386,000	560,247,000	557,094,000	552,126,000	612,000,000	543,158,000	565,601,000	601,723,000	2,228,952,000	2,221,859,000	2,266,560,000
Gas Royalty Interests Costs	'	'	'	'	'	'	'	'	53,028,000	38,867,000	59,331,000
Purchased Gas Costs	'	'	'	'	'	'	'	'	4,837,000	2,711,000	3,831,000
Related Party Activity	'	'	'	'	'	'	'	'	0	0	0
Freight Expense	3,946,000	11,563,000	13,426,000	10,125,000	14,061,000	27,430,000	49,472,000	49,293,000	35,438,000	107,079,000	175,444,000
Selling, General and Administrative Expenses	'	'	'	'	'	'	'	'	90,408,000	90,740,000	114,643,000
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	461,122,000	427,115,000	430,577,000
Interest Expense	'	'	'	'	'	'	'	'	219,198,000	220,042,000	248,344,000
Taxes Other Than Income	'	'	'	'	'	'	'	'	160,627,000	162,426,000	174,392,000
Acquisition and Financing Fees	'	'	'	'	'	'	'	'	0	0	14,907,000
Gains (Losses) on Extinguishment of Debt	'	'	'	'	'	'	'	'	0	0	16,090,000
Total Costs	'	'	'	'	'	'	'	'	3,253,610,000	3,270,839,000	3,504,119,000
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	46,075,000	406,687,000	872,926,000
Income Taxes	'	'	'	'	'	'	'	'	-33,189,000	88,728,000	191,251,000
Income (Loss) from Continuing Operations Attributable to Parent	146,595,000	-72,169,000	107,580,000	8,562,000	-3,725,000	-26,316,000	155,789,000	80,906,000	79,264,000	317,959,000	681,675,000
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	79,264,000	317,959,000	'
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	579,792,000	70,114,000	'
Net Income (Loss)	'	'	'	'	'	'	'	'	659,056,000	388,073,000	632,497,000
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax	591,144,000	8,120,000	42,060,000	-21,375,000	1,904,000	14,814,000	-3,050,000	16,290,000	579,792,000	70,114,000	-49,178,000
Less: Net Loss (Income) Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	1,386,000	397,000	0
Net Income Attributable to CONSOL Energy Inc Shareholders	738,183,000	-63,651,000	149,903,000	-12,526,000	-1,564,000	-11,368,000	152,739,000	97,196,000	660,442,000	388,470,000	632,497,000
Parent Issuer	'	'	'	'	'	'	'	'	'	'	'
Schedule of Condensed Consolidating Statement of Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	0	0	0
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Other Income	'	'	'	'	'	'	'	'	930,481,000	613,340,000	876,233,000
Total Revenue and Other Income	'	'	'	'	'	'	'	'	930,481,000	613,340,000	876,233,000
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	'	'	'	'	'	'	'	'	170,702,000	127,372,000	108,681,000
Gas Royalty Interests Costs	'	'	'	'	'	'	'	'	0	0	0
Purchased Gas Costs	'	'	'	'	'	'	'	'	0	0	0
Related Party Activity	'	'	'	'	'	'	'	'	35,678,000	12,865,000	4,767,000
Freight Expense	'	'	'	'	'	'	'	'	0	0	0
Selling, General and Administrative Expenses	'	'	'	'	'	'	'	'	0	0	0
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	12,857,000	12,172,000	12,194,000
Interest Expense	'	'	'	'	'	'	'	'	211,449,000	208,894,000	235,370,000
Taxes Other Than Income	'	'	'	'	'	'	'	'	3,669,000	401,000	950,000
Acquisition and Financing Fees	'	'	'	'	'	'	'	'	'	'	14,907,000
Gains (Losses) on Extinguishment of Debt	'	'	'	'	'	'	'	'	'	'	-16,090,000
Total Costs	'	'	'	'	'	'	'	'	434,355,000	361,704,000	392,959,000
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	496,126,000	251,636,000	483,274,000
Income Taxes	'	'	'	'	'	'	'	'	-164,316,000	-136,834,000	-149,223,000
Income (Loss) from Continuing Operations Attributable to Parent	'	'	'	'	'	'	'	'	'	'	632,497,000
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	660,442,000	388,470,000	'
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	0	0	'
Net Income (Loss)	'	'	'	'	'	'	'	'	660,442,000	388,470,000	632,497,000
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax	'	'	'	'	'	'	'	'	'	'	0
Less: Net Loss (Income) Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	0	0	'
Net Income Attributable to CONSOL Energy Inc Shareholders	'	'	'	'	'	'	'	'	660,442,000	388,470,000	632,497,000
Cnx Gas Guarantor [Member]	'	'	'	'	'	'	'	'	'	'	'
Schedule of Condensed Consolidating Statement of Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	740,869,000	660,442,000	751,767,000
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	63,202,000	49,405,000	4,344,000
Sales-Purchased Gas	'	'	'	'	'	'	'	'	6,531,000	3,316,000	66,929,000
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Other Income	'	'	'	'	'	'	'	'	57,592,000	56,946,000	58,923,000
Total Revenue and Other Income	'	'	'	'	'	'	'	'	868,194,000	770,109,000	881,963,000
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	'	'	'	'	'	'	'	'	493,416,000	407,045,000	388,507,000
Gas Royalty Interests Costs	'	'	'	'	'	'	'	'	53,069,000	38,922,000	59,377,000
Purchased Gas Costs	'	'	'	'	'	'	'	'	4,837,000	2,711,000	3,831,000
Related Party Activity	'	'	'	'	'	'	'	'	0	0	0
Freight Expense	'	'	'	'	'	'	'	'	0	0	0
Selling, General and Administrative Expenses	'	'	'	'	'	'	'	'	44,733,000	40,101,000	50,429,000
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	229,562,000	202,956,000	206,821,000
Interest Expense	'	'	'	'	'	'	'	'	8,605,000	5,098,000	9,398,000
Taxes Other Than Income	'	'	'	'	'	'	'	'	35,176,000	33,892,000	34,023,000
Acquisition and Financing Fees	'	'	'	'	'	'	'	'	'	'	0
Gains (Losses) on Extinguishment of Debt	'	'	'	'	'	'	'	'	'	'	0
Total Costs	'	'	'	'	'	'	'	'	869,398,000	730,725,000	752,386,000
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	-1,204,000	39,384,000	129,577,000
Income Taxes	'	'	'	'	'	'	'	'	1,420,000	15,021,000	51,876,000
Income (Loss) from Continuing Operations Attributable to Parent	'	'	'	'	'	'	'	'	'	'	77,701,000
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	-2,624,000	24,363,000	'
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	0	0	'
Net Income (Loss)	'	'	'	'	'	'	'	'	-2,624,000	24,363,000	77,701,000
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax	'	'	'	'	'	'	'	'	'	'	0
Less: Net Loss (Income) Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	1,386,000	397,000	'
Net Income Attributable to CONSOL Energy Inc Shareholders	'	'	'	'	'	'	'	'	-1,238,000	24,760,000	77,701,000
