10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 __________________________________________________

FORM 10-Q

 __________________________________________________ 

(Mark One)

x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934.

For the quarterly period ended June 30, 2013

OR

o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission file number: 001-14901

  __________________________________________________

CONSOL Energy Inc.

(Exact name of registrant as specified in its charter)

Delaware	51-0337383
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

1000 CONSOL Energy Drive

Canonsburg, PA 15317-6506

(724) 485-4000

(Address, including zip code, and telephone number, including area code, of registrant’s principal executive offices)

 __________________________________________________ 

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes  x    No  o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes  x    No   o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer  x    Accelerated filer  o    Non-accelerated filer  o    Smaller Reporting Company  o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes  o    No  x

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.

Class	Shares outstanding as of July 18, 2013
Common stock, $0.01 par value	228,848,942

TABLE OF CONTENTS
		Page
PART I FINANCIAL INFORMATION
ITEM 1.	Condensed Financial Statements
	Consolidated Statements of Income for the three and six months ended June 30, 2013 and 2012	3
	Consolidated Statements of Comprehensive Income for the three and six months ended June 30, 2013 and 2012	4
	Consolidated Balance Sheets at June 30, 2013 and December 31, 2012	5
	Consolidated Statement of Stockholders’ Equity for the six months ended June 30, 2013	7
	Consolidated Statements of Cash Flows for the six months ended June 30, 2013 and 2012	8
	Notes to Unaudited Consolidated Financial Statements	9
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	41
ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	88
ITEM 4.	Controls and Procedures	90
PART II OTHER INFORMATION
ITEM 1.	Legal Proceedings	91
ITEM 4.	Mine Safety Disclosures	91
ITEM 6.	Exhibits	91

PART I

FINANCIAL INFORMATION

ITEM 1. CONDENSED FINANCIAL STATEMENTS

CONSOL ENERGY INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

(Dollars in thousands, except per share data)

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2013			2012		2013			2012
Sales—Outside	$	1,125,776		$	1,189,293	$	2,351,941		$	2,500,764
Sales—Gas Royalty Interests	17,028			9,533		31,232			21,739
Sales—Purchased Gas	1,406			651		2,764			1,490
Freight—Outside	10,125			49,472		24,186			98,765
Other Income	62,345			205,538		96,197			258,499
Total Revenue and Other Income	1,216,680			1,454,487		2,506,320			2,881,257
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	855,878			856,889		1,788,841			1,760,930
Gas Royalty Interests Costs	13,534			7,124		25,340			17,373
Purchased Gas Costs	1,061			869		2,020			1,386
Freight Expense	10,125			49,472		24,186			98,765
Selling, General and Administrative Expenses	37,123			33,732		70,793			72,731
Depreciation, Depletion and Amortization	159,307			153,824		320,622			309,171
Interest Expense	54,518			56,593		107,896			114,713
Taxes Other Than Income	83,325			84,329		166,112			175,956
Total Costs	1,214,871			1,242,832		2,505,810			2,551,025
Earnings Before Income Taxes	1,809			211,655		510			330,232
Income Taxes	14,622			58,945		15,144			80,326
Net (Loss) Income	(12,813		)	152,710		(14,634		)	249,906
Add: Net Loss Attributable to Noncontrolling Interest	287			29		544			29
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(12,526	)	$	152,739	$	(14,090	)	$	249,935
Earnings Per Share:
Basic	$	(0.05	)	$	0.67	$	(0.06	)	$	1.10
Dilutive	$	(0.05	)	$	0.67	$	(0.06	)	$	1.09
Weighted Average Number of Common Shares Outstanding:
Basic	228,721,980			227,548,394		228,520,886			227,408,832
Dilutive	228,721,980			229,252,185		228,520,886			229,122,594
Dividends Paid Per Share	$	0.125		$	0.125	$	0.125		$	0.250

The accompanying notes are an integral part of these financial statements.

3

CONSOL ENERGY INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

(Dollars in thousands)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2013			2012			2013			2012
Net (Loss) Income	$	(12,813	)	$	152,710		$	(14,634	)	$	249,906
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments (Net of tax: ($26,489), ($4,570), ($54,739), ($40,467))	42,904			7,586			88,661			67,159
Net Increase in the Value of Cash Flow Hedges (Net of tax: ($31,466), ($6,869), ($17,500), ($55,877))	45,749			10,663			27,154			86,739
Reclassification of Cash Flow Hedges from OCI to Earnings (Net of tax: $10,542, $36,697, $22,526, $68,077)	(9,528		)	(57,847		)	(32,241		)	(105,788		)
Other Comprehensive Income (Loss)	79,125			(39,598		)	83,574			48,110
Comprehensive Income	66,312			113,112			68,940			298,016
Add: Comprehensive Loss Attributable to Noncontrolling Interest	287			29			544			29
Comprehensive Income Attributable to CONSOL Energy Inc. Shareholders	$	66,599		$	113,141		$	69,484		$	298,045

The accompanying notes are an integral part of these financial statements.

4

CONSOL ENERGY INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Dollars in thousands)

	(Unaudited)
	June 30, 2013		December 31, 2012
ASSETS
Current Assets:
Cash and Cash Equivalents	$	71,938	$	21,878
Accounts and Notes Receivable:
Trade	347,367		428,328
Notes Receivables	350,977		318,387
Other Receivables	151,269		131,131
Accounts Receivable - Securitized	40,719		37,846
Inventories	227,994		247,766
Deferred Income Taxes	143,004		148,104
Recoverable Income Taxes	1,930		—
Restricted Cash	—		48,294
Prepaid Expenses	137,643		157,360
Total Current Assets	1,472,841		1,539,094
Property, Plant and Equipment:
Property, Plant and Equipment	16,194,251		15,545,204
Less—Accumulated Depreciation, Depletion and Amortization	5,770,506		5,354,237
Total Property, Plant and Equipment—Net	10,423,745		10,190,967
Other Assets:
Deferred Income Taxes	388,703		444,585
Restricted Cash	—		20,379
Investment in Affiliates	256,097		222,830
Notes Receivable	1,512		25,977
Other	210,030		227,077
Total Other Assets	856,342		940,848
TOTAL ASSETS	$	12,752,928	$	12,670,909

The accompanying notes are an integral part of these financial statements.

5

CONSOL ENERGY INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Dollars in thousands, except per share data)

	(Unaudited)
	June 30, 2013			December 31, 2012
LIABILITIES AND EQUITY
Current Liabilities:
Accounts Payable	$	461,415		$	507,982
Current Portion of Long-Term Debt	13,422			13,485
Short-Term Notes Payable	173,000			25,073
Accrued Income Taxes	—			34,219
Borrowings Under Securitization Facility	40,719			37,846
Other Accrued Liabilities	798,645			768,494
Total Current Liabilities	1,487,201			1,387,099
Long-Term Debt:
Long-Term Debt	3,124,000			3,124,473
Capital Lease Obligations	47,750			50,113
Total Long-Term Debt	3,171,750			3,174,586
Deferred Credits and Other Liabilities:
Postretirement Benefits Other Than Pensions	2,820,186			2,832,401
Pneumoconiosis Benefits	177,146			174,781
Mine Closing	459,392			446,727
Gas Well Closing	193,946			148,928
Workers’ Compensation	155,518			155,648
Salary Retirement	109,691			218,004
Reclamation	50,051			47,965
Other	102,987			131,025
Total Deferred Credits and Other Liabilities	4,068,917			4,155,479
TOTAL LIABILITIES	8,727,868			8,717,164
Stockholders’ Equity:
Common Stock, $.01 Par Value; 500,000,000 Shares Authorized, 228,834,765 Issued and 228,800,010 Outstanding at June 30, 2013; 228,129,467 Issued and 228,094,712 Outstanding at December 31, 2012	2,291			2,284
Capital in Excess of Par Value	2,336,417			2,296,908
Preferred Stock, 15,000,000 shares authorized, None issued and outstanding	—			—
Retained Earnings	2,351,320			2,402,551
Accumulated Other Comprehensive Loss	(663,768		)	(747,342		)
Common Stock in Treasury, at Cost—34,755 Shares at June 30, 2013 and 34,755 Shares at December 31, 2012	(609		)	(609		)
Total CONSOL Energy Inc. Stockholders’ Equity	4,025,651			3,953,792
Noncontrolling Interest	(591		)	(47		)
TOTAL EQUITY	4,025,060			3,953,745
TOTAL LIABILITIES AND EQUITY	$	12,752,928		$	12,670,909

The accompanying notes are an integral part of these financial statements.

6

CONSOL ENERGY INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(Dollars in thousands, except per share data)

	Common Stock		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			Total Equity
December 31, 2012	$	2,284	$	2,296,908		$	2,402,551		$	(747,342	)	$	(609	)	$	3,953,792		$	(47	)	$	3,953,745
(Unaudited)
Net Loss	—		—			(14,090		)	—			—			(14,090		)	(544		)	(14,634		)
Other Comprehensive Income	—		—			—			83,574			—			83,574			—			83,574
Comprehensive (Loss) Income	—		—			(14,090		)	83,574			—			69,484			(544		)	68,940
Issuance of Common Stock	7		2,490			—			—			—			2,497			—			2,497
Treasury Stock Activity	—		—			(8,540		)	—			—			(8,540		)	—			(8,540		)
Tax Cost From Stock-Based Compensation	—		(2,222		)	—			—			—			(2,222		)	—			(2,222		)
Amortization of Stock-Based Compensation Awards	—		39,241			—			—			—			39,241			—			39,241
Dividends ($0.125 per share)	—		—			(28,601		)	—			—			(28,601		)	—			(28,601		)
Balance at June 30, 2013	$	2,291	$	2,336,417		$	2,351,320		$	(663,768	)	$	(609	)	$	4,025,651		$	(591	)	$	4,025,060

The accompanying notes are an integral part of these financial statements.

7

CONSOL ENERGY INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(Dollars in thousands)

	Six Months Ended
	June 30,
	2013			2012
Operating Activities:
Net (Loss) Income	$	(14,634	)	$	249,906
Adjustments to Reconcile Net (Loss) Income to Net Cash Provided By Operating Activities:
Depreciation, Depletion and Amortization	320,622			309,171
Stock-Based Compensation	39,241			26,935
Gain on Sale of Assets	(32,958		)	(189,981		)
Amortization of Mineral Leases	761			3,631
Deferred Income Taxes	6,998			30,625
Equity in Earnings of Affiliates	(16,667		)	(15,103		)
Changes in Operating Assets:
Accounts and Notes Receivable	25,360			40,034
Inventories	19,772			(46,726		)
Prepaid Expenses	24,433			19,709
Changes in Other Assets	24,512			10,604
Changes in Operating Liabilities:
Accounts Payable	(13,470		)	(41,266		)
Other Operating Liabilities	(6,019		)	(65,693		)
Changes in Other Liabilities	2,807			23,456
Other	12,636			12,647
Net Cash Provided by Operating Activities	393,394			367,949
Investing Activities:
Capital Expenditures	(758,000		)	(714,399		)
Change in Restricted Cash	68,673			—
Proceeds from Sales of Assets	240,801			252,229
Net Investments In Equity Affiliates	(16,600		)	(21,839		)
Net Cash Used in Investing Activities	(465,126		)	(484,009		)
Financing Activities:
Proceeds from Short-Term Borrowings	173,000			—
Payments on Miscellaneous Borrowings	(30,162		)	(4,662		)
Proceeds from Securitization Facility	2,873			—
Tax Benefit from Stock-Based Compensation	2,185			1,608
Dividends Paid	(28,601		)	(56,833		)
Issuance of Common Stock	2,497			457
Issuance of Treasury Stock	—			109
Debt Issuance and Financing Fees	—			(148		)
Net Cash Provided by (Used In) Financing Activities	121,792			(59,469		)
Net Increase (Decrease) in Cash and Cash Equivalents	50,060			(175,529		)
Cash and Cash Equivalents at Beginning of Period	21,878			375,736
Cash and Cash Equivalents at End of Period	$	71,938		$	200,207

The accompanying notes are an integral part of these financial statements.

8

CONSOL ENERGY INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

(Dollars in thousands, except per share data)

NOTE 1—BASIS OF PRESENTATION:

The accompanying Unaudited Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by generally accepted accounting principles for complete financial statements. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included. Operating results for the three and six months ended June 30, 2013 are not necessarily indicative of the results that may be expected for future periods.

The balance sheet at December 31, 2012 has been derived from the Audited Consolidated Financial Statements at that date but does not include all the notes required by generally accepted accounting principles for complete financial statements. For further information, refer to the Consolidated Financial Statements and related notes for the year ended December 31, 2012 included in CONSOL Energy Inc.'s Form 10-K.

Certain amounts in prior periods have been reclassified to conform with the report classifications of the year ended December 31, 2012, with no effect on previously reported net income or stockholders' equity.

Basic earnings per share are computed by dividing net (loss) income attributable to shareholders by the weighted average shares outstanding during the reporting period. Dilutive earnings per share are computed similarly to basic earnings per share except that the weighted average shares outstanding are increased to include additional shares from the assumed exercise of stock options, performance stock options, and CONSOL share units, and the assumed vesting of restricted and performance share units, if dilutive. The number of additional shares is calculated by assuming that outstanding stock options, performance share options, and CONSOL share units were exercised, that outstanding restricted stock units and performance share units were released, and that the proceeds from such activities were used to acquire shares of common stock at the average market price during the reporting period. CONSOL Energy Inc. (CONSOL Energy or the Company) 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:

	Three Months Ended June 30,		Six Months Ended June 30,
	2013	2012	2013	2012
Anti-Dilutive Options	4,845,029	2,421,923	4,845,029	2,418,983
Anti-Dilutive Restricted Stock Units	1,383,908	2,642	1,383,908	13,552
Anti-Dilutive Performance Share Units	83,356	91,340	83,356	91,340
Anti-Dilutive Performance Share Options	602,101	501,744	602,101	501,744
	6,914,394	3,017,649	6,914,394	3,025,619

The table below sets forth the share-based awards that have been exercised or released:

	Three Months Ended June 30,		Six Months Ended June 30,
	2013	2012	2013	2012
Options	160,119	39,418	245,113	51,134
Restricted Stock Units	89,632	64,589	568,141	522,607
Performance Share Units	—	—	159,228	229,730
	249,751	104,007	972,482	803,471

The weighted average exercise price per share of the options exercised during the three months ended June 30, 2013 and 2012 was $9.90 and $10.26, respectively. The weighted average exercise price per share of the options exercised during the six months ended June 30, 2013 and 2012 was $10.16 and $11.07, respectively.

9

The computations for basic and dilutive earnings per share are as follows:

	Three Months Ended June 30,					Six Months Ended June 30,
	2013			2012		2013			2012
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(12,526	)	$	152,739	$	(14,090	)	$	249,935
Weighted average shares of common stock outstanding:
Basic	228,721,980			227,548,394		228,520,886			227,408,832
Effect of stock-based compensation awards	—			1,703,791		—			1,713,762
Dilutive	228,721,980			229,252,185		228,520,886			229,122,594
Earnings per share:
Basic	$	(0.05	)	$	0.67	$	(0.06	)	$	1.10
Dilutive	$	(0.05	)	$	0.67	$	(0.06	)	$	1.09

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	27,154			48,766			75,920
Amounts reclassified from accumulated other comprehensive income	(32,241		)	39,895			7,654
New current period other comprehensive income	(5,087		)	88,661			83,574
Balance at June 30, 2013	$	71,674		$	(735,442	)	$	(663,768	)

The following table shows the reclassification of adjustments out of Accumulated Other Comprehensive Loss:

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Derivative Instruments (Note 12)
Natural gas price swaps	$	(20,070	)	$	(94,544	)	$	(54,767	)	$	(173,865	)
Tax benefit	10,542			36,697			22,526			68,077
Net of tax	$	(9,528	)	$	(57,847	)	$	(32,241	)	$	(105,788	)
Actuarially Determined Long-Term Liability Adjustments*(Note 3 and Note 4)
Amortization of prior service costs	$	(8,211	)	$	(13,915	)	$	(16,423	)	$	(26,021	)
Recognized net actuarial loss	23,559			26,072			48,747			53,077
Settlement loss	5,087			—			32,202			—
Total	20,435			12,157			64,526			27,056
Tax expense	(7,800		)	(4,571		)	(24,631		)	(10,173		)
Net of tax	$	12,635		$	7,586		$	39,895		$	16,883

*Excludes amounts related to the remeasurement of the Actuarially Determined Long-Term Liabilities for the three months and six months ended June 30, 2013 and June 30, 2012.

10

NOTE 2—ACQUISITIONS AND DISPOSITIONS:

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 May 2013, CONSOL Energy completed a sale-leaseback of longwall shields for the Robinson Run Mine. Cash proceeds for the sale were $68,337. A loss of $236 was recognized due to transaction fees and is 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.

In April 2013, the Company and the Commonwealth of Pennsylvania (Commonwealth) entered into a Settlement Agreement and Release Settlement settling all of the Commonwealth's claims regarding the Ryerson Park Dam (Dam) and the Ryerson Park Lake (Lake).   The Settlement provides 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 provides 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.

On March 31, 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 50% of the acreage and accordingly, reimbursed CNX Gas Company for 50% of the associated costs during the three months ended June 30, 2013.

In March 2013, CONSOL Energy completed a sale-leaseback of longwall shields for the Shoemaker Mine. Cash proceeds for the sale were $63,839. A loss of $279 was recognized due to transaction fees and is 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.

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 is 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, of which $48,294 was restricted, were received related to this transaction. These proceeds were net of $637 in transaction fees. The restrictions on the cash were removed during the three months ended March 31, 2013 and are reflected as a Change in Restricted Cash in the Investing section of the Consolidated Statement of Cash Flows. Additionally, a note receivable was recognized in 2012 related to the two additional cash payments to be received in June 2013 and June 2014. One payment of $25,500 was received in June 2013. A note receivable of $24,500 is included in Accounts and Notes Receivables - Notes Receivables in the Consolidated Balance Sheet at June 30, 2013. The second payment is due June 2014. 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.

11

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 Statements of Income for the year ended December 31, 2012.

NOTE 3—COMPONENTS OF PENSION AND OTHER POSTRETIREMENT BENEFIT (OPEB) PLANS NET PERIODIC BENEFIT COSTS:

Components of net periodic costs (benefits) for the three and six months ended June 30 are as follows:

	Pension Benefits												Other Postretirement Benefits
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2013			2012			2013			2012			2013			2012			2013			2012
Service cost	$	5,581		$	4,850		$	11,287		$	10,003		$	4,849		$	4,566		$	9,698		$	9,766
Interest cost	8,909			9,415			17,752			18,793			29,619			32,795			59,237			68,322
Expected return on plan assets	(12,711		)	(11,452		)	(24,855		)	(23,079		)	—			—			—			—
Amortization of prior service cost (credits)	(407		)	(407		)	(815		)	(815		)	(7,804		)	(13,410		)	(15,608		)	(25,009		)
Recognized net actuarial loss	10,547			11,654			22,722			23,917			17,595			20,020			35,190			40,365
Settlement loss	5,087			—			32,202			—			—			—			—			—
Net periodic benefit cost	$	17,006		$	14,060		$	58,293		$	28,819		$	44,259		$	43,971		$	88,517		$	93,444

For the six months ended June 30, 2013, $34,376 was paid to the pension trust for pension benefits from operating 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 $50,000 to the pension trust in 2013. Net periodic benefit costs are allocated to Costs of Goods Sold and Other Operating Charges and Selling, General and Administrative Expenses in the Consolidated Statements of Income.

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 six months ended June 30, 2013. Accordingly, CONSOL Energy recognized expense of $5,087 and $32,202 for the three and six months ended June 30, 2013, respectively, in Costs of Goods Sold and Other Operating Charges in the Consolidated Statements 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 a remeasurement of the pension plan at June 30 and March 31, 2013. The June 30, 2013 remeasurement resulted in a change to the discount rate to 4.84% from 4.12% at March 31, 2013. The June remeasurement reduced the pension liability by $48,957. The June settlement and corresponding remeasurement of the pension plan resulted in an adjustment of $33,414 in other comprehensive income, net of $20,630 in deferred taxes. The March 31, 2013 remeasurement resulted in a change to the discount rate to 4.12% from 4.00% at December 31, 2012. The March remeasurement reduced the pension liability by $29,916. The March settlement and corresponding remeasurement of the pension plan resulted in an adjustment of $35,261 in other comprehensive income, net of $21,770 in deferred taxes. Currently, the settlement and remeasurement of the pension plan will result in a $10,960 reduction to pension expense compared to what was originally expected to be recognized for the remaining six months of 2013. It is reasonably possible that CONSOL Energy will incur additional settlement charges in 2013, which would require the pension plan to be remeasured using updated assumptions.

CONSOL Energy does not expect to contribute to the other postretirement benefit plan in 2013. We intend to pay benefit claims as they become due. For the six months ended June 30, 2013, $83,106 of other postretirement benefits have been paid.

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NOTE 4—COMPONENTS OF COAL WORKERS’ PNEUMOCONIOSIS (CWP) AND WORKERS’ COMPENSATION NET PERIODIC BENEFIT COSTS:

Components of net periodic costs (benefits) for the three and six months ended June 30 are as follows:

	CWP												Workers' Compensation
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2013			2012			2013			2012			2013			2012			2013			2012
Service cost	$	2,135		$	1,928		$	4,270		$	3,856		$	3,533		$	3,634		$	7,066		$	7,268
Interest cost	1,808			1,991			3,616			3,982			1,655			1,778			3,310			3,556
Amortization of actuarial gain	(4,212		)	(4,933		)	(8,425		)	(9,867		)	(699		)	(986		)	(1,398		)	(1,972		)
State administrative fees and insurance bond premiums	—			—			—			—			1,345			1,635			3,004			3,545
Legal and administrative costs	—			—			—			—			591			648			1,182			1,296
Net periodic (benefit) cost	$	(269	)	$	(1,014	)	$	(539	)	$	(2,029	)	$	6,425		$	6,709		$	13,164		$	13,693

CONSOL Energy does not expect to contribute to the CWP plan in 2013. We intend to pay benefit claims as they become due. For the six months ended June 30, 2013, $5,372 of CWP benefit claims have been paid.

CONSOL Energy does not expect to contribute to the workers’ compensation plan in 2013. We intend to pay benefit claims as they become due. For the six months ended June 30, 2013, $14,946 of workers’ compensation benefits, state administrative fees and surety bond premiums have been paid.

NOTE 5—INCOME TAXES:

The effective tax rate for the 2013 and 2012 six-month periods was 2,969.4% and 24.3%, respectively.

The rate for the six months ended June 30, 2013 differs from the U.S. federal statutory rate of 35% primarily due to a $25,471 income tax charge for excess depletion, $8,269 discrete income tax charge related to the gain on sale of the Potomac coal reserves and a $1,585 income tax benefit due to a refund claim related to prior year Commonwealth of Pennsylvania taxes.

The rate for the six months ended June 30, 2012 differs from the U.S. federal statutory rate of 35% primarily due to a $39,275 benefit recorded for excess depletion.

The total amounts of uncertain tax positions at June 30, 2013 and 2012 were $22,770 and $25,570, respectively. If these uncertain tax positions were recognized, approximately $2,071 and $3,891, respectively, would affect CONSOL Energy’s effective tax rate. There were no additions to the liability for unrecognized tax benefits during the six months ended June 30, 2013 and 2012.

CONSOL Energy recognizes interest accrued related to uncertain tax positions in its interest expense. As of June 30, 2013 and 2012, the Company reported an accrued interest liability relating to uncertain tax positions of $5,505 and $6,429, respectively. The accrued interest liability includes $675 and $1,055 of interest expense that is reflected in the Company’s Consolidated Statements of Income for the six months ended June 30, 2013 and 2012, respectively.

CONSOL Energy recognizes penalties accrued related to uncertain tax positions in its income tax expense. As of June 30, 2013 and 2012, CONSOL Energy had no accrued liability for tax penalties.

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NOTE 6—INVENTORIES:

Inventory components consist of the following:

	June 30, 2013		December 31, 2012
Coal	$	52,406	$	78,825
Merchandise for resale	36,476		35,363
Supplies	139,112		133,578
Total Inventories	$	227,994	$	247,766

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 $18,734 and $19,700 at June 30, 2013 and December 31, 2012, respectively.

NOTE 7—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 June 30, 2013, there were letters of credit outstanding against the facility of $159,281. 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 Topics 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 commercial paper rates, plus a charge for administrative services paid to the financial institutions. Costs associated with the receivables facility totaled $440 and $913 for three and six months ended June 30, 2013, respectively. Costs associated with the receivables facility totaled $437 and $856 for three and six months ended June 30, 2012, 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 June 30, 2013 and December 31, 2012, eligible accounts receivable totaled $181,000 and $200,000, respectively. There was no subordinated retained interest at June 30, 2013 and at December 31, 2012. There were $40,719 borrowings under the Securitization Facility recorded on the Consolidated Balance Sheet as of June 30, 2013 and $37,846 at December 31, 2012. The accounts receivable securitization program increased $2,873in the six months ended June 30, 2013 and there was no change in the six months ended June 30, 2012. The increase is reflected in the Net Cash Provided by (Used in) Financing Activities in the Consolidated Statement of Cash Flows. In accordance with the facility agreement, the Company is able to receive proceeds based upon the eligible accounts receivable at the previous month end.

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NOTE 8—PROPERTY, PLANT AND EQUIPMENT:

	June 30, 2013		December 31, 2012
Coal and other plant and equipment	$	6,086,734	$	6,030,620
Intangible drilling cost	1,721,384		1,550,297
Proven gas properties	1,597,626		1,596,838
Coal properties and surface lands	1,455,541		1,346,151
Unproven gas properties	1,371,532		1,266,017
Gas gathering equipment	1,034,927		1,006,882
Airshafts	727,674		706,388
Mine development	583,494		537,939
Leased coal lands	529,700		529,758
Gas wells and related equipment	542,284		492,367
Coal advance mining royalties	396,034		391,501
Other gas assets	125,194		82,217
Gas advance royalties	22,127		8,229
Total Property Plant and Equipment	16,194,251		15,545,204
Less: Accumulated DD&A	5,770,506		5,354,237
Total Net PP&E	$	10,423,745	$	10,190,967

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 LLC (CNX Gas Company), a wholly owned subsidiary of CONSOL Energy, completed a sale to Hess Ohio Developments, LLC (Hess) of 50% of nearly 200 thousand net Utica Shale acres in Ohio. Cash proceeds related to this transaction were $54,254, which were net of $5,719 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 aggregate amount of the drilling carry can be adjusted downward under provisions of the joint venture agreements in certain events. 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 announced, 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 will be 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 itself 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. The discounted notes receivable of $311,754 and $296,344 were recorded in Accounts and Notes Receivables-Notes Receivable and Other Assets-Notes Receivable, respectively. 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

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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 aggregate amount of the drilling carry may also be adjusted downward under provisions of the joint venture agreements in certain events.

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 then can review and respond to the asserted title defects, or cure them, and ultimately, if the claim is not resolved, either party can submit the defect to an arbitrator for resolution. If they establish any title defects which are not resolved in favor of CONSOL Energy or if the subject acreage is reassigned to us at our request, then subject to certain deductibles, Noble's aggregate carried cost obligation under the joint venture agreements will be reduced by the value the parties previously allocated to the affected acreage in the transaction. If a significant percentage of the oil and gas interests we contributed have title defects, the carried costs could be materially reduced and our aggregate share of the drilling and completion costs for wells in these joint ventures could materially increase. Noble Energy has submitted a final title defect notice to CONSOL Energy. Based on our review of the title defect notice, Noble has asserted title defects with respect to approximately 75,000 gross deal acres, having a carry value of approximately $481,000, which have not yet been addressed. We are working closely with Noble to address these alleged defects and we believe that we will resolve most of those defects favorably to CONSOL Energy. To date, we have conceded defects which have an aggregate value of approximately $57,000 in excess of the applicable deductibles. The impact of these conceded defects was $2,470 and $8,780 of expense for the three and six months ended June 30, 2013 and is included in Cost of Goods Sold and Other Charges in the Consolidated Statement of Income.

The following table provides information about our industry participation agreements as of June 30, 2013:

Shale Play	Industry Participation Agreement Partner	Industry Participation Agreement Date	Drilling Carries Remaining*
Marcellus	Noble Energy, Inc.	September 30, 2011	$	2,034,785
Utica	Hess Ohio Developments, LLC	October 21, 2011	$	279,248

*See above for a description of the impact on the drilling carries of title defects that have been asserted by Noble Energy.

NOTE 9—SHORT-TERM NOTES PAYABLE:

CONSOL Energy's $1,500,000 Senior Secured Credit Agreement expires April 12, 2016. 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 $1,500,000 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 2.50 to 1.00, measured quarterly. The interest coverage ratio was 3.44 to 1.00 at June 30, 2013. The facility includes a maximum leverage ratio covenant of no more than 4.50 to 1.00, measured quarterly. The leverage ratio was 3.65 to 1.00 at June 30, 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 0.12 to 1.00 at June 30, 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 June 30, 2013 and December 31, 2012, the $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 for 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 unlimited investments in joint ventures for the development and operation of gas gathering systems and

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provides for $600,000 of loans, advances and dividends from CNX Gas to CONSOL Energy. Investments in CONE Gathering, LLC (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 1.20 to 1.00 at June 30, 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 36.85 to 1.00 at June 30, 2013. At June 30, 2013, the $1,000,000 facility had $173,000 borrowings outstanding and $70,051 of letters of credit outstanding, leaving $756,949 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. The average interest rate for the three months and six months ended June 30, 2013 was 1.69% and 1.76%, respectively. Accrued interest of $62 and $29 is included in Other Accrued Liabilities in the Consolidated Balance Sheet at June 30, 2013 and December 31, 2012, respectively.

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 June 30, 2013.

NOTE 10—LONG-TERM DEBT:

	June 30, 2013		December 31, 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 (7.43% weighted average interest rate for June 30, 2013 and December 31, 2012)	20,394		20,394
Other long-term notes maturing at various dates through 2031 (total value of $6,612 and $7,300 less unamortized discount of $1,286 and $1,542 at June 30, 2013 and December 31, 2012, respectively).	5,326		5,758
	3,128,585		3,129,017
Less amounts due in one year *	4,585		4,544
Long-Term Debt	$	3,124,000	$	3,124,473

* Excludes current portion of Capital Lease Obligations of $8,837 and $8,941 at June 30, 2013 and December 31, 2012, respectively.

Accrued interest related to Long-Term Debt of $63,269 and $63,363 was included in Other Accrued Liabilities in the Consolidated Balance Sheets at June 30, 2013 and December 31, 2012, respectively.

NOTE 11—COMMITMENTS AND CONTINGENCIES:

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 $792,000.

The following lawsuits and claims include those for which a loss is probable and an accrual has been recognized.

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American Electric Corp: On August 8, 2011, the United States Environmental Protection Agency, Region IV, sent Consolidation Coal Company a General Notice and Offer to Negotiate regarding the Ellis Road/American Electric Corp. Superfund Site in Jacksonville, Florida. The General Notice was sent to approximately 180 former customers of American Electric Corp. CONSOL Energy has confirmed that it did business with American Electric Corp. in 1983 and 1984. The General Notice indicated that the Environmental Protection Agency (EPA) has determined that polychlorinated biphenyls (PCBs) and other contaminants in the soils and sediments at and near the site require a removal action. The Offer to Negotiate invited the potentially responsible parties (PRPs) to enter into an Administrative Settlement Agreement and Order on Consent (AOC) to provide for conducting the removal action under the EPA oversight and to reimburse the EPA for its past costs, in the amount of $384 and for its future costs. CONSOL Energy responded to the EPA indicating its willingness to participate in such negotiations, and CONSOL Energy is participating in a group of potentially responsible parties to conduct the removal action. The AOC was signed on July 20, 2012, and as a result, the EPA granted the performing parties a $408 orphan share credit, which will offset the EPA's past costs. The actual scope of the work has yet to be determined, but the current estimate of the total costs of the removal action is in the range of $2,000 to $5,400, with CONSOL Energy's share of such costs at approximately 8%. In 2011, CONSOL Energy established an initial accrual based on its allocated share of the costs among the viable former customers of American Electric Corp. During the year ended December 31, 2012, CONSOL Energy funded $250 to an independent trust established for the remediation, which is 50% of CONSOL Energy's allocated share of the trust fund. The liability is immaterial to the overall financial position of CONSOL Energy and is included in Other Accrued Liabilities on the Consolidated Balance Sheet.

Ward Transformer Superfund Site: CONSOL Energy was notified in November 2004 by the EPA that it is a potentially responsible party (PRP) under the Superfund program established by the Comprehensive Environmental Response, Compensation and Liability Act of 1980, as amended (CERCLA), with respect to the Ward Transformer site in Wake County, North Carolina. The EPA, CONSOL Energy and two other PRPs entered into an administrative Settlement Agreement and Order of Consent, requiring those PRPs to undertake and complete a PCB soil removal action, at and in the vicinity of the Ward Transformer property. In June 2008, while conducting the PCB soil excavation on the Ward property, it was determined that PCBs have migrated onto adjacent properties and in September 2008, the EPA notified CONSOL Energy and 60 other companies that they are PRPs for these additional areas. The current estimated cost of remedial action for the area CONSOL Energy was originally named a PRP, including payment of the EPA's past and future cost, is approximately $65,000. The current estimated cost of the most likely remediation plan for the additional areas discovered is approximately $11,000. CONSOL Energy recognized no expense in Cost of Goods Sold and Other charges in the three or six months ended June 30, 2013 and 2012, respectively. Also, CONSOL Energy has provided funding to an independent trust established for this remediation. CONSOL Energy funded $430 in the six months ended June 30, 2013. No funding was made in the six months ended June 30, 2012. As of June 30, 2013, CONSOL Energy and the other participating PRPs had asserted CERCLA cost recovery and contribution claims against approximately 225 nonparticipating PRPs to recover a share of the costs incurred and to be incurred to conduct the removal actions at the Ward Site. CONSOL Energy's portion of recoveries from settled claims is $4,369. Accordingly, the liability reflected in Other Accrued Liabilities was reduced by these settled claims. The remaining net liability at June 30, 2013 is $2,762.

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 is included in Other Accrued Liabilities on the Consolidated Balance Sheet. Past payments by Fairmont with respect to asbestos cases have not been material.

Ryerson Dam Litigation: In 2008, the Pennsylvania Department of Conservation and Natural Resources (the Commonwealth) filed a six-count Complaint in the Court of Common Pleas of Allegheny County, Pennsylvania, claiming that the Company's underground longwall mining activities at its Bailey Mine caused cracks and seepage damage to the Ryerson Park Dam. The Commonwealth subsequently breached the dam, thereby eliminating the Ryerson Park Lake. The Commonwealth claimed that the Company is liable for dam reconstruction costs, lake restoration costs and natural resource damages totaling $58,000. In October 2008, the Common Pleas Court ruled that natural resource damages were not recoverable and referred the Commonwealth's claim to the Pennsylvania Department of Environmental Protection (DEP). In February 2010, the DEP issued

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an interim report, concluding that the alleged damage was subsidence related. The DEP estimated the cost of repair to be approximately $20,000. The Company appealed the DEP's findings to the Pennsylvania Environmental Hearing Board (PEHB). In April 2013, this Company and the Commonwealth entered into a Settlement Agreement and Release settling all of the Commonwealth's claims regarding the Dam and the Lake. The Settlement provides 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 provides 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 certain coal and mining rights in an area of the Bailey Mine where a mining permit application is currently pending.

South Carolina Electric & Gas Company Arbitration: In April, 2009, South Carolina Electric & Gas Company (SCE&G), a public utility, filed an arbitration complaint, against CONSOL of Kentucky Inc. and CONSOL Energy Sales Company, both wholly owned subsidiaries of CONSOL Energy, seeking $36,000 in damages. SCE&G claimed it suffered those damages in obtaining cover coal to replace coal which was not delivered in 2008 under a coal sales agreement.  CONSOL Energy counterclaimed against SCE&G for $9,400 for terminating coal shipments under the sales agreement, alleging that SCE&G had agreed that shortfalls could be made up in 2009.  A four day hearing on the claims commenced on April 30, 2012. On December 21, 2012, the Arbitration Panel awarded SCE&G $9,735, plus interest at 8.75% from January 9, 2011, and attorney fees. The Award is against CONSOL of Kentucky only. The Panel is currently considering SCE&G's attorney fee claim of $1,873, which has been vigorously opposed by CONSOL Energy. 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.

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 conflicting claimant, 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, and the District Judge has scheduled argument on the Objections on September 12, 2013. Discovery is proceeding in this litigation. 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

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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, and the District Judge has scheduled argument on the Objections on September 12, 2013. Discovery is proceeding in this litigation. 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.

CNX Gas Shareholders Litigation: CONSOL Energy was named as a defendant in four putative class actions brought by alleged shareholders of CNX Gas Corporation challenging the tender offer by CONSOL Energy to acquire all of the shares of CNX Gas common stock that CONSOL Energy did not already own for $38.25 per share. The two cases filed in Pennsylvania Common Pleas Court have been stayed and the two cases filed in the Delaware Chancery Court have been consolidated under the caption In Re CNX Gas Shareholders Litigation (C.A. No. 5377-VCL).  (A third case filed in Delaware was voluntarily dismissed by the plaintiff in 2010.) All four actions generally allege that CONSOL Energy breached and/or aided and abetted in the breach of fiduciary duties purportedly owed to CNX Gas public shareholders, essentially alleging that the $38.25 per share price that CONSOL Energy paid to CNX Gas shareholders in the tender offer and subsequent short-form merger was unfair. Among other things, the actions sought a permanent injunction against or rescission of the tender offer, damages, and attorneys' fees and expenses. Following a mediation, the parties to the Delaware litigation have agreed in principle to a settlement and release of all of the claims of the plaintiff class (as defined in a January 20, 2011 order of certification) in exchange for defendants' agreement to establish a settlement fund in the amount of $42,730 for distribution to class members, of which CONSOL Energy is responsible for $20,200. On May 8, 2013, the parties executed and filed with the Court a Stipulation and Agreement of Compromise and Settlement. A Settlement Hearing has been scheduled by the Court on August 23, 2013.

The following lawsuits and claims include those for which a loss is reasonably possible, but not probable, and accordingly no accrual has been recognized.

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: 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. Service was effected on April 1, 2013 by waiver. A Motion to Dismiss Plaintiffs' Complaint and, in the Alternative, Motion for More Definitive Statement was filed by the defendants on May 31, 2013. Plaintiffs' Response in opposition to the Motion to Dismiss was filed on June 20, 2013, and the defendants on July 1, 2013, filed their Reply to the Response. Without first seeking the required leave of Court, plaintiffs filed a Sur Reply brief on July 8, 2013, for the first time arguing the interpretation of the Virginia Mine Void Statute urged by defendants was unconstitutional. The defendants have moved to strike the Sur Reply and have asked the Court to deny plaintiffs' after-the-fact Motion for Leave to file the Sur Reply brief. CONSOL Energy intends to vigorously defend the suit.

Hall Litigation: A purported class action lawsuit was filed on December 23, 2010 styled Hall v. CONSOL Gas Company in Allegheny County Pennsylvania Common Pleas Court.  The named plaintiff is Earl D. Hall.  The purported class plaintiffs are all Pennsylvania oil and gas lessors to Dominion Exploration and Production Company, whose leases were acquired by CONSOL Energy.  The complaint alleges more than 1,000 similarly situated lessors.  The lawsuit alleges that CONSOL Energy incorrectly calculated royalties by (i) calculating line loss on the basis of allocated volumes rather than on a well-by-well basis, (ii) possibly calculating the royalty on the basis of an incorrect price, (iii) possibly taking unreasonable deductions for post-production costs and costs that were not arms-length, (iv) not paying royalties on gas lost or used before the point of sale, and (v) not paying

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royalties on oil production. The complaint also alleges that royalty statements were false and misleading.  The complaint seeks damages, interest and an accounting on a well-by-well basis. The case has been inactive since December 2011. 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.

    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 trial on the issue of whether a drilling that deviates from the coal seam results in damage to the gas owner is now scheduled for October 21, 2013. CNX Gas Company and CONSOL Energy believe this lawsuit to be without merit and intend 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 amended its complaint twice to include allegations that CONSOL Energy and Dominion Resources are liable for their subsidiaries' actions and that Rowland's title has been slandered. Motions to dismiss have been denied, discovery is proceeding but stayed pending mediation. Initial mediation efforts have been unsuccessful but settlement discussions are continuing. 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.

Majorsville Storage Field Declaratory Judgment: On March 3, 2011, an attorney sent a letter to CNX Gas Company regarding certain leases that CNX Gas Company obtained from Columbia Gas in Greene County, Pennsylvania involving the Majorsville Storage Field. The letter was written on behalf of three lessors alleging that the leases totaling 525 acres are invalid, and had expired by their terms. The plaintiffs' theory is that the rights of storage and production are severable under the leases. Ignoring the fact that the leases have been used for gas storage, they claim that since there has been no production or development of production, the right to produce gas expired at the end of the primary terms. On June 16, 2011, in the Court of Common Pleas of Greene County, Pennsylvania, the Company filed a declaratory judgment action, seeking to have a court confirm the validity of the leases. Discovery is proceeding in this litigation. We believe that we will prevail in this litigation based on the language of the leases and the current status of the law. Consequently, we have not recognized any liability related to these actions.

The following lawsuit and claims include those for which a loss is remote and accordingly, no accrual has been recognized, although if a non-favorable verdict were received the impact could be material.

Comer Litigation: In 2005, plaintiffs Ned Comer and others filed a purported class action lawsuit in the U.S. District Court for the Southern District of Mississippi against a number of companies in energy, fossil fuels and chemical industries, including CONSOL Energy styled, Comer, et al. v. Murphy Oil, et al. (Comer I). The plaintiffs, residents and owners of property along the Mississippi Gulf coast, alleged that the defendants caused the emission of greenhouse gases that contributed to global warming, which in turn caused a rise in sea levels and added to the ferocity of Hurricane Katrina, which combined to destroy the plaintiffs' property. The District Court dismissed the case and the plaintiffs appealed. The Circuit Court panel reversed and the defendants sought a rehearing before the entire court. A rehearing before the entire court was granted, which had the effect of vacating the panel's reversal, but before the case could be heard on the merits, a number of judges recused themselves and there was no longer a quorum. As a result, the District Court's dismissal was effectively reinstated. The plaintiffs asked the U.S. Supreme Court to require the Circuit Court to address the merits of their appeal. On January 11, 2011, the Supreme Court denied that request. Although that should have resulted in the dismissal being final, the plaintiffs filed a lawsuit on May 27, 2011, in the same jurisdiction against essentially the same defendants making nearly identical allegations as in the original lawsuit (Comer II). The trial court dismissed this case, and the dismissal was appealed. On May 14, 2013, a panel of the U.S. Court of Appeals for

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the Fifth Circuit affirmed, holding res judicata arising from Comer I bars the plaintiffs' claims in Comer II. On June 5, 2013, the Fifth Circuit issued its mandate. If they wish to do so, plaintiffs have until August 12, 2013, to file a certiorari petition with the Supreme Court of the United States.

At June 30, 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. No amounts related to these financial guarantees and letters of credit are recorded as liabilities on the financial statements. CONSOL Energy management believes that these guarantees will expire without being funded, and therefore the commitments will not have a material adverse effect on financial condition.

	Amount of Commitment Expiration Per Period
	Total Amounts Committed		Less Than 1  Year		1-3 Years		3-5 Years		Beyond 5  Years
Letters of Credit:
Employee-Related	$	190,157	$	95,847	$	94,310	$	—	$	—
Environmental	56,294		54,566		1,728		—		—
Other	83,246		31,015		52,231		—		—
Total Letters of Credit	329,697		181,428		148,269		—		—
Surety Bonds:
Employee-Related	204,884		194,884		10,000		—		—
Environmental	533,725		527,938		5,787		—		—
Other	30,946		30,935		10		—		1
Total Surety Bonds	769,555		753,757		15,797		—		1
Total Commitments	$	1,099,252	$	935,185	$	164,066	$	—	$	1

Employee-related financial guarantees have primarily been provided to support the United Mine Workers’ of America’s 1992 Benefit Plan and various state and federal workers’ compensation self-insurance programs. Environmental financial guarantees have primarily been provided to support various performance bonds related to reclamation and other environmental issues. Coal and Gas financial guarantees have primarily been provided to support various sales contracts. Other guarantees have also been extended to support insurance policies, legal matters, full and timely payments of mining equipment leases, and various other items necessary in the normal course of business.

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 June 30, 2013, the purchase obligations for each of the next five years and beyond were as follows:

Obligations Due	Amount
Less than 1 year	$	258,380
1 - 3 years	164,240
3 - 5 years	131,751
More than 5 years	405,934
Total Purchase Obligations	$	960,305

Costs related to these purchase obligations include:

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	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2013		2012		2013		2012
Major equipment purchases	$	15,116	$	31,989	$	48,542	$	45,175
Firm transportation expense	31,017		15,822		59,542		30,867
Gas drilling obligations	25,904		28,517		54,768		58,093
Other	—		129		—		427
Total costs related to purchase obligations	$	72,037	$	76,457	$	162,852	$	134,562

NOTE 12—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 requires 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.  

                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 revenues from the underlying commodity. As of June 30, 2013, the total notional amount of the Company’s outstanding natural gas swap contracts was 197.7 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. During the next twelve months, $49,614 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 settlements 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 June 30, 2013 of CONSOL Energy's derivative instruments, which were all natural gas swaps and qualify as cash flow hedges, was an asset of $120,973 and a liability of $4,854. The total asset is comprised of $82,061 and $38,912 which were included in Prepaid Expense and Other Assets, respectively, on the Consolidated Balance Sheets. The total liability is comprised of $860 and $3,994 which were included in Other Accrued Liabilities and Other Liabilities, respectively, on the Consolidated Balance Sheets.

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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 were as follows:

	For the Three Months Ended June 30,
	2013			2012
Natural Gas Price Swaps
Beginning Balance – Accumulated OCI	$	35,453		$	179,915
Gain/(Loss) recognized in Accumulated OCI	$	45,749		$	10,663
Less: Gain reclassified from Accumulated OCI into Outside Sales	$	9,528		$	57,847
Ending Balance – Accumulated OCI	$	71,674		$	132,731
Gain/(Loss) recognized in Outside Sales for ineffectiveness	$	(3,753	)	$	882

	For the Six Months Ended June 30,
	2013			2012
Natural Gas Price Swaps
Beginning Balance – Accumulated OCI	$	76,761		$	151,780
Gain/(Loss) recognized in Accumulated OCI	$	27,154		$	86,739
Less: Gain reclassified from Accumulated OCI into Outside Sales	$	32,241		$	105,788
Ending Balance – Accumulated OCI	$	71,674		$	132,731
Gain/(Loss) recognized in Outside Sales for ineffectiveness	$	(2,712	)	$	47

There were no amounts excluded from the assessment of hedge effectiveness in 2013 or 2012.

NOTE 13—FAIR VALUE OF FINANCIAL INSTRUMENTS:

The financial instruments measured at fair value on a recurring basis are summarized below:

	Fair Value Measurements at June 30, 2013						Fair Value Measurements at December 31, 2012
Description	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Gas Cash Flow Hedges	$	—	$	116,119	$	—	$	—	$	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 amount reported in the balance sheets for restricted cash approximates its fair value due to the short-term maturity of these instruments.

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.

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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:

	June 30, 2013						December 31, 2012
	Carrying Amount			Fair Value			Carrying Amount			Fair Value
Cash and Cash Equivalents	$	71,938		$	71,938		$	21,878		$	21,878
Restricted Cash (a)	$	—		$	—		$	68,673		$	68,673
Short-Term Notes Payable	$	(173,000	)	$	(173,000	)	$	(25,073	)	$	(25,073	)
Borrowings Under Securitization Facility	$	(40,719	)	$	(40,719	)	$	(37,846	)	$	(37,846	)
Long-Term Debt	$	(3,128,585	)	$	(3,270,812	)	$	(3,129,017	)	$	(3,378,058	)

(a) The 2012 restricted cash balance includes $48,294 and $20,379 located in current assets and other assets of the Consolidated Balance Sheet, respectively.

NOTE 14—SEGMENT INFORMATION:

CONSOL Energy has two principal business divisions: Coal and Gas. 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 six months ended June 30, 2013, the Thermal aggregated segment includes the following mines: Bailey, Blacksville #2, Enlow Fork, Fola Complex, Loveridge, McElroy, Miller Creek Complex, Robinson Run and Shoemaker. For the six months ended June 30, 2013, the Low Volatile Metallurgical aggregated segment includes the Buchanan Mine and Amonate Complex. For the six months ended June 30, 2013, the High Volatile Metallurgical aggregated segment includes: Bailey, Blacksville #2, Enlow Fork, Fola Complex, Loveridge and Robinson Run 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. 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 Coalbed Methane, Marcellus, 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. CONSOL Energy’s All Other segment includes terminal services, river and dock services, industrial supply services, general and administrative activities and other business activities. 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.

Annually, the preparation of our gas reserve estimates are completed in accordance with CONSOL Energy's prescribed internal control procedures, which include verification of input data into a gas reserve 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 2012 gas reserve results, which are reported in the Supplemental Gas Data year ended December 31, 2012 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 14 years of experience in the oil and gas industry.

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Industry segment results for the three months ended June 30, 2013 are:

	Thermal		Low Volatile Metallurgical		High Volatile Metallurgical		Other Coal			Total Coal		Coalbed Methane		Marcellus Shale		Shallow Oil and Gas			Other Gas			Total Gas			All Other			Corporate, Adjustments & Eliminations			Consolidated
Sales—outside	$	697,945	$	111,006	$	57,115	$	5,005		$	871,071	$	87,799	$	46,577	$	33,745		$	3,115		$	171,236		$	83,469		$	—		$	1,125,776	(A)
Sales—purchased gas	—		—		—		—			—		—		—		—			1,406			1,406			—			—			1,406
Sales—gas royalty interests	—		—		—		—			—		—		—		—			17,028			17,028			—			—			17,028
Freight—outside	—		—		—		10,125			10,125		—		—		—			—			—			—			—			10,125
Intersegment transfers	—		—		—		—			—		—		—		—			926			926			32,428			(33,354		)	—
Total Sales and Freight	$	697,945	$	111,006	$	57,115	$	15,130		$	881,196	$	87,799	$	46,577	$	33,745		$	22,475		$	190,596		$	115,897		$	(33,354	)	$	1,154,335
Earnings (Loss) Before Income Taxes	$	103,768	$	30,819	$	17,245	$	(86,354	)	$	65,478	$	22,124	$	11,680	$	(5,576	)	$	(32,838	)	$	(4,610	)	$	(883	)	$	(58,176	)	$	1,809	(B)
Segment assets										$	5,600,934											$	6,170,531		$	363,819		$	617,644		$	12,752,928	(C)
Depreciation, depletion and amortization										$	100,751											$	52,236		$	6,320		$	—		$	159,307
Capital expenditures										$	157,558											$	188,463		$	6,007		$	—		$	352,028

(A)    Included in the Coal segment are sales of $157,318 to First Energy and $138,700 to Xcoal Energy & Resources each comprising over 10% of sales.

(B)     Includes equity in earnings of unconsolidated affiliates of $11,526, $1,030 and $(686) for Coal, Gas and All Other, respectively.

(C)    Includes investments in unconsolidated equity affiliates of $22,119, $170,589 and $63,389 for Coal, Gas and All Other, respectively.

26

Industry segment results for the three months ended June 30, 2012 are:

	Thermal		Low Volatile Metallurgical		High Volatile Metallurgical		Other Coal		Total Coal		Coalbed Methane		Marcellus Shale		Shallow Oil and Gas			Other Gas			Total Gas		All Other			Corporate, Adjustments & Eliminations			Consolidated
Sales—outside	$	748,303	$	120,481	$	71,250	$	4,736	$	944,770	$	88,080	$	23,730	$	34,207		$	2,082		$	148,099	$	96,424		$	—		$	1,189,293	(D)
Sales—purchased gas	—		—		—		—		—		—		—		—			651			651		—			—			651
Sales—gas royalty interests	—		—		—		—		—		—		—		—			9,533			9,533		—			—			9,533
Freight—outside	—		—		—		49,472		49,472		—		—		—			—			—		—			—			49,472
Intersegment transfers	—		—		—		—		—		—		—		—			360			360		36,136			(36,496		)	—
Total Sales and Freight	$	748,303	$	120,481	$	71,250	$	54,208	$	994,242	$	88,080	$	23,730	$	34,207		$	12,626		$	158,643	$	132,560		$	(36,496	)	$	1,248,949
Earnings (Loss) Before Income Taxes	$	133,697	$	42,780	$	19,418	$	61,286	$	257,181	$	24,344	$	4,835	$	(2,410	)	$	(25,625	)	$	1,144	$	14,962		$	(61,632	)	$	211,655	(E)
Segment assets									$	5,445,502											$	5,970,939	$	360,673		$	820,782		$	12,597,896	(F)
Depreciation, depletion and amortization									$	100,684											$	47,326	$	(5,782	)	$	11,596		$	153,824
Capital expenditures									$	253,587											$	143,206	$	11,160		$	—		$	407,953

(D) Included in the Coal segment are sales of $136,576 to First Energy and $181,566 to Xcoal Energy & Resources each comprising over 10% of sales.

(E) Includes equity in earnings of unconsolidated affiliates of $1,483, $2,037 and $3,648 for Coal, Gas and All Other, respectively.

(F)    Includes investments in unconsolidated equity affiliates of $21,090, $132,545 and $55,638 for Coal, Gas and All Other, respectively.

27

Industry segment results for the six months ended June 30, 2013 are:

	Thermal		Low Volatile Metallurgical		High Volatile Metallurgical		Other Coal			Total Coal		Coalbed Methane		Marcellus Shale		Shallow Oil and Gas			Other Gas			Total Gas			All Other			Corporate, Adjustments & Eliminations			Consolidated
Sales—outside	$	1,459,217	$	257,834	$	115,737	$	10,668		$	1,843,456	$	171,439	$	94,988	$	66,181		$	6,470		$	339,078		$	169,407		$	—		$	2,351,941	(G)
Sales—purchased gas	—		—		—		—			—		—		—		—			2,764			2,764			—			—			2,764
Sales—gas royalty interests	—		—		—		—			—		—		—		—			31,232			31,232			—			—			31,232
Freight—outside	—		—		—		24,186			24,186		—		—		—			—			—			—			—			24,186
Intersegment transfers	—		—		—		—			—		—		—		—			1,762			1,762			67,905			(69,667		)	—
Total Sales and Freight	$	1,459,217	$	257,834	$	115,737	$	34,854		$	1,867,642	$	171,439	$	94,988	$	66,181		$	42,228		$	374,836		$	237,312		$	(69,667	)	$	2,410,123
Earnings (Loss) Before Income Taxes	$	232,200	$	85,536	$	30,597	$	(189,353	)	$	158,980	$	43,436	$	25,448	$	(9,737	)	$	(64,397	)	$	(5,250	)	$	(41,435	)	$	(111,785	)	$	510	(H)
Segment assets										$	5,600,934											$	6,170,531		$	363,819		$	617,644		$	12,752,928	(I)
Depreciation, depletion and amortization										$	203,462											$	104,635		$	12,525		$	—		$	320,622
Capital expenditures										$	354,896											$	395,593		$	7,511		$	—		$	758,000

(G)    Included in the Coal segment are sales of $328,300 to First Energy and $321,821 to Xcoal Energy & Resources each comprising over 10% of sales.

(H)     Includes equity in earnings of unconsolidated affiliates of $12,343, $4,212 and $112 for Coal, Gas and All Other, respectively.

(I)    Includes investments in unconsolidated equity affiliates of $22,119, $170,589 and $63,389 for Coal, Gas and All Other, respectively.

28

Industry segment results for the six months ended June 30, 2012 are:

	Thermal		Low Volatile Metallurgical		High Volatile Metallurgical		Other Coal		Total Coal		Coalbed Methane		Marcellus Shale		Shallow Oil and Gas			Other Gas			Total Gas		All Other		Corporate, Adjustments & Eliminations			Consolidated
Sales—outside	$	1,560,356	$	293,221	$	131,818	$	13,691	$	1,999,086	$	187,615	$	47,521	$	68,580		$	4,586		$	308,302	$	193,376	$	—		$	2,500,764	(J)
Sales—purchased gas	—		—		—		—		—		—		—		—			1,490			1,490		—		—			1,490
Sales—gas royalty interests	—		—		—		—		—		—		—		—			21,739			21,739		—		—			21,739
Freight—outside	—		—		—		98,765		98,765		—		—		—			—			—		—		—			98,765
Intersegment transfers	—		—		—		—		—		—		—		—			826			826		73,345		(74,171		)	—
Total Sales and Freight	$	1,560,356	$	293,221	$	131,818	$	112,456	$	2,097,851	$	187,615	$	47,521	$	68,580		$	28,641		$	332,357	$	266,721	$	(74,171	)	$	2,622,758
Earnings (Loss) Before Income Taxes	$	262,146	$	122,121	$	35,354	$	30	$	419,651	$	60,734	$	8,086	$	(6,132	)	$	(49,044	)	$	13,644	$	19,045	$	(122,108	)	$	330,232	(K)
Segment assets									$	5,445,502											$	5,970,939	$	360,673	$	820,782		$	12,597,896	(L)
Depreciation, depletion and amortization									$	201,446											$	96,129	$	—	$	11,596		$	309,171
Capital expenditures									$	448,016											$	241,661	$	24,722	$	—		$	714,399

(J) Included in the Coal segment are sales of $280,731 to First Energy and $319,907 to Xcoal Energy & Resources each comprising over 10% of sales.

(K) Includes equity in earnings of unconsolidated affiliates of $6,290, $3,981 and $4,832 for Coal, Gas and All Other, respectively.

(L)    Includes investments in unconsolidated equity affiliates of $21,090, $132,545 and $55,638 for Coal, Gas and All Other, respectively.

29

Reconciliation of Segment Information to Consolidated Amounts:

Earnings Before Income Taxes:

	For the Three Months Ended June 30,						For the Six Months Ended June 30,
	2013			2012			2013			2012
Segment Earnings Before Income Taxes for total reportable business segments	$	60,868		$	258,325		$	153,730		$	433,295
Segment (Loss) Earnings Before Income Taxes for all other businesses	(883		)	14,962			(41,435		)	19,045
Interest expense, net and other non-operating activity (M)	(56,406		)	(58,943		)	(109,066		)	(118,985		)
Other Corporate Items (M)	(1,770		)	(2,689		)	(2,719		)	(3,123		)
Earnings Before Income Taxes	$	1,809		$	211,655		$	510		$	330,232

Total Assets:	June 30,
	2013		2012
Segment assets for total reportable business segments	$	11,771,465	$	11,416,441
Segment assets for all other businesses	363,819		360,673
Items excluded from segment assets:
Cash and other investments (M)	45,905		186,611
Recoverable income taxes	1,930		—
Deferred tax assets	531,707		588,722
Bond issuance costs	38,102		45,449
Total Consolidated Assets	$	12,752,928	$	12,597,896

_________________________ 

(M) Excludes amounts specifically related to the gas segment.

30

NOTE 15—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 Three Months Ended June 30, 2013 (unaudited):

	Parent Issuer			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination			Consolidated
Sales—Outside	$	—		$	172,161		$	897,541		$	53,610		$	2,464		$	1,125,776
Sales—Gas Royalty Interests	—			17,028			—			—			—			17,028
Sales—Purchased Gas	—			1,406			—			—			—			1,406
Freight—Outside	—			—			10,125			—			—			10,125
Other Income	198,207			11,235			45,706			5,404			(198,207		)	62,345
Total Revenue and Other Income	198,207			201,830			953,372			59,014			(195,743		)	1,216,680
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	4,249			125,632			660,137			53,467			12,393			855,878
Gas Royalty Interests Costs	—			13,544			—			—			(10		)	13,534
Purchased Gas Costs	—			1,061			—			—			—			1,061
Related Party Activity	35,231			—			(50,571		)	436			14,904			—
Freight Expense	—			—			10,125			—			—			10,125
Selling, General and Administrative Expenses	—			11,717			25,058			348			—			37,123
Depreciation, Depletion and Amortization	3,252			52,236			103,321			498			—			159,307
Interest Expense	50,807			2,136			1,679			10			(114		)	54,518
Taxes Other Than Income	88			—			82,507			730			—			83,325
Total Costs	93,627			206,326			832,256			55,489			27,173			1,214,871
Earnings (Loss) Before Income Taxes	104,580			(4,496		)	121,116			3,525			(222,916		)	1,809
Income Tax Expense (Benefit)	117,106			(1,747		)	(96,692		)	(4,045		)	—			14,622
Net (Loss) Income	(12,526		)	(2,749		)	217,808			7,570			(222,916		)	(12,813		)
Add: Net Loss Attributable to Noncontrolling Interest	—			287			—			—			—			287
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(12,526	)	$	(2,462	)	$	217,808		$	7,570		$	(222,916	)	$	(12,526	)

31

Balance Sheet at June 30, 2013 (unaudited):

	Parent Issuer		CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination			Consolidated
Assets:
Current Assets:
Cash and Cash Equivalents	$	45,267	$	26,851		$	122		$	(302	)	$	—		$	71,938
Accounts and Notes Receivable:
Trade	—		62,013			—			285,354			—			347,367
Notes Receivable	234		323,835			26,908			—			—			350,977
Other Receivables	4,449		133,895			8,436			4,489			—			151,269
Accounts Receivable—Securitized	—		—			—			40,719			—			40,719
Inventories	—		14,619			176,899			36,476			—			227,994
Deferred Income Taxes	169,905		(26,901		)	—			—			—			143,004
Recoverable Income Taxes	16,038		(14,108		)	—			—			—			1,930
Prepaid Expenses	12,795		86,893			36,494			1,461			—			137,643
Total Current Assets	248,688		607,097			248,859			368,197			—			1,472,841
Property, Plant and Equipment:
Property, Plant and Equipment	221,174		6,368,437			9,578,914			25,726			—			16,194,251
Less-Accumulated Depreciation, Depletion and Amortization	134,785		1,064,498			4,552,589			18,634			—			5,770,506
Total Property, Plant and Equipment-Net	86,389		5,303,939			5,026,325			7,092			—			10,423,745
Other Assets:
Deferred Income Taxes	820,406		(431,703		)	—			—			—			388,703
Investment in Affiliates	10,128,714		170,589			764,618			—			(10,807,824		)	256,097
Notes Receivable	184		—			1,328			—			—			1,512
Other	112,660		47,888			39,568			9,914			—			210,030
Total Other Assets	11,061,964		(213,226		)	805,514			9,914			(10,807,824		)	856,342
Total Assets	$	11,397,041	$	5,697,810		$	6,080,698		$	385,203		$	(10,807,824	)	$	12,752,928
Liabilities and Equity:
Current Liabilities:
Accounts Payable	$	193,082	$	208,852		$	48,729		$	10,752		$	—		$	461,415
Accounts Payable (Recoverable)—Related Parties	3,847,815		65,771			(4,118,674		)	153,288			51,800			—
Current Portion Long-Term Debt	1,562		5,972			5,081			807			—			13,422
Short-Term Notes Payable	—		224,800			—			—			(51,800		)	173,000
Borrowings Under Securitization Facility	—		—			—			40,719			—			40,719
Other Accrued Liabilities	140,353		64,908			582,911			10,473			—			798,645
Total Current Liabilities	4,182,812		570,303			(3,481,953		)	216,039			—			1,487,201
Long-Term Debt:	3,005,012		43,897			121,252			1,589			—			3,171,750
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	—		—			2,820,186			—			—			2,820,186
Pneumoconiosis Benefits	—		—			177,146			—			—			177,146
Mine Closing	—		—			459,392			—			—			459,392
Gas Well Closing	—		115,802			78,144			—			—			193,946
Workers’ Compensation	—		—			155,199			319			—			155,518
Salary Retirement	109,691		—			—			—			—			109,691
Reclamation	—		—			50,051			—			—			50,051
Other	73,875		11,703			17,409			—			—			102,987
Total Deferred Credits and Other Liabilities	183,566		127,505			3,757,527			319			—			4,068,917
Total CONSOL Energy Inc. Stockholders’ Equity	4,025,651		4,956,696			5,683,872			167,256			(10,807,824		)	4,025,651
Noncontrolling Interest	—		(591		)	—			—			—			(591		)
Total Liabilities and Equity	$	11,397,041	$	5,697,810		$	6,080,698		$	385,203		$	(10,807,824	)	$	12,752,928

32

Income Statement for the Three Months Ended June 30, 2012 (unaudited):

	Parent Issuer			CNX Gas Guarantor		Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Sales—Outside	$	—		$	148,459	$	976,515	$	64,785	$	(466	)	$	1,189,293
Sales—Gas Royalty Interests	—			9,533		—		—		—			9,533
Sales—Purchased Gas	—			651		—		—		—			651
Freight—Outside	—			—		49,472		—		—			49,472
Other Income	249,780			18,098		30,352		5,215		(97,907		)	205,538
Total Revenue and Other Income	249,780			176,741		1,056,339		70,000		(98,373		)	1,454,487
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	22,351			101,695		662,457		62,811		7,575			856,889
Gas Royalty Interests Costs	—			7,131		—		—		(7		)	7,124
Purchased Gas Costs	—			869		—		—		—			869
Related Party Activity	(14,013		)	—		22,782		447		(9,216		)	—
Freight Expense	—			—		49,472		—		—			49,472
Selling, General and Administrative Expenses	—			9,313		24,185		234		—			33,732
Depreciation, Depletion and Amortization	2,895			47,326		103,085		518		—			153,824
Interest Expense	52,932			1,191		2,560		11		(101		)	56,593
Taxes Other Than Income	27			8,164		75,425		713		—			84,329
Total Costs	64,192			175,689		939,966		64,734		(1,749		)	1,242,832
Earnings (Loss) Before Income Taxes	185,588			1,052		116,373		5,266		(96,624		)	211,655
Income Tax Expense (Benefit)	32,849			326		23,788		1,982		—			58,945
Net (Loss) Income	152,739			726		92,585		3,284		(96,624		)	152,710
Add: Net Loss Attributable to Noncontrolling Interest	—			29		—		—		—			29
Net Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	152,739		$	755	$	92,585	$	3,284	$	(96,624	)	$	152,739

33

Balance Sheet at December 31, 2012:

	Parent Issuer		CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Assets:
Current Assets:
Cash and Cash Equivalents	$	17,491	$	3,352		$	175		$	860	$	—		$	21,878
Accounts and Notes Receivable:
Trade	—		58,126			—			370,202		—			428,328
Notes Receivable	154		315,730			2,503			—		—			318,387
Other Receivables	6,335		214,748			33,289			5,159		(128,400		)	131,131
Accounts Receivable—Securitized	—		—			—			37,846		—			37,846
Inventories	—		14,133			198,269			35,364		—			247,766
Deferred Income Taxes	174,176		(26,072		)	—			—		—			148,104
Restricted Cash	—		—			48,294			—		—			48,294
Prepaid Expenses	29,589		86,186			40,215			1,370		—			157,360
Total Current Assets	227,745		666,203			322,745			450,801		(128,400		)	1,539,094
Property, Plant and Equipment:
Property, Plant and Equipment	216,448		5,956,207			9,347,370			25,179		—			15,545,204
Less-Accumulated Depreciation, Depletion and Amortization	126,048		960,613			4,249,507			18,069		—			5,354,237
Total Property, Plant and Equipment-Net	90,400		4,995,594			5,097,863			7,110		—			10,190,967
Other Assets:
Deferred Income Taxes	884,310		(439,725		)	—			—		—			444,585
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			32,016			10,188		—			227,077
Total Other Assets	10,920,537		(229,914		)	847,191			10,188		(10,607,154		)	940,848
Total Assets	$	11,238,682	$	5,431,883		$	6,267,799		$	468,099	$	(10,735,554	)	$	12,670,909
Liabilities and Equity:
Current Liabilities:
Accounts Payable	$	177,734	$	166,182		$	154,936		$	9,130	$	—		$	507,982
Accounts Payable (Recoverable)-Related Parties	3,599,216		23,981			(3,749,584		)	254,787		(128,400		)	—
Current Portion of Long-Term Debt	1,554		5,953			5,222			756		—			13,485
Short-Term Notes Payable	25,073		—			—			—		—			25,073
Accrued Income Taxes	20,488		13,731			—			—		—			34,219
Borrowings Under Securitization Facility	—		—			—			37,846		—			37,846
Other Accrued Liabilities	135,407		57,074			566,485			9,528		—			768,494
Total Current Liabilities	3,959,472		266,921			(3,022,941		)	312,047		(128,400		)	1,387,099
Long-Term Debt:	3,005,515		46,081			121,523			1,467		—			3,174,586
Deferred Credits and Other Liabilities:
Postretirement Benefits Other Than Pensions	—		—			2,832,401			—		—			2,832,401
Pneumoconiosis Benefits	—		—			174,781			—		—			174,781
Mine Closing	—		—			446,727			—		—			446,727
Gas Well Closing	—		80,097			68,831			—		—			148,928
Workers’ Compensation	—		—			155,342			306		—			155,648
Salary Retirement	218,004		—			—			—		—			218,004
Reclamation	—		—			47,965			—		—			47,965
Other	101,899		24,518			4,608			—		—			131,025
Total Deferred Credits and Other Liabilities	319,903		104,615			3,730,655			306		—			4,155,479
Total CONSOL Energy Inc. Stockholders’ Equity	3,953,792		5,014,313			5,438,562			154,279		(10,607,154		)	3,953,792
Noncontrolling Interest	—		(47		)	—			—		—			(47		)
Total Liabilities and Equity	$	11,238,682	$	5,431,883		$	6,267,799		$	468,099	$	(10,735,554	)	$	12,670,909

34

Income Statement for the Six Months Ended June 30, 2013 (unaudited):

	Parent Issuer			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination			Consolidated
Sales—Outside	$	—		$	340,840		$	1,901,698		$	107,663		$	1,740		$	2,351,941
Sales—Gas Royalty Interests	—			31,232			—			—			—			31,232
Sales—Purchased Gas	—			2,764			—			—			—			2,764
Freight—Outside	—			—			24,186			—			—			24,186
Other Income	276,183			24,459			60,961			10,777			(276,183		)	96,197
Total Revenue and Other Income	276,183			399,295			1,986,845			118,440			(274,443		)	2,506,320
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	80,239			239,984			1,341,842			107,193			19,583			1,788,841
Gas Royalty Interests Costs	—			25,361			—			—			(21		)	25,340
Purchased Gas Costs	—			2,020			—			—			—			2,020
Related Party Activity	22,675			—			(58,349		)	840			34,834			—
Freight Expense	—			—			24,186			—			—			24,186
Selling, General and Administrative Expenses	—			21,829			48,305			659			—			70,793
Depreciation, Depletion and Amortization	6,447			104,635			208,558			982			—			320,622
Interest Expense	100,976			3,797			3,323			21			(221		)	107,896
Taxes Other Than Income	265			6,698			157,513			1,636			—			166,112
Total Costs	210,602			404,324			1,725,378			111,331			54,175			2,505,810
Earnings (Loss) Before Income Taxes	65,581			(5,029		)	261,467			7,109			(328,618		)	510
Income Tax Expense (Benefit)	79,671			(1,955		)	(59,883		)	(2,689		)	—			15,144
Net (Loss) Income	(14,090		)	(3,074		)	321,350			9,798			(328,618		)	(14,634		)
Add: Net Loss Attributable to Noncontrolling Interest	—			544			—			—			—			544
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(14,090	)	$	(2,530	)	$	321,350		$	9,798		$	(328,618	)	$	(14,090	)

35

Income Statement for the Six Months Ended June 30, 2012 (unaudited):