Other Subsidiary Guarantors	'	'	'	'	'	'	'	'	'	'	'
Schedule of Condensed Consolidating Statement of Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	2,061,652,000	2,221,421,000	3,009,104,000
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	35,438,000	107,079,000	175,633,000
Other Income	'	'	'	'	'	'	'	'	100,757,000	316,592,000	48,673,000
Total Revenue and Other Income	'	'	'	'	'	'	'	'	2,197,847,000	2,645,092,000	3,233,410,000
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	'	'	'	'	'	'	'	'	1,313,601,000	1,417,519,000	1,443,472,000
Gas Royalty Interests Costs	'	'	'	'	'	'	'	'	0	0	0
Purchased Gas Costs	'	'	'	'	'	'	'	'	0	0	0
Related Party Activity	'	'	'	'	'	'	'	'	-112,626,000	-22,466,000	-25,720,000
Freight Expense	'	'	'	'	'	'	'	'	35,438,000	107,079,000	175,444,000
Selling, General and Administrative Expenses	'	'	'	'	'	'	'	'	44,357,000	49,222,000	62,729,000
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	216,726,000	209,923,000	209,159,000
Interest Expense	'	'	'	'	'	'	'	'	-423,000	6,470,000	3,911,000
Taxes Other Than Income	'	'	'	'	'	'	'	'	118,675,000	125,288,000	136,382,000
Acquisition and Financing Fees	'	'	'	'	'	'	'	'	'	'	0
Gains (Losses) on Extinguishment of Debt	'	'	'	'	'	'	'	'	'	'	0
Total Costs	'	'	'	'	'	'	'	'	1,615,748,000	1,893,035,000	2,005,377,000
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	582,099,000	752,057,000	1,228,033,000
Income Taxes	'	'	'	'	'	'	'	'	126,164,000	204,105,000	279,500,000
Income (Loss) from Continuing Operations Attributable to Parent	'	'	'	'	'	'	'	'	'	'	948,533,000
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	455,935,000	547,952,000	'
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	0	0	'
Net Income (Loss)	'	'	'	'	'	'	'	'	455,935,000	547,952,000	948,533,000
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax	'	'	'	'	'	'	'	'	'	'	0
Less: Net Loss (Income) Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	0	0	'
Net Income Attributable to CONSOL Energy Inc Shareholders	'	'	'	'	'	'	'	'	455,935,000	547,952,000	948,533,000
Non-Guarantors	'	'	'	'	'	'	'	'	'	'	'
Schedule of Condensed Consolidating Statement of Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	216,419,000	243,059,000	234,998,000
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Other Income	'	'	'	'	'	'	'	'	20,614,000	21,639,000	26,309,000
Total Revenue and Other Income	'	'	'	'	'	'	'	'	237,033,000	264,698,000	261,307,000
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	'	'	'	'	'	'	'	'	219,450,000	239,502,000	228,291,000
Gas Royalty Interests Costs	'	'	'	'	'	'	'	'	0	0	0
Purchased Gas Costs	'	'	'	'	'	'	'	'	0	0	0
Related Party Activity	'	'	'	'	'	'	'	'	1,767,000	1,814,000	1,986,000
Freight Expense	'	'	'	'	'	'	'	'	0	0	0
Selling, General and Administrative Expenses	'	'	'	'	'	'	'	'	1,318,000	1,417,000	1,485,000
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	1,977,000	2,064,000	2,403,000
Interest Expense	'	'	'	'	'	'	'	'	47,000	44,000	53,000
Taxes Other Than Income	'	'	'	'	'	'	'	'	3,107,000	2,845,000	3,037,000
Acquisition and Financing Fees	'	'	'	'	'	'	'	'	'	'	0
Gains (Losses) on Extinguishment of Debt	'	'	'	'	'	'	'	'	'	'	0
Total Costs	'	'	'	'	'	'	'	'	227,666,000	247,686,000	237,255,000
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	9,367,000	17,012,000	24,052,000
Income Taxes	'	'	'	'	'	'	'	'	3,543,000	6,436,000	9,098,000
Income (Loss) from Continuing Operations Attributable to Parent	'	'	'	'	'	'	'	'	'	'	14,954,000
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	5,824,000	10,576,000	'
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	579,792,000	70,114,000	'
Net Income (Loss)	'	'	'	'	'	'	'	'	585,616,000	80,690,000	-34,224,000
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax	'	'	'	'	'	'	'	'	'	'	-49,178,000
Less: Net Loss (Income) Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	0	0	'
Net Income Attributable to CONSOL Energy Inc Shareholders	'	'	'	'	'	'	'	'	585,616,000	80,690,000	-34,224,000
Elimination	'	'	'	'	'	'	'	'	'	'	'
Schedule of Condensed Consolidating Statement of Operations [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Sales-Outside	'	'	'	'	'	'	'	'	-3,389,000	-2,372,000	-4,862,000
Sales-Gas Royalty Interests	'	'	'	'	'	'	'	'	0	0	0
Sales-Purchased Gas	'	'	'	'	'	'	'	'	0	0	0
Freight-Outside	'	'	'	'	'	'	'	'	0	0	0
Other Income	'	'	'	'	'	'	'	'	-930,481,000	-613,341,000	-871,006,000
Total Revenue and Other Income	'	'	'	'	'	'	'	'	-933,870,000	-615,713,000	-875,868,000
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	'	'	'	'	'	'	'	'	31,783,000	30,421,000	97,609,000
Gas Royalty Interests Costs	'	'	'	'	'	'	'	'	-41,000	-55,000	-46,000
Purchased Gas Costs	'	'	'	'	'	'	'	'	0	0	0
Related Party Activity	'	'	'	'	'	'	'	'	75,181,000	7,787,000	18,967,000
Freight Expense	'	'	'	'	'	'	'	'	0	0	0
Selling, General and Administrative Expenses	'	'	'	'	'	'	'	'	0	0	0
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	0	0	0
Interest Expense	'	'	'	'	'	'	'	'	-480,000	-464,000	-388,000
Taxes Other Than Income	'	'	'	'	'	'	'	'	0	0	0
Acquisition and Financing Fees	'	'	'	'	'	'	'	'	'	'	0
Gains (Losses) on Extinguishment of Debt	'	'	'	'	'	'	'	'	'	'	0
Total Costs	'	'	'	'	'	'	'	'	106,443,000	37,689,000	116,142,000
Earnings Before Income Taxes	'	'	'	'	'	'	'	'	-1,040,313,000	-653,402,000	-992,010,000
Income Taxes	'	'	'	'	'	'	'	'	0	0	0
Income (Loss) from Continuing Operations Attributable to Parent	'	'	'	'	'	'	'	'	'	'	-992,010,000
Income (Loss) from Continuing Operations, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	-1,040,313,000	-653,402,000	'
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	0	0	'
Net Income (Loss)	'	'	'	'	'	'	'	'	-1,040,313,000	-653,402,000	-992,010,000
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax	'	'	'	'	'	'	'	'	'	'	0
Less: Net Loss (Income) Attributable to Noncontrolling Interest	'	'	'	'	'	'	'	'	0	0	'
Net Income Attributable to CONSOL Energy Inc Shareholders	'	'	'	'	'	'	'	'	($1,040,313,000)	($653,402,000)	($992,010,000)