	Parent Issuer			CNX Gas Guarantor		Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Sales—Outside	$	—		$	309,128	$	2,058,803	$	133,807	$	(974	)	$	2,500,764
Sales—Gas Royalty Interests	—			21,739		—		—		—			21,739
Sales—Purchased Gas	—			1,490		—		—		—			1,490
Freight—Outside	—			—		98,765		—		—			98,765
Other Income	417,765			34,403		60,055		11,172		(264,896		)	258,499
Total Revenue and Other Income	417,765			366,760		2,217,623		144,979		(265,870		)	2,881,257
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	71,531			200,340		1,345,213		129,227		14,619			1,760,930
Gas Royalty Interests Costs	—			17,386		—		—		(13		)	17,373
Purchased Gas Costs	—			1,386		—		—		—			1,386
Related Party Activity	(7,000		)	—		24,040		949		(17,989		)	—
Freight Expense	—			—		98,765		—		—			98,765
Selling, General and Administrative Expenses	—			19,293		52,757		681		—			72,731
Depreciation, Depletion and Amortization	5,816			96,129		206,185		1,041		—			309,171
Interest Expense	107,694			2,409		4,789		22		(201		)	114,713
Taxes Other Than Income	663			16,364		157,396		1,533		—			175,956
Total Costs	178,704			353,307		1,889,145		133,453		(3,584		)	2,551,025
Earnings (Loss) Before Income Taxes	239,061			13,453		328,478		11,526		(262,286		)	330,232
Income Tax Expense (Benefit)	(10,874		)	5,273		81,577		4,350		—			80,326
Net (Loss) Income	249,935			8,180		246,901		7,176		(262,286		)	249,906
Add: Net Loss Attributable to Noncontrolling Interest	—			29		—		—		—			29
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	249,935		$	8,209	$	246,901	$	7,176	$	(262,286	)	$	249,935

36

Cash Flow for the Six Months EndedJune 30, 2013 (unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination			Consolidated
Net Cash Provided by Operating Activities	$	35,486		$	263,284		$	46,545		$	(3,721	)	$	51,800		$	393,394
Cash Flows from Investing Activities:
Capital Expenditures	$	(7,511	)	$	(395,593	)	$	(354,896	)	$	—		$	—		$	(758,000	)
Change in Restricted Cash	—			—			68,673			—			—			68,673
Proceeds from Sales of Assets	—			5,644			235,144			13			—			240,801
Net Investments In Equity Affiliates	—			(22,501		)	5,901			—			—			(16,600		)
Net Cash (Used in) Provided by Investing Activities	$	(7,511	)	$	(412,450	)	$	(45,178	)	$	13		$	—		$	(465,126	)
Cash Flows from Financing Activities:
Proceeds from (Payments on) Short-Term Borrowings	$	—		$	224,800		$	—		$	—		$	(51,800	)	$	173,000
Payments on Miscellaneous Borrowings	(26,280		)	—			(3,555		)	(327		)	—			(30,162		)
Proceeds from Securitization Facility	—			—			—			2,873			—			2,873
Dividends (Paid) Received	21,399			(50,000		)	—			—			—			(28,601		)
Proceeds from Issuance of Common Stock	2,497			—			—			—			—			2,497
Other Financing Activities	2,185			—			—			—			—			2,185
Net Cash Provided by (Used in) Financing Activities	$	(199	)	$	174,800		$	(3,555	)	$	2,546		$	(51,800	)	$	121,792

Cash Flow for the Six Months EndedJune 30, 2012 (unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination		Consolidated
Net Cash Provided by Operating Activities	$	271,127		$	124,367		$	(28,281	)	$	736		$	—	$	367,949
Cash Flows from Investing Activities:
Capital Expenditures	$	(24,722	)	$	(241,661	)	$	(448,016	)	$	—		$	—	$	(714,399	)
Investments in Equity Affiliates	—			(35,150		)	(750		)	—			—		(35,900		)
Distributions from Equity Affiliates	—			3,500			10,561			—			—		14,061
Proceeds from Sales of Assets	169,500			30,249			52,469			11			—		252,229
Net Cash (Used in) Provided by Investing Activities	$	144,778		$	(243,062	)	$	(385,736	)	$	11		$	—	$	(484,009	)
Cash Flows from Financing Activities:
Dividends Paid	$	143,167		$	(200,000	)	$	—		$	—		$	—	$	(56,833	)
Other Financing Activities	1,580			(3,751		)	2			(467		)	—		(2,636		)
Net Cash Provided by (Used in) Financing Activities	$	144,747		$	(203,751	)	$	2		$	(467	)	$	—	$	(59,469	)

37

Statement of Comprehensive Income for the Three Months Ended June 30, 2013 (Unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Net (Loss) Income	$	(12,526	)	$	(2,749	)	$	217,808	$	7,570	$	(222,916	)	$	(12,813	)
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	42,904			—			42,904		—		(42,904		)	42,904
Net (Decrease) Increase in the Value of Cash Flow Hedge	45,749			45,749			—		—		(45,749		)	45,749
Reclassification of Cash Flow Hedge from OCI to Earnings	(9,528		)	(9,528		)	—		—		9,528			(9,528		)
Other Comprehensive (Loss) Income:	79,125			36,221			42,904		—		(79,125		)	79,125
Comprehensive Income (Loss)	66,599			33,472			260,712		7,570		(302,041		)	66,312
Add: Comprehensive Loss Attributable to Noncontrolling Interest	—			287			—		—		—			287
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	66,599		$	33,759		$	260,712	$	7,570	$	(302,041	)	$	66,599

Statement of Comprehensive Income for the Three Months Ended June 30, 2012 (Unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Net Income (Loss)	$	152,739		$	726		$	92,585	$	3,284	$	(96,624	)	$	152,710
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	7,586			—			7,586		—		(7,586		)	7,586
Net Increase (Decrease) in the Value of Cash Flow Hedge	10,663			10,663			—		—		(10,663		)	10,663
Reclassification of Cash Flow Hedge from OCI to Earnings	(57,847		)	(57,847		)	—		—		57,847			(57,847		)
Other Comprehensive Income (Loss):	(39,598		)	(47,184		)	7,586		—		39,598			(39,598		)
Comprehensive Income (Loss)	113,141			(46,458		)	100,171		3,284		(57,026		)	113,112
Add: Comprehensive Loss Attributable to Noncontrolling Interest	—			29			—		—		—			29
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	113,141		$	(46,429	)	$	100,171	$	3,284	$	(57,026	)	$	113,141

38

Statement of Comprehensive Income for the Six Months EndedJune 30, 2013 (Unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Net (Loss) Income	$	(14,090	)	$	(3,074	)	$	321,350	$	9,798	$	(328,618	)	$	(14,634	)
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	88,661			—			88,661		—		(88,661		)	88,661
Net (Decrease) Increase in the Value of Cash Flow Hedge	27,154			27,154			—		—		(27,154		)	27,154
Reclassification of Cash Flow Hedge from OCI to Earnings	(32,241		)	(32,241		)	—		—		32,241			(32,241		)
Other Comprehensive Income (Loss):	83,574			(5,087		)	88,661		—		(83,574		)	83,574
Comprehensive Income (Loss)	69,484			(8,161		)	410,011		9,798		(412,192		)	68,940
Add: Comprehensive Loss Attributable to Noncontrolling Interest	—			544			—		—		—			544
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	69,484		$	(7,617	)	$	410,011	$	9,798	$	(412,192	)	$	69,484

Statement of Comprehensive Income for the Six Months EndedJune 30, 2012 (Unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Net Income (Loss)	$	249,935		$	8,180		$	246,901	$	7,176	$	(262,286	)	$	249,906
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	67,159			—			67,159		—		(67,159		)	67,159
Net Increase (Decrease) in the Value of Cash Flow Hedge	86,739			86,739			—		—		(86,739		)	86,739
Reclassification of Cash Flow Hedge from OCI to Earnings	(105,788		)	(105,788		)	—		—		105,788			(105,788		)
Other Comprehensive Income (Loss):	48,110			(19,049		)	67,159		—		(48,110		)	48,110
Comprehensive Income (Loss)	298,045			(10,869		)	314,060		7,176		(310,396		)	298,016
Add: Comprehensive Loss Attributable to Noncontrolling Interest	—			29			—		—		—			29
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	298,045		$	(10,840	)	$	314,060	$	7,176	$	(310,396	)	$	298,045

39

NOTE 16—RELATED PARTY TRANSACTIONS:

CONE Gathering LLC Related Party Transactions

During the six months ended June 30, 2013, 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 $6,129 and $13,456 for the three and six months ended June 30, 2013, respectively, and were $4,262 and $7,724 for the three and six months ended June 30, 2012, respectively, which were included in Cost of Goods Sold on the Consolidated Statements of Income.

As of June 30, 2013 and December 31, 2012, CONSOL Energy and CNX Gas Company had a net payable of $1,509 and $3,142, respectively, due CONE which was comprised of the following items:

	June 30,			December 31,
	2013			2012			Location on Balance Sheet
Reimbursement for CONE Expenses	$	(733	)	$	(1,336	)	Accounts Receivable–Other
Reimbursement for Services Provided to CONE	(153		)	(341		)	Accounts Receivable–Other
CONE Gathering Capital Reimbursement	—			(18		)	Accounts Receivable–Other
CONE Gathering Fee Payable	2,395			4,837			Accounts Payable
Net Payable due CONE	$	1,509		$	3,142

NOTE 17—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.

40

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

General

After a strong market rally early in the second quarter from extended winter weather, natural gas prices began to decline below $4.00 per MMBtu in June from a cooler than expected start to summer and power generation switching back to coal from natural gas.  Despite the decrease, natural gas prices remained significantly above 2012 levels.  During the second quarter, cooler than normal temperatures slowly applied downward pressure on both thermal coal and natural gas prices as the market cautiously awaited the arrival of summer heat.  By the quarter's end, however, the U.S. had experienced 12% fewer cooling degree days than the previous year which negatively impacted thermal coal and natural gas demand.  From a fuel-mix perspective, coal-fired electric generation increased by 10% year over year, while higher natural gas prices reduced gas consumption by 18% over the same period.  Despite the cooler weather, natural gas underground inventory levels remained below the five year average. Although global economic uncertainties persisted, continued disciplined coal production, slow natural gas production growth and decreasing natural gas net imports helped slow inventory growth and keep prices stable.

Second quarter coal consumption was aided by increased natural gas prices in April and May.  As natural gas prices rose above $4.00 per MMbtu, coal fired electric generation continued to be strong.  Early government estimates show that coal-fired generation produced 39% of U.S. power during the second quarter compared with 34% during the same period in 2012, and 40% in the first quarter 2013.  Conventional hydropower and nuclear generation gained share during the second quarter, at the expense of coal and natural gas generation.  Utility coal stockpiles declined throughout the quarter versus 2012 periods.  Increased natural gas prices and domestic coal production cuts contributed to continued stabilization of coal prices. 

                In the longer term, the outlook for domestic thermal coal continues to face regulatory challenges.  In line with President Obama's climate change initiative and the upcoming 2015 deadline for the U.S. Environmental Protection Agency's Mercury and Air Toxics Standards (MATS) rule, utilities are retiring non-compliant coal-fired units and less efficient coal-fired units. 

                Internationally, U.S. exports are expected to decline in 2013 after a record year in 2012.  After a strong first quarter, early government data for second quarter thermal exports shows a 30% decrease over the year ago period.  For the first half of 2013, thermal coal exports are down 10% over the 2012 first half.  Low international pricing, in combination with a stronger domestic market, contributed to the decline.  Longer-term fundamentals for U.S. thermal coal exports remain favorable as subsidized mining in Europe is phased out, nuclear growth plans are curtailed, and coal continues to maintain a cost advantage over other more expensive oil-linked fuels.

   While the U.S. second quarter benchmark price for premium metallurgical coal rose 4% over the prior quarter, spot prices declined to multi-year lows.  Price deterioration in the spot market helped push the quarterly benchmark price in the U.S. third quarter 16% lower than the second quarter.  The low price environment is indicative of the continued oversupplied position of the global metallurgical coal market. 

                Global steel production in 2013 has grown at a 4% annualized rate over 2012, largely driven by record production in China.  Steel production outside of China has remained under pressure as a result of limited demand growth and steel mill overcapacity.  In response to the weak metallurgical coal market, CONSOL Energy has positioned itself by reducing metallurgical coal production in 2013 and increasing thermal coal output.

41

CONSOL Energy's coal sales outlook is as follows:

	Q3 2013		2013		2014		2015
Estimated Coal Sales (millions of tons)	13.4 - 13.9		55.5 - 57.5		60.4		61.7
Est. Low-Vol Met Sales	0.7 -0.9		4.0-4.2		4.7		5.2
Tonnage: Firm	0.2		2.8		—		—
Avg. Price: Sold (Firm)	$	113.81	$	103.34	$	—	$	—
Est. High-Vol Met Sales	0.6+		2.6+		4.8		6.4
Tonnage: Firm	0.4		2.4		0.2		0.2
Avg. Price: Sold (Firm)	$	60.55	$	63.67	$	75.53	$	74.74
Est. Thermal Sales	12.3+		49.9+		50.9		50.1
Tonnage: Firm	12.3		49.8		28.1		14.8
Avg. Price: Sold (Firm)	$	59.02	$	58.93	$	60.45	$	60.99

Note: While most of the data in the table are single point estimates, the inherent uncertainty of markets and mining operations means that investors should consider a reasonable range around these estimates. N/A means not available or not forecast. CONSOL Energy has chosen not to forecast prices for open tonnage due to ongoing customer negotiations. In the thermal sales category, the open tonnage includes two items: sold, but unpriced tons and collared tons. Collared tons in 2014 are 7.0 million tons, with a ceiling of $55.90 per ton and a floor of $46.32 per ton. Collared tons in 2015 are 8.7 million tons, with a ceiling of $57.43 per ton and a floor of $44.86 per ton. Calendar year 2013 includes 0.1 million tons from Amonate. The Amonate tons are not included in the category breakdowns.

CONSOL Energy expects Capital investment costs for the BMX Mine to total $710 million. The increase from the prior estimate is due, in part, to a lower sales price for development tons, which increases the dollars being capitalized during the development phase.

CONSOL Energy expects its net gas production to be between 170 – 175 Bcfe for the year. Third quarter gas production, net to CONSOL Energy, is expected to be approximately 43 – 45 Bcfe.

Several significant events occurred in the six months ended June 30, 2013. These events include the following:

• On March 12, 2013, smoke was detected exiting the Orndoff shaft at CONSOL Energy's Blacksville No. 2 Mine near Wayne in Greene County, Pennsylvania. All day shift underground employees were safely evacuated and no one sustained injuries. The location of the fire was identified and containment and extinguishment procedures were followed. The fire was successfully extinguished and the longwall restarted May 20, 2013. This event resulted in a pre-tax expense of $38.4 million in the six months ended June 30, 2013.

• On June 24, 2013, CONSOL Energy closed the sale of the Potomac coal reserves located in Grant and Tucker Counties in West Virginia. Cash proceeds from the sale were $25.0 million. The transaction resulted in a $24.7 million gain on the sale of assets.

• Pension settlement accounting required the acceleration of previously unrecognized actuarial losses due to lump sum payments from the Company's salary retirement pension plan exceeding the annual projected service and interest costs of the plan. The pension settlement resulted in $32.2 million pre-tax expense adjustment. Many of the lump sum payments in the six months ended June 30, 2013 were paid to employees who elected to retire under the 2012 Voluntary Severance Incentive program. Also, pension settlement required the pension plan to be remeasured using updated assumptions at June 30, 2013. The updated assumptions include resetting the discount rate used in the actuarial calculation. See Note 3 - Components of Pension and Other Postretirement Benefit (OPEB) Plans Net Periodic Benefit Costs, in the Notes to the Unaudited Consolidated Financial Statements included in this Form 10-Q for additional details of the updated assumptions.

• A review of certain titles in the Company's Marcellus Shale acreage, continued throughout the six months ended June 30, 2013. As part of the title defect process the company is working through with its joint venture partner, Noble Energy, CONSOL Energy conceded title defects on acreage which had a book value to CONSOL Energy of $8.8 million. See Note 8 - Property, Plant and Equipment, in the Notes to the Unaudited Consolidated Financial Statements included in this Form 10-Q for additional details.

• CNX Gas Company 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 $46.3 million as an up-front bonus payment at closing.  Approximately 7.6% percent

42

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 forgoes the bonus. Our joint venture partner, Noble Energy, has acquired 50% of the acreage and accordingly, reimbursed CNX Gas Company for 50% of the associated costs during the three months ended June 30, 2013.

• In the six months ended June 30, 2013, an agreement in principle was reached for resolution of the class actions brought by shareholders of CNX Gas challenging the tender offer by CONSOL Energy to acquire all the shares of CNX Gas common stock that CONSOL Energy did not already own for $38.25 per share in May 2010 in principle. The total settlement provides for a payment to the plaintiffs of $42.73 million, of which the company expects to pay $20.20 million. On May 8, 2013, the parties executed and filed with the Court a stipulation and agreement of compromise and settlement. A settlement hearing has been scheduled by the Court on August 23, 2013. See Note 11 - Commitments and Contingencies, in the Notes to the Unaudited Consolidated Financial Statements included in this Form 10-Q for additional details.    

CONSOL Energy continues to manage several significant matters that may affect our business and impact our financial results in the future including the following:

• The Cross States Air Pollution Rule (CSAPR) was finalized by the Environmental Protection Agency (EPA) in July 2011. The rule required reductions in SO2 and NOx emissions in the eastern U.S. by January 1, 2012 (phase 1) and January 1, 2014 (phase 2). However, CSAPR was vacated by a three-judge panel of the D.C. Circuit on August 21, 2012, and the full D.C. Circuit declined to hear the case in January 2013. EPA and environmental groups appealed the decision to the Supreme Court on March 29, 2013. Until legal challenges are resolved and/or EPA develops a replacement rule, the Clean Air Interstate Rule (CAIR) will remain in effect.

• On July 9, 2013, Pennsylvania Governor, Tom Corbett signed the Oil and Gas Lease Act (SB 529). The Act reinstated the Guaranteed Minimum Royalty Act of 1979 and it permits pooling of already leased acreage. The Act does not authorize forced pooling.

• Challenges in the overall environment in which we operate create increased risks that we must continuously monitor and manage. These risks include increased scrutiny of existing safety regulations and the development of new safety regulations and additional environmental restrictions.

• Federal and state environmental regulators are reviewing our operations more closely and are more strictly interpreting and enforcing existing environmental laws and regulations, resulting in increased costs and delays.

• Federal and state regulators have proposed regulations which, if adopted, would adversely impact our business.   These proposed regulations could require significant changes in the manner in which we operate and/or would increase the cost of our operations. For example, the Department of Interior, Office of Surface Mining Reclamation and Enforcement (OSM) is currently preparing an environmental impact statement relating to OSM's consideration of five alternatives for amending its coal mining stream protection rules.  All of the alternatives, except the no action alternative, could make it more costly to mine our coal and/or could eliminate the ability to mine some of our coal.  OSM has indicated that it will not issue a draft rule or a draft environmental impact statement until sometime in 2014.  Other examples are the Mercury and Air Toxic Standards (MATS) (remanded by the court and re-proposed by the EPA in November 2012) and the Utility Maximum Achievable Control Technology (Utility MACTS) rules issued by the EPA. These new regulations set mercury and air toxic standards for new and existing coal and oil fired electric utility steam generating units and include more stringent new source performance standards (NSPS) for particulate matter (PM), SO2 and NOx.  The EPA reconsidered the UMACT rules and recently finalized revised new source performance standards for coal based power plants which raised some emission limits.  The standards remain stringent and costly for compliance. On April 18, 2012, the EPA published new final New Source Performance Standards for gas wells and related facilities. These rules apply to wells that were hydraulically fractured after August 23, 2011 and require the implementation by January 1, 2015 of technologies that capture the gas that is currently vented or flared during completion (hydrofracturing) of a well.  Low pressure wells, including coalbed methane wells, are excluded from these new standards.

• In April 2012, the EPA published its proposed New Source Performance Standards (NSPS) for carbon dioxide emissions from coal powered electric generating units. The proposed rules will apply to new power plants and to existing plants that make major modifications. If the rules are adopted as proposed, the only new coal fired power plants that will be able to meet the proposed emission limits will be coal fired plants with carbon dioxide capture and storage (CCS). Commercial scale CCS is not likely to be available in the near future, and if available, it may make coal fired electric generation units uneconomical compared to new gas fired electric generation units.  Thus, if finalized the proposed rules could seriously threaten the construction of new coal fired electric generating units. EPA did not meet an April 13, 2013 deadline to publish final rules and, according to the EPA, no specific timetable is set to publish the final rules.

• CONSOL Energy surface coal mining operations in West Virginia are subject to several citizen suits and several citizen groups' Notices of Intent to Sue relating to alleged violations of water discharge permits from our coal mining

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operations.  In each of these matters, CONSOL Energy investigates the complaints, if necessary develops and implements compliance plans, and defends the citizen suits as appropriate. 

• In late June 2012, CONSOL Energy received informal notification from the Pennsylvania Department of Environmental Protection of the Department's intent pursuant to a Technical Guidance Document entitled “Surface Water Protection-Underground Bituminous Coal Mining” to require a change in the mine plan of a pending application for a permit for expansion of the Company's Bailey longwall mine.  If ultimately required, this change in mine plan could have a material effect on CONSOL Energy's forecasted production for 2015. Although CONSOL Energy does not agree that a modification of its mining plan is necessary to comply with applicable regulatory performance standards, CONSOL Energy is currently reviewing the notification and any modifications that would be required if CONSOL Energy is compelled to modify its application.

• Additional pension settlement charges are reasonably possible to occur throughout the remainder of 2013. When lump sum payments from the pension plan exceed the service and interest expense, pension settlement accounting requires unamortized actuarial gains and losses related to the lump sum payouts to be amortized immediately. The threshold for pension settlement was reached as of March 31, 2013 and the corresponding charge has been recognized as discussed above. Additional pension settlement charges throughout the remainder of 2013 could be material to the financial results of CONSOL Energy.

• For 2013, CONSOL Energy has stepped up its asset sale process to include coal and gas transportation infrastructure, in order to capitalize on the current market environment and to re-invest proceeds in higher return projects. As previously announced, a process is in place to evaluate and potentially monetize several assets this year as long as fair value is received for those assets.

• CONSOL Energy is currently evaluating our overall corporate structure to consider different alternatives to unlock additional value for shareholders.

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Results of Operations

Three Months EndedJune 30, 2013 Compared with Three Months EndedJune 30, 2012

Net Income Attributable to CONSOL Energy Shareholders

CONSOL Energy reported a net loss attributable to CONSOL Energy shareholders of $13 million, or $(0.05) per diluted share, for the three months ended June 30, 2013. Net income attributable to CONSOL Energy shareholders was $153 million, or $0.67 per diluted share, for the three months ended June 30, 2012.

The coal division includes thermal coal, high volatile metallurgical coal, low volatile metallurgical coal and other coal. The total coal division contributed $65 million of earnings before income tax for the three months ended June 30, 2013 compared to $257 million for the three months ended June 30, 2012. The total coal division sold 13.8 million tons of coal produced from CONSOL Energy mines for the three months ended June 30, 2013 compared to 14.4 million tons for the three months ended June 30, 2012.

The average sales price and total costs per ton for all active coal operations were as follows:

	For the Three Months Ended June 30,
	2013		2012		Variance			Percent Change
Average Sales Price per ton sold	$	62.74	$	65.58	$	(2.84	)	(4.3	)%
Average Cost of Goods Sold per ton	51.87		52.04		(0.17		)	(0.3	)%
Margin per ton sold	$	10.87	$	13.54	$	(2.67	)	(19.7	)%

The lower average sales price per ton sold is due to weakened pricing in the global metallurgical and domestic thermal coal markets, along with a reduction in sales tons in the period-to-period comparison. The average coal sales price in the 2013 period was also lower due to the renewal of several domestic thermal contracts whose pricing was reduced effective January 1, 2013.

Changes in the average cost of goods sold per ton were primarily related to the following items:

• Direct operating costs improved primarily due to a decrease in all direct operating costs at the Blacksville No. 2 Mine which is the result of the mine being idled until May 20th due to the fire, as previously discussed. Costs were also improved due to the shutdown of the Fola Mining Complex in August 2012.

• Average direct operating costs were impaired due to CONSOL Energy entering into several new leases for various types of mining equipment at our Bailey Mine, Robinson Run Mine, and Shoemaker Mine.

• Direct services to operations are improved due to a reduction in direct administration employees as a result of the 2012 Voluntary Severance Incentive Plan discussed below under general and administrative costs.

• Depreciation, depletion and amortization was improved primarily due to lower expense at the Blacksville No. 2 Mine related to the mine being shut down due to the fire, the shutdown of operations at the Fola Mining Complex and the timing of assets going into service or being fully depreciated.

The total gas division includes CBM, Shallow Oil and Gas, Marcellus and other gas. The total gas division had a $5 million loss before income tax for the three months ended June 30, 2013 compared to $1 million of income before income tax for the three months ended June 30, 2012. Total gas production was 38.6 billion cubic feet for the three months ended June 30, 2013 compared to 37.3 billion cubic feet for the three months ended June 30, 2012. Total gas volumes increased primarily as a result of the on-going Marcellus drilling program.

The average sales price and total costs for all active gas operations were as follows: 

	For the Three Months Ended June 30,
	2013		2012		Variance		Percent Change
Average Sales Price per thousand cubic feet sold	$	4.46	$	3.98	$	0.48	12.1%
Average Costs per thousand cubic feet sold	3.77		3.34		0.43		12.9%
Margin per thousand cubic feet sold	$	0.69	$	0.64	$	0.05	7.8%

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Total gas division outside sales revenues were $173 million for the three months ended June 30, 2013 compared to $149 million for the three months ended June 30, 2012. The increase was primarily due to the 3.5% increase in volumes sold, along with the a 12.1% increase in average price per thousand cubic feet sold. The increase in average sales price is the result of the increase in general market prices and sales of natural gas liquids and condensate, partially offset by various gas swap transactions that occurred throughout both periods. The gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 19.7 billion cubic feet of our produced gas sales volumes for the three months ended June 30, 2013 at an average price of $4.73 per thousand cubic feet. These financial hedges represented 19.1 billion cubic feet of our produced gas sales volumes for the three months ended June 30, 2012 at an average price of $5.25 per thousand cubic feet.

Changes in the average cost per thousand cubic feet of gas sold were primarily related to the following items:

• Gathering costs increased in the period-to-period comparison due to higher firm transportation costs and increased processing fees associated with natural gas liquids.

• Lifting costs increased due to higher accretion expense related to the estimated well plugging liability. Road repair and maintenance costs also increased in the current period.

• Depreciation, depletion and amortization increased due to higher units-of-production rates for producing properties.

• These were offset, in part, by higher volumes in the period-to-period comparison due to the on-going Marcellus drilling program. Fixed costs are allocated over increased volumes, resulting in lower unit costs.

The other segment includes industrial supplies activity, terminal, river and dock service activity, income taxes and other business activities not assigned to the coal or gas segment.

General and administrative costs are allocated between divisions (Coal, Gas, Other) based primarily on percentage of total revenue and percentage of total projected capital expenditures. General and administrative costs are excluded from the coal and gas unit costs above. Total General and administrative costs were made up of the following items:

	For the Three Months Ended June 30,
	2013		2012		Variance			Percent Change
Consulting and professional services	$	8	$	5	$	3		60.0	%
Contributions	5		3		2			66.7	%
Advertising and promotion	2		2		—			—	%
Employee wages and related expenses	13		15		(2		)	(13.3	)%
Miscellaneous	7		7		—			—	%
Total Company General and administrative Expenses	$	35	$	32	$	3		9.4	%

Total Company General and administrative Expenses changed due to the following:

• Consulting and professional services increased $3 million in the period-to-period comparison due to various legal proceedings and corporate initiatives, none of which are individually significant.

• Contributions increased $2 million related to various transactions that occurred throughout both periods, none of which are individually significant.

• Advertising and promotion remained consistent in the period-to-period comparison.

• Employee wages and related expenses decreased $2 million primarily attributable to fewer employees as a result of the 2012 Voluntary Severance Incentive Plan and lower salary other post-employment benefit expenses (OPEB) in the period-to-period comparison. The lower OPEB expenses relate to changes in the discount rates and other assumptions.

• Miscellaneous General and administrative expenses remained consistent in the period-to-period comparison.

Total Company long-term liabilities, such as OPEB, the salary retirement plan, workers' compensation and long-term disability are actuarially calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. Total CONSOL Energy expense related to our actuarial liabilities was $65 million for the three months ended June 30, 2013 compared to $62 million for the three months ended June 30, 2012. The increase of $3 million for total CONSOL Energy expense was primarily due to required pension settlement accounting of $5 million related to lump sum distributions made for the 2013 plan year exceeding the total of the service cost and interest cost for the 2013 plan year. The pension settlement was not allocated to individual operating segments and is therefore not included in unit costs presented for coal or gas. This was offset, in part, due to a modification to the benefit plan for salaried employees

46

and a increase in the discount rate assumptions used to calculate expense for benefit plans at the measurement date, which is December 31. See Note 3 - Components of Pension and Other Postretirement Benefit Plans Net Periodic Benefit Costs and Note 4 - Components of Coal Workers' Pneumoconiosis (CWP) and Workers' Compensation Net Periodic Benefit Costs in the Notes to the Unaudited Consolidated Financial Statements for additional detail of the total Company expense decrease.

TOTAL COAL SEGMENT ANALYSIS for the three months ended June 30, 2013 compared to the three months ended June 30, 2012:

The coal segment contributed $65 million of earnings before income tax in the three months ended June 30, 2013 compared to $257 million in the three months ended June 30, 2012. Variances by the individual coal segments are discussed below.

	For the Three Months Ended														Difference to Three Months Ended
	June 30, 2013														June 30, 2012
	Thermal Coal			High Vol Met Coal		Low Vol Met Coal			Other Coal			Total Coal			Thermal Coal			High Vol Met Coal			Low Vol Met Coal			Other Coal			Total Coal
Sales:
Produced Coal	$	698		$	57	$	111		$	—		$	866		$	(50	)	$	(14	)	$	(10	)	$	(2	)	$	(76	)
Purchased Coal	—			—		—			5			5			—			—			—			2			2
Total Outside Sales	698			57		111			5			871			(50		)	(14		)	(10		)	—			(74		)
Freight Revenue	—			—		—			10			10			—			—			—			(39		)	(39		)
Other Income	1			1		—			46			48			1			—			—			(138		)	(137		)
Total Revenue and Other Income	699			58		111			61			929			(49		)	(14		)	(10		)	(177		)	(250		)
Costs and Expenses:
Beginning inventory costs	44			—		8			—			52			(66		)	—			(7		)	—			(73		)
Total direct operating costs	369			26		53			83			531			(7		)	(7		)	(3		)	49			32
Total royalty/production taxes	50			3		7			—			60			(1		)	(1		)	(2		)	(1		)	(5		)
Total direct services to operations	60			4		6			36			106			(6		)	(2		)	1			(50		)	(57		)
Total retirement and disability	43			3		6			5			57			(1		)	—			(2		)	2			(1		)
Depreciation, depletion and amortization	72			5		9			14			100			(5		)	(2		)	(2		)	10			1
Ending inventory costs	(43		)	—		(9		)	—			(52		)	67			—			17			—			84
Total Costs and Expenses	595			41		80			138			854			(19		)	(12		)	2			10			(19		)
Freight Expense	—			—		—			10			10			—			—			—			(39		)	(39		)
Total Costs	595			41		80			148			864			(19		)	(12		)	2			(29		)	(58		)
Earnings (Loss) Before Income Taxes	$	104		$	17	$	31		$	(87	)	$	65		$	(30	)	$	(2	)	$	(12	)	$	(148	)	$	(192	)

THERMAL COAL SEGMENT

The thermal coal segment contributed $104 million to total Company earnings before income tax for the three months ended June 30, 2013 and $134 million for the three months ended June 30, 2012. The thermal coal revenue and cost components on a per unit basis for these periods are as follows:

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	For the Three Months Ended June 30,
	2013		2012		Variance			Percent Change
Company Produced Thermal Tons Sold (in millions)	11.8		12.2		(0.4		)	(3.3	)%
Average Sales Price Per Thermal Ton Sold	$	59.39	$	61.47	$	(2.08	)	(3.4	)%
Beginning Inventory Costs Per Thermal Ton	$	50.57	$	55.60	$	(5.03	)	(9.0	)%
Total Direct Operating Costs Per Thermal Ton Produced	$	31.60	$	30.96	$	0.64		2.1	%
Total Royalty/Production Taxes Per Thermal Ton Produced	4.26		4.18		0.08			1.9	%
Total Direct Services to Operations Per Thermal Ton Produced	5.17		5.42		(0.25		)	(4.6	)%
Total Retirement and Disability Per Thermal Ton Produced	3.68		3.62		0.06			1.7	%
Total Depreciation, Depletion and Amortization Costs Per Thermal Ton Produced	6.20		6.36		(0.16		)	(2.5	)%
Total Production Costs Per Thermal Ton Produced	$	50.91	$	50.54	$	0.37		0.7	%
Ending Inventory Costs Per Thermal Ton	$	55.36	$	56.03	$	(0.67	)	(1.2	)%
Total Costs Per Thermal Ton Sold	$	50.60	$	50.50	$	0.10		0.2	%
Average Margin Per Thermal Ton Sold	$	8.79	$	10.97	$	(2.18	)	(19.9	)%

Thermal coal revenue was $699 million for the three months ended June 30, 2013 compared to $748 million for the three months ended June 30, 2012. The $49 million decrease was attributable to a $2.08 per ton lower average sales price and 0.4 million reduction in tons sold. The lower average thermal coal sales price in the 2013 period was the result of the renewal of several domestic thermal contracts whose pricing was reduced effective January 1, 2013. The reduction in tons was partially due to the Blacksville No. 2 Mine being idled for most of the quarter as a result of the mine fire that was previously discussed. Also, 0.5 million tons of thermal coal were priced on the export market at an average sales price of $68.68 per ton for the three months ended June 30, 2013 compared to 2.3 million tons at an average price of $55.09 per ton for the three months ended June 30, 2012.

Total cost of goods sold are comprised of changes in thermal coal inventory, both volumes and carrying values, and costs of tons produced in the period. Total cost of goods sold for thermal coal was $595 million for the three months ended June 30, 2013, or $19 million lower than the $614 million for the three months ended June 30, 2012. Total cost of goods sold for thermal coal was $50.60 per ton in the three months ended June 30, 2013 compared to $50.50 per ton in the three months ended June 30, 2012. The decrease in total dollars and increase in unit costs per thermal ton produced was due to the items described below.

Direct operating costs are comprised of labor, supplies, maintenance, power and preparation plant charges related to the extraction and sale of coal. These costs are reviewed regularly by management and are considered to be the direct responsibility of mine management. Direct operating costs related to the thermal coal segment were $369 million in the three months ended June 30, 2013 compared to $376 million in the three months ended June 30, 2012. Direct operating costs were $31.60 per ton produced in the current period compared to $30.96 per ton produced in the prior period. Changes in the average direct operating costs per thermal ton produced were primarily related to the following items:

• In 2013, CONSOL Energy entered into several new leases for various mining equipment, which resulted in higher cost per ton produced in the period-to-period comparison.

• The Blacksville No. 2 mine was idled in 2013 until May 20th due to the fire that was previously discussed. This resulted in a reduction in all direct operating costs.

• The Fola Mining Complex was idled in August 2012 which resulted in lower direct operating costs per ton produced in the period-to-period comparison. The mine, which was idled for market reasons, was a higher cost mining operation which when removed reduced the overall average direct operating costs per ton produced.

Royalties and production taxes were $50 million, or improved $1 million in the current period due primarily to the shutdown of the Fola Mining Complex in August 2012, as previously discussed.

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Direct services to the operations are comprised of items which support groups manage on behalf of the coal operations. Costs included in direct services are comprised of subsidence costs, direct administrative and selling costs, permitting and compliance costs, mine closing and reclamation costs, and water treatment costs. The cost of these support services was $60 million in the current period compared to $66 million in the prior period. Direct services to the operations were $5.17 per ton produced in the current period compared to $5.42 per ton produced in the prior period. Changes in the average direct service to operations cost per thermal ton produced were primarily related to a reduction in direct administrative employees as a result of the 2012 Voluntary Severance Incentive Plan, as previously discussed.

Retirement and disability costs are comprised of the expenses related to the Company's long-term liabilities, such as other post-retirement benefits (OPEB), the salary retirement plan, workers' compensation, coal workers' pneumoconiosis (CWP) and long-term disability. These liabilities are actuarially calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. The retirement and disability costs attributable to the thermal coal segment were $43 million for the three months ended June 30, 2013 compared to $44 million for the three months ended June 30, 2012. The decrease in the thermal coal retirement and disability costs was primarily attributable to an increase in discount rates used to calculate the 2013 cost of the long-term liabilities and a modification of the salaried other post-retirement benefit plan that occurred June 30, 2012. These improvements were offset, in part, by the reduction in production volumes which negatively impacted unit costs.

Depreciation, depletion and amortization for the thermal coal segment was $72 million for the three months ended June 30, 2013 compared to $77 million for the three months ended June 30, 2012. Unit costs per thermal ton produced were lower in the three months ended June 30, 2013 compared to the three months ended June 30, 2012 due to production being halted at the Blacksville No. 2 Mine for most of the 2013 period due to the fire. This resulted in no amortization or depletion expense for that period. Unit costs were also improved due to the idling of the Fola Mining Complex in 2012.

Changes in thermal coal inventory volumes and carrying value resulted in $1 million of cost of goods sold in the three months ended June 30, 2013 and had no impact in the three months ended June 30, 2012. Thermal coal inventory was 0.8 million tons at June 30, 2013 compared to 2.0 million tons at June 30, 2012.

HIGH VOL METALLURGICAL COAL SEGMENT

The high volatile metallurgical coal segment contributed $17 million to total Company earnings before income tax for the three months ended June 30, 2013 compared to $19 million for the three months ended June 30, 2012. The high volatile metallurgical coal revenue and cost components on a per unit basis for these periods are as follows:

	For the Three Months Ended June 30,
	2013		2012		Variance			Percent Change
Company Produced High Vol Met Tons Sold (in millions)	0.9		1.2		(0.3		)	(25.0	)%
Average Sales Price Per High Vol Met Ton Sold	$	62.50	$	59.94	$	2.56		4.3	%
Beginning Inventory Costs Per High Vol Met Ton	$	—	$	—	$	—		—	%
Total Direct Operating Costs Per High Vol Met Ton Produced	$	29.12	$	27.88	$	1.24		4.4	%
Total Royalty/Production Taxes Per High Vol Met Ton Produced	2.88		3.01		(0.13		)	(4.3	)%
Total Direct Services to Operations Per High Vol Met Ton Produced	4.53		4.85		(0.32		)	(6.6	)%
Total Retirement and Disability Per High Vol Met Ton Produced	2.86		2.74		0.12			4.4	%
Total Depreciation, Depletion and Amortization Costs Per High Vol Met Ton Produced	5.62		6.46		(0.84		)	(13.0	)%
Total Production Costs Per High Vol Met Ton Produced	$	45.01	$	44.94	$	0.07		0.2	%
Ending Inventory Costs Per High Vol Met Ton	$	—	$	—	$	—		—	%
Total Costs Per High Vol Met Ton Sold	$	45.01	$	44.94	$	0.07		0.2	%
Margin Per High Vol Met Ton Sold	$	17.49	$	15.00	$	2.49		16.6	%

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High volatile metallurgical coal revenue was $58 million for the three months ended June 30, 2013 compared to $72 million for the three months ended June 30, 2012. Average sales prices for high volatile metallurgical coal increased $2.56 per ton in a period-to-period comparison. CONSOL Energy priced 0.8 million tons of high volatile metallurgical coal in the export market at an average sales price of $60.83 per ton for the three months ended June 30, 2013 compared to 1.1 million tons at an average price of $57.30 per ton for the three months ended June 30, 2012. The remaining tons sold in the period-to-period comparison were sold on the domestic market.

Total cost of goods sold is comprised of changes in high volatile metallurgical coal inventory, both volumes and carrying values, and costs of tons produced in the period. Total cost of goods sold for high volatile metallurgical coal was $41 million for the three months ended June 30, 2013, or $12 million lower than the $53 million for the three months ended June 30, 2012. Total cost of goods sold for high volatile metallurgical coal was $45.01 per ton in the three months ended June 30, 2013 compared to $44.94 per ton in the three months ended June 30, 2012. The increase in cost of goods sold per high volatile metallurgical ton was due to the items described below.

Direct operating costs are comprised of labor, supplies, maintenance, power and preparation plant charges related to the extraction and sale of coal. These costs are reviewed regularly by management and are considered to be the direct responsibility of mine management. Direct operating costs related to the high volatile metallurgical coal segment were $26 million in the three months ended June 30, 2013 compared to $33 million in the three months ended June 30, 2012. Direct operating costs were $29.12 per ton produced in the current period compared to $27.88 per ton produced in the prior period. The increase in the average direct operating costs per high volatile metallurgical ton produced were primarily related to fewer tons produced. Fixed costs are allocated over less tons, resulting in higher unit costs.

Royalties and production taxes were $3 million or improved $1 million in the current period due primarily to the shutdown of the Fola Mining Complex in August 2012, as previously discussed.

Direct services to the operations are comprised of items which support groups manage on behalf of the coal operations. Costs included in direct services are comprised of subsidence costs, direct administrative and selling costs, permitting and compliance costs, mine closing and reclamation costs, and water treatment costs. The costs of these support services for high volatile metallurgical coal were $4 million in the current period compared to $6 million in the prior period. Decreased costs were attributable to lower subsidence costs due to the timing and nature of properties undermined. Direct services to the operations for high volatile metallurgical coal were $4.53 per ton produced in the current period compared to $4.85 per ton produced in the prior period. Changes in the average direct service to operations cost per ton for high volatile metallurgical coal produced were primarily related to lower subsidence expenses, offset, in part, by lower tons produced.

Retirement and disability costs are comprised of the expenses related to the Company's long-term liabilities, such as other post-employment benefits (OPEB), the salary retirement plan, workers' compensation, coal workers' pneumoconiosis (CWP) and long-term disability. These liabilities are actuarially calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. The retirement and disability costs attributable to the high volatile metallurgical coal segment were $3 million for the three months ended June 30, 2013 and June 30, 2012. Even though total dollars remained consistent, unit costs were negatively impacted due to the reduction in volumes.

Depreciation, depletion and amortization for the high volatile metallurgical coal segment was $5 million for the three months ended June 30, 2013 compared to $7 million in the three months ended June 30, 2012. Unit costs per high volatile ton produced were lower in the three months ended June 30, 2013 compared to the three months ended June 30, 2012 due to the shutdown of the Fola Mining Complex in August 2012.

There were no changes in volumes or carrying value of coal inventory in the three months ended June 30, 2013 and June 30, 2012. There was no high volatile metallurgical coal inventory at June 30, 2013 or June 30, 2012.

LOW VOL METALLURGICAL COAL SEGMENT

The low volatile metallurgical coal segment contributed $31 million to total Company earnings before income tax in the three months ended June 30, 2013 compared to $43 million in the three months ended June 30, 2012. The low volatile metallurgical coal revenue and cost components on a per ton basis for these periods are as follows:

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	For the Three Months Ended June 30,
	2013		2012		Variance			Percent Change
Company Produced Low Vol Met Tons Sold (in millions)	1.1		1.0		0.1			10.0	%
Average Sales Price Per Low Vol Met Ton Sold	$	97.54	$	123.71	$	(26.17	)	(21.2	)%
Beginning Inventory Costs Per Low Vol Met Ton	$	85.60	$	72.97	$	12.63		17.3	%
Total Direct Operating Costs Per Low Vol Met Ton Produced	$	44.31	$	48.66	$	(4.35	)	(8.9	)%
Total Royalty/Production Taxes Per Low Vol Met Ton Produced	5.97		8.10		(2.13		)	(26.3	)%
Total Direct Services to Operations Per Low Vol Met Ton Produced	4.90		4.50		0.40			8.9	%
Total Retirement and Disability Per Low Vol Met Ton Produced	5.56		7.00		(1.44		)	(20.6	)%
Total Depreciation, Depletion and Amortization Costs Per Low Vol Met Ton Produced	7.90		9.51		(1.61		)	(16.9	)%
Total Production Costs Per Low Vol Met Ton Produced	$	68.64	$	77.77	$	(9.13	)	(11.7	)%
Ending Inventory Costs Per Low Vol Met Ton	$	64.76	$	69.84	$	(5.08	)	(7.3	)%
Total Costs Per Low Vol Met Ton Sold	$	70.46	$	79.80	$	(9.34	)	(11.7	)%
Margin Per Low Vol Met Ton Sold	$	27.08	$	43.91	$	(16.83	)	(38.3	)%

Low volatile metallurgical coal revenue was $111 million for the three months ended June 30, 2013 compared to $121 million for the three months ended June 30, 2012. The $10 million decrease was attributable to a $26.17 per ton lower average sales price and was partially offset by a 0.1 million increase in tons sold. Average sales prices for low volatile metallurgical coal decreased in the period-to-period comparison due to the weakening in global metallurgical coal demand. For the 2013 period, 0.8 million tons of low volatile metallurgical coal were priced on the export market at an average price of $89.02 per ton compared to 0.8 million tons at an average price of $107.72 per ton for the 2012 period. The remaining tons sold in the period-to-period comparison were sold on the domestic market.

Total cost of goods sold is comprised of changes in low volatile metallurgical coal inventory, both volumes and carrying values, and costs of tons produced in the period. Total cost of goods sold for low volatile metallurgical coal was $80 million for the three months ended June 30, 2013, or $2 million higher than the $78 million for the three months ended June 30, 2012. Total cost of goods sold for low volatile metallurgical coal was $70.46 per ton in the three months ended June 30, 2013 compared to $79.80 per ton in the three months ended June 30, 2012. The decrease in cost of goods sold per low volatile metallurgical ton was due to the following items described below.

Direct operating costs are comprised of labor, supplies, maintenance, power and preparation plant charges related to the extraction and sale of coal. These costs are reviewed regularly by management and are considered to be the direct responsibility of mine management. Direct operating costs related to the low volatile metallurgical coal segment were $53 million in the three months ended June 30, 2013 compared to $56 million in the three months ended June 30, 2012. Direct operating costs improved primarily due to a five-day work schedule being implemented in the 2013 period at the Buchanan Mine and due to a decrease in contract mining fees resulting from the idling of the Amonate Complex in September 2012. Direct operating costs were $44.31 per ton produced in the current period compared to $48.66 per ton produced in the prior period. Low volatile metallurgical coal production was 1.2 million tons in the three months ended June 30, 2013 compared to 1.1 million tons in the three months ended June 30, 2012.

Royalties and production taxes were $7 million, or improved $2 million in the current period, compared to $9 million in the prior period. Unit costs also improved $2.13 per low volatile metallurgical ton produced to $5.97 per ton produced in the current period compared to $8.10 per ton produced in the prior period. Average cost per low volatile metallurgical ton produced decreased due to lower royalties and lower production taxes. These decreases were related to lower average sales prices.

Direct services to the operations are comprised of items which support groups manage on behalf of the coal operations. Costs included in direct services are comprised of subsidence costs, direct administrative and selling costs, permitting and compliance costs, mine closing and reclamation costs, and water treatment costs. The costs of these support services for low volatile metallurgical coal were $6 million in the current period and $5 million in the prior period. Direct services to the

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operations for low volatile metallurgical coal were $4.90 per ton produced in the current period compared to $4.50 per ton produced in the prior period. Changes in the average direct service to operations cost per ton for low volatile metallurgical coal produced were primarily related to an increase in water treatment cost.

Retirement and disability costs are comprised of the expenses related to the Company's long-term liabilities, such as other post-retirement benefits (OPEB), the salary retirement plan, workers' compensation, coal workers' pneumoconiosis (CWP) and long-term disability. These liabilities are actuarially calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. The retirement and disability costs attributable to the low volatile metallurgical coal segment were $6 million for the three months ended June 30, 2013 compared to $8 million for the three months ended June 30, 2012. The decrease in the low volatile metallurgical coal retirement and disability costs was primarily attributable to an increase in discount rates used to calculate the cost of the long-term liabilities and a modification of the salaried other post-retirement benefit plan that occurred on June 30, 2012. This, coupled with the increase in volumes, resulted in an improvement on the unit costs of $1.44 in the period-to-period comparison.

Depreciation, depletion and amortization for the low volatile metallurgical coal segment was $9 million for the three months ended June 30, 2013 compared to $11 million for the three months ended June 30, 2012. Unit costs per low volatile metallurgical tons produced were lower in the three months ended June 30, 2013 compared to the three months ended June 30, 2012 primarily due to the Amonate Complex being idled in September 2012 and the Buchanan reverse osmosis plant being temporarily idled in April and May 2013.

Changes in low volatile metallurgical coal inventory volumes and carrying value resulted in a decrease of $1 million to cost of goods sold in the three months ended June 30, 2013 and an increase of $10 million to cost of goods sold in the three months ended June 30, 2012. Produced low volatile metallurgical coal inventory was 0.1 million tons at June 30, 2013 compared to 0.3 million tons at June 30, 2012.

OTHER COAL SEGMENT

The other coal segment had a loss before income tax of $87 million for the three months ended June 30, 2013 compared to earnings before income tax of $61 million for the three months ended June 30, 2012. The other coal segment includes purchased coal activities, idle mine activities, as well as various activities assigned to the coal segment but not allocated to each individual mine.

Other coal segment produced coal sales includes revenue from the sale of less than 0.1 million tons of coal which was recovered during the reclamation process at idled facilities for the three months ended June 30, 2012. No coal was recovered during the reclamation process at idled facilities for the three months ended June 30, 2013. The primary focus of the activity atthese locations is reclaiming disturbed land in accordance with the mining permit requirements after final mining has occurred. The tons sold are incidental to total Company production or sales.

Purchased coal sales consist of revenues from processing third-party coal in our preparation plants for blending purposes to meet customer coal specifications and coal purchased from third parties and sold directly to our customers. The revenues were $5 million for the three months ended June 30, 2013 compared to $3 million for the three months ended June 30, 2012.

Freight revenue is the amount billed to customers for transportation costs incurred. This revenue is based on weight of coal shipped, negotiated freight rates and method of transportation (i.e. rail, barge, truck, etc.) used by the customers to which CONSOL Energy contractually provides transportation services. Freight revenue is offset by freight expense. Freight revenue was $10 million for the three months ended June 30, 2013 compared to $49 million for the three months ended June 30, 2012. The $39 million decrease in freight revenue was due to decreased shipments under contracts which CONSOL Energy contractually provides transportation services.

Miscellaneous other income was $46 million for the three months ended June 30, 2013 compared to $184 million for the three months ended June 30, 2012. The change is due to the following items:

• Gain on sale of assets attributable to the Other Coal segment were $26 million in the three months ended June 30, 2013 compared to $163 million in the three months ended June 30, 2012. The decrease of $137 million was primarily related to 2012 sales of non-producing assets in the Northern Powder River Basin that resulted in income of $151 million, as well as the coal lands and surface rights in southern West Virginia that resulted in income of $11 million. This is offset, in part, by the 2013 sale of Potomac coal reserves that resulted in income of $25 million. See Note 2 - Acquisitions and Dispositions in the Notes to the Unaudited Consolidated Financial Statements for additional detail of

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these sales. The remaining change was related to various transactions that occurred throughout both periods, none of which were individually material.

• Equity in earnings of affiliates increased $6 million due to higher earnings from our equity affiliates.

• The remaining $7 million decrease is due to various items, none of which are individually significant.

Other coal segment total costs were $148 million for the three months ended June 30, 2013 compared to $177 million for the three months ended June 30, 2012. The decrease of $29 million was primarily due to the following items:

	For the Three Months Ended June 30,
	2013		2012		Variance
Blacksville No. 2 Mine Fire	$	23	$	—	$	23
Purchased Coal	10		7		3
Stock-based compensation	8		7		1
Closed and idle mines	38		50		(12		)
Freight expense	10		49		(39		)
Other	59		64		(5		)
Total Other Coal Segment Costs	$	148	$	177	$	(29	)

• The Blacksville No. 2 Mine fire expense was due to a fire that occurred on March 12, 2013. The mine resumed production on May 20, 2013. Insurance recovery is uncertain at this time and the impact of any potential recovery has not been reflected in the three months ended June 30, 2013.

• Purchased coal costs increased due to higher amounts of coal that needed to be purchased to fulfill various contracts.

• Stock-based compensation was higher in the period-to-period comparison primarily due to additional non-cash amortization expense and accelerated non-cash amortization for retiree-eligible employees who received awards under the new CONSOL Share Unit (CSU) program.  The new program replaces several previously provided long-term executive compensation award programs.  The compensation expense of the CSU program will not be materially different from the total expense of the previous programs over the three-year performance period.

• Closed and idle mine costs decreased approximately $12 million for the three months ended June 30, 2013 compared to the three months ended June 30, 2012. There was a $24 million decrease in asset retirement obligations. This was primarily due to an increase in the reclamation liability at the Fola Mining Complex in the June 2012 period due to new regulatory requirements, and water and selenium treatment estimates. The decrease was offset, in part, by an increase of $7 million due to the idling of the Fola Mining Complex in August 2012, and an increase of $2 million due to the idling of the Amonate Complex in September 2012. The remaining increase of $3 million was due to other changes in the operational status of various other mines, between idled and operating throughout both periods, none of which were individually material.

• Freight expense is based on weight of coal shipped, negotiated freight rates and method of transportation (i.e. rail, barge, truck, etc.) used by the customers to which CONSOL Energy contractually provides transportation services. Freight revenue is the amount billed to customers for transportation costs incurred. Freight expense is offset by freight revenue. The decrease in freight expense was due to decreased shipments under contracts which CONSOL Energy contractually provides transportation services.

• Other expenses related to the Other Coal segment decreased $5 million due to various transactions that occurred throughout both periods, none of which were individually material.

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TOTAL GAS SEGMENT ANALYSIS for the three months ended June 30, 2013 compared to the three months ended June 30, 2012:

The gas segment had a $5 million loss before income tax in the three months ended June 30, 2013 compared to earnings before income tax of $1 million in the three months ended June 30, 2012.

	For the Three Months Ended													Difference to Three Months Ended
	June 30, 2013													June 30, 2012
	CBM		Shallow Oil and Gas			Marcellus		Other Gas			Total Gas			CBM			Shallow Oil and Gas			Marcellus		Other Gas			Total Gas
Sales:
Produced	$	88	$	34		$	47	$	3		$	172		$	—		$	—		$	23	$	1		$	24
Related Party	1		—			—		—			1			—			—			—		—			—
Total Outside Sales	89		34			47		3			173			—			—			23		1			24
Gas Royalty Interest	—		—			—		17			17			—			—			—		7			7
Purchased Gas	—		—			—		1			1			—			—			—		1			1
Other Income	—		—			—		11			11			—			—			—		(7		)	(7		)
Total Revenue and Other Income	89		34			47		32			202			—			—			23		2			25
Lifting	10		10			5		1			26			(1		)	(1		)	3		1			2
Ad Valorem, Severance, and Other Taxes	3		3			1		—			7			1			1			—		—			2
Gathering	29		9			10		1			49			3			4			5		—			12
Gas Direct Administrative, Selling & Other	2		2			7		1			12			(2		)	(2		)	5		(1		)	—
Depreciation, Depletion and Amortization	23		15			12		2			52			1			1			3		—			5
General & Administration	—		—			—		12			12			—			—			—		3			3
Gas Royalty Interest	—		—			—		14			14			—			—			—		7			7
Purchased Gas	—		—			—		1			1			—			—			—		—			—
Exploration and Other Costs	—		—			—		10			10			—			—			—		(6		)	(6		)
Other Corporate Expenses	—		—			—		22			22			—			—			—		5			5
Interest Expense	—		—			—		2			2			—			—			—		1			1
Total Cost	67		39			35		66			207			2			3			16		10			31
Earnings Before Income Tax	$	22	$	(5	)	$	12	$	(34	)	$	(5	)	$	(2	)	$	(3	)	$	7	$	(8	)	$	(6	)

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COALBED METHANE (CBM) GAS SEGMENT

The CBM segment contributed $22 million to the total Company earnings before income tax for the three months ended June 30, 2013 compared to $24 million for the three months ended June 30, 2012.

	For the Three Months Ended June 30,
	2013		2012		Variance			Percent Change
Produced Gas CBM sales volumes (in billion cubic feet)	20.8		22.3		(1.5		)	(6.7	)%
Average CBM sales price per thousand cubic feet sold	$	4.26	$	3.96	$	0.30		7.6	%
Average CBM lifting costs per thousand cubic feet sold	0.48		0.45		0.03			6.7	%
Average CBM ad valorem, severance, and other taxes per thousand cubic feet sold	0.13		0.11		0.02			18.2	%
Average CBM gathering costs per thousand cubic feet sold	1.40		1.17		0.23			19.7	%
Average CBM direct administrative, selling & other costs per thousand cubic feet sold	0.10		0.18		(0.08		)	(44.4	)%
Average CBM depreciation, depletion and amortization costs per thousand cubic feet sold	1.09		0.96		0.13			13.5	%
Total Average CBM costs per thousand cubic feet sold	3.20		2.87		0.33			11.5	%
Average Margin for CBM	$	1.06	$	1.09	$	(0.03	)	(2.8	)%

CBM sales revenues were $89 million in the three months ended June 30, 2013 and 2012. The 6.7% decrease in volumes sold was offset by a 7.6% increase in average sales price per thousand cubic feet sold. The increase in CBM average sales price was the result of higher average market prices offset by various gas swap transactions that matured in each period. The gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 11.6 billion cubic feet of our produced CBM gas sales volumes for the three months ended June 30, 2013 at an average price of $4.58 per thousand cubic feet. For the three months ended June 30, 2012, these financial hedges represented 10.9 billion cubic feet at an average price of $5.33 per thousand cubic feet. CBM sales volumes decreased 1.5 billion cubic feet for the three months ended June 30, 2013 compared to the 2012 period primarily due to normal well declines without a corresponding increase in wells drilled. Currently, the focus of the gas division is to develop its Marcellus and Utica acreage.

Total costs for the CBM segment were $67 million for the three months ended June 30, 2013 compared to $65 million for the three months ended June 30, 2012. The increase in total costs for the CBM segment are due to the following items:

•CBM lifting costs were $10 million for the three months ended June 30, 2013 compared to $11 million for the three months ended June 30, 2012. The decrease in total dollars and the $0.03 per thousand cubic feet increase in average lifting unit costs are both directly related to the decreased sales volumes as discussed above.

•CBM ad valorem, severance and other taxes were $3 million for the three months ended June 30, 2013 compared to $2 million for the three months ended June 30, 2012. The $1 million increase in total dollars was primarily due to increased severance tax expense due to higher average gas sales prices. The $0.02 per thousand cubic feet increase in unit costs is primarily due to the higher average gas sales prices and decrease in sales volumes.

•CBM gathering costs were $29 million for the three months ended June 30, 2013 compared to $26 million for the three months ended June 30, 2012. The $0.23 per thousand cubic feet increase in average CBM gathering unit costs are related to increased power costs due to higher utility rates, increased pipeline maintenance, increased road maintenance and lower volumes sold in the period-to-period comparison.

•CBM direct administrative, selling & other costs for the CBM segment were $2 million for the three months ended June 30, 2013 compared to $4 million for the three months ended June 30, 2012. Direct administrative, selling & other costs attributable to the total gas segment are allocated to the individual gas segments based on a combination of production and employee counts. The decrease in direct administrative, selling & other costs was primarily due to reduced direct administrative labor and CBM volumes representing a smaller proportion of total natural gas volumes sold. Improvements in unit costs were offset, in part, by the reduction in volumes.

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•Depreciation, depletion and amortization attributable to the CBM segment was $23 million for the three months ended June 30, 2013 compared to $22 million for the three months ended June 30, 2012. There was approximately $16 million, or $0.76 per unit-of-production, of depreciation, depletion and amortization related to CBM gas and related well equipment that was reflected on a units-of-production method of depreciation in the three months ended June 30, 2013. The production portion of depreciation, depletion and amortization was $15 million, or $0.67 per unit-of-production in the three months ended June 30, 2012. There was approximately $7 million, or $0.33 average per unit cost of depreciation, depletion and amortization related to gathering and other equipment reflected on a straight line basis for the three months ended June 30, 2013. The non-production related depreciation, depletion and amortization was $7 million, or $0.29 per thousand cubic feet for the three months ended June 30, 2012.

SHALLOW OIL AND GAS SEGMENT

The Shallow Oil and Gas segment had a loss before income tax of $5 million for the three months ended June 30, 2013 compared to a loss before income tax of $2 million for the three months ended June 30, 2012.

	For the Three Months Ended June 30,
	2013			2012			Variance			Percent Change
Produced Gas Shallow Oil and Gas sales volumes (in billion cubic feet)	6.7			7.2			(0.5		)	(6.9	)%
Average Shallow Oil and Gas sales price per thousand cubic feet sold	$	5.00		$	4.74		$	0.26		5.5	%
Average Shallow Oil and Gas lifting costs per thousand cubic feet sold	1.46			1.46			—			—	%
Average Shallow Oil and Gas ad valorem, severance, and other taxes per thousand cubic feet sold	0.43			0.30			0.13			43.3	%
Average Shallow Oil and Gas gathering costs per thousand cubic feet sold	1.35			0.77			0.58			75.3	%
Average Shallow Oil and Gas direct administrative, selling & other costs per thousand cubic feet sold	0.34			0.53			(0.19		)	(35.8	)%
Average Shallow Oil and Gas depreciation, depletion and amortization costs per thousand cubic feet sold	2.25			2.01			0.24			11.9	%
Total Average Shallow Oil and Gas costs per thousand cubic feet sold	5.83			5.07			0.76			15.0	%
Average Margin for Shallow Oil and Gas	$	(0.83	)	$	(0.33	)	$	(0.50	)	(151.5	)%

Shallow Oil and Gas sales revenues were $34 million for both the three months ended June 30, 2013 and 2012. The 6.9% decrease in volumes sold was offset, in part, by a 5.5% increase in average sales price. The increase in shallow oil and gas average sales price is the result of higher average market prices offset by various gas swap transactions that matured in each period. These gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 3.6 billion cubic feet of our produced shallow oil and gas sales volumes for the three months ended June 30, 2013 at an average price of $5.21 per thousand cubic feet. For the three months ended June 30, 2012, these financial hedges represented 5.4 billion cubic feet at an average price of $5.25 per thousand cubic feet.

Total costs for the shallow oil and gas segment were $39 million for the three months ended June 30, 2013 compared to $36 million for the three months ended June 30, 2012. The increase in total costs for the shallow oil and gas segment are due to the following items:

•Shallow Oil and Gas lifting costs were $10 million for the three months ended June 30, 2013 compared to $11 million for the three months ended June 30, 2012. The $1 million decrease to total costs is due to lower road maintenance, lower salt water disposal costs and lower contract services in the current period, offset, in part, by an increase in accretion expense on the well plugging liability. The average unit costs remained consistent in the period-to-period comparison due to the decrease in sales volumes.

•Shallow Oil and Gas ad valorem, severance and other taxes were $3 million for the three months ended June 30, 2013 and $2 million for the three months ended June 30, 2012. The $1 million increase in total costs was primarily due to higher average sales prices during the current period. The $0.13 per thousand cubic feet increase in average unit costs is primarily due to the higher average sales prices and decreased sales volumes.

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•Shallow Oil and Gas gathering costs were $9 million for the three months ended June 30, 2013 compared to $5 million for the three months ended June 30, 2012. Gathering costs increased $4 million primarily due to increased firm transportation costs and higher compressor repair and maintenance costs in the period-to-period comparison.

•Shallow Oil and Gas direct administrative, selling & other costs were $2 million for the three months ended June 30, 2013 compared to $4 million for the three months ended June 30, 2012. Direct administrative, selling & other costs attributable to the total gas segment are allocated to the individual gas segments based on a combination of production and employee counts. The $2 million decrease in the period-to-period comparison is due to reduced direct administrative labor and Shallow Oil and Gas volumes representing a smaller proportion of total natural gas volumes sold. The decrease in costs were offset, in part, by lower sales volumes.

•Depreciation, depletion and amortization costs were $15 million for the three months ended June 30, 2013 compared to $14 million for the three months ended June 30, 2012. There was approximately $13 million, or $1.98 per unit-of production, of depreciation, depletion and amortization related to Shallow Oil and Gas gas and related well equipment that was reflected on a units-of-production method of depreciation for the three months ended June 30, 2013. There was approximately $12 million, or $1.77 per unit-of-production, of depreciation, depletion and amortization related to Shallow Oil and Gas gas and related well equipment that was reflected on a units-of-production method of depreciation for the three months ended June 30, 2012. There was approximately $2 million, or $0.27 per thousand cubic feet, of depreciation, depletion and amortization related to gathering and other equipment that is reflected on a straight-line basis for the three months ended June 30, 2013. There was $2 million, or $0.24 per thousand cubic feet, of depreciation, depletion and amortization related to gathering and other equipment that is reflected on a straight-line basis for the three months ended June 30, 2012.

MARCELLUS GAS SEGMENT

The Marcellus segment contributed $12 million to the total Company earnings before income tax for the three months ended June 30, 2013 compared to $5 million for the three months ended June 30, 2012.

	For the Three Months Ended June 30,
	2013		2012		Variance			Percent Change
Produced Gas Marcellus sales volumes (in billion cubic feet)	10.4		7.2		3.2			44.4	%
Average Marcellus sales price per thousand cubic feet sold	$	4.49	$	3.28	$	1.21		36.9	%
Average Marcellus lifting costs per thousand cubic feet sold	0.44		0.28		0.16			57.1	%
Average Marcellus ad valorem, severance, and other taxes per thousand cubic feet sold	0.15		0.13		0.02			15.4	%
Average Marcellus gathering costs per thousand cubic feet sold	0.95		0.64		0.31			48.4	%
Average Marcellus direct administrative, selling & other costs per thousand cubic feet sold	0.63		0.27		0.36			133.3	%
Average Marcellus depreciation, depletion and amortization costs per thousand cubic feet sold	1.19		1.29		(0.10		)	(7.8	)%
Total Average Marcellus costs per thousand cubic feet sold	3.36		2.61		0.75			28.7	%
Average Margin for Marcellus	$	1.13	$	0.67	$	0.46		68.7	%

The Marcellus segment sales revenues were $47 million for the three months ended June 30, 2013 compared to $24 million for the three months ended June 30, 2012. The $23 million increase is primarily due to a 44.4% increase in volumes sold, and a 36.9% increase in average sales prices in the period-to-period comparison. The increase in Marcellus average sales price was the result of the improvement in general market prices and sales of natural gas liquids and condensate, offset by various gas swap transactions that matured in the three months ended June 30, 2013. These gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 4.5 billion cubic feet of our produced Marcellus gas sales volumes for the three months ended June 30, 2013 at an average price of $4.74 per thousand cubic feet. For the three months ended June 30, 2012, these financial hedges represented 2.8 billion cubic feet at an average price of $4.95 per thousand cubic feet. The increase in sales volumes is primarily due to additional wells coming on-line from our on-going drilling program.

Total costs for the Marcellus segment were $35 million for the three months ended June 30, 2013 compared to $19 million for the three months ended June 30, 2012. The increase in total costs for the Marcellus segment are due to the following items:

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•Marcellus lifting costs were $5 million for the three months ended June 30, 2013 compared to $2 million for the three months ended June 30, 2012. The increase primarily relates to increased road maintenance costs, increased salt water disposal costs, and increased accretion expense on the well plugging liability.

•Marcellus ad valorem, severance and other taxes were $1 million for the three months ended June 30, 2013 and 2012. The increase in average unit costs was primarily due to an increase in severance tax expense caused by higher average gas sales prices during the current period.

•Marcellus gathering costs were $10 million for the three months ended June 30, 2013 compared to $5 million for the three months ended June 30, 2012. Average gathering costs increased $0.31 per unit primarily due to increased firm transportation costs, and increased processing fees associated with natural gas liquids.

•Marcellus direct administrative, selling & other costs were $7 million for the three months ended June 30, 2013 compared to $2 million for the three months ended June 30, 2012. Direct administrative, selling & other costs attributable to the total gas segment are allocated to the individual gas segments based on a combination of production and employee counts. The increase in direct administrative, selling & other costs was primarily due to Marcellus volumes representing a larger proportion of total natural gas volumes sold. The impact on average unit costs from the increase in direct administrative costs was partially offset by higher volumes sold.

•Depreciation, depletion and amortization costs were $12 million for the three months ended June 30, 2013 compared to $9 million for the three months ended June 30, 2012. There was approximately $12 million, or $1.18 per unit-of-production, of depreciation, depletion and amortization related to Marcellus gas and related well equipment that was reflected on a units-of-production method of depreciation in the three months ended June 30, 2013. There was approximately $8 million, or $1.14 per unit-of-production, of depreciation, depletion and amortization related to Marcellus gas and related well equipment that was reflected on a units-of-production method of depreciation for the three months ended June 30, 2012. There was less than $1 million, or $0.01 per thousand cubic feet, of depreciation, depletion and amortization related to gathering and other equipment that was reflected on a straight line basis for the three months ended June 30, 2013. There was $1 million, or $0.15 per thousand cubic feet, of depreciation, depletion and amortization related to gathering and other equipment reflected on a straight line basis for the three months ended June 30, 2012.

OTHER GAS SEGMENT

The other gas segment includes activity not assigned to the CBM, Shallow Oil and Gas or Marcellus gas segments. This segment includes purchased gas activity, gas royalty interest activity, exploration and other costs, other corporate expenses, and miscellaneous operational activity not assigned to a specific gas segment.

Other gas sales volumes are primarily related to production from the Chattanooga Shale in Tennessee and the Utica Shale in Ohio. Revenue from these operations were approximately $3 million for the three months ended June 30, 2013 and $2 million for the three months ended June 30, 2012. Total costs related to these other sales were $5 million for the three months ended June 30, 2013 and June 30, 2012. A per unit analysis of the other operating costs in Chattanooga Shale and Utica Shale is not meaningful due to the low volumes sold in the period-to-period analysis.

Royalty interest gas sales represent the revenues related to the portion of production belonging to royalty interest owners sold by the CONSOL Energy gas segment. Royalty interest gas sales revenue was $17 million for the three months ended June 30, 2013 compared to $10 million for the three months ended June 30, 2012. The changes in market prices, contractual differences among leases, and the mix of average and index prices used in calculating royalties contributed to the period-to-period increase.

	For the Three Months Ended June 30,
	2013		2012		Variance			Percent Change
Gas Royalty Interest Sales Volumes (in billion cubic feet)	3.9		4.2		(0.3		)	(7.1	)%
Average Sales Price Per thousand cubic feet	$	4.31	$	2.26	$	2.05		90.7	%

Purchased gas sales volumes represent volumes of gas sold at market prices that were purchased from third-party producers. Purchased gas sales revenues were $1 million for the three months ended June 30, 2013 and less than $1 million for the three months ended June 30, 2012.

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	For the Three Months Ended June 30,
	2013		2012		Variance		Percent Change
Purchased Gas Sales Volumes (in billion cubic feet)	0.4		0.3		0.1		33.3	%
Average Sales Price Per thousand cubic feet	$	3.96	$	2.39	$	1.57	65.7	%

Other income was $11 million for the three months ended June 30, 2013 compared to $18 million for the three months ended June 30, 2012. The $7 million change was primarily due to the following items:

• Interest income related to the notes receivable from the Noble joint venture transaction decreased $4 million due to the payment of the first note in September 2012.

• Gains on dispositions of non-core acreage and equipment decreased $2 million due to various transactions that occurred throughout both periods, none of which are individually material.

• There was a decrease of $1 million in various other transactions, none of which are individually material.

General and administrative costs are allocated to the total gas segment based on percentage of total revenue and percentage of total projected capital expenditures. Costs were $12 million for the three months ended June 30, 2013 compared to $9 million for the three months ended June 30, 2012. Refer to the discussion of total company general and administrative costs contained in the section "Net Income Attributable to CONSOL Energy Shareholders"of this quarterly report for a detailed cost explanation.

Royalty interest gas costs represent the costs related to the portion of production belonging to royalty interest owners sold by the CONSOL Energy gas segment. Royalty interest gas costs were $14 million for the three months ended June 30, 2013 compared to $7 million for the three months ended June 30, 2012. The changes in market prices, contractual differences among leases, and the mix of average and index prices used in calculating royalties contributed to the period-to-period change.

	For the Three Months Ended June 30,
	2013		2012		Variance			Percent Change
Gas Royalty Interest Sales Volumes (in billion cubic feet)	3.9		4.2		(0.3		)	(7.1	)%
Average Cost Per thousand cubic feet sold	$	3.43	$	1.69	$	1.74		103.0	%

Purchased gas volumes represent volumes of gas purchased from third-party producers that we sell. The higher average cost per thousand cubic feet is due to overall price changes and contractual differences among customers in the period-to-period comparison. Purchased gas costs were $1 million for the three months ended June 30, 2013 and 2012.