Guarantor_Subsidiaries_Balance

Guarantor Subsidiaries Balance Sheet (Detail) (USD $)	Dec. 31, 2013	Jan. 02, 2013	Dec. 31, 2012	Jan. 02, 2012	Dec. 31, 2011	Jan. 02, 2011
In Thousands, unless otherwise specified
Current Assets:	'	'	'	'	'	'
Cash and Cash Equivalents	$327,420	$21,862	$21,862	$375,736	$375,736	$32,794
Accounts and Notes Receivable:	'	'	'	'	'	'
Trade	332,574	'	428,328	'	'	'
Notes, Loans and Financing Receivable, Net, Current	25,861	'	318,387	'	'	'
Other Receivables	243,973	'	131,131	'	'	'
Securitized	'	'	37,846	'	'	'
Inventories	157,914	'	170,808	'	'	'
Income Taxes Receivable, Current	10,705	'	0	'	'	'
Deferred Income Taxes	211,303	'	84,777	'	'	'
Restricted Cash and Cash Equivalents, Current	0	'	48,294	'	'	'
Prepaid Expenses	135,842	'	148,431	'	'	'
Assets of Disposal Group, Including Discontinued Operation, Current	0	'	149,230	'	'	'
Total Current Assets	1,445,592	'	1,539,094	'	'	'
Property, Plant and Equipment:	'	'	'	'	'	'
Property, Plant and Equipment, Gross	13,578,509	'	12,121,557	'	'	'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	4,136,247	'	3,613,499	'	'	'
Disposal Group, Including Discontinued Operation, Property, Plant, and Equipment, Net	0	'	1,682,909	'	'	'
Total Property, Plant and Equipment-Net	9,442,262	'	10,190,967	'	'	'
Other Assets:	'	'	'	'	'	'
Restricted Cash	0	'	20,379	'	'	'
Investments in Unconsolidated Equity Affiliates	291,675	'	222,830	'	'	'
Notes, Loans and Financing Receivable, Net, Noncurrent	125	'	25,977	'	'	'
Other	214,013	'	216,235	'	'	'
Disposal Group, Including Discontinued Operation, Other Assets	0	'	782,112	'	'	'
Total Other Assets	505,813	'	1,267,533	'	'	'
Total Assets	11,393,667	'	12,997,594	'	'	'
Current Liabilities:	'	'	'	'	'	'
Accounts Payable	514,580	'	498,515	'	'	'
Accounts Payable (Recoverable)- Related Parties	0	'	0	'	'	'
Current Portion Long-Term Debt	11,455	'	12,484	'	'	'
Short-term Non-bank Loans and Notes Payable	0	'	25,073	'	'	'
Accrued Income Taxes	'	'	34,219	'	'	'
Borrowings under Securitization Facility	0	'	37,846	'	'	'
Other Accrued Liabilities	565,697	'	545,748	'	'	'
Other Accrued Liabilities, Current	122,902	'	144,352	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	28,239	'	233,214	'	'	'
Total Current Liabilities	1,119,971	'	1,387,099	'	'	'
Long-Term Debt	3,115,963	'	3,123,600	'	'	'
Capital Lease Obligations	47,596	'	49,413	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation	0	'	1,573	'	'	'
Long-Term Debt:	3,163,559	'	3,174,586	'	'	'
Deferred Tax Liabilities, Net, Noncurrent	242,643	'	326,685	'	'	'
Deferred Credits and Other Liabilities	'	'	'	'	'	'
Postretirement Benefits Other Than Pensions	961,127	'	882,600	'	'	'
Pneumoconiosis	111,971	'	114,136	'	'	'
Mine Closing	320,723	'	289,818	'	'	'
Gas Well Closing	175,603	'	146,002	'	'	'
Workers' Compensation	71,468	'	60,396	'	'	'
Salary Retirement	48,252	'	218,004	'	'	'
Reclamation	40,706	'	47,965	'	'	'
Other	131,355	'	118,307	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	0	'	2,278,251	'	'	'
Total Deferred Credits and Other Liabilities	2,103,848	'	4,482,164	'	'	'
Total CONSOL Energy Inc. Stockholders' Equity	5,006,289	'	3,953,792	'	'	'
Noncontrolling Interest	0	'	-47	'	'	'
TOTAL LIABILITIES AND EQUITY	11,393,667	'	12,997,594	'	'	'
Parent Issuer	'	'	'	'	'	'
Current Assets:	'	'	'	'	'	'
Cash and Cash Equivalents	320,473	'	17,491	'	'	'
Accounts and Notes Receivable:	'	'	'	'	'	'
Trade	0	'	0	'	'	'
Notes, Loans and Financing Receivable, Net, Current	1,238	'	154	'	'	'
Other Receivables	17,657	'	6,335	'	'	'
Securitized	'	'	0	'	'	'
Inventories	0	'	0	'	'	'
Income Taxes Receivable, Current	-16,262	'	'	'	'	'
Deferred Income Taxes	219,566	'	174,176	'	'	'
Restricted Cash and Cash Equivalents, Current	'	'	0	'	'	'
Prepaid Expenses	43,698	'	29,589	'	'	'
Assets of Disposal Group, Including Discontinued Operation, Current	'	'	0	'	'	'
Total Current Assets	586,370	'	227,745	'	'	'
Property, Plant and Equipment:	'	'	'	'	'	'
Property, Plant and Equipment, Gross	220,355	'	216,448	'	'	'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	145,754	'	126,048	'	'	'
Disposal Group, Including Discontinued Operation, Property, Plant, and Equipment, Net	'	'	0	'	'	'
Total Property, Plant and Equipment-Net	74,601	'	90,400	'	'	'
Other Assets:	'	'	'	'	'	'
Restricted Cash	'	'	0	'	'	'
Investments in Unconsolidated Equity Affiliates	11,965,054	'	9,917,050	'	'	'
Notes, Loans and Financing Receivable, Net, Noncurrent	125	'	239	'	'	'
Other	145,401	'	118,938	'	'	'
Disposal Group, Including Discontinued Operation, Other Assets	'	'	0	'	'	'
Total Other Assets	12,110,580	'	10,036,227	'	'	'
Total Assets	12,771,551	'	10,354,372	'	'	'
Current Liabilities:	'	'	'	'	'	'
Accounts Payable	180,261	'	177,734	'	'	'
Accounts Payable (Recoverable)- Related Parties	4,563,327	'	3,599,216	'	'	'
Current Portion Long-Term Debt	1,029	'	1,554	'	'	'
Short-term Non-bank Loans and Notes Payable	0	'	25,073	'	'	'
Accrued Income Taxes	'	'	20,488	'	'	'
Borrowings under Securitization Facility	'	'	0	'	'	'
Other Accrued Liabilities	144,612	'	135,407	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	0	'	0	'	'	'
Total Current Liabilities	4,889,229	'	3,959,472	'	'	'
Long-Term Debt	3,004,213	'	3,004,798	'	'	'
Capital Lease Obligations	1,245	'	717	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation	'	'	0	'	'	'
Long-Term Debt:	3,005,458	'	3,005,515	'	'	'
Deferred Tax Liabilities, Net, Noncurrent	-232,904	'	-884,310	'	'	'
Deferred Credits and Other Liabilities	'	'	'	'	'	'