	For the Three Months Ended June 30,
	2013		2012		Variance		Percent Change
Purchased Gas Volumes (in billion cubic feet)	0.4		0.3		0.1		33.3	%
Average Cost Per thousand cubic feet sold	$	2.99	$	2.19	$	0.80	36.5	%

Exploration and other costs were $10 million for the three months ended June 30, 2013 compared to $16 million for the three months ended June 30, 2012. The $6 million decrease is due to the following items:

	For the Three Months Ended June 30,
	2013		2012		Variance			Percent Change
Marcellus Title Defects	$	2	$	—	$	2		100	%
Exploration	5		5		—			—	%
Lease Expiration Costs	3		11		(8		)	(72.7	)%
Total Exploration and Other Costs	$	10	$	16	$	(6	)	(37.5	)%

• As part of the title defect process the company is working through with its joint venture partner, Noble Energy, CONSOL Energy conceded title defects on acreage which had a book value to CONSOL Energy of $2 million.

• Exploration expenses remained consistent in the period-to-period comparison.

59

• Lease expiration costs relate to locations where CONSOL Energy allowed the primary term lease to expire because of unfavorable drilling economics. The $8 million decrease is due to CONSOL Energy allowing fewer leases to expire in the current period when compared with the prior period.

Other corporate expenses were $22 million for the three months ended June 30, 2013 compared to $17 million for the three months ended June 30, 2012. The $5 million increase in the period-to-period comparison was made up of the following items:

	For the Three Months Ended June 30,
	2013		2012		Variance			Percent Change
Unutilized firm transportation	$	9	$	3	$	6		200	%
Stock-based compensation	5		4		1			25	%
Bank fees	2		2		—			—	%
Short term incentive compensation	4		7		(3		)	(42.9	)%
Other	2		1		1			100	%
Total Other Corporate Expenses	$	22	$	17	$	5		29.4	%

• Unutilized firm transportation costs represent pipeline transportation capacity the gas segment has obtained to enable gas production to flow uninterrupted as sales volumes increase. The $6 million increase is due to increased firm transportation capacity which has not been utilized by active operations.

• Stock-based compensation was higher in the period-to-period comparison primarily due to additional non-cash amortization expense and accelerated non-cash amortization for retiree-eligible employees who received awards under the new CONSOL Share Unit (CSU) program. The new program replaces several previously provided long-term executive compensation award programs.  The compensation expense of the CSU program will not be materially different from the total expense of the previous programs over the three-year performance period.

• Bank fees remained consistent in the period-to-period comparison.

• The short-term incentive compensation program is designed to increase compensation to eligible employees when CNX Gas reaches predetermined targets for safety, production and unit costs. Short-term incentive compensation expense was lower for the 2013 period compared to the 2012 period due to the projected lower payouts.

• Other corporate expense increased $1 million due to various transactions that occurred throughout both periods, none of which were individually material.

Interest expense related to the gas segment was $2 million for the three months ended June 30, 2013 compared to $1 million for the three months ended June 30, 2012. Interest was incurred on the CNX Gas revolving credit facility and a capital lease. The $1 million increase was primarily due to higher levels of borrowings on the revolving credit facility throughout the period-to-period comparison.

OTHER SEGMENT ANALYSIS for the three months ended June 30, 2013 compared to the three months ended June 30, 2012:

The other segment includes activity from the sales of industrial supplies, the transportation operations and various other corporate activities that are not allocated to the coal or gas segment. The other segment had a loss before income tax of $58 million for the three months ended June 30, 2013 compared to a loss before income tax of $45 million for the three months ended June 30, 2012. The other segment also includes total Company income tax expense of $15 million for the three months ended June 30, 2013 compared to $59 million for the three months ended June 30, 2012.

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	For the Three Months Ended June 30,
	2013			2012			Variance			Percent Change
Sales—Outside	$	83		$	96		$	(13	)	(13.5	)%
Other Income	3			3			—			—	%
Total Revenue	86			99			(13		)	(13.1	)%
Cost of Goods Sold and Other Charges	81			81			—			—	%
Depreciation, Depletion & Amortization	7			6			1			16.7	%
Taxes Other Than Income Tax	3			2			1			50.0	%
Interest Expense	53			55			(2		)	(3.6	)%
Total Costs	144			144			—			—	%
Loss Before Income Tax	(58		)	(45		)	(13		)	28.9	%
Income Tax	15			59			(44		)	(74.6	)%
Net Loss	$	(73	)	$	(104	)	$	31		29.8	%

Industrial supplies:

Outside Sales from industrial supplies was $54 million for the three months ended June 30, 2013 compared to $64 million for the three months ended June 30, 2012. The decrease of $10 million was primarily related to lower sales volumes.

Total costs related to industrial supply sales were $53 million for the three months ended June 30, 2013 compared to $62 million for the three months ended June 30, 2012. The decrease of $9 million was primarily related to lower sales volumes and various changes in inventory costs, none of which were individually material.

Transportation operations:

Outside Sales from transportation operations was $29 million for the three months ended June 30, 2013 compared to $32 million for the three months ended June 30, 2012. The decrease of $3 million was primarily attributable to decreased thru-put at the CNX Marine Terminal offset, in part, by higher per ton thru-put rates.

Total costs related to the transportation operations were $25 million for the three months ended June 30, 2013 compared to $21 million for the three months ended June 30, 2012. The increase of $4 million was due to various items in both periods, none of which were individually material.

Miscellaneous other:

Additional other income remained consistent at $3 million for the three months ended June 30, 2013 and June 30, 2012.

Other corporate costs were $66 million for the three months ended June 30, 2013 compared to $61 million for the three months ended June 30, 2012. Other corporate costs increased due to the following items:

	For the Three Months Ended June 30,
	2013		2012		Variance
Pension settlement	$	5	$	—	$	5
Bank fees	4		3		1
Interest expense	53		56		(3		)
Other	4		2		2
	$	66	$	61	$	5

• Pension settlement adjustment is the acceleration of unrecognized actuarial losses due to lump sum payments from the pension plan exceeding the annual projected service and interest costs of the plan.

• Bank fees increased $1 million due to various transactions that occurred throughout both periods, none of which were individually material.

• Interest expense decreased $3 million primarily due to an increase in capitalized interest due to higher capital expenditures for major construction projects in the current period.

• Other corporate items increased $2 million due to various transactions that occurred throughout both periods, none of which were individually material.

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Income Taxes:

The effective income tax rate was 808.3% for the three months ended June 30, 2013 compared to 27.8% for the three months ended June 30, 2012. The effective rates for the three months ended June 30, 2013 and 2012 were calculated using the annual effective rate projection on recurring earnings and include tax liabilities related to certain discrete transactions. The relationship between pre-tax earnings and percentage depletion impacts the effective tax rate. See Note 5 - Income Taxes of the Notes to the Condensed Consolidated Financial Statements of this Form 10-Q for additional information. 

	For the Three Months Ended June 30,
	2013			2012			Variance			Percent Change
Total Company Earnings Before Income Tax	$	2		$	212		$	(210	)	(99.2	)%
Income Tax Expense	$	15		$	59		$	(44	)	(74.6	)%
Effective Income Tax Rate	808.3		%	27.8		%	780.5		%

Results of Operations

Six Months EndedJune 30, 2013 Compared with Six Months EndedJune 30, 2012

Net Income Attributable to CONSOL Energy Shareholders

CONSOL Energy reported a net loss attributable to CONSOL Energy shareholders of $14 million, or $(0.06) per diluted share, for the six months ended June 30, 2013. Net income attributable to CONSOL Energy shareholders was $250 million, or $1.09 per diluted share, for the six months ended June 30, 2012.

The coal division includes thermal coal, high volatile metallurgical coal, low volatile metallurgical coal and other coal. The total coal division contributed $158 million of earnings before income tax for the six months ended June 30, 2013 compared to $419 million for the six months ended June 30, 2012. The total coal division sold 29.0 million tons of coal produced from CONSOL Energy mines for the six months ended June 30, 2013 and 29.6 million tons of coal produced from CONSOL Energy mines for the six months ended June 30, 2012.

The average sales price and total costs per ton for all active coal operations were as follows:

	For the Six Months Ended June 30,
	2013		2012		Variance			Percent Change
Average Sales Price per ton sold	$	63.17	$	67.37	$	(4.20	)	(6.2	)%
Average Cost of Goods Sold per ton	51.25		53.36		(2.11		)	(4.0	)%
Margin per ton sold	$	11.92	$	14.01	$	(2.09	)	(14.9	)%

The lower average sales price per ton sold reflects a decrease in the global metallurgical and thermal coal markets. The coal division priced 5.0 million tons on the export market at an average sales price of $72.74 for the six months ended June 30, 2013 compared to 6.7 million tons at an average price of $75.85 per ton for the six months ended June 30, 2012. All other tons were sold on the domestic market.

Changes in the average cost of goods sold per ton were primarily related to the following items:

• Direct operating costs improved primarily due to a decrease in all direct operating costs at the Blacksville No. 2 Mine which is the result of the mine being idled until May 20th due to the fire, as previously discussed. In March and April 2012, the Blacksville No. 2 Mine ran the continuous miners and worked on various projects, but the longwall was idled resulting in higher 2012 unit costs. This did not occur in the 2013 period.

• Costs were improved due to a reduction in gas well plugging costs at the Shoemaker Mine and due to the shutdown of the Fola Mining Complex in August 2012.

• Average direct operating costs were impaired due to CONSOL Energy entering into several new leases for various types of mining equipment at our Bailey Mine, Robinson Run Mine, and Shoemaker Mine.

• In March and April 2012, the Buchanan Mine ran the continuous miners and worked on various projects, but the longwall was idled resulting in lower 2012 unit costs. This did not occur in the 2013 period.

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• Direct services to operations are improved primarily due to a reduction in subsidence expenses related to the timing and nature of properties and streams undermined as well as a reduction in direct administration employees as a result of the 2012 Voluntary Severance Incentive Plan discussed below under general and administrative costs.

• Depreciation, depletion and amortization was improved primarily due to lower production at Blacksville No. 2 Mine related to the mine being shut down due to the fire, the shutdown of operations at the Fola Mining Complex and the timing of assets going in service or being fully depreciated.

The total gas division includes CBM, Shallow Oil and Gas, Marcellus and other gas. The total gas division had a $5 million loss before income tax for the six months ended June 30, 2013 compared to $13 million of earnings before income tax for the six months ended June 30, 2012. Total gas production was 77.8 billion cubic feet for the six months ended June 30, 2013 compared to 75.0 billion cubic feet for the six months ended June 30, 2012. Total gas volumes increased primarily as a result of the on-going Marcellus drilling program.

The average sales price and total costs for all active gas operations were as follows: 

	For the Six Months Ended June 30,
	2013		2012		Variance			Percent Change
Average Sales Price per thousand cubic feet sold	$	4.38	$	4.12	$	0.26		6.3%
Average Costs per thousand cubic feet sold	3.65		3.36		0.29			8.6%
Margin per thousand cubic feet sold	$	0.73	$	0.76	$	(0.03	)	(3.9)%

Total gas division outside sales revenues were $341 million for the six months ended June 30, 2013 compared to $309 million for the six months ended June 30, 2012. The increase was primarily due to the 3.7% increase in volumes sold, along with a 6.3% increase in average price per thousand cubic feet sold. The increase in average sales price is the result of the increase in general market prices and sales of natural gas liquids, partially offset by various gas swap transactions that occurred throughout both periods. The gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 36.3 billion cubic feet of our produced gas sales volumes for the six months ended June 30, 2013 at an average price of $4.75 per thousand cubic feet. These financial hedges represented 38.2 billion cubic feet of our produced gas sales volumes for the six months ended June 30, 2012 at an average price of $5.25 per thousand cubic feet.

Changes in the average cost per thousand cubic feet of gas sold were primarily related to the following items:

• Gathering costs increased in the period-to-period comparison due to higher firm transportation costs and increased processing fees associated with natural gas liquids.

• Lifting costs increased due to increased accretion expense on the well plugging liability as well as increased salt water disposal costs. This impairment was partially offset by improvements related to decreased expenditures for contract services, environmental compliance and safety costs and well services costs in the current period.

• Higher units-of-production depreciation, depletion and amortization rates for producing properties.

• These increases were offset, in part, by higher volumes in the period-to-period comparison due to the on-going Marcellus drilling program. Fixed costs are allocated over increased volumes, resulting in lower unit costs.

The other segment includes industrial supplies activity, terminal, river and dock service activity, income taxes and other business activities not assigned to the coal or gas segment.

General and administrative costs are allocated between divisions (Coal, Gas and Other) based primarily on percentage of total revenue and percentage of total projected capital expenditures. General and administrative costs are excluded from the coal and gas unit costs above. Total general and administrative costs were made up of the following items:

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	For the Six Months Ended June 30,
	2013		2012		Variance			Percent Change
Consulting and professional services	$	15	$	12	$	3		25.0	%
Contributions	7		5		2			40.0	%
Advertising and promotion	4		4		—			—	%
Employee wages and related expenses	27		32		(5		)	(15.6	)%
Miscellaneous	14		13		1			7.7	%
Total Company General and Administrative Expenses	$	67	$	66	$	1		1.5	%

Total Company General and Administrative Expenses changed due to the following:

• Consulting and professional services increased $3 million in the period-to-period comparison due to various legal proceedings and corporate initiatives, none of which are individually significant.

• Contributions increased $2 million related to various transactions that occurred throughout both periods, none of which are individually material.

• Advertising and promotion remained consistent in the period-to-period comparison.

• Employee wages and related expenses decreased $5 million primarily attributable to fewer employees as a result of the 2012 Voluntary Severance Incentive Plan and lower salary other post-employment benefit (OPEB) expenses in the period-to-period comparison. The lower OPEB expenses relate to changes in the discount rates and other assumptions.

• Miscellaneous general and administrative expenses increased slightly in the period-to-period comparison due to various transactions, none of which were individually material.

Total Company long-term liabilities, such as OPEB, the salary retirement plan, workers' compensation and long-term disability are actuarially calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. Total CONSOL Energy expense related to our actuarial liabilities was $155 million for the six months ended June 30, 2013 compared to $131 million for the six months ended June 30, 2012. The increase of $24 million for total CONSOL Energy expense was primarily due to required pension settlement accounting of $32 million related to lump sum distributions made for the 2013 plan year exceeding the total of the service cost and interest cost for the 2013 plan year. The pension settlement was not allocated to individual operating segments and is therefore not included in unit costs presented for coal or gas. This was offset, in part, due to a modification to the benefit plan for salaried employees and an increase in the discount rate assumptions used to calculate expense for benefit plans at the measurement date, which is December 31. See Note 3 - Components of Pension and Other Postretirement Benefit Plans Net Periodic Benefit Costs and Note 4 - Components of Coal Workers' Pneumoconiosis (CWP) and Workers' Compensation Net Periodic Benefit Costs in the Notes to the Unaudited Consolidated Financial Statements for additional detail of the total Company expense decrease.

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TOTAL COAL SEGMENT ANALYSIS for the six months ended June 30, 2013 compared to the six months ended June 30, 2012:

The coal segment contributed $158 million of earnings before income tax in the six months ended June 30, 2013 compared to $419 million in the six months ended June 30, 2012. Variances by the individual coal segments are discussed below.

	For the Six Months Ended														Difference to Six Months Ended
	June 30, 2013														June 30, 2012
	Thermal Coal			High Vol Met Coal		Low Vol Met Coal			Other Coal			Total Coal			Thermal Coal			High Vol Met Coal			Low Vol Met Coal			Other Coal			Total Coal
Sales:
Produced Coal	$	1,459		$	116	$	258		$	—		$	1,833		$	(101	)	$	(16	)	$	(35	)	$	(6	)	$	(158	)
Purchased Coal	—			—		—			11			11			—			—			—			3			3
Total Outside Sales	1,459			116		258			11			1,844			(101		)	(16		)	(35		)	(3		)	(155		)
Freight Revenue	—			—		—			24			24			—			—			—			(75		)	(75		)
Other Income	1			2		—			61			64			1			(4		)	—			(150		)	(153		)
Total Revenue and Other Income	1,460			118		258			96			1,932			(100		)	(20		)	(35		)	(228		)	(383		)
Costs and Expenses:
Beginning inventory costs	58			—		21			—			79			(32		)	—			5			—			(27		)
Total direct operating costs	760			57		102			102			1,021			(49		)	(6		)	(13		)	39			(29		)
Total royalty/production taxes	102			3		14			1			120			(5		)	(4		)	(4		)	(1		)	(14		)
Total direct services to operations	117			10		12			124			263			(35		)	(3		)	1			(21		)	(58		)
Total retirement and disability	88			6		13			8			115			(4		)	—			(3		)	1			(6		)
Depreciation, depletion and amortization	145			11		20			27			203			(13		)	(3		)	(1		)	19			2
Ending inventory costs	(42		)	—		(9		)	—			(51		)	68			—			17			—			85
Total Costs and Expenses	1,228			87		173			262			1,750			(70		)	(16		)	2			37			(47		)
Freight Expense	—			—		—			24			24			—			—			—			(75		)	(75		)
Total Costs	1,228			87		173			286			1,774			(70		)	(16		)	2			(38		)	(122		)
Earnings (Loss) Before Income Taxes	$	232		$	31	$	85		$	(190	)	$	158		$	(30	)	$	(4	)	$	(37	)	$	(190	)	$	(261	)

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THERMAL COAL SEGMENT

The thermal coal segment contributed $232 million to total Company earnings before income tax for the six months ended June 30, 2013 and $262 million for the six months ended June 30, 2012. The thermal coal revenue and cost components on a per unit basis for these periods are as follows:

	For the Six Months Ended June 30,
	2013		2012		Variance			Percent Change
Company Produced Thermal Tons Sold (in millions)	24.6		25.3		(0.7		)	(2.8	)%
Average Sales Price Per Thermal Ton Sold	$	59.19	$	61.66	$	(2.47	)	(4.0	)%
Beginning Inventory Costs Per Thermal Ton	$	50.92	$	58.32	$	(7.40	)	(12.7	)%
Total Direct Operating Costs Per Thermal Ton Produced	$	31.30	$	31.45	$	(0.15	)	(0.5	)%
Total Royalty/Production Taxes Per Thermal Ton Produced	4.21		4.16		0.05			1.2	%
Total Direct Services to Operations Per Thermal Ton Produced	4.82		5.90		(1.08		)	(18.3	)%
Total Retirement and Disability Per Thermal Ton Produced	3.63		3.58		0.05			1.4	%
Total Depreciation, Depletion and Amortization Costs Per Thermal Ton Produced	5.96		6.12		(0.16		)	(2.6	)%
Total Production Costs Per Thermal Ton Produced	$	49.92	$	51.21	$	(1.29	)	(2.5	)%
Ending Inventory Costs Per Thermal Ton	$	55.36	$	56.03	$	(0.67	)	(1.2	)%
Total Costs Per Thermal Ton Sold	$	49.81	$	51.32	$	(1.51	)	(2.9	)%
Average Margin Per Thermal Ton Sold	$	9.38	$	10.34	$	(0.96	)	(9.3	)%

Thermal coal revenue was $1,460 million for the six months ended June 30, 2013 compared to $1,560 million for the six months ended June 30, 2012. The $100 million decrease was attributable to a $2.47 per ton lower average sales price and 0.7 million reduction in tons sold. The lower average thermal coal sales price in the 2013 period was the result of the renewal of several domestic thermal contracts whose pricing was reduced effective January 1, 2013. Also, 1.5 million tons of thermal coal were priced on the export market at an average sales price of $61.67 per ton for the six months ended June 30, 2013 compared to 3.3 million tons at an average price of $57.12 per ton for the six months ended June 30, 2012.

Total cost of goods sold is comprised of changes in thermal coal inventory, both volumes and carrying values, and costs of tons produced in the period. Total cost of goods sold for thermal coal was $1,228 million for the six months ended June 30, 2013, or $70 million lower than the $1,298 million for the six months ended June 30, 2012. Total cost of goods sold for thermal coal was $49.81 per ton in the six months ended June 30, 2013 compared to $51.32 per ton in the six months ended June 30, 2012. The decrease in costs of goods sold per thermal ton was due to the items described below.

Direct operating costs are comprised of labor, supplies, maintenance, power and preparation plant charges related to the extraction and sale of coal. These costs are reviewed regularly by management and are considered to be the direct responsibility of mine management. Direct operating costs related to the thermal coal segment were $760 million in the six months ended June 30, 2013 compared to $809 million in the six months ended June 30, 2012. Direct operating costs were $31.30 per ton produced in the current period compared to $31.45 per ton produced in the prior period. Changes in the average direct operating costs per thermal ton produced were primarily related to the following items:

• The Blacksville No. 2 mine was idled on March 12, 2013 and resumed production on May 20, 2013 due to the fire that was previously discussed, this resulted in a reduction in all direct operating costs.

• In March and April 2012, the Blacksville No. 2 Mine ran the continuous miners and worked on various projects, but the longwall was idled resulting in higher 2012 unit costs. This did not occur in 2013.

• The Fola Mining Complex was idled in August 2012 which resulted in lower direct operating costs per ton produced in the period-to-period comparison. The mine, which was idled for market reasons, was a higher cost mining operation which when removed reduced the overall average direct operating costs per ton produced.

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• In 2013, CONSOL Energy entered into several new leases for various mining equipment, which resulted in higher cost per ton produced in the period-to-period comparison.

Royalties and production taxes decreased $5 million to $102 million in the current period. Average cost per thermal ton produced increased $0.05 per ton to $4.21 per ton sold, due to lower production volumes and lower average sales prices which is the basis for most production taxes.

Direct services to the operations are comprised of items which support groups manage on behalf of the coal operations. Costs included in direct services are comprised of subsidence costs, direct administrative and selling costs, permitting and compliance costs, mine closing and reclamation costs, and water treatment costs. The cost of these support services was $117 million in the current period compared to $152 million in the prior period. Direct services to the operations were $4.82 per ton produced in the current period compared to $5.90 per ton produced in the prior period. Changes in the average direct service to operations cost per thermal ton produced were primarily related to the following items:

• Average direct service costs to operations were improved due to a reduction in subsidence expense. The reduction was the result of the timing and nature of properties undermined in the period-to-period comparison.

• Average direct service costs to operations were also improved due to a reduction in direct administrative employees as a result of the 2012 Voluntary Severance Incentive Plan, that was discussed previously.

Retirement and disability costs are comprised of the expenses related to the Company's long-term liabilities, such as other post-retirement benefits (OPEB), the salary retirement plan, workers' compensation, coal workers' pneumoconiosis (CWP) and long-term disability. These liabilities are actuarially calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. The retirement and disability costs attributable to the thermal coal segment were $88 million for the six months ended June 30, 2013 compared to $92 million for the six months ended June 30, 2012. The decrease in the thermal coal retirement and disability costs was primarily attributable to an increase in discount rates used to calculate the 2013 cost of the long-term liabilities and a modification of the salaried other post-retirement benefit plan that occurred June 30, 2012. Average cost per thermal ton produced increased $0.05 per ton to $3.63 per ton sold due to lower production volumes.

Depreciation, depletion and amortization for the thermal coal segment was $145 million for the six months ended June 30, 2013 compared to $158 million for the six months ended June 30, 2012. Unit costs per thermal ton produced were lower in the six months ended June 30, 2013 compared to the six months ended June 30, 2012 due to the idling of the Fola Mining Complex in August 2012.

Changes in thermal coal inventory volumes and carrying value resulted in $16 million of cost of goods sold in the six months ended June 30, 2013 compared to a $20 million reduction of cost of goods sold in the six months ended June 30, 2012. Thermal coal inventory was 0.8 million tons at June 30, 2013 compared to 2.0 million tons at June 30, 2012.

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HIGH VOL METALLURGICAL COAL SEGMENT

The high volatile metallurgical coal segment contributed $31 million to total Company earnings before income tax for the six months ended June 30, 2013 compared to $35 million for the six months ended June 30, 2012. The high volatile metallurgical coal revenue and cost components on a per unit basis for these periods are as follows:

	For the Six Months Ended June 30,
	2013		2012		Variance			Percent Change
Company Produced High Vol Met Tons Sold (in millions)	1.8		2.2		(0.4		)	(18.2	)%
Average Sales Price Per High Vol Met Ton Sold	$	64.57	$	60.95	$	3.62		5.9	%
Beginning Inventory Costs Per High Vol Met Ton	$	—	$	—	$	—		—	%
Total Direct Operating Costs Per High Vol Met Ton Produced	$	31.87	$	29.03	$	2.84		9.8	%
Total Royalty/Production Taxes Per High Vol Met Ton Produced	1.44		3.17		(1.73		)	(54.6	)%
Total Direct Services to Operations Per High Vol Met Ton Produced	5.86		6.14		(0.28		)	(4.6	)%
Total Retirement and Disability Per High Vol Met Ton Produced	3.32		2.91		0.41			14.1	%
Total Depreciation, Depletion and Amortization Costs Per High Vol Met Ton Produced	5.93		6.26		(0.33		)	(5.3	)%
Total Production Costs Per High Vol Met Ton Produced	$	48.42	$	47.51	$	0.91		1.9	%
Ending Inventory Costs Per High Vol Met Ton	$	—	$	—	$	—		—	%
Total Costs Per High Vol Met Ton Sold	$	48.42	$	47.51	$	0.91		1.9	%
Margin Per High Vol Met Ton Sold	$	16.15	$	13.44	$	2.71		20.2	%

High volatile metallurgical coal revenue was $118 million for the six months ended June 30, 2013 compared to $138 million for the six months ended June 30, 2012. Average sales prices for high volatile metallurgical coal increased $3.62 per ton in a period-to-period comparison. CONSOL Energy priced 1.6 million tons of high volatile metallurgical coal in the export market at an average sales price of $62.21 per ton for the six months ended June 30, 2013 compared to 1.9 million tons at an average price of $58.15 per ton for the six months ended June 30, 2012. The remaining tons sold in the period-to-period comparison were sold on the domestic market.

Total cost of goods sold is comprised of changes in high volatile metallurgical coal inventory, both volumes and carrying values, and costs of tons produced in the period. Total cost of goods sold for high volatile metallurgical coal was $87 million for the six months ended June 30, 2013, or $16 million lower than the $103 million for the six months ended June 30, 2012. Total cost of goods sold for high volatile metallurgical coal was $48.42 per ton in the six months ended June 30, 2013 compared to $47.51 per ton in the six months ended June 30, 2012. The increase in cost of goods sold per high volatile metallurgical ton was due to the items described below.

Direct operating costs are comprised of labor, supplies, maintenance, power and preparation plant charges related to the extraction and sale of coal. These costs are reviewed regularly by management and are considered to be the direct responsibility of mine management. Direct operating costs related to the high volatile metallurgical coal segment were $57 million in the six months ended June 30, 2013 compared to $63 million in the six months ended June 30, 2012. The reduction in total dollars was primarily due to a reduction in mine maintenance and supply expense as a result of the shutdown of the Fola Mining Complex in August 2012. Direct operating costs were $31.87 per ton produced in the current period compared to $29.03 per ton produced in the prior period. The increase in the average direct operating costs per high volatile metallurgical ton produced was primarily due to fewer tons produced. Fixed costs are allocated over less tons, resulting in higher unit costs.

Royalties and production taxes improved $4 million in the current period due primarily to the shutdown of the Fola Mining Complex in August 2012.

Direct services to operations are comprised of items which support groups manage on behalf of the coal operations. Costs included in direct services are comprised of subsidence costs, direct administrative and selling costs, permitting and compliance

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costs, mine closing and reclamation costs, and water treatment costs. The costs of these support services for high volatile metallurgical coal were $10 million in the current period compared to $13 million in the prior period. Direct services to the operations for high volatile metallurgical coal were $5.86 per ton in the current period compared to $6.14 per ton in the prior period. Changes in the average direct services to operations cost per ton for high volatile metallurgical coal produced were primarily related to the following items:

• Average direct service costs to operations were improved due to a reduction in subsidence expense. The reduction was the result of the timing and nature of properties undermined in the period-to-period comparison.

• Average direct service costs to operations were also improved due to a reduction in direct administrative employees as a result of the 2012 Voluntary Severance Incentive Plan, that was discussed previously.

Retirement and disability costs are comprised of the expenses related to the Company's long-term liabilities, such as other post-retirement benefits (OPEB), the salary retirement plan, workers' compensation, coal workers' pneumoconiosis (CWP) and long-term disability. These liabilities are actuarially calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. The retirement and disability costs attributable to the high volatile metallurgical coal segment were $6 million for the six months ended June 30, 2013 and June 30, 2012. The reduction in production volumes had a negative impact on the unit costs.

Depreciation, depletion and amortization for the high volatile metallurgical coal segment was $11 million for the six months ended June 30, 2013 and $14 million for the six months ended June 30, 2012. Unit costs per high volatile ton produced were lower in the six months ended June 30, 2013 compared to the six months ended June 30, 2012 due primarily to the shutdown of the Fola Mining Complex in August 2012.

There were no changes in volumes or carrying value of coal inventory in the six months ended June 30, 2013 and June 30, 2012. There was no high volatile metallurgical coal inventory at June 30, 2013 or June 30, 2012.

LOW VOL METALLURGICAL COAL SEGMENT

The low volatile metallurgical coal segment contributed $85 million to total Company earnings before income tax in the six months ended June 30, 2013 compared to $122 million in the six months ended June 30, 2012. The low volatile metallurgical coal revenue and cost components on a per ton basis for these periods are as follows:

	For the Six Months Ended June 30,
	2013		2012		Variance			Percent Change
Company Produced Low Vol Met Tons Sold (in millions)	2.6		2.0		0.6			30.0	%
Average Sales Price Per Low Vol Met Ton Sold	$	100.41	$	146.40	$	(45.99	)	(31.4	)%
Beginning Inventory Costs Per Low Vol Met Ton	$	86.38	$	67.60	$	18.78		27.8	%
Total Direct Operating Costs Per Low Vol Met Ton Produced	$	40.96	$	53.38	$	(12.42	)	(23.3	)%
Total Royalty/Production Taxes Per Low Vol Met Ton Produced	5.79		8.63		(2.84		)	(32.9	)%
Total Direct Services to Operations Per Low Vol Met Ton Produced	4.85		5.35		(0.50		)	(9.3	)%
Total Retirement and Disability Per Low Vol Met Ton Produced	5.37		7.62		(2.25		)	(29.5	)%
Total Depreciation, Depletion and Amortization Costs Per Low Vol Met Ton Produced	8.10		9.65		(1.55		)	(16.1	)%
Total Production Costs Per Low Vol Met Ton Produced	$	65.07	$	84.63	$	(19.56	)	(23.1	)%
Ending Inventory Costs Per Low Vol Met Ton	$	64.76	$	69.84	$	(5.08	)	(7.3	)%
Total Costs Per Low Vol Met Ton Sold	$	67.10	$	85.43	$	(18.33	)	(21.5	)%
Margin Per Low Vol Met Ton Sold	$	33.31	$	60.97	$	(27.66	)	(45.4	)%

Low volatile metallurgical coal revenue was $258 million for the six months ended June 30, 2013 compared to $293 million for the six months ended June 30, 2012. The $35 million decrease was attributable to a $45.99 per ton lower average sales price. Average sales prices for low volatile metallurgical coal decreased in the period-to-period comparison due to the

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weakening in global metallurgical coal demand. For the 2013 period, 2.0 million tons of low volatile metallurgical coal were priced on the export market at an average price of $89.53 per ton compared to 1.6 million tons at an average price of $136.32 per ton for the 2012 period. The remaining tons sold in the period-to-period comparison were sold on the domestic market.

Total cost of goods sold is comprised of changes in low volatile metallurgical coal inventory, both volumes and carrying values, and costs of tons produced in the period. Total cost of goods sold for low volatile metallurgical coal was $173 million for the six months ended June 30, 2013, or $2 million higher than the $171 million for the six months ended June 30, 2012. Total cost of goods sold for low volatile metallurgical coal was $67.10 per ton in the six months ended June 30, 2013 compared to $85.43 per ton in the six months ended June 30, 2012. The decrease in cost of goods sold per low volatile metallurgical ton was due to the following items described below.

Direct operating costs are comprised of labor, supplies, maintenance, power and preparation plant charges related to the extraction and sale of coal. These costs are reviewed regularly by management and are considered to be the direct responsibility of mine management. Direct operating costs related to the low volatile metallurgical coal segment were $102 million in the six months ended June 30, 2013 compared to $115 million in the six months ended June 30, 2012. Direct operating costs improved primarily as the result of several cost saving initiatives at the Buchanan Mine, such as, slowing the pace of major maintenance projects, right sizing the workforce to fit the recently implemented five-day work schedule, and opening the Horn Mountain portal, which allowed employees to enter the mine much closer to the longwall face. The improvement was partially offset by lower direct operating costs in the 2012 period due to the Buchanan Mine longwall being temporarily idled in March and April. Direct operating costs were $40.96 per ton produced in the current period compared to $53.38 per ton produced in the prior period. Low volatile metallurgical coal production was 2.5 million tons in the six months ended June 30, 2013 compared to 2.1 million tons in the six months ended June 30, 2012.

Royalties and production taxes improved $4 million to $14 million in the current period compared to $18 million in the prior period. Unit costs also improved $2.84 per low volatile metallurgical ton produced to $5.79 per ton produced in the current period compared to $8.63 per ton produced in the prior period. Average cost per low volatile metallurgical ton produced decreased due to lower royalties and lower production taxes, primarily related to lower average sales prices.

Direct services to the operations are comprised of items which support groups manage on behalf of the coal operations. Costs included in direct services are comprised of subsidence costs, direct administrative and selling costs, permitting and compliance costs, mine closing and reclamation costs, and water treatment costs. The costs of these support services for low volatile metallurgical coal were $12 million in the current and $11 million in the prior periods. Direct services to operations for low volatile metallurgical coal were $4.85 per ton produced in the current period compared to $5.35 per ton produced in the prior period. Changes in the average direct services to operations cost per ton for low volatile metallurgical coal produced were due to a reduction in direct administrative employees as a result of the 2012 Voluntary Severance Incentive Plan and due to higher tons of coal produced in the period-to-period comparison.

Retirement and disability costs are comprised of the expenses related to the Company's long-term liabilities, such as other post-retirement benefits (OPEB), the salary retirement plan, workers' compensation, coal workers' pneumoconiosis (CWP) and long-term disability. These liabilities are actuarially calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. The retirement and disability costs attributable to the low volatile metallurgical coal segment were $13 million for the six months ended June 30, 2013 compared to $16 million for the six months ended June 30, 2012. The decrease in the low volatile metallurgical coal retirement and disability costs was primarily attributable to an increase in discount rates used to calculate the cost of the long-term liabilities and a modification of the salaried other post-retirement benefit plan that occurred on June 30, 2012. This, coupled with the increase in volumes, resulted in an improvement on the unit costs of $2.25 in the period-to-period comparison.

Depreciation, depletion and amortization for the low volatile metallurgical coal segment was $20 million for the six months ended June 30, 2013 compared to $21 million for the six months ended June 30, 2012. Unit costs per low volatile metallurgical tons produced were lower in the six months ended June 30, 2013 compared to the six months ended June 30, 2012 primarily due to the Amonate Complex being idled in September 2012 and the Buchanan reverse osmosis plant being temporarily idled in April and May 2013.

Changes in low volatile metallurgical coal inventory volumes and carrying value resulted in an increase of $12 million to cost of goods sold in the six months ended June 30, 2013 and a decrease of $10 million to cost of goods sold in the six months ended June 30, 2012. Produced low volatile metallurgical coal inventory was 0.1 million tons at June 30, 2013 compared to 0.3 million tons at June 30, 2012.

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OTHER COAL SEGMENT

The other coal segment had a loss before income tax of $190 million for the six months ended June 30, 2013 and had zero net income before taxes for the six months ended June 30, 2012. The other coal segment includes purchased coal activities, idle mine activities, as well as various activities assigned to the coal segment but not allocated to each individual mine.