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	48,252	'	218,004	'	'	'
Reclamation	0	'	0	'	'	'
Other	55,227	'	101,899	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	'	'	0	'	'	'
Total Deferred Credits and Other Liabilities	-129,425	'	-564,407	'	'	'
Total CONSOL Energy Inc. Stockholders' Equity	5,006,289	'	3,953,792	'	'	'
Noncontrolling Interest	'	'	0	'	'	'
TOTAL LIABILITIES AND EQUITY	12,771,551	'	10,354,372	'	'	'
Cnx Gas Guarantor [Member]	'	'	'	'	'	'
Current Assets:	'	'	'	'	'	'
Cash and Cash Equivalents	6,238	'	3,352	'	'	'
Accounts and Notes Receivable:	'	'	'	'	'	'
Trade	71,911	'	58,126	'	'	'
Notes, Loans and Financing Receivable, Net, Current	0	'	315,730	'	'	'
Other Receivables	207,128	'	214,748	'	'	'
Securitized	'	'	0	'	'	'
Inventories	15,185	'	14,133	'	'	'
Income Taxes Receivable, Current	26,967	'	'	'	'	'
Deferred Income Taxes	-8,263	'	-26,072	'	'	'
Restricted Cash and Cash Equivalents, Current	'	'	0	'	'	'
Prepaid Expenses	65,701	'	86,186	'	'	'
Assets of Disposal Group, Including Discontinued Operation, Current	'	'	0	'	'	'
Total Current Assets	384,867	'	666,203	'	'	'
Property, Plant and Equipment:	'	'	'	'	'	'
Property, Plant and Equipment, Gross	6,919,972	'	5,956,207	'	'	'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	1,188,464	'	960,613	'	'	'
Disposal Group, Including Discontinued Operation, Property, Plant, and Equipment, Net	'	'	0	'	'	'
Total Property, Plant and Equipment-Net	5,731,508	'	4,995,594	'	'	'
Other Assets:	'	'	'	'	'	'
Restricted Cash	'	'	0	'	'	'
Investments in Unconsolidated Equity Affiliates	206,060	'	143,876	'	'	'
Notes, Loans and Financing Receivable, Net, Noncurrent	0	'	0	'	'	'
Other	30,728	'	65,935	'	'	'
Disposal Group, Including Discontinued Operation, Other Assets	'	'	0	'	'	'
Total Other Assets	236,788	'	209,811	'	'	'
Total Assets	6,353,163	'	5,871,608	'	'	'
Current Liabilities:	'	'	'	'	'	'
Accounts Payable	324,226	'	166,182	'	'	'
Accounts Payable (Recoverable)- Related Parties	23,287	'	23,981	'	'	'
Current Portion Long-Term Debt	6,258	'	5,953	'	'	'
Short-term Non-bank Loans and Notes Payable	332,487	'	0	'	'	'
Accrued Income Taxes	'	'	13,731	'	'	'
Borrowings under Securitization Facility	'	'	0	'	'	'
Other Accrued Liabilities	89,080	'	57,074	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	0	'	0	'	'	'
Total Current Liabilities	775,338	'	266,921	'	'	'
Long-Term Debt	0	'	0	'	'	'
Capital Lease Obligations	42,852	'	46,081	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation	'	'	0	'	'	'
Long-Term Debt:	42,852	'	46,081	'	'	'
Deferred Tax Liabilities, Net, Noncurrent	475,547	'	439,725	'	'	'
Deferred Credits and Other Liabilities	'	'	'	'	'	'
Postretirement Benefits Other Than Pensions	0	'	0	'	'	'
Pneumoconiosis	0	'	0	'	'	'
Mine Closing	0	'	0	'	'	'
Gas Well Closing	119,429	'	80,097	'	'	'
Workers' Compensation	0	'	0	'	'	'
Salary Retirement	0	'	0	'	'	'
Reclamation	0	'	0	'	'	'
Other	61,190	'	24,518	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	'	'	0	'	'	'
Total Deferred Credits and Other Liabilities	656,166	'	544,340	'	'	'
Total CONSOL Energy Inc. Stockholders' Equity	4,878,807	'	5,014,313	'	'	'
Noncontrolling Interest	'	'	-47	'	'	'
TOTAL LIABILITIES AND EQUITY	6,353,163	'	5,871,608	'	'	'
Other Subsidiary Guarantors	'	'	'	'	'	'
Current Assets:	'	'	'	'	'	'
Cash and Cash Equivalents	0	'	159	'	'	'
Accounts and Notes Receivable:	'	'	'	'	'	'
Trade	0	'	0	'	'	'
Notes, Loans and Financing Receivable, Net, Current	24,623	'	2,503	'	'	'
Other Receivables	14,969	'	33,289	'	'	'
Securitized	'	'	0	'	'	'
Inventories	99,320	'	121,311	'	'	'
Income Taxes Receivable, Current	0	'	'	'	'	'
Deferred Income Taxes	0	'	-63,327	'	'	'
Restricted Cash and Cash Equivalents, Current	'	'	48,294	'	'	'
Prepaid Expenses	24,915	'	31,286	'	'	'
Assets of Disposal Group, Including Discontinued Operation, Current	'	'	0	'	'	'
Total Current Assets	163,827	'	173,515	'	'	'
Property, Plant and Equipment:	'	'	'	'	'	'
Property, Plant and Equipment, Gross	6,412,378	'	5,923,723	'	'	'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	2,783,043	'	2,508,769	'	'	'
Disposal Group, Including Discontinued Operation, Property, Plant, and Equipment, Net	'	'	0	'	'	'
Total Property, Plant and Equipment-Net	3,629,335	'	3,414,954	'	'	'
Other Assets:	'	'	'	'	'	'
Restricted Cash	'	'	20,379	'	'	'
Investments in Unconsolidated Equity Affiliates	70,222	'	769,058	'	'	'
Notes, Loans and Financing Receivable, Net, Noncurrent	0	'	25,738	'	'	'
Other	28,831	'	21,174	'	'	'
Disposal Group, Including Discontinued Operation, Other Assets	'	'	0	'	'	'
Total Other Assets	99,053	'	836,349	'	'	'
Total Assets	3,892,215	'	4,424,818	'	'	'
Current Liabilities:	'	'	'	'	'	'
Accounts Payable	493	'	145,469	'	'	'
Accounts Payable (Recoverable)- Related Parties	-5,055,923	'	-3,749,584	'	'	'
Current Portion Long-Term Debt	3,372	'	4,221	'	'	'
Short-term Non-bank Loans and Notes Payable	0	'	0	'	'	'
Accrued Income Taxes	'	'	0	'	'	'
Borrowings under Securitization Facility	'	'	0	'	'	'
Other Accrued Liabilities	322,606	'	343,739	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	0	'	0	'	'	'
Total Current Liabilities	-4,729,452	'	-3,256,155	'	'	'
Long-Term Debt	111,750	'	118,802	'	'	'
Capital Lease Obligations	1,724	'	1,148	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation	'	'	0	'	'	'
Long-Term Debt:	113,474	'	119,950	'	'	'
Deferred Tax Liabilities, Net, Noncurrent	0	'	771,270	'	'	'
Deferred Credits and Other Liabilities	'	'	'	'	'	'
Postretirement Benefits Other Than Pensions	961,127	'	882,600	'	'	'
Pneumoconiosis	111,971	'	114,136	'	'	'