Other coal segment produced coal sales includes revenue from the sale of 0.1 million tons of coal which was recovered during the reclamation process at idled facilities for the six months ended June 30, 2012. No coal was recovered during the reclamation process at idled facilities for the six months ended June 30, 2013. The primary focus of the activity at these locations is reclaiming disturbed land in accordance with the mining permit requirements after final mining has occurred. The tons sold are incidental to total Company production or sales.

Purchased coal sales consist of revenues from processing third-party coal in our preparation plants for blending purposes to meet customer coal specifications and coal purchased from third parties and sold directly to our customers. The revenues were $11 million for the six months ended June 30, 2013 compared to $8 million for the six months ended June 30, 2012.

Freight revenue is the amount billed to customers for transportation costs incurred. This revenue is based on weight of coal shipped, negotiated freight rates and method of transportation (i.e. rail, barge, truck, etc.) used by the customers to which CONSOL Energy contractually provides transportation services. Freight revenue is offset by freight expense. Freight revenue was $24 million for the six months ended June 30, 2013 compared to $99 million for the six months ended June 30, 2012. The $75 million decrease in freight revenue was due to decreased shipments under contracts which CONSOL Energy contractually provides transportation services.

Miscellaneous other income was $61 million for the six months ended June 30, 2013 compared to $211 million for the six months ended June 30, 2012. The $150 million decrease is due to the following items:

• Gain on sale of assets attributable to the Other Coal segment was $27 million in the six months ended June 30, 2013 compared to $180 million in the six months ended June 30, 2012. The decrease of $153 million was primarily related to 2012 sales of non-producing assets in the Northern Powder River Basin that resulted in income of $151 million, as well as coal and surface lands in Illinois and West Virginia that resulted in income of $22 million. This is offset by the 2013 sale of Potomac coal reserves that resulted in income of $25 million. See Note 2—Acquisitions and Dispositions in the Notes to the Unaudited Consolidated Financial Statements for additional detail of these sales. The remaining change was related to various transactions that occurred throughout both periods, none of which were individually material.

• Equity in earnings of affiliates increased $5 million due to higher earnings from our equity affiliates.

• In the six months ended June 30, 2013, $3 million of business interruption insurance proceeds were received related to the 2012 Bailey Belt Conveyor accident. There is no assurance that additional proceeds from the incident will be received.

• In the six months ended June 30, 2012, there was an additional $6 million in income that was related to certain thermal coal contract buyouts. There were no such items in the six months ended June 30, 2013.

• The remaining $1 million decrease in other income is due to various items, none of which are individually material.

Other coal segment total costs were $286 million for the six months ended June 30, 2013 compared to $324 million for the six months ended June 30, 2012. The decrease of $38 million was due to the following items:

	For the Six Months Ended June 30,
	2013		2012		Variance
Blacksville No. 2 Mine Fire	$	38	$	—	$	38
Stock-based compensation	25		16		9
Purchased coal	21		18		3
Closed and idle mines	68		71		(3		)
Freight expense	24		99		(75		)
Other	110		120		(10		)
Total Other Coal Segment Costs	$	286	$	324	$	(38	)

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• The Blacksville No. 2 Mine fire expense was due to a fire that occurred on March 12, 2013. The mine resumed production on May 20, 2013. Insurance recovery is uncertain at this time and the impact of any potential recovery has not been reflected in the six months ended June 30, 2013.

• Stock-based compensation was higher in the period-to-period comparison primarily due to additional non-cash amortization expense and accelerated non-cash amortization for retiree-eligible employees who received awards under the new CONSOL Share Unit (CSU) program.  The new program replaces several previously provided long-term executive compensation award programs.  The compensation expense of the CSU program will not be materially different from the total expense of the previous programs over the three-year performance period.

• Purchased coal costs increased due to an increase in the amount of coal that was purchased to fulfill various contracts.

• Closed and idle mine costs decreased approximately $3 million for the six months ended June 30, 2013 compared to the six months ended June 30, 2012.  There was a $24 million decrease in asset retirement obligations. This was primarily due to an increase in the reclamation liability at the Fola Mining Complex in the June 2012 period due to new regulatory requirements, and water and selenium treatment estimates. The decrease was offset, in part, by an increase of $13 million due to the idling of the Fola Mining Complex in August 2012, and an increase of $5 million due to the idling of the Amonate Complex in September 2012. The remaining increase of $3 million was due to other changes in the operational status of various other mines, between idled and operating throughout both periods, none of which were individually material.

• Freight expense is based on weight of coal shipped, negotiated freight rates and method of transportation (i.e. rail, barge, truck, etc.) used by the customers to which CONSOL Energy contractually provides transportation services. Freight revenue is the amount billed to customers for transportation costs incurred. Freight expense is offset by freight revenue. The decrease in freight expense was due to decreased shipments under contracts which CONSOL Energy contractually provides transportation services.

• Other expenses related to the coal segment decreased $10 million due to various transactions that occurred throughout both periods, none of which were individually material.

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TOTAL GAS SEGMENT ANALYSIS for the six months ended June 30, 2013 compared to the six months ended June 30, 2012:

The gas segment had a loss of $5 million before income tax in the six months ended June 30, 2013 compared to earnings of $13 million in the six months ended June 30, 2012.

	For the Six Months Ended													Difference to Six Months Ended
	June 30, 2013													June 30, 2012
	CBM		Shallow Oil and Gas			Marcellus		Other Gas			Total Gas			CBM			Shallow Oil and Gas			Marcellus		Other Gas			Total Gas
Sales:
Produced	$	172	$	66		$	95	$	6		$	339		$	(15	)	$	(3	)	$	47	$	2		$	31
Related Party	2		—			—		—			2			1			—			—		—			1
Total Outside Sales	174		66			95		6			341			(14		)	(3		)	47		2			32
Gas Royalty Interest	—		—			—		31			31			—			—			—		9			9
Purchased Gas			—			—		3			3			—			—			—		1			1
Other Income	—		—			—		24			24			—			—			—		(10		)	(10		)
Total Revenue and Other Income	174		66			95		64			399			(14		)	(3		)	47		2			32
Lifting	19		17			9		2			47			—			(4		)	3		1			—
Ad Valorem, Severance, and Other Taxes	4		6			3		(1		)	12			(1		)	1			1		(1		)	—
Gathering	58		19			19		1			97			7			8			10		—			25
Gas Direct Administrative, Selling & Other	4		4			13		2			23			(5		)	(4		)	8		(1		)	(2		)
Depreciation, Depletion and Amortization	45		30			26		4			105			2			—			8		(2		)	8
General & Administration	—		—			—		22			22			—			—			—		3			3
Gas Royalty Interest	—		—			—		25			25			—			—			—		8			8
Purchased Gas	—		—			—		2			2			—			—			—		1			1
Exploration and Other Costs	—		—			—		21			21			—			—			—		—			—
Other Corporate Expenses	—		—			—		46			46			—			—			—		6			6
Interest Expense	—		—			—		4			4			—			—			—		1			1
Total Cost	130		76			70		128			404			3			1			30		16			50
Earnings Before Income Tax	$	44	$	(10	)	$	25	$	(64	)	$	(5	)	$	(17	)	$	(4	)	$	17	$	(14	)	$	(18	)

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COALBED METHANE (CBM) GAS SEGMENT

The CBM segment contributed $44 million to the total Company earnings before income tax for the six months ended June 30, 2013 compared to $61 million for the six months ended June 30, 2012.

	For the Six Months Ended June 30,
	2013		2012		Variance			Percent Change
Produced Gas CBM sales volumes (in billion cubic feet)	41.6		45.1		(3.5		)	(7.8	)%
Average CBM sales price per thousand cubic feet sold	$	4.17	$	4.18	$	(0.01	)	(0.2	)%
Average CBM lifting costs per thousand cubic feet sold	0.46		0.43		0.03			7.0	%
Average CBM ad valorem, severance, and other taxes per thousand cubic feet sold	0.09		0.12		(0.03		)	(25.0	)%
Average CBM gathering costs per thousand cubic feet sold	1.39		1.12		0.27			24.1	%
Average CBM direct administrative, selling & other costs per thousand cubic feet sold	0.09		0.21		(0.12		)	(57.1	)%
Average CBM depreciation, depletion and amortization costs per thousand cubic feet sold	1.09		0.95		0.14			14.7	%
Total Average CBM costs per thousand cubic feet sold	3.12		2.83		0.29			10.2	%
Average Margin for CBM	$	1.05	$	1.35	$	(0.30	)	(22.2	)%

CBM sales revenues were $174 million in the six months ended June 30, 2013 compared to $188 million for the six months ended June 30, 2012. The $14 million decrease was primarily due to an 7.8% decrease in volumes sold and a 0.2% decrease in average sales price per thousand cubic feet sold. CBM sales volumes decreased 3.5 billion cubic feet for the six months ended June 30, 2013 compared to the 2012 period primarily due to normal well declines without a corresponding increase in wells drilled. Currently, the focus of the gas division is to develop its Marcellus and Utica acreage. The decrease in CBM average sales price was the result of higher average market prices offset by various gas swap transactions that matured in each period. The gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 20.6 billion cubic feet of our produced CBM gas sales volumes for the six months ended June 30, 2013 at an average price of $4.60 per thousand cubic feet. For the six months ended June 30, 2012, these financial hedges represented 23.1 billion cubic feet at an average price of $5.33 per thousand cubic feet.

Total costs for the CBM segment were $130 million for the six months ended June 30, 2013 compared to $127 million for the six months ended June 30, 2012. The increase in total costs for the CBM segment are due to the following items:

•CBM lifting costs were $19 million for the six months ended June 30, 2013 and 2012. The $0.03 per thousand cubic feet increase in average lifting costs during the current year is directly related to the decrease in gas sales volumes.

•CBM ad valorem, severance and other taxes were $4 million for the six months ended June 30, 2013 compared to $5 million for the six months ended June 30, 2012. The $1 million decrease in total dollars was primarily due to a reassessment of our 2012 ad valorem taxes paid to Tazewell County, Virginia resulting in a current period refund. Decreased ad valorem and severance expense resulted in a decrease in average unit costs, offset, in part, by an increase due to the reduction of volumes.

•CBM gathering costs were $58 million for the six months ended June 30, 2013 compared to $51 million for the six months ended June 30, 2012. This $7 million increase in total dollars and the $0.27 per thousand cubic feet increase in average CBM gathering unit costs are related to increased power costs due to higher utility rates, increased pipeline maintenance expense, increased road maintenance expenses and lower volumes sold in the period-to-period comparison.

•CBM direct administrative, selling and other costs for the CBM segment were $4 million for the six months ended June 30, 2013 compared to $9 million for the six months ended June 30, 2012. Direct administrative, selling & other costs attributable to the total gas segment are allocated to the individual gas segments based on a combination of production and employee counts. The decrease in direct administrative, selling & other costs was primarily due to reduced direct administrative labor and CBM volumes representing a smaller proportion of total natural gas volumes sold. Improvements in unit costs were offset, in part, by the reduction in volumes.

•Depreciation, depletion and amortization attributable to the CBM segment was $45 million for the six months ended June 30, 2013 compared to $43 million for the six months ended June 30, 2012. There was approximately $31 million, or $0.75

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per unit-of-production, of depreciation, depletion and amortization related to CBM gas and related well equipment that was reflected on a units-of-production method of depreciation in the six months ended June 30, 2013. The production portion of depreciation, depletion and amortization was $30 million, or $0.66 per unit-of-production in the six months ended June 30, 2012. There was approximately $14 million, or $0.34 average per unit cost of depreciation, depletion and amortization related to gathering and other equipment reflected on a straight line basis for the six months ended June 30, 2013. The non-production related depreciation, depletion and amortization was $13 million, or $0.29 per thousand cubic feet for the six months ended June 30, 2012.

SHALLOW OIL AND GAS SEGMENT

The Shallow Oil and Gas segment had a loss before income tax of $10 million for the six months ended June 30, 2013 compared to a loss before income tax of $6 million for the six months ended June 30, 2012.

	For the Six Months Ended June 30,
	2013			2012			Variance			Percent Change
Produced Gas Shallow Oil and Gas sales volumes (in billion cubic feet)	13.8			14.8			(1.0		)	(6.8	)%
Average Shallow Oil and Gas sales price per thousand cubic feet sold	$	4.78		$	4.63		$	0.15		3.2	%
Average Shallow Oil and Gas lifting costs per thousand cubic feet sold	1.22			1.39			(0.17		)	(12.2	)%
Average Shallow Oil and Gas ad valorem, severance, and other taxes per thousand cubic feet sold	0.40			0.32			0.08			25.0	%
Average Shallow Oil and Gas gathering costs per thousand cubic feet sold	1.39			0.78			0.61			78.2	%
Average Shallow Oil and Gas direct administrative, selling & other costs per thousand cubic feet sold	0.33			0.56			(0.23		)	(41.1	)%
Average Shallow Oil and Gas depreciation, depletion and amortization costs per thousand cubic feet sold	2.14			1.99			0.15			7.5	%
Total Average Shallow Oil and Gas costs per thousand cubic feet sold	5.48			5.04			0.44			8.7	%
Average Margin for Shallow Oil and Gas	$	(0.70	)	$	(0.41	)	$	(0.29	)	70.7	%

Shallow Oil and Gas sales revenues were $66 million for the six months ended June 30, 2013 compared to $69 million for the six months ended June 30, 2012. The $3 million decrease was primarily due to the 6.8% decrease in volumes sold, offset, in part, by a 3.2% increase in average sales price. The increase in shallow oil and gas average sales price is the result of higher average market prices offset by various gas swap transactions that matured in each period. These gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 6.8 billion cubic feet of our produced shallow oil and gas sales volumes for the six months ended June 30, 2013 at an average price of $5.24 per thousand cubic feet. For the six months ended June 30, 2012, these financial hedges represented 9.5 billion cubic feet at an average price of $5.23 per thousand cubic feet.

Total costs for the shallow oil and gas segment were $76 million for the six months ended June 30, 2013 compared to $75 million for the six months ended June 30, 2012. The increase in total costs for the shallow oil and gas segment are due to the following items:

•Shallow Oil and Gas lifting costs were $17 million for the six months ended June 30, 2013 compared to $21 million for the six months ended June 30, 2012. The $4 million decrease to total costs and $0.17 per thousand cubic feet decrease in average unit costs is due to lower road maintenance, lower salt water disposal costs and lower contract services in the current period, offset, in part, by an increase in accretion expense on the well plugging liability.

•Shallow Oil and Gas ad valorem, severance and other taxes were $6 million for the six months ended June 30, 2013 and $5 million for the six months ended June 30, 2012. The $1 million increase to total costs is primarily due to higher average sales prices in the current period. The $0.08 per thousand cubic feet increase to average unit costs is due to higher average sales prices and lower sales volumes.

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•Shallow Oil and Gas gathering costs were $19 million for the six months ended June 30, 2013 compared to $11 million for the six months ended June 30, 2012. Gathering costs increased $8 million primarily due to increased firm transportation costs in the period-to-period comparison.

•Shallow Oil and Gas direct administrative, selling and other costs were $4 million for the six months ended June 30, 2013 compared to $8 million for the six months ended June 30, 2012. Direct administrative, selling and other costs attributable to the total gas segment are allocated to the individual gas segments based on a combination of production and employee counts. The $4 million decrease in the period-to-period comparison is due to reduced direct administrative labor and Shallow Oil and Gas volumes representing a smaller proportion of total natural gas volumes sold. The decrease in costs were offset, in part, by lower sales volumes.

•Depreciation, depletion and amortization costs remained consistent at $30 million for the six months ended June 30, 2013 and 2012. There was approximately $26 million, or $1.87 per unit-of production, of depreciation, depletion and amortization related to Shallow Oil and Gas gas and related well equipment that was reflected on a units-of-production method of depreciation for the six months ended June 30, 2013. There was approximately $26 million, or $1.74 per unit-of-production, of depreciation, depletion and amortization related to Shallow Oil and Gas gas and related well equipment that was reflected on a units-of-production method of depreciation for the six months ended June 30, 2012. There was approximately $4 million, or $0.27 per thousand cubic feet, of depreciation, depletion and amortization related to gathering and other equipment that is reflected on a straight-line basis for the six months ended June 30, 2013. There was $4 million, or $0.25 per thousand cubic feet, of depreciation, depletion and amortization related to gathering and other equipment that is reflected on a straight-line basis for the six months ended June 30, 2012.

MARCELLUS GAS SEGMENT

The Marcellus segment contributed $25 million to the total Company earnings before income tax for the six months ended June 30, 2013 compared to $8 million for the six months ended June 30, 2012.

	For the Six Months Ended June 30,
	2013		2012		Variance			Percent Change
Produced Gas Marcellus sales volumes (in billion cubic feet)	21.0		13.9		7.1			51.1	%
Average Marcellus sales price per thousand cubic feet sold	$	4.51	$	3.41	$	1.10		32.3	%
Average Marcellus lifting costs per thousand cubic feet sold	0.45		0.43		0.02			4.7	%
Average Marcellus ad valorem, severance, and other taxes per thousand cubic feet sold	0.14		0.14		—			—	%
Average Marcellus gathering costs per thousand cubic feet sold	0.89		0.61		0.28			45.9	%
Average Marcellus direct administrative, selling & other costs per thousand cubic feet sold	0.60		0.34		0.26			76.5	%
Average Marcellus depreciation, depletion and amortization costs per thousand cubic feet sold	1.22		1.31		(0.09		)	(6.9	)%
Total Average Marcellus costs per thousand cubic feet sold	3.30		2.83		0.47			16.6	%
Average Margin for Marcellus	$	1.21	$	0.58	$	0.63		108.6	%

The Marcellus segment sales revenues were $95 million for the six months ended June 30, 2013 compared to $48 million for the six months ended June 30, 2012. The $47 million increase is primarily due to a 51.1% increase in volumes sold, and a 32.3% increase in average sales prices in the period-to-period comparison. The increase in sales volumes is primarily due to additional wells coming on-line from our on-going drilling program. The increase in Marcellus average sales price was the result of the improvement in general market prices and sales of natural gas liquids, offset by various gas swap transactions that matured in the six months ended June 30, 2013. These gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 8.8 billion cubic feet of our produced Marcellus gas sales volumes for the six months ended June 30, 2013 at an average price of $4.74 per thousand cubic feet. For the six months ended June 30, 2012, these financial hedges represented 5.5 billion cubic feet at an average price of $4.97 per thousand cubic feet.

Total costs for the Marcellus segment were $70 million for the six months ended June 30, 2013 compared to $40 million for the six months ended June 30, 2012. The increase in total costs for the Marcellus segment are due to the following items:

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•Marcellus lifting costs were $9 million for the six months ended June 30, 2013 compared to $6 million for the six months ended June 30, 2012. The increase primarily relates to an increase in salt water disposal costs, road maintenance costs, and well tending costs.

•Marcellus ad valorem, severance and other taxes were $3 million for the six months ended June 30, 2013 compared to $2 million for the six months ended June 30, 2012. The increase relates to the higher average sales price and an increase in volumes sold, as the per-unit costs remained consistent for the 2013 and 2012 periods.

•Marcellus gathering costs were $19 million for the six months ended June 30, 2013 compared to $9 million for the six months ended June 30, 2012. Average gathering costs increased $0.28 per unit primarily due to increased firm transportation costs, and increased processing fees associated with natural gas liquids.

•Marcellus direct administrative, selling and other costs were $13 million for the six months ended June 30, 2013 compared to $5 million for the six months ended June 30, 2012. Direct administrative, selling and other costs attributable to the total gas segment are allocated to the individual gas segments based on a combination of production and employee counts. The increase in direct administrative, selling & other costs was primarily due to Marcellus volumes representing a larger proportion of total natural gas volumes. The impact on average unit costs from the increase in direct administrative labor was offset by higher volumes sold.

•Depreciation, depletion and amortization costs were $26 million for the six months ended June 30, 2013 compared to $18 million for the six months ended June 30, 2012. There was approximately $25 million, or $1.20 per unit-of-production, of depreciation, depletion and amortization related to Marcellus gas and related well equipment that was reflected on a units-of-production method of depreciation in the six months ended June 30, 2013. There was approximately $16 million, or $1.17 per unit-of-production, of depreciation, depletion and amortization related to Marcellus gas and related well equipment that was reflected on a units-of-production method of depreciation for the six months ended June 30, 2012. There was approximately $1 million, or $0.02 per thousand cubic feet, of depreciation, depletion and amortization related to gathering and other equipment that was reflected on a straight line basis for the six months ended June 30, 2013. There was $2 million, or $0.14 per thousand cubic feet, of depreciation, depletion and amortization related to gathering and other equipment reflected on a straight line basis for the six months ended June 30, 2012.

OTHER GAS SEGMENT

The other gas segment includes activity not assigned to the CBM, Shallow Oil and Gas or Marcellus gas segments. This segment includes purchased gas activity, gas royalty interest activity, exploration and other costs, other corporate expenses, and miscellaneous operational activity not assigned to a specific gas segment.

Other gas sales volumes are primarily related to production from the Chattanooga Shale in Tennessee and the Utica Shale in Ohio. Revenue from these operations were approximately $6 million for the six months ended June 30, 2013 and $4 million for the six months ended June 31, 2012. Total costs related to these other sales were $8 million for the six months ended June 30, 2013 and $11 million for the six months ended June 30, 2012. A per unit analysis of the other operating costs in Chattanooga Shale and Utica Shale is not meaningful due to the low volumes sold in the period-to-period analysis.

Royalty interest gas sales represent the revenues related to the portion of production belonging to royalty interest owners sold by the CONSOL Energy gas segment. Royalty interest gas sales revenue was $31 million for the six months ended June 30, 2013 compared to $22 million for the six months ended June 30, 2012. The changes in market prices, contractual differences among leases, and the mix of average and index prices used in calculating royalties contributed to the period-to-period increase.

	For the Six Months Ended June 30,
	2013		2012		Variance			Percent Change
Gas Royalty Interest Sales Volumes (in billion cubic feet)	7.4		8.3		(0.9		)	(10.8	)%
Average Sales Price Per thousand cubic feet	$	4.21	$	2.61	$	1.60		61.3	%

Purchased gas sales volumes represent volumes of gas sold at market prices that were purchased from third-party producers. Purchased gas sales revenues were $3 million for the six months ended June 30, 2013 and $2 million for the six months ended June 30, 2012.

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	For the Six Months Ended June 30,
	2013		2012		Variance		Percent Change
Purchased Gas Sales Volumes (in billion cubic feet)	0.7		0.6		0.1		16.7	%
Average Sales Price Per thousand cubic feet	$	3.69	$	2.70	$	0.99	36.7	%

Other income was $24 million for the six months ended June 30, 2013 compared to $34 million for the six months ended June 30, 2012. The $10 million change was primarily due to a $7 million decrease in interest income related to the timing of collections on the notes receivable from the Noble joint venture transaction, a $2 million decrease in gains on dispositions of non-core acreage and equipment, and a $1 million decrease in various other transactions, none of which are individually material.

General and administrative costs are allocated to the total gas segment based on percentage of total revenue and percentage of total projected capital expenditures. Costs were $22 million for the six months ended June 30, 2013 and $19 million for the six months ended June 30, 2012. Refer to the discussion of total company general and administrative costs contained in the section "Net Income Attributable to CONSOL Energy Shareholders"of this quarterly report for a detailed cost explanation.

Royalty interest gas costs represent the costs related to the portion of production belonging to royalty interest owners sold by the CONSOL Energy gas segment. Royalty interest gas costs were $25 million for the six months ended June 30, 2013 compared to $17 million for the six months ended June 30, 2012. The changes in market prices, contractual differences among leases, and the mix of average and index prices used in calculating royalties contributed to the period-to-period change.

	For the Six Months Ended June 30,
	2013		2012		Variance			Percent Change
Gas Royalty Interest Sales Volumes (in billion cubic feet)	7.4		8.3		(0.9		)	(10.8	)%
Average Cost Per thousand cubic feet sold	$	3.42	$	2.08	$	1.34		64.4	%

Purchased gas volumes represent volumes of gas purchased from third-party producers that we sell. The higher average cost per thousand cubic feet is due to overall price changes and contractual differences among customers in the period-to-period comparison. Purchased gas costs were $2 million for the six months ended June 30, 2013 and $1 million for the six months ended June 30, 2012.

	For the Six Months Ended June 30,
	2013		2012		Variance		Percent Change
Purchased Gas Volumes (in billion cubic feet)	0.7		0.6		0.1		16.7	%
Average Cost Per thousand cubic feet sold	$	2.70	$	1.94	$	0.76	39.2	%

Exploration and other costs remained consistent at $21 million for the six months ended June 30, 2013 and 2012.

	For the Six Months Ended June 30,
	2013		2012		Variance			Percent Change
Marcellus Title Defects	$	9	$	—	$	9		100	%
Exploration	9		9		—			—	%
Lease Expiration Costs	3		12		(9		)	(75	)%
Total Exploration and Other Costs	$	21	$	21	$	—		—	%

• As part of the title defect process the company is working through with its joint venture partner, Noble Energy, CONSOL Energy conceded title defects on acreage which had a book value to CONSOL Energy of $9 million.

• Exploration expense remained consistent in the period-to-period comparison.

• Lease expiration costs relate to locations where CONSOL Energy allowed the primary term lease to expire because of unfavorable drilling economics. The $9 million decrease is due to CONSOL Energy allowing less leases to expire in the current period when compared with the prior period.

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Other corporate expenses were $46 million for the six months ended June 30, 2013 compared to $40 million for the six months ended June 30, 2012. The $6 million increase in the period-to-period comparison was made up of the following items:

	For the Six Months Ended June 30,
	2013		2012		Variance			Percent Change
Unutilized firm transportation	$	16	$	5	$	11		220	%
Stock-based compensation	14		10		4			40	%
Legal fees	2		2		—			—	%
Bank fees	3		4		(1		)	(25	)%
PA Impact fees	—		4		(4		)	(100	)%
Short-term incentive compensation	9		14		(5		)	(35.7	)%
Other	2		1		1			100	%
Total Other Corporate Expenses	$	46	$	40	$	6		15	%

• Unutilized firm transportation costs represent pipeline transportation capacity the gas segment has obtained to enable gas production to flow uninterrupted as sales volumes increase. The $11 million increase is due to increased firm transportation capacity which has not been utilized by active operations.

• Stock-based compensation was higher in the period-to-period comparison primarily due to additional non-cash amortization expense and accelerated non-cash amortization for retiree-eligible employees who received awards under the new CONSOL Share Unit (CSU) program, when compared to the prior year's quarter.  The new program replaces several previously provided long-term executive compensation award programs.  The compensation expense of the CSU program will not be materially different from the total expense of the previous programs over the three-year performance period.

• Legal fees remained consistent in the period-to-period comparison.

• Bank Fees decreased $1 million due to various transactions that occurred throughout both periods, none of which were individually material.

• PA impact fees are related to legislation in the state of Pennsylvania (Act 13 of 2012, House Bill 1950) which was signed into law during the first quarter of 2012. This legislation permits Pennsylvania counties to impose annual fees on unconventional gas wells located within their borders. As part of the legislation, all unconventional wells which were drilled prior to January 1, 2012 were assessed an initial fee related to periods prior to 2012. The $4 million represents this one-time initial assessment on wells drilled prior to January 1, 2012. On-going PA impact fees which relate to current year wells drilled are included as part of ad valorem, severance and other taxes in the Marcellus gas segment.

• The short-term incentive compensation program is designed to increase compensation to eligible employees when CNX Gas reaches predetermined targets for safety, production and unit costs. Short-term incentive compensation expense was lower for the 2013 period compared to the 2012 period due to the projected lower payouts.

• Other corporate related expense increased $1 million due to various transactions that occurred throughout both periods, none of which were individually material.

Interest expense related to the gas segment was $4 million for the six months ended June 30, 2013 compared to $3 million for the six months ended June 30, 2012. Interest was incurred by the gas segment on the CNX Gas revolving credit facility and a capital lease. The $1 million increase was primarily due to higher levels of borrowings on the revolving credit facility throughout the period-to-period comparison.

OTHER SEGMENT ANALYSIS for the six months ended June 30, 2013 compared to the six months ended June 30, 2012:

The other segment includes activity from the sales of industrial supplies, the transportation operations and various other corporate activities that are not allocated to the coal or gas segment. The other segment had a loss before income tax of $153 million for the six months ended June 30, 2013 compared to a loss before income tax of $102 million for the six months ended June 30, 2012. The other segment also includes total Company income tax expense of $15 million for the six months ended June 30, 2013 compared to $80 million for the six months ended June 30, 2012.

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	For the Six Months Ended June 30,
	2013			2012			Variance			Percent Change
Sales—Outside	$	169		$	193		$	(24	)	(12.4	)%
Other Income	8			7			1			14.3	%
Total Revenue	177			200			(23		)	(11.5	)%
Cost of Goods Sold and Other Charges	207			172			35			20.3	%
Depreciation, Depletion & Amortization	13			12			1			8.3	%
Taxes Other Than Income Tax	6			6			—			—	%
Interest Expense	104			112			(8		)	(7.1	)%
Total Costs	330			302			28			9.3	%
Loss Before Income Tax	(153		)	(102		)	(51		)	50.0	%
Income Tax	15			80			(65		)	(81.3	)%
Net Loss	$	(168	)	$	(182	)	$	14		(7.7	)%

Industrial supplies:

Outside sales from industrial supplies was $108 million for the six months ended June 30, 2013 compared to $134 million for the six months ended June 30, 2012. The decrease of $26 million was primarily related to lower sales volumes.

Total costs related to industrial supply sales were $106 million for the six months ended June 30, 2013 compared to $130 million for the six months ended June 30, 2012. The decrease of $24 million was primarily related to lower sales volumes and various changes in inventory costs, none of which were individually material.

Transportation operations:

Outside sales from transportation operations was $61 million for the six months ended June 30, 2013 compared to $59 million for the six months ended June 30, 2012. The increase of $2 million was primarily attributable to higher per ton thru-put rates at the CNX Marine Terminal offset, in part, by decreased thru-put.

Total costs related to the transportation operations were $50 million for the six months ended June 30, 2013 compared to $42 million for the six months ended June 30, 2012. The increase of $8 million was due to various items in both periods, none of which were individually material.

Miscellaneous other:

Additional other income of $8 million was recognized for the six months ended June 30, 2013 compared to $7 million for the six months ended June 30, 2012. The $1 million increase was primarily due to an increase in interest income.

Other corporate costs in the other segment were $174 million for the six months ended June 30, 2013 compared to $130 million for the six months ended June 30, 2012. Other corporate costs increased due to the following items:

	For the Six Months Ended June 30,
	2013		2012		Variance
Pension Settlement	$	32	$	—	$	32
CNX Gas shareholder settlement	20		—		20
Bank fees	7		7		—
Interest Expense	104		113		(9		)
Other	11		10		1
	$	174	$	130	$	44

• Pension settlement adjustment is the result of accounting rules requiring acceleration of unrecognized actuarial losses when lump sum payments from a plan exceed the annual projected service and interest costs of the plan.

• The CNX Gas shareholder settlement is the result of an agreement in principle for resolution of the class actions brought by shareholders of CNX Gas challenging the tender offer by CONSOL Energy to acquire all the shares of CNX Gas common stock that CONSOL Energy did not already own for $38.25 per share in May 2010. The total

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settlement provides for a payment to the plaintiffs of $42.73 million, of which the Company expects to pay $20.2 million. This settlement is subject to court approval and to the execution of final agreements with the parties.

• Bank Fees remained consistent throughout both periods.

• Interest expense decreased $9 million primarily due to an increase in capitalized interest due to higher capital expenditures for major construction projects in the current period.

• Other corporate items increased $1 million due to various transactions that occurred throughout both periods, none of which were individually material.

Income Taxes:

The effective income tax rate was 2,969.4% for the six months ended June 30, 2013 compared to 24.3% for the six months ended June 30, 2012. The effective rates for the six months ended June 30, 2013 and 2012 were calculated using the annual effective rate projection on recurring earnings and include tax liabilities related to certain discrete transactions. The relationship between pre-tax earnings and percentage depletion impacts the effective tax rate. See Note 5—Income Taxes of the Notes to the Condensed Consolidated Financial Statements of this Form 10-Q for additional information. 

	For the Six Months Ended June 30,
	2013			2012			Variance			Percent Change
Total Company Earnings Before Income Tax	$	1		$	330		$	(329	)	(99.6	)%
Income Tax Expense	$	15		$	80		$	(65	)	(80.9	)%
Effective Income Tax Rate	2,969.4		%	24.3		%	2,945.1		%

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Liquidity and Capital Resources

CONSOL Energy generally has satisfied its working capital requirements and funded its capital expenditures and debt service obligations with cash generated from operations and proceeds from borrowings. CONSOL Energy's $1.5 billion Senior Secured Credit Agreement expires April 12, 2016. 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 $1.5 billion of borrowings and letters of credit. CONSOL Energy can request an additional $250 million 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 (EBITDA), measured quarterly. The facility includes a minimum interest coverage ratio covenant of no less than 2.50 to 1.00, measured quarterly. The interest coverage ratio is calculated as the ratio of EBITDA to cash interest expense of CONSOL Energy and certain of its subsidiaries. The interest coverage ratio was 3.44 to 1.00 at June 30, 2013. The facility includes a maximum leverage ratio covenant of no more than 4.50 to 1.00, measured quarterly. The leverage ratio is calculated as the ratio of financial covenant debt to twelve-month trailing EBITDA for CONSOL Energy and certain subsidiaries. Financial covenant debt is comprised of the outstanding indebtedness and specific letters of credit, less cash on hand, for CONSOL Energy and certain of its subsidiaries. EBITDA, as used in the covenant calculation, excludes non-cash compensation expenses, non-recurring transaction expenses, uncommon gains and losses, gains and losses on discontinued operations and includes cash distributions received from affiliates plus pro-rata earnings from material acquisitions. The leverage ratio was 3.65 to 1.00 at June 30, 2013. The facility also includes a senior secured leverage ratio covenant of no more than 2.00 to 1.00, measured quarterly. The senior secured leverage ratio is calculated as the ratio of secured debt to EBITDA. Secured debt is defined as the outstanding borrowings and letters of credit on the revolving credit facility. The senior secured leverage ratio was 0.12 to 1.00 at June 30, 2013. 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 company and amend, modify or restate, in any material way, the senior unsecured notes. At June 30, 2013, the facility had no outstanding borrowings and $100 million of letters of credit outstanding, leaving $1.4 billion of unused capacity. From time to time, CONSOL Energy is required to post financial assurances to satisfy contractual and other requirements generated in the normal course of business. Some of these assurances are posted to comply with federal, state or other government agencies statutes and regulations. We sometimes use letters of credit to satisfy these requirements and these letters of credit reduce our borrowing facility capacity.

CONSOL Energy also has an accounts receivable securitization facility. This facility allows the Company to receive, on a revolving basis, up to $200 million of short-term funding and letters of credit. The accounts receivable facility supports sales, on a continuous basis to financial institutions, of eligible trade accounts receivable. CONSOL Energy has agreed to continue servicing the sold receivables for the financial institutions for a fee based upon market rates for similar services. The cost of funds is based on commercial paper rates plus a charge for administrative services paid to financial institutions. At June 30, 2013, eligible accounts receivable totaled approximately $181 million. At June 30, 2013, the facility had $41 million of outstanding borrowings and $159 million of letters of credit outstanding.

CNX Gas' $1.0 billion 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 $1.0 billion for borrowings and letters of credit. CNX Gas can request an additional $250 million increase in the aggregate borrowing limit amount. Fees and interest rate spreads are based on the percentage of facility utilization, measured quarterly. The facility includes a minimum interest coverage ratio covenant of no less than 3.00 to 1.00, measured quarterly. The interest coverage ratio is calculated as the ratio of EBITDA to cash interest expense for CNX Gas and its subsidiaries. The interest coverage ratio was 36.85 to 1.00 at June 30, 2013. The facility also includes a maximum leverage ratio covenant of no more than 3.50 to 1.00, measured quarterly. The leverage ratio is calculated as the ratio of financial covenant debt to twelve-month trailing EBITDA for CNX Gas and its subsidiaries. Financial covenant debt is comprised of the outstanding indebtedness and letters of credit, less cash on hand, for CNX Gas and its subsidiaries. EBITDA, as used in the covenant calculation, excludes non-cash compensation expenses, non-recurring transaction expenses, gains and losses on the sale of assets, uncommon gains and losses, gains and losses on discontinued operations and includes cash distributions received from affiliates plus pro-rata earnings from material acquisitions. The leverage ratio was 1.20 to 1.00 at June 30, 2013. Covenants in the facility limit CNX Gas' ability to dispose of assets, make investments, pay dividends and merge with another company. The credit facility allows unlimited investments in joint ventures for the development and operation of gas gathering systems and provides for $600 million of loans, advances and dividends from CNX Gas to CONSOL Energy. Investments in CONE are unrestricted. At June 30, 2013, the facility had $173 million drawn and $70 million of letters of credit outstanding, leaving $757 million of unused capacity.