Mine Closing	320,723	'	289,818	'	'	'
Gas Well Closing	56,174	'	65,905	'	'	'
Workers' Compensation	71,136	'	60,090	'	'	'
Salary Retirement	0	'	0	'	'	'
Reclamation	40,706	'	47,965	'	'	'
Other	14,938	'	-8,110	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	'	'	0	'	'	'
Total Deferred Credits and Other Liabilities	1,576,775	'	2,223,674	'	'	'
Total CONSOL Energy Inc. Stockholders' Equity	6,931,418	'	5,337,349	'	'	'
Noncontrolling Interest	'	'	0	'	'	'
TOTAL LIABILITIES AND EQUITY	3,892,215	'	4,424,818	'	'	'
Non-Guarantors	'	'	'	'	'	'
Current Assets:	'	'	'	'	'	'
Cash and Cash Equivalents	709	'	860	'	'	'
Accounts and Notes Receivable:	'	'	'	'	'	'
Trade	260,663	'	370,202	'	'	'
Notes, Loans and Financing Receivable, Net, Current	0	'	0	'	'	'
Other Receivables	4,219	'	5,159	'	'	'
Securitized	'	'	37,846	'	'	'
Inventories	43,409	'	35,364	'	'	'
Income Taxes Receivable, Current	0	'	'	'	'	'
Deferred Income Taxes	0	'	0	'	'	'
Restricted Cash and Cash Equivalents, Current	'	'	0	'	'	'
Prepaid Expenses	1,528	'	1,370	'	'	'
Assets of Disposal Group, Including Discontinued Operation, Current	'	'	149,230	'	'	'
Total Current Assets	310,528	'	600,031	'	'	'
Property, Plant and Equipment:	'	'	'	'	'	'
Property, Plant and Equipment, Gross	25,804	'	25,179	'	'	'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	18,986	'	18,069	'	'	'
Disposal Group, Including Discontinued Operation, Property, Plant, and Equipment, Net	'	'	1,682,909	'	'	'
Total Property, Plant and Equipment-Net	6,818	'	1,690,019	'	'	'
Other Assets:	'	'	'	'	'	'
Restricted Cash	'	'	0	'	'	'
Investments in Unconsolidated Equity Affiliates	0	'	0	'	'	'
Notes, Loans and Financing Receivable, Net, Noncurrent	0	'	0	'	'	'
Other	9,053	'	10,188	'	'	'
Disposal Group, Including Discontinued Operation, Other Assets	'	'	782,112	'	'	'
Total Other Assets	9,053	'	792,300	'	'	'
Total Assets	326,399	'	3,082,350	'	'	'
Current Liabilities:	'	'	'	'	'	'
Accounts Payable	9,600	'	9,130	'	'	'
Accounts Payable (Recoverable)- Related Parties	136,822	'	254,787	'	'	'
Current Portion Long-Term Debt	796	'	756	'	'	'
Short-term Non-bank Loans and Notes Payable	0	'	0	'	'	'
Accrued Income Taxes	'	'	0	'	'	'
Borrowings under Securitization Facility	'	'	37,846	'	'	'
Other Accrued Liabilities	9,399	'	9,528	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	28,239	'	233,214	'	'	'
Total Current Liabilities	184,856	'	545,261	'	'	'
Long-Term Debt	0	'	0	'	'	'
Capital Lease Obligations	1,775	'	1,467	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation	'	'	1,573	'	'	'
Long-Term Debt:	1,775	'	3,040	'	'	'
Deferred Tax Liabilities, Net, Noncurrent	0	'	0	'	'	'
Deferred Credits and Other Liabilities	'	'	'	'	'	'
Postretirement Benefits Other Than Pensions	0	'	0	'	'	'
Pneumoconiosis	0	'	0	'	'	'
Mine Closing	0	'	0	'	'	'
Gas Well Closing	0	'	0	'	'	'
Workers' Compensation	332	'	306	'	'	'
Salary Retirement	0	'	0	'	'	'
Reclamation	0	'	0	'	'	'
Other	0	'	0	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	'	'	2,278,251	'	'	'
Total Deferred Credits and Other Liabilities	332	'	2,278,557	'	'	'
Total CONSOL Energy Inc. Stockholders' Equity	139,436	'	255,492	'	'	'
Noncontrolling Interest	'	'	0	'	'	'
TOTAL LIABILITIES AND EQUITY	326,399	'	3,082,350	'	'	'
Elimination	'	'	'	'	'	'
Current Assets:	'	'	'	'	'	'
Cash and Cash Equivalents	0	'	0	'	'	'
Accounts and Notes Receivable:	'	'	'	'	'	'
Trade	0	'	0	'	'	'
Notes, Loans and Financing Receivable, Net, Current	0	'	0	'	'	'
Other Receivables	0	'	-128,400	'	'	'
Securitized	'	'	0	'	'	'
Inventories	0	'	0	'	'	'
Income Taxes Receivable, Current	0	'	'	'	'	'
Deferred Income Taxes	0	'	0	'	'	'
Restricted Cash and Cash Equivalents, Current	'	'	0	'	'	'
Prepaid Expenses	0	'	0	'	'	'
Assets of Disposal Group, Including Discontinued Operation, Current	'	'	0	'	'	'
Total Current Assets	0	'	-128,400	'	'	'
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, Net	'	'	0	'	'	'
Total Property, Plant and Equipment-Net	0	'	0	'	'	'
Other Assets:	'	'	'	'	'	'
Restricted Cash	'	'	0	'	'	'
Investments in Unconsolidated Equity Affiliates	-11,949,661	'	-10,607,154	'	'	'
Notes, Loans and Financing Receivable, Net, Noncurrent	0	'	0	'	'	'
Other	0	'	0	'	'	'
Disposal Group, Including Discontinued Operation, Other Assets	'	'	0	'	'	'
Total Other Assets	-11,949,661	'	-10,607,154	'	'	'
Total Assets	-11,949,661	'	-10,735,554	'	'	'
Current Liabilities:	'	'	'	'	'	'
Accounts Payable	0	'	0	'	'	'
Accounts Payable (Recoverable)- Related Parties	332,487	'	-128,400	'	'	'
Current Portion Long-Term Debt	0	'	0	'	'	'
Short-term Non-bank Loans and Notes Payable	-332,487	'	0	'	'	'
Accrued Income Taxes	'	'	0	'	'	'
Borrowings under Securitization Facility	'	'	0	'	'	'
Other Accrued Liabilities	0	'	0	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Current	0	'	0	'	'	'
Total Current Liabilities	0	'	-128,400	'	'	'
Long-Term Debt	'	'	0	'	'	'
Capital Lease Obligations	0	'	0	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation	'	'	0	'	'	'
Long-Term Debt:	0	'	0	'	'	'
Deferred Tax Liabilities, Net, Noncurrent	0	'	0	'	'	'
Deferred Credits and Other Liabilities	'	'	'	'	'	'
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	'	0	'	'	'
Other	0	'	0	'	'	'
Liabilities of Disposal Group, Including Discontinued Operation, Noncurrent	'	'	0	'	'	'
Total Deferred Credits and Other Liabilities	0	'	0	'	'	'
Total CONSOL Energy Inc. Stockholders' Equity	-11,949,661	'	-10,607,154	'	'	'
Noncontrolling Interest	'	'	0	'	'	'
TOTAL LIABILITIES AND EQUITY	($11,949,661)	'	($10,735,554)	'	'	'