Uncertainty in the financial markets brings additional potential risks to CONSOL Energy. The risks include declines in our stock price, less availability and higher costs of additional credit, potential counterparty defaults, and commercial bank failures. Financial market disruptions may impact our collection of trade receivables. As a result, CONSOL Energy regularly

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monitors the creditworthiness of our customers. We believe that our current group of customers are financially sound and represent no abnormal business risk.

CONSOL Energy believes that cash generated from operations and our borrowing capacity will be sufficient to meet our working capital requirements, anticipated capital expenditures (other than major acquisitions), scheduled debt payments, anticipated dividend payments and to provide required letters of credit. Nevertheless, the ability of CONSOL Energy to satisfy its working capital requirements, to service its debt obligations, to fund planned capital expenditures or to pay dividends will depend upon future operating performance, which will be affected by prevailing economic conditions in the coal and gas industries and other financial and business factors, some of which are beyond CONSOL Energy’s control.

In order to manage the market risk exposure of volatile natural gas prices in the future, CONSOL Energy enters into various physical gas supply transactions with both gas marketers and end users for terms varying in length. CONSOL Energy has also entered into various gas swap transactions that qualify as financial cash flow hedges, which exist parallel to the underlying physical transactions. The fair value of these contracts was a net asset of $116 million at June 30, 2013. The ineffective portion of these contracts was a loss of $3.8 million and $2.7 million during the three and six months ended June 30, 2013. No issues related to our hedge agreements have been encountered to date.

CONSOL Energy frequently evaluates potential acquisitions. CONSOL Energy has funded acquisitions with cash generated from operations and a variety of other sources, depending on the size of the transaction, including debt and equity financing. There can be no assurance that additional capital resources, including debt and equity financing, will be available to CONSOL Energy in the future on terms which CONSOL Energy finds acceptable, or at all.

Cash Flows (in millions)

	For the Six Months Ended June 30,
	2013			2012			Change
Cash flows from operating activities	$	393		$	368		$	25
Cash used in investing activities	$	(465	)	$	(484	)	$	19
Cash used in financing activities	$	122		$	(59	)	$	181

Cash flows provided by operating activities changed in the period-to-period comparison primarily due to the following items:

• Operating cash flow decreased $265 million in 2013 due to lower net income in the period-to-period comparison.

• Operating cash flows increased $157 million in the period-to-period comparison due to changes in the gains on the sale of assets. See Note 2 - Acquisitions and Dispositions in the Notes to the Unaudited Consolidated Financial Statements for additional details.

• Other changes in operating assets, operating liabilities, other assets and other liabilities which occurred throughout both periods also contributed to the increase in operating cash flows.

Net cash used in investing activities changed in the period-to-period comparison primarily due to the following items:

• Capital expenditures increased $44 million in the period-to-period comparison due to:

◦ Coal segment capital expenditures decreased $94 million. The decrease was comprised of $54 million related to the completion of the Northern West Virginia RO system as well as a $55 million decrease in various miscellaneous transactions that occurred throughout both periods, none of which were individually material. Mineral lease expenditures associated with our advance mining royalties and leased coal assets also decreased $5 million in 2013. The decrease is offset, in part, by an increase of $20 million in longwall shield projects;

◦ Gas segment capital expenditures increased $154 million. The increase was comprised of increased drilling costs in the Marcellus and Utica plays, CONSOL Energy's agreement to lease oil and gas rights from the Allegheny County Airport Authority, land acquisitions in Monroe and Noble Counties in Ohio, and various other individually insignificant projects;

◦ Other capital expenditures decreased $16 million due to various miscellaneous transactions that occurred throughout both periods, none of which were individually material.

• Proceeds from the sale of assets decreased $11 million in the period-to-period comparison due to:

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◦ $25 million received in June 2013 related to the sale of Potomac Coal reserves;

◦ $68 million received in May 2013 related to the Robinson Run longwall shield sale-leaseback;

◦ $64 million received in March 2013 related to the Shoemaker Mine longwall shield sale-leaseback;

◦ $71 million received in January 2013 related to the Bailey Mine longwall shield sale-leaseback;

◦ $170 million received in June 2012 related to the sale of Youngs Creek;

◦ $26 million received in April 2012 related to sale of Elk Creek; and

◦ $43 million decrease due to various other transactions that occurred throughout both periods, none of which were individually material.

◦ See Note 2 - Acquisitions and Dispositions, in the Notes to the Unaudited Consolidated Financial Statements included in this Form 10-Q for more information.

• Distributions from/investments in equity affiliates increased $5 million due to various miscellaneous transactions that occurred throughout both periods, none of which were individually material.

• The release of $69 million of restricted cash of which $48 million is associated with the Ram River & Scurry Canadian asset proceeds received during December 2012. The remaining $21 million is associated with the Ryerson Dam Settlement.

Net cash used in financing activities changed in the period-to-period comparison primarily due to the following items:

• In 2013, CONSOL Energy received $173 million of short term borrowings under the revolving credit facilities.

• In 2013, CONSOL Energy repaid $30 million of borrowings related to a miscellaneous short term note payable and only $5 million in the 2012 period.

• The accelerated declaration and payment of the regular quarterly dividend in the fourth quarter of 2012 resulted in no dividends paid in the first quarter of 2013 and $29 million in dividends paid in the second quarter of 2013. As compared to $57 million in dividends paid in the six months ended June 30, 2012.

• In 2013, CONSOL Energy received $3 million of borrowing under its Securitization Facility.

• $2 million in additional cash received due to various other transactions that occurred throughout both periods, none of which were individually material.

The following is a summary of our significant contractual obligations at June 30, 2013 (in thousands):

	Payments due by Year
	Less Than 1 Year		1-3 Years		3-5 Years		More Than 5 Years		Total
Short-term Notes Payable	$	173,000	$	—	$	—	$	—	$	173,000
Borrowings Under Securitization Facility	40,719		—		—		—		40,719
Purchase Order Firm Commitments	174,317		6,297		—		—		180,614
Gas Firm Transportation	84,063		157,943		131,751		405,934		779,691
Long-Term Debt	4,585		8,488		1,505,220		1,610,292		3,128,585
Interest on Long-Term Debt	245,428		491,294		371,007		307,353		1,415,082
Capital (Finance) Lease Obligations	8,837		13,967		11,777		22,006		56,587
Interest on Capital (Finance) Lease Obligations	3,702		5,731		4,101		2,831		16,365
Operating Lease Obligations	131,738		242,520		171,199		155,385		700,842
Long-Term Liabilities—Employee Related (a)	223,458		441,956		435,786		2,307,981		3,409,181
Other Long-Term Liabilities (b)	242,092		184,738		82,254		482,786		991,870
Total Contractual Obligations (c)	$	1,331,939	$	1,552,934	$	2,713,095	$	5,294,568	$	10,892,536

 _________________________

(a) Long-Term Liabilities - Employee Related include other post-employment benefits, work-related injuries and illnesses. Estimated salaried retirement contributions required to meet minimum funding standards under ERISA are excluded from the pay-out table due to the uncertainty regarding amounts to be contributed. Estimated 2013 contributions are expected to approximate $50 million.

(b) Other long-term liabilities include mine reclamation and closure and other long-term liability costs.

(c) The significant obligation table does not include obligations to taxing authorities due to the uncertainty surrounding the ultimate settlement of amounts and timing of these obligations.

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Debt

At June 30, 2013, CONSOL Energy had total long-term debt and capital lease obligations of $3.185 billion outstanding, including the current portion of long-term debt of $13 million. This long-term debt consisted of:

• An aggregate principal amount of $1.50billion of 8.00% senior unsecured notes due in April 2017. Interest on the notes is payable April 1 and October 1 of each year. Payment of the principal and interest on the notes are guaranteed by most of CONSOL Energy’s subsidiaries.

• An aggregate principal amount of $1.25billion of 8.25% senior unsecured notes due in April 2020. Interest on the notes is payable April 1 and October 1 of each year. Payment of the principal and interest on the notes are guaranteed by most of CONSOL Energy’s subsidiaries.

• An aggregate principal amount of $250million of 6.375% notes due in March 2021. Interest on the notes is payable March 1 and September 1 of each year. Payment of the principal and interest on the notes are guaranteed by most of CONSOL Energy's subsidiaries.

• An aggregate principal amount of $103million of industrial revenue bonds which were issued to finance the Baltimore port facility and bear interest at 5.75% per annum and mature in September 2025. Interest on the industrial revenue bonds is payable March 1 and September 1 of each year.

• Advance royalty commitments of $20million with an average interest rate of 7.43% per annum.

• An aggregate principal amount of $5million on other various rate notes maturing through June 2031.

• An aggregate principal amount of $57million of capital leases with a weighted average interest rate of 6.35% per annum.

At June 30, 2013, CONSOL Energy also had no outstanding borrowings and had approximately $100 million of letters of credit outstanding under the $1.5 billion senior secured revolving credit facility.

At June 30, 2013, CONSOL Energy had $41 million in outstanding borrowings and had $159 million of letters of credit outstanding under the accounts receivable securitization facility.

At June 30, 2013, CNX Gas, a wholly owned subsidiary of CONSOL Energy, had $173 million in outstanding borrowings and approximately $70 million of letters of credit outstanding under its $1.0 billion secured revolving credit facility.

Total Equity and Dividends

CONSOL Energy had total equity of $4.0 billion at June 30, 2013 and at December 31, 2012. Total equity remained consistent in the period-to-period analysis primarily due to a decrease in actuarial liabilities associated with the March 31, 2013 and June 30, 2013 pension plan remeasurements, an increase related to stock-based compensation, offset by changes in the fair value of cash flow hedges and treasury stock activity. See the Consolidated Statements of Stockholders' Equity in Item 1 of this Form 10-Q for additional details.

Dividend information for the current year to date were as follows:

Declaration Date	Amount Per Share		Record Date	Payment Date
July 26, 2013	$	0.125	August 9, 2013	August 23, 2013
April 26, 2013	$	0.125	May 10, 2013	May 24, 2013

The declaration and payment of dividends by CONSOL Energy is subject to the discretion of CONSOL Energy’s Board of Directors, and no assurance can be given that CONSOL Energy will pay dividends in the future. CONSOL Energy’s Board of Directors determines whether dividends will be paid quarterly. The determination to pay dividends will depend upon, among other things, general business conditions, CONSOL Energy’s financial results, contractual and legal restrictions regarding the payment of dividends by CONSOL Energy, planned investments by CONSOL Energy and such other factors as the Board of Directors deems relevant. Our credit facility limits our ability to pay dividends in excess of an annual rate of $0.40 per share when our leverage ratio exceeds 4.50 to 1.00 or our availability is less than or equal to $100 million. The leverage ratio was 3.65 to 1.00 and our availability was approximately $1.4 billion at June 30, 2013. The credit facility does not permit dividend payments in the event of default. The indentures to the 2017, 2020 and 2021 notes limit dividends to $0.40 per share annually unless several conditions are met. Conditions include no defaults, ability to incur additional debt and other payment limitations under the indentures. There were no defaults in the six months ended June 30, 2013.

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Off-Balance Sheet Transactions

CONSOL Energy does not maintain off-balance sheet transactions, arrangements, obligations or other relationships with unconsolidated entities or others that are reasonably likely to have a material current or future effect on CONSOL Energy’s financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources which are not disclosed in the Notes to the Unaudited Consolidated Financial Statements. CONSOL Energy participates in various multi-employer benefit plans such as the UMWA 1974 Pension Plan, the UMWA Combined Benefit Fund and the UMWA 1993 Benefit Plan which generally accepted accounting principles recognize on a pay as you go basis. These benefit arrangements may result in additional liabilities that are not recognized on the balance sheet at June 30, 2013. The various multi-employer benefit plans are discussed in Note 17—Other Employee Benefit Plans in the Notes to the Audited Consolidated Financial Statements in Item 8 of the December 31, 2012 Form 10-K. CONSOL Energy also uses a combination of surety bonds, corporate guarantees and letters of credit to secure our financial obligations for employee-related, environmental, performance and various other items which are not reflected on the balance sheet at June 30, 2013. Management believes these items will expire without being funded. See Note 11—Commitments and Contingencies in the Notes to the Unaudited Consolidated Financial Statements included in Item 1 of this Form 10-Q for additional details of the various financial guarantees that have been issued by CONSOL Energy.

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.

Forward-Looking Statements

We are including the following cautionary statement in this Quarterly Report on Form 10-Q to make applicable and take advantage of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 for any forward-looking statements made by, or on behalf, of us. With the exception of historical matters, the matters discussed in this Quarterly Report on Form 10-Q are forward-looking statements (as defined in Section 21E of the Exchange Act) that involve risks and uncertainties that could cause actual results to differ materially from projected results. Accordingly, investors should not place undue reliance on forward-looking statements as a prediction of actual results. The forward-looking statements may include projections and estimates concerning the timing and success of specific projects and our future production, revenues, income and capital spending. When we use the words “believe,” “intend,” “expect,” “may,” “should,” “anticipate,” “could,” “estimate,” “plan,” “predict,” “project,” or their negatives, or other similar expressions, the statements which include those words are usually forward-looking statements. When we describe strategy that involves risks or uncertainties, we are making forward-looking statements. The forward-looking statements in this Quarterly Report on Form 10-Q speak only as of the date of this Quarterly Report on Form 10-Q; we disclaim any obligation to update these statements unless required by securities law, and we caution you not to rely on them unduly. We have based these forward-looking statements on our current expectations and assumptions about future events. While our management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond our control. These risks, contingencies and uncertainties relate to, among other matters, the following:

• deterioration in global economic conditions in any of the industries in which our customers operate, or sustained uncertainty in financial markets cause conditions we cannot predict;

• an extended decline in demand for or prices we receive for our coal and natural gas affecting our operating results and cash flows;

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• our customers extending existing contracts or entering into new long-term contracts for coal;

• our reliance on major customers;

• our inability to collect payments from customers if their creditworthiness declines;

• the disruption of rail, barge, gathering, processing and transportation facilities and other systems that deliver our coal and natural gas to market;

• a loss of our competitive position because of the competitive nature of the coal and natural gas industries, or a loss of our competitive position because of overcapacity in these industries impairing our profitability;

• our inability to maintain satisfactory labor relations;

• coal users switching to other fuels in order to comply with various environmental standards related to coal combustion emissions;

• the impact of potential, as well as any adopted regulations relating to greenhouse gas emissions on the demand for coal and natural gas;

• foreign currency fluctuations could adversely affect the competitiveness of our coal abroad;

• the risks inherent in coal and natural gas operations being subject to unexpected disruptions, including geological conditions, equipment failure, timing of completion of significant construction or repair of equipment, fires, explosions, accidents and weather conditions which could impact financial results;

• decreases in the availability of, or increases in, the price of commodities or capital equipment used in our mining operations;

• decreases in the availability of, an increase in the prices charged by third party contractors or, failure of third party contractors to provide quality services to us in a timely manner could impact our profitability;

• obtaining and renewing governmental permits and approvals for our coal and gas operations;

• the effects of government regulation on the discharge into the water or air, and the disposal and clean-up of, hazardous substances and wastes generated during our coal and natural gas operations;

• our ability to find adequate water sources for our use in gas drilling, or our ability to dispose of water used or removed from strata in connection with our gas operations at a reasonable cost and within applicable environmental rules;

• the effects of stringent federal and state employee health and safety regulations, including the ability of regulators to shut down a mine or natural gas well;

• the potential for liabilities arising from environmental contamination or alleged environmental contamination in connection with our past or current coal and gas operations;

• the effects of mine closing, reclamation, gas well closing and certain other liabilities;

• uncertainties in estimating our economically recoverable coal and gas reserves;

• defects may exist in our chain of title and we may incur additional costs associated with perfecting title for coal or gas rights on some of our properties or failing to acquire these additional rights may result in a reduction of our estimated reserves;

• the impacts of various asbestos litigation claims;

• the outcomes of various legal proceedings, which are more fully described in our reports filed under the Securities Exchange Act of 1934;

• increased exposure to employee-related long-term liabilities;

• exposure to multi-employer pension plan liabilities;

• minimum funding requirements by the Pension Protection Act of 2006 (the Pension Act) coupled with the significant investment and plan asset losses suffered during the recent economic decline has exposed us to making additional required cash contributions to fund the pension benefit plans which we sponsor and the multi-employer pension benefit plans in which we participate;

• lump sum payments made to retiring salaried employees pursuant to our defined benefit pension plan exceeding total service and interest cost in a plan year;

• acquisitions that we recently have completed or may make in the future including the accuracy of our assessment of the acquired businesses and their risks, achieving any anticipated synergies, integrating the acquisitions and unanticipated changes that could affect assumptions we may have made and divestitures we anticipate may not occur or produce anticipated proceeds;

• the terms of our existing joint ventures restrict our flexibility, actions taken by the other party in our gas joint ventures may impact our financial position and various circumstances could cause us not to realize the benefits we anticipate receiving from these joint ventures;

• the anti-takeover effects of our rights plan could prevent a change of control;

• risks associated with our debt;

• replacing our natural gas reserves, which if not replaced, will cause our gas reserves and gas production to decline;

• our hedging activities may prevent us from benefiting from price increases and may expose us to other risks;

• changes in federal or state income tax laws, particularly in the area of percentage depletion and intangible drilling costs, could cause our financial position and profitability to deteriorate; and

• other factors discussed in our 2012 Form 10-K under “Risk Factors,” which is on file at the Securities and Exchange Commission.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

In addition to the risks inherent in operations, CONSOL Energy is exposed to financial, market, political and economic risks. The following discussion provides additional detail regarding CONSOL Energy's exposure to the risks of changing commodity prices, interest rates and foreign exchange rates.

CONSOL Energy is exposed to market price risk in the normal course of selling natural gas production and to a lesser extent in the sale of coal. CONSOL Energy sells coal under both short-term and long-term contracts with fixed price and/or indexed price contracts that reflect market value. CONSOL Energy uses fixed-price contracts, collar-price contracts and derivative commodity instruments that qualify as cash-flow hedges under the Derivatives and Hedging Topic of the Financial Accounting Standards Board Accounting Standards Codification to minimize exposure to market price volatility in the sale of natural gas. Our risk management policy prohibits the use of derivatives for speculative purposes.

CONSOL Energy has established risk management policies and procedures to strengthen the internal control environment of the marketing of commodities produced from its asset base. All of the derivative instruments without other risk assessment procedures are held for purposes other than trading. They are used primarily to mitigate uncertainty, volatility and cover underlying exposures. CONSOL Energy's market risk strategy incorporates fundamental risk management tools to assess market price risk and establish a framework in which management can maintain a portfolio of transactions within pre-defined risk parameters.

CONSOL Energy believes that the use of derivative instruments, along with our risk assessment procedures and internal controls, mitigates our exposure to material risks. However, the use of derivative instruments without other risk assessment procedures could materially affect CONSOL Energy's results of operations depending on market prices. Nevertheless, we believe that use of these instruments will not have a material adverse effect on our financial position or liquidity.

For a summary of accounting policies related to derivative instruments, see Note 1—Significant Accounting Policies in the Notes to the Audited Consolidated Financial Statements in Item 8 of CONSOL Energy's 2012 Form 10-K.

A sensitivity analysis has been performed to determine the incremental effect on future earnings, related to open derivative instruments at June 30, 2013. A hypothetical 10 percent decrease in future natural gas prices would increase future earnings related to derivatives by $45.2 million. Similarly, a hypothetical 10 percent increase in future natural gas prices would decrease future earnings related to derivatives by $45.1 million.

CONSOL Energy’s interest expense is sensitive to changes in the general level of interest rates in the United States. At June 30, 2013, CONSOL Energy had $3,185 million aggregate principal amount of debt outstanding under fixed-rate instruments and $214 million aggregate principal amount of debt outstanding under variable-rate instruments. CONSOL Energy’s primary exposure to market risk for changes in interest rates relates to our revolving credit facility, under which there were no borrowings outstanding at June 30, 2013. A 100 basis-point increase in the average rate for CONSOL Energy’s revolving credit facility would not have significantly increased the net loss for the period. CNX Gas’ facility had outstanding borrowings of $173 million at June 30, 2013 and bore interest at a weighted average rate of 1.76% per annum during the six months ended June 30, 2013. Due to the level of borrowings against this facility and the low weighted average interest rate in the six months ended June 30, 2013, a 100 basis-point increase in the average rate for CNX Gas’ revolving credit facility would not have significantly increased the net loss for the period.

Almost all of CONSOL Energy’s transactions are denominated in U.S. dollars, and, as a result, it does not have material exposure to currency exchange-rate risks.

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Hedging Volumes

As of July 9, 2013 our hedged volumes for the periods indicated are as follows:

	For the Three Months Ended
	March 31,		June 30,		September 30,		December 31,		Total Year
2013 Fixed Price Volumes
Hedged Mcf	N/A		N/A		24,046,537		24,046,537		48,093,074
Weighted Average Hedge Price per thousand cubic feet	N/A		N/A		$	4.62	$	4.62	$	4.62
2014 Fixed Price Volumes
Hedged Mcf	16,634,945		16,819,778		17,004,611		17,004,611		67,463,945
Weighted Average Hedge Price per thousand cubic feet	$	4.92	$	4.92	$	4.92	$	4.92	$	4.92
2015 Fixed Price Volumes
Hedged Mcf	13,194,340		13,340,943		13,487,547		13,487,547		53,510,377
Weighted Average Hedge Price per thousand cubic feet	$	4.24	$	4.24	$	4.24	$	4.24	$	4.24
2016 Fixed Price Volumes
Hedged Mcf	7,125,472		7,125,472		7,203,774		7,203,774		28,658,492
Weighted Average Hedge Price per thousand cubic feet	$	4.45	$	4.45	$	4.45	$	4.45	$	4.45

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ITEM 4. CONTROLS AND PROCEDURES

Disclosure controls and procedures. CONSOL Energy, under the supervision and with the participation of its management, including CONSOL Energy’s principal executive officer and principal financial officer, evaluated the effectiveness of the Company’s “disclosure controls and procedures,” as such term is defined in Rule 13a-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), as of the end of the period covered by this Quarterly Report on Form 10-Q. Based on that evaluation, CONSOL Energy’s principal executive officer and principal financial officer have concluded that the Company’s disclosure controls and procedures are effective as of June 30, 2013 to ensure that information required to be disclosed by CONSOL Energy in reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms, and includes controls and procedures designed to ensure that information required to be disclosed by CONSOL Energy in such reports is accumulated and communicated to CONSOL Energy’s management, including CONSOL Energy’s principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

Changes in internal controls over financial reporting. There were no changes in the Company's internal controls over financial reporting that occurred during the fiscal quarter covered by this Quarterly Report on Form 10-Q that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

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PART II

OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The first through the nineteenth paragraphs of Note 11—Commitments and Contingencies in the Notes to the Unaudited Consolidated Financial Statements included in Item 1 of this Form 10-Q are incorporated herein by reference.

ITEM 4.     MINE SAFETY DISCLOSURES

The information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17 CFR 229.104) is included in exhibit 95 to this quarterly report.

ITEM 6. EXHIBITS

10.1	Stipulation and Agreement of Compromise and Settlement, dated May 8, 2013, between and among (i) plaintiffs Harold L. Hurwitz and James R. Gummel, on their own behalf and on behalf of the Class (as defined therein) and (ii) defendants CNX Gas Corporation, CONSOL Energy Inc. and certain individual defendants.
10.2	Amendment No. 1, dated April 19, 2013, to the Asset Acquisition Agreement, dated August 17, 2011, between CNX Gas Company LLC and Noble Energy, Inc.
31.1	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
95	Mine Safety and Health Administration Safety Data.
101	Interactive Data File (Form 10-Q for the quarterly period ended June 30, 2013 furnished in XBRL).

In accordance with SEC Release 33-8238, Exhibits 32.1 and 32.2 are being furnished and not filed.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

Dated: August 5, 2013

CONSOL ENERGY INC.
By:	/S/    J. BRETT HARVEY
	J. Brett Harvey
	Chairman of the Board and Chief Executive Officer (Duly Authorized Officer and Principal Executive Officer)
By:	/S/    DAVID M. KHANI
	David M. Khani
	Chief Financial Officer and Executive Vice President (Duly Authorized Officer and Principal Financial Officer)
By:	/S/    LORRAINE L. RITTER
	Lorraine L. Ritter
	Controller and Vice President (Duly Authorized Officer and Principal Accounting Officer)

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EX-10.1

IN THE COURT OF CHANCERY OF THE STATE OF DELAWARE

IN RE CNX GAS CORPORATION SHAREHOLDERS LITIGATION ) ) CONSOLIDATED C.A. No. 5377-VCL

STIPULATION AND AGREEMENT OF COMPROMISE AND SETTLEMENT

This Stipulation and Agreement of Compromise and Settlement (the “Settlement Agreement” or the “Stipulation”), dated May 8, 2013, which is entered into between and among (i) plaintiffs Harold L. Hurwitz (“Hurwitz”) and James R. Gummel (“Gummel”) (collectively, “Plaintiffs”), on their own behalf and on behalf of the Class (defined below), and (ii) defendants CNX Gas Corporation (“CNX Gas” or the “Company”), CONSOL Energy Inc. (“CONSOL”), J. Brett Harvey (“Harvey”), Philip W. Baxter (“Baxter”), and Raj K. Gupta (“Gupta”) (collectively, “Defendants”), by and through their undersigned attorneys, states all of the terms of the settlement and resolution of the Consolidated Action (defined below) and is intended by the parties to this Stipulation (the “Parties”) to fully and finally compromise, resolve, discharge and settle the Released Claims (defined below) subject to the approval of the Court of Chancery of the State of Delaware (the “Court”):

Background of the Settlement

WHEREAS, as of March 20, 2010, CONSOL was the largest single stockholder of CNX Gas, owning approximately 83% of the Company’s shares issued and outstanding at that time;

WHEREAS, on March 20, 2010, CONSOL entered into an agreement with CNX Gas’s largest public stockholder (other than CONSOL), T. Rowe Price Associates, Inc. (“T. Rowe Price”), pursuant to which CONSOL agreed to commence a tender offer to acquire all of the shares of CNX Gas common stock that CONSOL did not already own at a price of $38.25, in cash, per share (the “Tender Offer”);

WHEREAS, T. Rowe Price was also CONSOL’s third largest stockholder, owning approximately 11,809,600 shares of CONSOL common stock, or 6.51% of CONSOL’s shares issued and outstanding at that time;

WHEREAS, on March 21, 2010, CONSOL announced that it had entered into the agreement with T. Rowe Price and that it had agreed to commence the Tender Offer. CONSOL subsequently announced that, in the event the conditions of the Tender Offer were satisfied, CONSOL would effect a short-form merger between CNX Gas and a subsidiary of CONSOL (the “Merger,” and together with the Tender Offer, the “Transaction”);

WHEREAS, on March 29, 2010, Gummel filed a putative class action lawsuit in this Court, captioned Gummel v. CONSOL Energy, Inc., C.A. No. 5377-VCL (“Gummel Action”), against CONSOL alleging, among other things, that it breached its fiduciary duties by attempting to acquire the remaining outstanding shares of CNX Gas not already owned by CONSOL through a coercive and unfair process and for an unfair price;

WHEREAS, on March 29, 2010, Daniel Schurr filed a putative class action lawsuit in the Court of Common Pleas of Washington County, Pennsylvania (“Pennsylvania Court”), captioned Schurr v. CNX Gas Corporation, Case No. 2010-2333 (“Schurr Action”), against the Company, members of the Company’s Board of Directors (“Board”), certain officers of the Company and CONSOL, and CONSOL, alleging that the Company’s directors and officers breached their fiduciary duties by, among other things, placing their own interests and the interests of the Company’s majority stockholder ahead of those of the Company’s public stockholders, and further alleging that CNX Gas and CONSOL aided and abetted those breaches of fiduciary duty;

WHEREAS, on March 30, 2010, Ira Gaines (“Gaines”) filed a putative class action lawsuit in this Court, captioned Gaines v. CNX Gas Corporation, C.A. No. 5378-VCL (“Gaines Action”), against the Company, members of the Board, and CONSOL, alleging that the Company’s directors breached their fiduciary duties by, among other things, (i) engaging in a flawed process and failing to act in the interests of CNX Gas’s public stockholders, and (ii) agreeing to an inadequate offer price, and further alleging that CONSOL aided and abetted those breaches of fiduciary duty;

WHEREAS, on April 12, 2010, Samuel S. Polen filed a putative class action lawsuit in the Pennsylvania Court, captioned Polen v. CNX Gas Corporation, Case No. 2010-2626 (together with the Schurr Action, the “Pennsylvania Actions”), against the Company, members of the Company’s Board, and CONSOL, alleging, among other things, that the Company’s directors breached their fiduciary duties by agreeing to sell CNX Gas to CONSOL through an unfair process and for an unfair price, and that CNX Gas and CONSOL aided and abetted those breaches of fiduciary duty;

WHEREAS, on April 12, 13, and 20, 2010, Defendants filed motions to stay the Pennsylvania Actions;

WHEREAS, on April 13, 2010, Hurwitz filed a putative class action lawsuit in this Court, captioned Hurwitz v. CNX Gas Corporation, C.A. No. 5405-VCL (“Hurwitz Action”), against the Company, members of the Board, and CONSOL, alleging that the directors breached their fiduciary duties because they, among other things, (i) had material conflicts of interest by virtue of Defendants Harvey, Gupta, and Baxter all being members of CONSOL’s board of directors, and (ii) as directors of the Company, agreed to accept an inadequate and unfair price, and further alleging that CNX Gas aided and abetted those breaches of fiduciary duty;

WHEREAS, on April 15, 2010, the CNX Gas Board formed a special committee (“Special Committee”) consisting of the Company’s independent director, John R. Pipski (“Pipski”), to evaluate the Tender Offer;

WHEREAS, Plaintiffs Gaines and Hurwitz jointly served their First Request for the Production of Documents and Things to All Defendants on April 16, 2010;

WHEREAS, on April 21, 2010, the Court entered an Order of Consolidation and Appointment of Lead Counsel, which consolidated the Gummel, Gaines, and Hurwitz Actions under the caption In re CNX Gas Corporation Shareholders Litigation, C.A. No. 5377-VCL (the “Consolidated Action”), designated Rigrodsky & Long, P.A. as Plaintiffs’ Co-Lead Counsel, and designated Levi & Korsinsky, LLP as a member of Plaintiffs’ Executive Committee;

WHEREAS, on April 26, 2010, the Pennsylvania Court entered an Order granting Defendants’ motions to stay the Pennsylvania Actions;

WHEREAS, on April 28, 2010, CONSOL announced it was commencing the Tender Offer. The Offer to Purchase was filed with the United States Securities and Exchange Commission (“SEC”) on April 28, 2010 on Schedule TO (“Schedule TO”). The Tender Offer was scheduled to expire on May 26, 2010;

WHEREAS, Plaintiffs filed a Motion for Expedited Proceedings on April 28, 2010, which sought expedited discovery and an expedited hearing and briefing schedule with respect to Plaintiffs’ concomitantly-filed Motion for Preliminary Injunction;

WHEREAS, on April 30, 2010, Plaintiffs filed a Motion for Commission directed to T. Rowe Price, which was granted on May 3, and on May 3, Plaintiffs filed a Motion for Commission directed to Lazard Ltd. (“Lazard”), the Special Committee’s financial advisor, which was granted the same day;

WHEREAS, on May 3, 2010, Plaintiffs served a Subpoena ad testificandum and duces tecum directed to Stifel Nicolaus & Company, Inc. (“Stifel”), CONSOL’s financial advisor in connection with the Transaction;

WHEREAS, the parties subsequently came to an agreement regarding a schedule for expedited proceedings and the presentation of Plaintiffs’ Motion for Preliminary Injunction, and a stipulated Order Regarding Expedited Proceedings was entered by the Court on May 5, 2010;

WHEREAS, on May 11, 2010, the Special Committee filed its Solicitation/Recommendation Statement on Schedule 14D-9 (“14D-9”). In the 14D-9, the Special Committee stated that it expressed no opinion with respect to the Tender Offer and that it was remaining neutral regarding the Tender Offer;

WHEREAS, on May 12, 2010, Plaintiffs’ counsel took the deposition of Defendant Harvey;

WHEREAS, on May 12, 2010, Plaintiffs’ counsel took the deposition of Albert Garner, a managing director of Lazard;

WHEREAS, on May 13, 2010, Plaintiffs’ counsel took the deposition of David Giroux, a portfolio manager at T. Rowe Price;

WHEREAS, on May 14, 2010, Plaintiffs’ counsel took the deposition of Christopher Shebby (“Shebby”), a managing director at Stifel;

WHEREAS, on May 14, 2010, Plaintiffs’ counsel took the deposition of Pipski, the sole member of the Special Committee and the independent director of CNX Gas;

WHEREAS, on May 18, 2010, Plaintiffs filed their Verified Consolidated Class Action Complaint (“Consolidated Complaint”), alleging, among other things, that (i) the Special Committee was unable to perform its function of fully evaluating the Tender Offer because the Special Committee was not granted the authority to consider other alternatives, (ii) the valuation analysis performed by Lazard was flawed and skewed in favor of CONSOL, and (iii) negotiations between CONSOL and T. Rowe Price failed to afford the Company’s minority stockholders any protection. The Consolidated Complaint also alleged numerous omissions of material fact in the 14D-9 and in the Schedule TO filed by CONSOL;

WHEREAS, also on May 18, 2010, Plaintiffs filed their Opening Brief in Support of Their Motion for Preliminary Injunction;

WHEREAS, on May 21, 2010, Defendants filed their Answering Briefs in Opposition to Plaintiffs’ Motion for a Preliminary Injunction;

WHEREAS, on May 22, 2010, Plaintiffs filed their Reply Brief in Support of Their Motion for a Preliminary Injunction;

WHEREAS, on May 24, 2010, the Court held an oral argument on the Motion for Preliminary Injunction;

WHEREAS, on May 25, 2010, the Court entered an Order denying Plaintiffs’ Motion for Preliminary Injunction and issued its accompanying Opinion. Among other things, the Opinion stated that the Transaction would be reviewed for entire fairness. The Court found that Plaintiffs had demonstrated a reasonable likelihood of success on the merits of their claims regarding the fairness of the Tender Offer, but found that Plaintiffs’ disclosure claims were meritless. The Court ultimately denied Plaintiffs’ Motion for Preliminary Injunction because Plaintiffs had not shown any threat of irreparable harm that could not be remedied by an award of post-closing damages;

WHEREAS, on May 26, 2010, the Tender Offer expired. Approximately 95% of the outstanding CNX Gas shares not already owned by CONSOL were tendered in the offer. A subsidiary of CONSOL then consummated the Merger with CNX Gas on May 28, 2010;

WHEREAS, on June 4, 2010, Defendants filed their Application for Certification of Interlocutory Appeal;

WHEREAS, on June 25, 2010, Plaintiffs filed a brief in support of their Opposition to the Application for Certification of Interlocutory Appeal;

WHEREAS, on July 5, 2010, the Court certified the interlocutory appeal. The Delaware Supreme Court declined to accept the interlocutory appeal in an Order dated July 8, 2010;

WHEREAS, on June 7, 2010, Pipski, CNX Gas, CONSOL and the Individual Defendants filed separate Motions to Dismiss the Consolidated Complaint. On June 30, 2010, Pipski filed his Opening Brief in support of his Motion to Dismiss;

WHEREAS, on July 20, 2010, Plaintiffs filed a second Motion for Commission directed to T. Rowe Price, which was granted the same day;

WHEREAS, on July 23, 2010, the Court dismissed Pipski from the case pursuant to a Stipulation and Order of Dismissal. On July 28, 2010, the Court entered a Stipulation and Order of Partial Dismissal, which dismissed Plaintiffs’ disclosure claims;

WHEREAS, on August 6, 2010, the remaining Defendants filed their Answer to the Consolidated Complaint;