Guarantor_Subsidiaries_Condens

Guarantor Subsidiaries, Condensed Statement of Cash Flows (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]	'	'	'
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	($979,126,000)	($671,621,000)	($375,214,000)
Cash Provided by (Used in) Investing Activities, Discontinued Operations	777,145,000	-328,789,000	-203,310,000
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	553,570,000	457,342,000	1,328,871,000
Cash Provided by (Used in) Operating Activities, Discontinued Operations	105,206,000	270,771,000	198,735,000
Net Cash Provided by Operating Activities	658,776,000	728,113,000	1,527,606,000
Investing Activities:	'	'	'
Capital Expenditures	-1,496,056,000	-1,245,497,000	-1,178,375,000
Increase (Decrease) in Restricted Cash	68,673,000	-48,294,000	0
Net Investment in Equity Affiliates	-35,712,000	-23,451,000	55,876,000
Proceeds from Sales of Assets	483,969,000	645,621,000	747,285,000
Net Cash Used in Investing Activities	-201,981,000	-1,000,410,000	-578,524,000
Financing Activities:	'	'	'
Dividends Paid	-85,832,000	-142,278,000	-96,356,000
(Payments on) Proceeds from Short-Term Borrowings	0	0	-284,000,000
Repayments of Other Debt	-31,544,000	16,195,000	-11,080,000
Payments on Securitization Facility	37,846,000	'	-200,000,000
Payments On Long Term Notes Including Redemption Premium	0	0	-265,785,000
Proceeds from Issuance of Long-Term Notes	0	0	250,000,000
Proceeds from Issuance of Common Stock	3,727,000	8,278,000	0
Other Financing Activities	778,000	53,024,000	-9,452,000
Net Cash Provided by (Used in) Financing Activities, Continuing Operations	-150,717,000	-80,976,000	-605,593,000
Cash Provided by (Used in) Financing Activities, Discontinued Operations	-520,000	-601,000	-547,000
Net Cash (Used in) Provided by Financing Activities	-151,237,000	-81,577,000	-606,140,000
Parent Issuer	'	'	'
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]	'	'	'
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	259,168,000	150,027,000	-41,162,000
Cash Provided by (Used in) Investing Activities, Discontinued Operations	0	0	0
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	51,093,000	-58,410,000	530,444,000
Cash Provided by (Used in) Operating Activities, Discontinued Operations	0	0	0
Net Cash Provided by Operating Activities	51,093,000	-58,410,000	530,444,000
Investing Activities:	'	'	'
Capital Expenditures	-68,796,000	-49,973,000	-41,172,000
Increase (Decrease) in Restricted Cash	0	0	'
Net Investment in Equity Affiliates	0	200,000,000	0
Proceeds from Sales of Assets	327,964,000	0	10,000
Net Cash Used in Investing Activities	259,168,000	150,027,000	-41,162,000
Financing Activities:	'	'	'
Dividends Paid	14,168,000	-142,278,000	-96,356,000
(Payments on) Proceeds from Short-Term Borrowings	0	'	-155,000,000
Repayments of Other Debt	25,952,000	'	'
Payments on Securitization Facility	0	'	-200,000,000
Payments On Long Term Notes Including Redemption Premium	'	'	-265,785,000
Proceeds from Issuance of Long-Term Notes	'	'	250,000,000
Proceeds from Issuance of Common Stock	3,727,000	8,278,000	'
Other Financing Activities	778,000	22,532,000	5,749,000
Net Cash Provided by (Used in) Financing Activities, Continuing Operations	-7,279,000	-111,468,000	-461,392,000
Cash Provided by (Used in) Financing Activities, Discontinued Operations	0	0	0
Net Cash (Used in) Provided by Financing Activities	-7,279,000	-111,468,000	-461,392,000
Cnx Gas Guarantor [Member]	'	'	'
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]	'	'	'
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	-665,132,000	-209,907,000	132,970,000
Cash Provided by (Used in) Investing Activities, Discontinued Operations	0	0	0
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	440,763,000	82,036,000	329,360,000
Cash Provided by (Used in) Operating Activities, Discontinued Operations	0	0	0
Net Cash Provided by Operating Activities	440,763,000	82,036,000	329,360,000
Investing Activities:	'	'	'
Capital Expenditures	-968,607,000	-532,636,000	-664,612,000
Increase (Decrease) in Restricted Cash	0	0	'
Net Investment in Equity Affiliates	-47,500,000	-37,400,000	50,626,000
Proceeds from Sales of Assets	350,975,000	360,129,000	746,956,000
Net Cash Used in Investing Activities	-665,132,000	-209,907,000	132,970,000
Financing Activities:	'	'	'
Dividends Paid	-100,000,000	-200,000,000	0
(Payments on) Proceeds from Short-Term Borrowings	332,487,000	'	-129,000,000
Repayments of Other Debt	0	'	'
Payments on Securitization Facility	0	'	0
Payments On Long Term Notes Including Redemption Premium	'	'	0
Proceeds from Issuance of Long-Term Notes	'	'	0
Proceeds from Issuance of Common Stock	0	0	'
Other Financing Activities	-5,232,000	-5,504,000	-13,162,000
Net Cash Provided by (Used in) Financing Activities, Continuing Operations	227,255,000	-205,504,000	-142,162,000
Cash Provided by (Used in) Financing Activities, Discontinued Operations	0	0	0
Net Cash (Used in) Provided by Financing Activities	227,255,000	-205,504,000	-142,162,000
Other Subsidiary Guarantors	'	'	'
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]	'	'	'
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	-573,274,000	-411,995,000	-468,496,000
Cash Provided by (Used in) Investing Activities, Discontinued Operations	0	0	0
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	572,683,000	412,293,000	465,847,000
Cash Provided by (Used in) Operating Activities, Discontinued Operations	0	0	0
Net Cash Provided by Operating Activities	572,683,000	412,293,000	465,847,000
Investing Activities:	'	'	'
Capital Expenditures	-458,653,000	-662,888,000	-472,591,000
Increase (Decrease) in Restricted Cash	-68,673,000	48,294,000	'
Net Investment in Equity Affiliates	11,788,000	13,949,000	5,250,000
Proceeds from Sales of Assets	-195,082,000	285,238,000	-1,155,000
Net Cash Used in Investing Activities	-573,274,000	-411,995,000	-468,496,000
Financing Activities:	'	'	'
Dividends Paid	0	0	0
(Payments on) Proceeds from Short-Term Borrowings	0	'	0
Repayments of Other Debt	4,800,000	'	'
Payments on Securitization Facility	0	'	0
Payments On Long Term Notes Including Redemption Premium	'	'	0
Proceeds from Issuance of Long-Term Notes	'	'	0
Proceeds from Issuance of Common Stock	0	0	'
Other Financing Activities	5,232,000	-1,408,000	-1,246,000
Net Cash Provided by (Used in) Financing Activities, Continuing Operations	432,000	-1,408,000	-1,246,000
Cash Provided by (Used in) Financing Activities, Discontinued Operations	0	0	0
Net Cash (Used in) Provided by Financing Activities	432,000	-1,408,000	-1,246,000
Non-Guarantors	'	'	'
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]	'	'	'
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	112,000	254,000	1,474,000
Cash Provided by (Used in) Investing Activities, Discontinued Operations	777,145,000	-328,789,000	-203,310,000
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	-843,456,000	21,423,000	3,220,000
Cash Provided by (Used in) Operating Activities, Discontinued Operations	105,206,000	270,771,000	198,735,000
Net Cash Provided by Operating Activities	-738,250,000	292,194,000	201,955,000
Investing Activities:	'	'	'
Capital Expenditures	0	0	0
Increase (Decrease) in Restricted Cash	0	0	'
Net Investment in Equity Affiliates	0	0	0
Proceeds from Sales of Assets	112,000	254,000	1,474,000
Net Cash Used in Investing Activities	777,257,000	-328,535,000	-201,836,000
Financing Activities:	'	'	'
Dividends Paid	0	0	0
(Payments on) Proceeds from Short-Term Borrowings	0	'	0
Repayments of Other Debt	792,000	'	'
Payments on Securitization Facility	37,846,000	'	0
Payments On Long Term Notes Including Redemption Premium	'	'	0
Proceeds from Issuance of Long-Term Notes	'	'	0
Proceeds from Issuance of Common Stock	0	0	'
Other Financing Activities	0	37,404,000	-793,000
Net Cash Provided by (Used in) Financing Activities, Continuing Operations	-38,638,000	37,404,000	-793,000
Cash Provided by (Used in) Financing Activities, Discontinued Operations	-520,000	-601,000	-547,000
Net Cash (Used in) Provided by Financing Activities	-39,158,000	36,803,000	-1,340,000
Elimination	'	'	'
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]	'	'	'
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	0	-200,000,000	0
Cash Provided by (Used in) Investing Activities, Discontinued Operations	0	0	0
Net Cash Provided by (Used in) Operating Activities, Continuing Operations	332,487,000	0	0
Cash Provided by (Used in) Operating Activities, Discontinued Operations	0	0	0
Net Cash Provided by Operating Activities	332,487,000	0	0
Investing Activities:	'	'	'
Capital Expenditures	0	0	0
Increase (Decrease) in Restricted Cash	0	0	'
Net Investment in Equity Affiliates	0	-200,000,000	0
Proceeds from Sales of Assets	0	0	0
Net Cash Used in Investing Activities	0	-200,000,000	0
Financing Activities:	'	'	'
Dividends Paid	0	200,000,000	0
(Payments on) Proceeds from Short-Term Borrowings	-332,487,000	'	0
Repayments of Other Debt	0	'	'
Payments on Securitization Facility	0	'	0
Payments On Long Term Notes Including Redemption Premium	'	'	0
Proceeds from Issuance of Long-Term Notes	'	'	0
Proceeds from Issuance of Common Stock	0	0	'
Other Financing Activities	0	0	0
Net Cash Provided by (Used in) Financing Activities, Continuing Operations	-332,487,000	200,000,000	0
Cash Provided by (Used in) Financing Activities, Discontinued Operations	0	0	0
Net Cash (Used in) Provided by Financing Activities	($332,487,000)	$200,000,000	$0

Guarantor_Subsidiaries_Financi3

Guarantor Subsidiaries Financial Information Guarantor Subsidiaries Comprehensive Income Statement (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net Income (Loss)	$659,056	$388,073	$632,497
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Treasury Rate Lock, Net of Tax	0	0	-96
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	456,493	129,231	-32,813
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	45,631	114,240	200,700
Net Income (Loss)	659,056	388,073	632,497
Other Comprehensive Income (Loss), Net of Tax	422,225	54,212	72,784
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	1,081,281	442,285	705,281
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest	1,386	397	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	1,082,667	442,682	705,281
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	-79,899	-189,259	-95,007
Parent Issuer	'	'	'
Net Income (Loss)	660,442	388,470	632,497
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Treasury Rate Lock, Net of Tax	'	'	-96
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	456,493	129,231	-32,813
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	45,631	114,240	200,700
Net Income (Loss)	660,442	388,470	632,497
Other Comprehensive Income (Loss), Net of Tax	422,225	54,212	72,784
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	1,082,667	442,682	'
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest	0	0	'
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	1,082,667	442,682	705,281
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	-79,899	-189,259	-95,007
Cnx Gas Guarantor [Member]	'	'	'
Net Income (Loss)	-2,624	24,363	77,701
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Treasury Rate Lock, Net of Tax	'	'	0
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	45,631	114,240	200,700
Net Income (Loss)	-2,624	24,363	77,701
Other Comprehensive Income (Loss), Net of Tax	-34,268	-75,019	105,693
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	-36,892	-50,656	'
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest	1,386	397	'
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-35,506	-50,259	183,394
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	-79,899	-189,259	-95,007
Other Subsidiary Guarantors	'	'	'
Net Income (Loss)	455,935	547,952	948,533
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Treasury Rate Lock, Net of Tax	'	'	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	456,493	129,231	-32,813
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	0	0	0
Net Income (Loss)	455,935	547,952	948,533
Other Comprehensive Income (Loss), Net of Tax	456,493	129,231	-32,813
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	912,428	677,183	'
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest	0	0	'
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	912,428	677,183	915,720
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	0	0	0
Non-Guarantors	'	'	'
Net Income (Loss)	585,616	80,690	-34,224
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Treasury Rate Lock, Net of Tax	'	'	0
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	0	0
Net Income (Loss)	585,616	80,690	-34,224
Other Comprehensive Income (Loss), Net of Tax	0	0	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	585,616	80,690	'
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest	0	0	'
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	585,616	80,690	-34,224
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	0	0	0
Elimination	'	'	'
Net Income (Loss)	-1,040,313	-653,402	-992,010
Other Comprehensive Income (Loss), Net of Tax [Abstract]	'	'	'
Treasury Rate Lock, Net of Tax	'	'	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	-456,493	-129,231	32,813
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	-45,631	-114,240	-200,700
Net Income (Loss)	-1,040,313	-653,402	-992,010
Other Comprehensive Income (Loss), Net of Tax	-422,225	-54,212	-72,880
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	-1,462,538	-707,614	'
Less: Comprehensive Loss (Income), Net of Tax, Attributable to Noncontrolling Interest	0	0	'
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-1,462,538	-707,614	-1,064,890
Derivative Instruments, Gain (Loss) Reclassification from Accumulated OCI to Income, Estimated Net Amount to be Transferred	$79,899	$189,259	$95,007

Related_Party_Details

Related Party (Details) (CONE [Member], USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Related Party Transaction [Line Items]	'	'	'
Due from Related Parties, Current	$5,448,000	$3,142,000	'
Related Party Transaction, Expenses from Transactions with Related Party	34,062,000	20,408,000	4,267,000
CONE Capital Reimbursement [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Due from Related Parties, Current	0	-18,000	'
Reimbursement for CONE Expenses [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Due from Related Parties, Current	-2,168,000	-1,336,000	'
Reimbursement for Services Provided to Cone [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Due from Related Parties, Current	-265,000	-341,000	'
CONE Gathering Fees [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Due to Related Parties, Current	$7,881,000	$4,837,000	'

Supplemental_Coal_Data_Unaudit2

Supplemental Coal Data (Unaudited) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009	Dec. 31, 2008
	T	T	T	T	T	T
Reserve Quantities [Roll Forward]	'	'	'	'	'	'
Sale of reserves in-place	0	0	-531,431,000	'	'	'
Proved Developed and Undeveloped Reserves, Production	172,380,000	156,325,000	153,504,000	'	'	'
Net change due to revisions in quantity estimates	$132,900	($104,158)	($83,580)	'	'	'
Steam [Member]	'	'	'	'	'	'
Reserve Quantities [Line Items]	'	'	'	'	'	'
Proved Undeveloped Reserve (Mass)	2,511,000	'	'	'	'	'
Coal Segment [Member]	'	'	'	'	'	'
Reserve Quantities [Line Items]	'	'	'	'	'	'
Proved Undeveloped Reserve (Mass)	3,032,000,000	4,229,000,000	4,314,000,000	4,229,000,000	4,350,000,000	4,372,000,000
Reserve Quantities [Roll Forward]	'	'	'	'	'	'
Purchase of minerals in place (Mass)	1,000,000	0	6,000,000	4,000,000	5,000,000	'
Sales of minerals in place (Mass)	-1,199,000,000	-155,000,000	0	-41,000,000	-3,000,000	'
Production of proved reserves (Mass)	-55,000,000	-55,000,000	-62,000,000	-62,000,000	-58,000,000	'
Net change due to revisions in quantity estimates	$56,000	$125,000	$141,000	($22,000)	$34,000	'
metallurgical coal [Member]	'	'	'	'	'	'
Reserve Quantities [Line Items]	'	'	'	'	'	'
Proved Undeveloped Reserve (Mass)	521,000,000	'	'	'	'	'
Affiliated Entity [Member]	'	'	'	'	'	'
Reserve Quantities [Line Items]	'	'	'	'	'	'
Proved Undeveloped Reserve (Mass)	'	57,000,000	41,000,000	145,000,000	172,000,000	170,000,000

Supplemental_Gas_Data_Capitali

Supplemental Gas Data Capitalized Costs (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Capitalized Costs Relating to Oil and Gas Producing Activities, by Geographic Area [Line Items]	'	'
Proven properties	$1,670,404	$1,596,838
Unproven properties	1,463,406	1,266,017
Drilling Cost	1,937,336	1,550,297
Wells and related equipment	688,548	492,364
Gathering assets	1,058,008	1,006,882
Oil and Gas Reclamation Liability, Noncurrent	113,481	70,753
Total Property, Plant and Equipment	6,931,183	5,983,151
Accumulated Depreciation, Depletion and Amortization	-1,187,409	-959,291
Net Capitalized Costs	$5,743,774	$5,023,860

Supplemental_Gas_Data_Oil_and_

Supplemental Gas Data Oil and Gas Expenditures (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]	'	'	'
Proven properties	$0	$50,005	$6,673
Unproven properties	260,477	28,634	58,731
Development	629,100	339,608	463,401
Exploration	95,413	130,312	131,419
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities	$984,990	$548,559	$660,224

Supplemental_Gas_Data_Results_

Supplemental Gas Data Results of Operations (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]	'	'	'
Production Revenue	$740,869	$660,442	$751,767
Sales-Gas Royalty Interests	63,202	49,405	66,929
Sales-Purchased Gas	6,531	3,316	4,344
Total Revenue	810,602	713,163	823,040
Lifting Costs	96,600	90,835	106,477
Production Tax Expense	28,677	26,145	26,261
Gathering Costs	201,023	160,575	142,339
Gas Royalty Interests Costs	53,028	38,867	59,331
Other Costs	'	39,029	18,095
Purchased Gas Costs	4,837	2,711	3,831
DD&A	229,562	202,956	206,821
Total Costs	723,979	608,740	623,556
Pre-tax Operating Income	86,623	104,423	199,484
Income Taxes	32,917	39,827	79,873
Results of Operations for Producing Activities excluding Corporate and Interest Costs	53,706	64,596	119,611
Cnx Gas Guarantor [Member]	'	'	'
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]	'	'	'
Sales-Gas Royalty Interests	63,202	49,405	4,344
Sales-Purchased Gas	6,531	3,316	66,929
Gas Royalty Interests Costs	53,069	38,922	59,377
Selling, General and Administrative Expenses	49,092	47,567	60,355
Other Costs	61,119	'	'
Purchased Gas Costs	$4,837	$2,711	$3,831

Supplemental_Gas_Data_Average_

Supplemental Gas Data Average Unit Prices (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MMcf	MMcf	MMcf
Average Sales Price and Production Costs Per Unit of Production [Line Items]	'	'	'
Oil and Gas Delivery Commitments and Contracts, Remaining Contractual Volume	60.3	'	'
Proved Developed and Undeveloped Reserves, Production	172,380,000	156,325,000	153,504,000
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	3.85	3	4.27
Average effects of financial settlements (per thousand cubic feet)	0.45	1.22	0.63
Average gas sales price including effects of financial settlements (per thousand cubic feet)	4.3	4.22	4.9
Average lifting costs, excluding ad valorem and severance taxes (per thousand cubic feet)	'.56	'.58	'.68

Supplemental_Gas_Data_Acreages

Supplemental Gas Data Acreages (Details)	Dec. 31, 2013
	acre
Gas and Oil Acreage [Line Items]	'
Productive Gas Wells, Number of Wells, Gross	15,063,000
Gas and Oil Acreage, Undeveloped, Net	59,346,000
unproved acreage gross	5,396,659,000
Gas and Oil Acreage, Unproved, Net	4,212,030,000
Total Acreage - Gross	6,044,066,000
Total Acreage - Net	4,799,069,000
Productive Gas Wells, Number of Wells, Net	12,874,000
Gas and Oil Area, Developed, Gross	542,388,000
Gas and Oil Area, Developed, Net	527,693,000
Gas and Oil Area, Undeveloped, Gross	105,019,000

Supplemental_Gas_Data_Oil_and_1

Supplemental Gas Data Oil and Gas Reserve Quantities (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Jan. 02, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

MMcf

MMcf

MMcf

MMcf

proved undeveloped [Member]

proved undeveloped [Member]

proved undeveloped [Member]

proved undeveloped [Member]

Price Changes [Member]

Plan and Other Revisions [Member]

Proved Developed [Member]

Proved Developed [Member]

Proved Developed [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

Natural Gas Liquids [Member]

Crude Oil and NGL [Member]

Crude Oil and NGL [Member]

Crude Oil and NGL [Member]

Crude Oil and NGL [Member]

Crude Oil and NGL [Member]

Crude Oil and NGL [Member]

Crude Oil and NGL [Member]

Crude Oil and NGL [Member]

Crude Oil and NGL [Member]

Crude Oil and NGL [Member]

Crude Oil and NGL [Member]

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

proved undeveloped [Member]

proved undeveloped [Member]

proved undeveloped [Member]

Plan and Other Revisions [Member]

Proved Developed [Member]

Proved Developed [Member]

Proved Developed [Member]

MMcf

MMcf

MMcf

MMcf

proved undeveloped [Member]

proved undeveloped [Member]

proved undeveloped [Member]

Plan and Other Revisions [Member]

Proved Developed [Member]

Proved Developed [Member]

Proved Developed [Member]

MMcf

MMcf

MMcf

MMcf

proved undeveloped [Member]

proved undeveloped [Member]

proved undeveloped [Member]

Plan and Other Revisions [Member]

Proved Developed [Member]

Proved Developed [Member]

Proved Developed [Member]

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

MMcf

Reserve Quantities [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payments to Acquire Property, Plant, and Equipment

$1,496,056,000

$1,245,497,000

$1,178,375,000

'

$202,066

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proved undeveloped reserves (Volume)

'

'

'

'

3,216,920,000

'

1,827,975,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

undeveloped reserves transferred to developed

'

'

'

'

-230,333,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Beginning reserves

5,731,214,000

3,993,458,000

3,480,027,000

3,731,597,000

3,216,920,000

1,827,975,000

'

1,344,222,000

'

'

2,514,294,000

2,165,483,000

2,135,805,000

'

3,905,437,000

3,470,551,000

3,724,361,000

3,114,695,000

1,755,525,000

1,344,222,000

'

2,470,412,000

2,149,912,000

2,126,330,000

21,547,000

13,375,000

25,000

0

15,607,000

12,075,000

0

'

5,939,000

1,717,000

0

2,807,000

1,297,000

1,555,000

1,206,000

1,431,000

0

0

'

1,375,000

878,000

1,579,000

Price Changes

171,953,000

241,989,000

-73,837,000

'

'

'

'

'

'

'

'

'

'

176,045,000

243,442,000

-76,486,000

'

'

'

'

'

'

'

'

-1,017,000

469,000

25,000

'

'

'

'

'

'

'

'

336,000

-710,000

416,000

'

'

'

'

'

'

'

'

Proved Developed and Undeveloped Reserves, Improved Recovery

104,757,000

-526,611,000

-9,976,000

'

'

'

'

'

'

'

'

'

'

104,728,000

-526,608,000

-9,976,000

'

'

'

'

'

'

'

'

4,000

0

0

'

'

'

'

'

'

'

'

1,000

-1,000

0

'

'

'

'

'

'

'

'

Extensions and discoveries(b)

1,633,426,000

954,378,000

517,178,000

'

1,519,681,000

'

'

'

11,410,000

88,187,000

'

'

'

1,567,634,000

873,104,000

'

'

'

'

'

517,023,000

'

'

'

9,623,000

12,992,000

'

'

'

'

'

0

'

'

'

1,343,000

553,000

'

'

'

'

'

27,000

'

'

'

Proved Developed and Undeveloped Reserves, Production

-172,380,000

-156,325,000

-153,504,000

'

'

'

'

'

'

'

'

'

'

168,737,000

155,052,000

152,940,000

'

'

'

'

'

'

'

'

438,000

111,000

0

'

'

'

'

'

'

'

'

170,000

100,000

94,000

'

'

'

'

'

'

'

'

Sale of reserves in-place

0

0

-531,431,000

'

'

'

'

'

'

'

'

'

'

0

0

531,431,000

'

'

'

'

'

'

'

'

0

0

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Supplemental_Gas_Data_Explorat

Supplemental Gas Data Exploratary Wells (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]	'	'	'
Less than one year	$17,728	'	'
Greater than One Year	0	'	'
Total	17,728	'	'
Costs expensed due to determination of dry hole or abandonment of project	8,596	3,320	5,108
Costs reclassified to wells, equipment and facilities based on the determination of proved reserves	$12,140	$14,447	$189

Supplemental_Gas_Data_PV10_Det

Supplemental Gas Data PV-10 (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'	'	'
Revenues	$21,602,594	$11,777,550	$14,804,398
Production costs	-7,105,962	-4,823,670	-5,262,635
Development costs	-3,902,875	-2,450,589	-1,674,829
Income tax expense	-4,025,626	-1,711,251	-2,989,435
Future Net Cash Flows	6,568,131	2,792,040	4,877,499
Discounted to present value at a 10% annual rate	-4,887,320	-2,055,834	-3,130,318
Total standardized measure of discounted net cash flows	$1,680,811	$736,206	$1,747,181

Supplemental_Gas_Data_PV10_Rec

Supplemental Gas Data PV-10 Reconciliation (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'	'	'	'
Revenues	$21,602,594	$11,777,550	$14,804,398	'
Net changes in sales prices and production costs	1,295,956	-1,480,573	-339,098	'
Net changes in sales prices and production costs	-365,477	-104,518	-217,186	'
Net change due to revisions in quantity estimates	132,900	-104,158	-83,580	'
Net change due to extensions, discoveries and improved recovery	383,308	14,645	324,755	'
Net change due to (divestiture) acquisition	0	0	-559,132	'
Development costs incurred during the period	625,824	333,640	463,401	'
Difference in previously estimated development costs compared to actual costs incurred during the period	-123,976	-96,749	154,137	'
Changes in estimated future development costs	-486,518	-153,104	155,619	'
Net change in future income taxes	-578,951	619,045	130,746	'
Accretion of discount and other	61,539	-39,203	56,698	'
Total discounted cash flow at end of period	1,680,811	736,206	1,747,181	1,660,821
Production costs	-7,105,962	-4,823,670	-5,262,635	'
Development costs	-3,902,875	-2,450,589	-1,674,829	'
Income tax expense	-4,025,626	-1,711,251	-2,989,435	'
Future Net Cash Flows	6,568,131	2,792,040	4,877,499	'
Discounted to present value at a 10% annual rate	-4,887,320	-2,055,834	-3,130,318	'
Total standardized measure of discounted net cash flows	$1,680,811	$736,206	$1,747,181	'

Supplemental_Quarterly_Info_Un2

Supplemental Quarterly Info (Unaudited) (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012	Jun. 30, 2012	Mar. 31, 2012	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Sales	$772,258	$753,080	$808,238	$759,948	$799,997	$681,717	$807,198	$878,118	'	'	'
Freight-Outside	3,946	11,563	13,426	10,125	14,061	27,430	49,472	49,293	35,438	107,079	175,633
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	562,386	560,247	557,094	552,126	612,000	543,158	565,601	601,723	2,228,952	2,221,859	2,266,560
Freight Expense	3,946	11,563	13,426	10,125	14,061	27,430	49,472	49,293	35,438	107,079	175,444
Net Income (Loss)	'	'	'	'	'	'	'	'	659,056	388,073	632,497
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax	591,144	8,120	42,060	-21,375	1,904	14,814	-3,050	16,290	579,792	70,114	-49,178
Income (Loss) from Continuing Operations Attributable to Parent	146,595	-72,169	107,580	8,562	-3,725	-26,316	155,789	80,906	79,264	317,959	681,675
Net Income Attributable to CONSOL Energy Inc Shareholders	$738,183	($63,651)	$149,903	($12,526)	($1,564)	($11,368)	$152,739	$97,196	$660,442	$388,470	$632,497
Basic	$3.22	($0.28)	$0.66	($0.05)	($0.01)	($0.05)	$0.67	$0.43	$2.89	$1.71	$2.79
Income (Loss) from Continuing Operations, Per Diluted Share	$0.64	($0.31)	$0.47	$0.04	($0.02)	($0.12)	$0.68	$0.35	$0.35	$1.39	$2.98
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Diluted Share	$2.56	$0.03	$0.18	($0.09)	$0.01	$0.07	($0.01)	$0.07	$2.52	$0.31	($0.22)
Income (Loss) from Continuing Operations, Per Basic Share	$0.64	($0.31)	$0.47	$0.04	($0.02)	($0.12)	$0.68	$0.36	$0.35	$1.40	$3.01
Diluted	$3.20	($0.28)	$0.65	($0.05)	($0.01)	($0.05)	$0.67	$0.42	$2.87	$1.70	$2.76
Income (Loss) from Discontinued Operations and Disposal of Discontinued Operations, Net of Tax, Per Basic Share	$2.58	$0.03	$0.19	($0.09)	$0.01	$0.07	($0.01)	$0.07	$2.54	$0.31	($0.22)
Weighted Average Number of Shares Outstanding, Basic	'	'	'	'	'	'	'	'	228,728,628	227,593,524	226,680,369
Diluted	'	'	'	'	'	'	'	'	230,077,942	229,141,767	229,003,599