WHEREAS, Plaintiffs served their Second Request for the Production of Documents and Things to All Defendants on August 19, 2010;

WHEREAS, on September 15, 2010, Plaintiffs’ counsel took the deposition of John Wakeman, a portfolio manager at T. Rowe Price;

WHEREAS, on September 17, 2010, Plaintiffs’ counsel took the deposition of Shawn Driscoll, a research analyst at T. Rowe Price;

WHEREAS, on September 21, 2010, Plaintiffs’ counsel took the deposition of John Linehan, T. Rowe Price’s Director of U.S. Equity;

WHEREAS, on September 29, 2010, Plaintiffs filed a Motion for Commission directed to Dominion Resources, Inc., which was granted on October 4, 2010;

WHEREAS, on November 9, 2010, Gaines voluntarily dismissed his claims against Defendants, while the remaining Plaintiffs continued to prosecute their claims;

WHEREAS, on December 3, 2010, Defendants’ counsel took the deposition of Plaintiff Gummel;

WHEREAS, on December 9, 2010, Defendants’ counsel took the deposition of Plaintiff Hurwitz;

WHEREAS, on December 17, 2010, Plaintiffs filed a Motion for Class Certification;

WHEREAS, on January 20, 2011, the Court entered a Stipulated Order Granting Plaintiffs’ Motion for Class Certification, which certified a class pursuant to Rule 23(b)(3) consisting of:

Any and all record holders and beneficial owners of common stock of CNX Gas at any time from March 21, 2010 through and including May 28, 2010. Excluded from the Class are Defendants, T. Rowe Price, and any person, firm, trust, corporation, or other entity related to or affiliated with any Defendant or T. Rowe Price;

WHEREAS, on February 18, 2011, Plaintiffs’ counsel continued their deposition of Defendant Harvey;

WHEREAS, on March 10, 2011, Plaintiffs’ counsel continued their deposition of Shebby;

WHEREAS, on March 11, 2011, Plaintiffs’ counsel took the deposition of Defendant Baxter;    

WHEREAS, on March 25, 2011, Plaintiffs’ counsel took the deposition of Defendant Gupta;

WHEREAS, on March 29, 2011, Plaintiffs’ counsel took the deposition of Patrick Keeley, co-head of investment banking at Stifel;    

WHEREAS, on April 1, 2011, Plaintiffs’ counsel took the deposition of Jerome Richey, Chief Legal Officer and Secretary for CONSOL and CNX Gas at the time of the Tender Offer;

WHEREAS, Plaintiffs filed with the Court and served upon Defendants the expert reports of Daniel Beaulne (“Beaulne”), Plaintiffs’ valuation expert, on April 29, 2011, May 27, 2011, and May 21, 2012;

WHEREAS, Defendants served expert reports of Dr. Scott T. Jones (“Jones”), Defendants’ valuation expert, on April 29, 2011, May 27, 2011, and June 20, 2012;

WHEREAS, on May 4, 2011, the Court granted a Stipulation whereby counsel for plaintiff Gaines withdrew from the Consolidated Action;

WHEREAS, on September 7, 2011, Plaintiffs served their Third Request for the Production of Documents and Things to All Defendants;

WHEREAS, on November 23, 2011, Plaintiffs filed a Motion to Extend the Fact Discovery Deadline and to Compel Production of Responsive Documents;

WHEREAS, on December 6, 2011, the Court entered a Briefing Schedule Regarding Plaintiffs’ Motion to Extend the Fact Discovery Deadline and to Compel Production of Responsive Documents;

WHEREAS, on July 19, 2012, Plaintiffs’ counsel took the deposition of Jones;

WHEREAS, on July 20, 2012, Defendants’ counsel took the deposition of Beaulne;

WHEREAS, on January 9, 2013, Plaintiffs’ counsel took the deposition of Stephen M. Kenney, an employee of CONSOL;

WHEREAS, throughout the course of the Consolidated Action, Defendants and third parties produced, and Plaintiffs’ counsel reviewed, over 95,000 pages of documents, including, inter alia, Board meeting minutes, Board presentations, and banker books;

WHEREAS, on January 9, 2013, the Court entered the Stipulated Fifth Amended Pre-Trial Scheduling Order that, among other things, scheduled a four-day trial to commence on March 11, 2013;

WHEREAS, on January 22, 2013, Plaintiffs filed their Opening Pre-Trial Brief, which argued, inter alia, that the process by which Defendants agreed to the Tender Offer was unfair, that the price paid in the Transaction was unfairly low and did not reflect the fair value of the Company, and that Defendants should bear the burden of proof to show the Transaction was entirely fair. Plaintiffs further argued that the negotiations between CONSOL and T. Rowe Price were not at arms’ length and the Special Committee was rendered powerless to negotiate a better deal, adopt other defensive measures, or seek alternative bidders;

WHEREAS, on January 28, 2013, Plaintiffs filed an Unopposed Motion for Approval of Class Notice, which was granted by the Court on January 31, 2013;

WHEREAS, beginning on or about February 13, 2013, the Notice of Pendency of Class Action and Class Certification (“Class Notice”) was disseminated to the Class, which notified stockholders of, among other things, their right to request exclusion from the Class and the procedure to do so. To Plaintiffs’ counsel’s knowledge, only one exclusion request has been received to date, which request was filed prior to the March 4, 2013 deadline for doing so (the “Exclusion Request”);

WHEREAS, on February 19, 2013, CNX Gas, CONSOL and the Individual Defendants filed their Pretrial Brief, arguing that the Court’s preliminary injunction Opinion holding that the unified standard was the appropriate standard by which to review the Tender Offer departed from existing Delaware Court of Chancery and Supreme Court precedent. Defendants also argued that they structured the Transaction in good-faith compliance with then-existing Delaware law. Defendants further argued that, even if the Transaction were to be subject to entire fairness review, the price offered by CONSOL was entirely fair and Plaintiffs and the Class sustained no damages;

WHEREAS, on February 21, 2013, Plaintiffs and Defendants engaged in a one-day in-person mediation session in Washington, D.C., conducted in good faith with arm’s-length negotiations under the supervision and with the assistance of JAMS mediators and arbitrators;

WHEREAS, following mediation, Plaintiffs’ counsel prepared a Pre-Trial Stipulation and Order and continued to prepare for trial;

WHEREAS, good faith, arm’s-length mediated negotiations continued telephonically following the one-day in-person mediation session;

WHEREAS, on February 28, 2013, the Parties reached an agreement in principle to settle the Consolidated Action and resolve Plaintiffs’ claims on the basis that Defendants would pay $42,730,913.50, to be distributed to the Class, which amount approximated the difference between $38.25 per share and $41.00 per share for each share owned by members of the Class at the time of the Closing (as defined herein);

WHEREAS, on March 1, 2013, counsel for the Parties informed the Court of the agreement in principle to settle the Consolidated Action, and requested adjournment of the upcoming deadlines and trial dates;

WHEREAS, Defendants acknowledge that negotiations with Plaintiffs’ counsel were the sole cause of the assumption by Defendants of the obligation to make the Settlement Payment (defined below) pursuant to the Settlement;

WHEREAS, Defendants have denied, and continue to deny, all allegations of wrongdoing, fault, liability or damage with respect to all claims asserted in the Consolidated Action and the Pennsylvania Actions, including that they have committed any violations of law, that they have acted improperly in any way, and that they have any liability or owe any damages of any kind to Plaintiffs and/or the Class, but are entering into this Stipulation solely because they consider it desirable that the Consolidated Action be settled and dismissed with prejudice in order to, among other things, (i) eliminate the uncertainty, burden, inconvenience, expense, and distraction of further litigation, and (ii) finally put to rest and terminate all the claims that were or could have been asserted by Plaintiffs or any other member of the Class against Defendants in the Consolidated Action, the Pennsylvania Actions, or in any other action, in any court or tribunal, relating to the Transaction;

WHEREAS, the entry by Plaintiffs into this Stipulation is not an admission as to the lack of any merit of any claims asserted in the Consolidated Action. In negotiating and evaluating the terms of this Stipulation, Plaintiffs’ counsel considered the legal and factual defenses to Plaintiffs’ claims that Defendants raised and might have raised throughout the pendency of the Consolidated Action. In addition, Plaintiffs considered the benefits to be provided to the Class through the Settlement Payment. Based upon their evaluation, Plaintiffs and Plaintiffs’ counsel have determined that the Settlement set forth in this Stipulation is fair, reasonable and adequate to Plaintiffs and the Class, and that it confers substantial benefits upon the Class;

WHEREAS, the Parties recognize the time and expense that would be incurred by further litigation and the uncertainties inherent in such litigation;

WHEREAS, the Settlement (defined below) of the Consolidated Action on the terms and conditions set forth herein includes, but is not limited to, a release of all claims that were or could have been asserted in the Consolidated Action;

NOW, THEREFORE, IT IS HEREBY STIPULATED, CONSENTED TO AND AGREED, by Plaintiffs, for themselves and on behalf of the Class, and Defendants that, subject to the approval of the Court and pursuant to Court of Chancery Rule 23 and the other conditions set forth herein, for the good and valuable consideration set forth herein and conferred on Plaintiffs and the Class, the Consolidated Action shall be finally and fully settled, compromised and dismissed, on the merits and with prejudice, and that the Released Claims shall be finally and fully compromised, settled, released and dismissed with prejudice as to the Released Parties, in the manner and upon the terms and conditions hereafter set forth.

A. Definitions

1.The following capitalized terms, used in this Stipulation and its Exhibits, shall have the meanings specified below:

(a)“Account” means an account at PNC Bank, NA, with Class Counsel (defined herein) as escrow agent, which is to be maintained by the Paying Agent (defined herein) and into which the Settlement Amount shall be deposited. The funds deposited into the Account shall be invested in instruments backed by the full faith and credit of the United States Government or an agency thereof, or if the yield on such instruments is negative, in an account fully insured by the United States Government or an agency thereof.

(b)“Administrative Costs” means all costs and expenses associated with providing notice of the Settlement to the Class or otherwise administering or carrying out the terms of the Settlement.

(c)“Class” means any and all record holders and beneficial owners of common stock of CNX Gas Corporation at any time from March 21, 2010 through and including May 28, 2010 (the “Class Period”). Excluded from the Class are Defendants, T. Rowe Price, and any person, firm, trust, corporation, or other entity related to or affiliated with any Defendant or T. Rowe Price (other than employees of such entities who were not directors or officers during the Class Period), as well as the stockholders who submitted the Exclusion Request.

(d)“Class Counsel” means Rigrodsky & Long, P.A.

(e)“Class Member” or “Class Members” mean a member or members of the Class.

(f)“Effective Date” means the first business day following the date on which all of the conditions set forth in Paragraph 14 hereof shall have occurred.

(g) “Fee and Expense Award” means an award to Class Counsel of fees and expenses to be paid from the Settlement Amount (defined herein) approved by the Court in accordance with this Stipulation and in full satisfaction of any and all claims for attorneys’ fees that have been, could be or could have been asserted by Plaintiffs’ counsel or any other counsel for any member of the Class.

(h)“Final,” when referring to the Order and Final Judgment, means that the Order and Final Judgment has been entered by the Court and one of the following has occurred: (i) the time for the filing or noticing of any motion for reconsideration, appeal, or other review of the Order and Final Judgment has expired without any such filing or notice, or (ii) the Order and Final Judgment has been affirmed in all material respects on an appeal or after reconsideration or other review and is no longer subject to review upon appeal, reconsideration, or other review, and the time for any petition for reconsideration, reargument, appeal or review of the Order and Final Judgment or any order affirming the Order and Final Judgment has expired; provided, however, that any disputes or appeals relating solely to the amount, payment or allocation of attorneys’ fees and expenses shall have no effect on finality for purposes of determining the date on which the Order and Final Judgment became final, and shall not otherwise prevent, limit, or otherwise affect the Order and Final Judgment or prevent, limit, delay or hinder the Order and Final Judgment’s becoming final.

(i)“Final Approval of the Fee Application” shall be deemed to occur on the first business day following the date any award of attorneys’ fees and expenses in connection with the Fee Application (defined herein) becomes final and no longer subject to further appeal or review, whether by affirmance on or exhaustion of any possible appeal or review, lapse of time or otherwise.

(j)“Net Settlement Amount” means the Settlement Amount as defined herein less any Fee and Expense Award and Administrative Costs.

(k)“Order and Final Judgment” means the Order and Final Judgment to be entered in the Consolidated Action substantially in the form attached as Exhibit D hereto or as modified by the Court with the written consent of the Parties or as modified by agreement of the Parties in writing.

(l)“Person” means any individual, corporation, partnership, limited liability company, association, affiliate, joint stock company, estate, trust, unincorporated association, entity, government and any political subdivision thereof, or any other type of business or legal entity.

(m)“Released Claims” means any and all manner of claims, demands, rights, liabilities, losses, obligations, duties, damages, costs, debts, expenses, interest, penalties, sanctions, fees, attorneys’ fees, actions, potential actions, causes of action, suits, agreements, judgments, decrees, matters, issues and controversies of any kind, nature or description whatsoever, whether known or unknown, disclosed or undisclosed, accrued or unaccrued, apparent or not apparent, foreseen or unforeseen, matured or not matured, suspected or unsuspected, liquidated or not liquidated, fixed or contingent, including Unknown Claims (defined below), that Plaintiffs or any or all other Class Members ever had, now have, or may have, whether direct, derivative, individual, class, representative, legal, equitable or of any other type, or in any other capacity, against any of the Released Parties (defined below), whether based on state, local, foreign, federal, statutory, regulatory, common or other law or rule (including, but not limited to, any claims under federal securities laws, including such claims within the exclusive jurisdiction of the federal courts, or state disclosure law or any claims that could be asserted derivatively on behalf of CNX Gas), which, now or hereafter, are based upon, arise out of, relate in any way to, or involve, directly or indirectly, (i) the Transaction (including either or both of the Tender Offer and the Merger), (ii) any deliberations or negotiations in connection with the Transaction, (iii) the consideration received by Class Members or by any other Person in connection with the Transaction, (iv) the Schedule TO, the 14D-9 or any other disclosures, public filings, periodic reports, press releases, proxy statements or other statements issued, made available or filed relating, directly or indirectly, to the Transaction, (v) the fiduciary duties and obligations of the Released Parties in connection with the Transaction, (vi) any of the allegations in any complaint or amendment(s) thereto filed in the Consolidated Action, including in any of its constituent actions, or the Pennsylvania Actions, or (vii) any other actions, transactions, occurrences, statements, representations, misrepresentations, omissions, allegations, facts, practices, events, claims or any other matters, things or causes whatsoever, or any series thereof, that were, could have been, or in the future can or might be alleged, asserted, set forth, claimed, embraced, involved, or referred to in, or otherwise related, directly or indirectly, in any way to, the Consolidated Action or the Pennsylvania Actions, or the subject matter of those actions; provided, however, that the Released Claims shall not include claims to enforce the Settlement.

(n)Whether or not any or all of the following Persons were named, served with process or appeared in the Consolidated Action, “Released Parties” means (i) Defendants (i.e., CNX Gas, CONSOL, Harvey, Baxter, and Gupta), (ii) any Person which is, was, or will be related to or affiliated with any or all of Defendants or in which any or all of Defendants has, had, or will have a controlling interest, and (iii) each and all of the foregoing’s respective past, present, or future family members, spouses, heirs, trusts, trustees, executors, estates, administrators, beneficiaries, distributees, foundations, agents, employees, fiduciaries, general or limited partners or partnerships, joint ventures, member firms, limited liability companies, corporations, parents, subsidiaries, divisions, affiliates, associated entities, stockholders, principals, officers, managers, directors, managing directors, members, managing members, managing agents, predecessors, predecessors-in-interest, successors, successors-in-interest, assigns, financial or investment advisors, advisors, consultants, investment bankers, entities providing any fairness opinion, underwriters, brokers, dealers, lenders, commercial bankers, attorneys, personal or legal representatives, accountants, insurers, co-insurers, reinsurers, and associates.

(o)“Settlement” means the settlement of the Consolidated Action between and among Plaintiffs, on behalf of themselves and the Class, and Defendants, as set forth in this Stipulation.

(p)“Settlement Amount” means a total of forty-two million, seven hundred thirty thousand nine hundred thirteen dollars and fifty cents in cash ($42,730,913.50). Defendants and/or their insurers will fund in its entirety the Settlement Amount. Nothing in this paragraph shall have an effect on the respective rights and obligations between or among Defendants or their respective insurers, or upon any separate agreements concerning the claims, defenses, debts, obligations or payments between or among Defendants.

(q)“Settlement Hearing” means the hearing to be held by the Court to determine whether to amend the Court’s previous Stipulated Order Granting Plaintiffs’ Motion for Class Certification (and/or re-certify the Class) on the terms described in Paragraph 3 hereof, whether Plaintiffs and Class Counsel have adequately represented the Class, whether the proposed Settlement should be approved as fair, reasonable and adequate to the Class, whether all Released Claims should be dismissed with prejudice, whether an Order and Final Judgment approving the Settlement should be entered, and whether and in what amount any award of attorneys’ fees and reimbursement of expenses should be paid to Plaintiffs’ counsel out of the Settlement Amount.

(r)“Settlement Payment Recipients” means all Class Members who were beneficial holders of CNX Gas common stock on May 26, 2010, or if they did not tender their shares in the Tender Offer, at the time of the consummation of the short-form merger on May 28, 2010 (the “Closing”), and who received consideration for shares of CNX Gas common stock in the Transaction, and who submitted a valid claim form in the form attached hereto as Exhibit C (the “Proof of Claim”) to the Paying Agent.

(s)“Unknown Claims” means any claim that any Plaintiff or any other Class Member does not know or suspect exists in his, her or its favor at the time of the release of the Released Claims as against the Released Parties, including without limitation those which, if known, might have affected the decision to enter into the Settlement or to object or to not object to the Settlement. With respect to any of the Released Claims, the Parties stipulate and agree that upon the occurrence of the Effective Date, Plaintiffs shall expressly and each Class Member shall be deemed to have, and by operation of the Order and Final Judgment shall have, expressly waived, relinquished and released any and all provisions, rights and benefits conferred by or under Cal. Civ. Code § 1542 or any law of the United States or any state of the United States or territory of the United States, or principle of common law, which is similar, comparable or equivalent to Cal. Civ. Code § 1542, which provides:

A GENERAL RELEASE DOES NOT EXTEND TO CLAIMS WHICH THE CREDITOR DOES NOT KNOW OR SUSPECT TO EXIST IN HIS OR HER FAVOR AT THE TIME OF EXECUTING THE RELEASE, WHICH IF KNOWN BY HIM OR HER MUST HAVE MATERIALLY AFFECTED HIS OR HER SETTLEMENT WITH THE DEBTOR.

Plaintiffs acknowledge, and the Class Members by operation of law shall be deemed to have acknowledged, that they may discover facts in addition to or different from those now known or believed to be true with respect to the Released Claims, but that it is the intention of Plaintiffs, and by operation of law the Class Members, to completely, fully, finally and forever extinguish any and all Released Claims, known or unknown, suspected or unsuspected, which now exist, or heretofore existed, or may hereafter exist, and without regard to the subsequent discovery of additional or different facts. Plaintiffs acknowledge, and the Class Members by operation of law shall be deemed to have acknowledged, that the inclusion of “Unknown Claims” in the definition of “Released Claims” was separately bargained for and was a material element of the Settlement and was relied upon by each and all of Defendants in entering into the Settlement Agreement.

B. Settlement Consideration

2.In consideration for the full and final release, settlement, dismissal, and discharge of any and all Released Claims against the Released Parties, the Parties have agreed to the following consideration:

(a)The “Settlement Payment”:

(i)Within five (5) business days after the Court’s entry of the Scheduling Order (defined herein and attached as Exhibit A), $400,000 of the Settlement Amount (the “Administration Fund”) shall be deposited into the Account, provided that Class Counsel has timely provided complete wire transfer information and instructions to Defendants. The Administration Fund shall be used by Class Counsel or its designees only to pay reasonable and necessary Administrative Costs.

(ii)Within ten (10) business days after the Effective Date, the remaining Settlement Amount shall be deposited (net of the $400,000 Administration Fund advancement provided for in subsection (i), above) into the Account, provided that Class Counsel has timely provided complete wire transfer information and instructions to Defendants. The Account shall be administered by a paying agent chosen by Class Counsel (the “Paying Agent”) and shall be used (i) to pay any Fee and Expense Award, (ii) to pay Administrative Costs, and (iii) following the payment of the foregoing (i) and (ii), for subsequent disbursement of the Net Settlement Amount to the Settlement Payment Recipients as provided in Paragraph 2(b) hereof.

(iii)Apart from the payment of the Settlement Amount in accordance with this Paragraph 2(a), Defendants shall have no further monetary obligation to Plaintiffs, the Class, any Class Member, Class Counsel, or any other Plaintiffs’ counsel. The Settlement Amount shall be paid without waiver of any right of Defendants to pursue claims against any insurers who have not reached separate settlements with Defendants regarding their contribution to the Settlement Amount.

(iv)Class Counsel shall be solely responsible for determining whether any taxes of any kind are due on income earned by the Account, for filing any necessary tax returns, and for causing any necessary taxes to be paid. Any such taxes, as well as any expenses incurred by Class Counsel in connection with determining the amount of, and paying, such taxes shall be considered Administrative Costs and shall be paid out of the Settlement Amount.

(b)Distribution of the Net Settlement Amount: As soon as reasonably practicable after the Effective Date, the Net Settlement Amount will be disbursed by the Paying Agent to the Settlement Payment Recipients and will be allocated on a per-share basis amongst the Settlement Payment Recipients who have submitted to the Paying Agent a valid Proof of Claim by the deadline provided in the Notice (defined herein) based on the number of shares of CNX Gas common stock held by the applicable Settlement Payment Recipient upon the Closing (provided that if a Settlement Payment Recipient held shares of CNX Gas common stock in registered form and has not submitted a letter of transmittal as of the Effective Date, such payment shall be allocated to such Settlement Payment Recipient but will not be remitted until such Settlement Payment Recipient has submitted its letter of transmittal or other satisfactory proof sufficient to determine whether such Class Member is a Settlement Payment Recipient) (the “Initial Distribution”). Defendants shall have no input, responsibility or liability for any claims, payments or determinations by the Paying Agent in respect of Class Member claims for payment under this Settlement. If Plaintiffs and/or the Paying Agent have made reasonable efforts to have Settlement Payment Recipients claim their payments, and the amount of the Net Settlement Amount that remains unclaimed by the Settlement Payment Recipients (the “Unclaimed Amount”) exceeds $100,000 after a period of six (6) months after the Initial Distribution, then the Unclaimed Amount will be re-disbursed by the Paying Agent for payment to all Settlement Payment Recipients, who claimed their payments in the Initial Distribution, on a pro rata basis. If, however, after a period of six (6) months after the Initial Distribution, the amount of the Unclaimed Amount is equal to or less than $100,000, or if any of the Unclaimed Amount remains unclaimed after the re-disbursement described in the preceding sentence, then any such unclaimed amount of the Net Settlement Amount shall be donated to the Delaware Combined Campaign for Justice.

(c)Costs of Distribution and Reservation of Rights: Plaintiffs or their designee shall pay out of the Account any and all costs associated with the allocation and distribution of the Net Settlement Amount (including the costs of any re-distribution of the Net Settlement Amount and the costs associated with any charitable donation).

(d)Other than as provided herein, Defendants, their insurers, and the Released Parties shall have no involvement in, responsibility for, or liability relating to the distribution of the Net Settlement Payment to Class Members. No Class Member shall have any claim against any Plaintiff, Plaintiffs’ counsel, any Defendant, any of the Released Parties, or any of their counsel or insurers based on the distributions made substantially in accordance with this Stipulation and/or orders of the Court.

C. Amendment to Class Certification Order

3.The Parties agree that Plaintiffs shall request that the Court amend its previous Stipulated Order Granting Plaintiffs’ Motion for Class Certification, dated January 20, 2011 (the “Certification Order”), to provide, in the Order and Final Judgment, that the Class shall be recertified for settlement purposes pursuant to Court of Chancery Rules 23(a) and 23(b)(1) and/or (b)(2). The definition of the Class also shall be modified to exclude from the Class, in addition to those Persons already excluded pursuant to the Certification Order, the stockholders who submitted the Exclusion Request.

D. Settlement Consideration, Releases, and Scope of the Settlement

4.Defendants shall make or shall cause their insurers to make the Settlement Payment, which shall be distributed to the Settlement Payment Recipients pursuant to Paragraph 2(b) hereof.

5.The Settlement Payment having been agreed to and provided in consideration for the full and final settlement and dismissal with prejudice of the Consolidated Action and the release of any and all Released Claims, including claims asserted in the Pennsylvania Actions, no Defendant or other Released Party shall have any obligation to pay or bear any additional amounts, expenses, costs, damages, or fees to or for the benefit of Plaintiffs or any Class Member in connection with this Settlement, including but not limited to attorneys’ fees and expenses for any counsel to any Class Member, or any costs of notice or settlement administration or otherwise.

6.As of the Effective Date, the Consolidated Action and the Released Claims shall be dismissed with prejudice, on the merits and without costs, except as provided herein.

7.As of the Effective Date, Plaintiffs and all Class Members, on behalf of themselves, and any and all of their respective successors-in-interest, successors, predecessors-in-interest, predecessors, representatives, trustees, executors, administrators, estates, heirs, assigns or transferees, immediate and remote, and any person or entity acting for or on behalf of, or claiming under, any of them, and each of them, agree to release and forever discharge, and by operation of the Order and Final Judgment shall release and forever discharge, all Released Claims as against all Released Parties.

8.As of the Effective Date, Defendants and all Released Parties agree to fully, completely, finally, and forever release, relinquish and discharge Plaintiffs and Plaintiffs’ counsel from all claims, including Unknown Claims, arising out of or relating to the institution, prosecution, settlement, or resolution of the Consolidated Action (provided, however, that this release, relinquishment and discharge shall not include claims by the Parties hereto to enforce the terms of the Settlement or Settlement Agreement).

9.As of the Effective Date, the Released Parties shall be deemed to be released and forever discharged from all of the Released Claims.

10.As of the Effective Date, Plaintiffs and all Class Members, and any and all of their respective successors-in-interest, successors, predecessors-in-interest, predecessors, representatives, trustees, executors, administrators, estates, heirs, assigns or transferees, immediate and remote, and any person or entity acting for or on behalf of, or claiming under, any of them, and each of them, will be forever barred and enjoined from commencing, instituting, maintaining, prosecuting or asserting, either directly or in any other capacity, in any forum, any Released Claims against any of the Released Parties.

E. Submission of the Settlement to the Court for Approval

11.As soon as practicable after this Settlement Agreement has been executed, the Parties shall jointly apply to the Court for entry of an Order in the form attached hereto as Exhibit A (the “Scheduling Order”), providing for, among other things: (a) the mailing to the Class Members of the Notice of Proposed Settlement of Class Action, Settlement Hearing and Right to Appear (the “Notice”) substantially in the form attached hereto as Exhibit B together with a Proof of Claim substantially in the form attached hereto as Exhibit C; (b) the scheduling of the Settlement Hearing to consider: (i) the proposed Settlement, (ii) the joint request of the parties that the Order and Final Judgment be entered substantially in the form attached hereto as Exhibit D, (iii) amendment of the Court’s previous Stipulated Order Granting Plaintiffs’ Motion for Class Certification on the terms described in Paragraph 3 hereof, and (iv) the Fee Application, and any objections to the foregoing; and (c) the injunction against the prosecution of any of the Released Claims pending further order of the Court. At the Settlement Hearing, the Parties shall jointly request that the Order and Final Judgment be entered substantially in the form attached hereto as Exhibit D.

12.Plaintiffs shall be responsible for providing notice of the Settlement to the Class. Defendants shall cooperate with Plaintiffs toward Plaintiffs’ obligation for providing notice, including but not limited to providing the last known address and phone number of all stockholders of record of CNX Gas common stock as of the Closing, and, to the extent reasonably available to Defendants for a relevant date prior to the Closing, providing a NOBO list. All costs of providing notice, as well as all other Administrative Costs, shall be paid from the Account, and no Defendant shall have any further responsibility for such costs. Notice shall be provided in accordance with the Scheduling Order.

13.Prior to the Settlement Hearing (as defined herein), Plaintiffs’ counsel and/or any administrator retained by them shall file with the Court an appropriate declaration or affidavit with respect to the preparation and mailing of the Notice.

F. Conditions of Settlement

14.This Settlement Agreement is expressly conditioned on and subject to each of the following conditions and, except as provided in Paragraph 20, shall be cancelled and terminated unless:

(a)The Court enters the Scheduling Order substantially in the form attached hereto as Exhibit A;

(b)The Court enters the Order and Final Judgment; and

(c)The Order and Final Judgment becomes Final.

G. Attorneys’ Fees and Expenses

15.Plaintiffs’ counsel intend to petition the Court for an award of attorneys’ fees in an aggregate amount of 27.5% of the Settlement Amount plus reimbursement of expenses incurred in connection with the Consolidated Action (the “Fee Application”), which petition will be wholly inclusive of any request for attorneys’ fees and expenses on behalf of any Class Member or his, her or its counsel in connection with the Settlement. Defendants agree not to oppose this request and shall take no position as to the Fee Application. The Parties acknowledge and agree that any attorneys’ fees and expenses awarded by the Court in the Consolidated Action to Plaintiffs’ counsel shall be paid solely from the Settlement Payment. The Fee Application shall be the only petition for attorneys’ fees and expenses filed by or on behalf of Plaintiffs and Plaintiffs’ counsel. The Parties shall cooperate in opposing any other petition for an award of attorneys’ fees or reimbursement of expenses in connection with any other litigation concerning the Transaction. In the event that the Court awards any attorney’s fees or reimbursement of expenses to counsel for any Class Member other than Class Counsel in connection with the Settlement, including counsel for any plaintiff in the Pennsylvania Actions, such fees and/or expenses shall be paid out of the Settlement Amount and no Defendant shall have any further responsibility therefor.

16.Prior to disbursement of the Net Settlement Amount, and in any event within three (3) business days of the latter of (i) the entry of an Order by the Court awarding attorney’s fees and expenses to Plaintiffs’ counsel or (ii) the funding of the Settlement Amount in the Account as described in Paragraph 2(a), the Paying Agent shall disburse from the Account to Class Counsel an amount equal to the Fee and Expense Award. In the event that the Fee and Expense Award is disapproved, reduced, reversed or otherwise modified, as a result of any further proceedings including any successful collateral attack, then Class Counsel shall, within five (5) business days after Class Counsel receives notice of any such disapproval, reduction, reversal or other modification of the Fee and Expense Award, return to the Account, as applicable, either the entirety of the Fee and Expense Award or the difference between the attorneys’ fees and expenses awarded by the Court in the Fee and Expense Award on the one hand, and any attorneys’ fees and expenses ultimately and finally awarded on appeal, further proceedings on remand or otherwise on the other hand.

17.Final resolution by the Court of the Fee Application shall not be a precondition to the Settlement or the dismissal of the Consolidated Action in accordance with the Settlement and this Stipulation, and the Fee Application may be considered separately from the Settlement. Neither any failure of the Court or any other court (including any appellate court) to approve the Fee Application in whole or in part, nor any other reduction, modification, or reversal of the award order or failure of the award order to become final, shall have any impact on the effectiveness of the Settlement, provide any of the Parties with the right to terminate the Settlement or this Stipulation, or affect or delay the binding effect or finality of the Order and Final Judgment and the release of the Released Claims. Notwithstanding any other provision of this Stipulation, no fees or expenses shall be paid to Plaintiffs’ counsel in the absence of the occurrence of Final Approval of the Fee Application.

18.Plaintiffs’ counsel warrant that no portion of any Fee and Expense Award shall be paid to any Plaintiff or any Class Member, except as approved by the Court.

H. Stay Pending Final Court Approval

19.Plaintiffs agree to stay the proceedings in the Consolidated Action, and to stay and not to initiate any and all other proceedings other than those incident to the Settlement itself, pending the occurrence of the Effective Date. The Parties’ respective deadlines to respond to any filed or served pleadings or discovery requests are extended indefinitely. The Parties also agree to use their best efforts to prevent, stay or seek dismissal of or oppose entry of any interim or final relief in favor of any Class Member in any other litigation against any of the Released Parties which challenges the Settlement, the Transaction, including any transactions contemplated thereby, or otherwise involves, directly or indirectly, a Released Claim.

I. Effect of Disapproval, Cancellation or Termination

20.If either (a) the Court does not enter the Order and Final Judgment, (b) the Court enters the Order and Final Judgment but on or following appellate review the Order and Final Judgment is modified or reversed in any material respect, or (c) any of the other conditions of Paragraph 14 is not satisfied, this Stipulation shall be cancelled and terminated unless counsel for each of the Parties to this Stipulation, within ten (10) business days from receipt of such ruling or notice of such event, agrees in writing with counsel for the other Parties hereto to proceed with this Stipulation and Settlement, including only with such modifications, if any, as to which all other Parties in their sole judgment and discretion may agree in writing. For purposes of this paragraph, an intent to proceed shall not be valid unless it is expressed in a signed writing. Neither a modification nor a reversal on appeal of the amount of fees, costs and expenses awarded by the Court to Plaintiffs’ counsel in the Consolidated Action shall be deemed a material modification of the Order and Final Judgment or this Stipulation. Notwithstanding any other provision hereof, each Defendant shall have the right to withdraw from the Settlement in the event that any claim related to the subject matter of the Consolidated Action, the Transaction, or the Released Claims is commenced or prosecuted against any of the Released Parties in any court prior to the Effective Date, and (following a motion by any Defendant and subject to the Parties’ obligations in Paragraph 19 hereof) any such claim is not dismissed with prejudice or stayed in contemplation of dismissal with prejudice following the Effective Date.

21.If this Stipulation is terminated pursuant to Paragraph 20 hereof, (a) Plaintiffs shall within ten (10) business days cause to be refunded to CONSOL all amounts held in the Account as of the date of termination (i.e., the Administration Fund, plus any interest earned thereon and less any reasonable and necessary Administrative Costs incurred prior to such date), and (b) all of the Parties to this Stipulation shall be deemed to have reverted to their respective litigation status immediately prior to the execution of the Stipulation, and they shall proceed in all respects as if the Stipulation had not been executed (except for Paragraphs 20, 21, 27, and 28 hereof, which shall survive the occurrence of any such event) and the related orders had not been entered, and in that event all of their respective claims and defenses as to any issue in the Consolidated Action shall be preserved without prejudice in any way. Furthermore, in the event of such termination, Plaintiffs and Plaintiffs’ counsel agree that neither this Stipulation, nor any statements made in connection with the negotiation of this Stipulation, may be used or entitle any Party to recover any fees, costs or expenses incurred in connection with the Consolidated Action or in connection with any other litigation or judicial proceeding.

J. Miscellaneous Provisions

22.All of the Exhibits referred to herein shall be incorporated by reference as though fully set forth herein.

23.This Stipulation may be amended, modified or waived only by a written instrument signed by counsel for all Parties hereto or their successors.

24.The Parties represent and agree that the terms of the Settlement were negotiated at arm’s length and in good faith by the Parties, and reflect a settlement that was reached voluntarily based upon adequate information and sufficient discovery and after consultation with experienced legal counsel.

25.If any deadline set forth in this Stipulation or the Exhibits thereto falls on a Saturday, Sunday or legal holiday, that deadline will be continued to the next business day.

26.The headings in this Stipulation are solely for the convenience of the attorneys for the Parties and the relevant courts. The headings shall not be deemed to be a part of this Stipulation and shall not be considered in construing or interpreting this Stipulation.

27.Neither this Stipulation, nor the fact or any terms of the Settlement, or any negotiations or proceedings in connection therewith, is evidence, or a presumption, admission or concession by any Party in the Consolidated Action, any signatory hereto or any Released Party, of any fault, liability or wrongdoing whatsoever, or lack of any fault, liability or wrongdoing, as to any facts or claims alleged or asserted in the Consolidated Action, or any other actions or proceedings. This Stipulation is not a finding or evidence of the validity or invalidity of any claims or defenses in the Consolidated Action or any other actions or proceedings, or any wrongdoing by any of the Defendants named therein or any damages or injury to any Class Member. Neither this Stipulation, nor any of the terms and provisions of this Stipulation, nor any of the negotiations or proceedings in connection therewith, nor any of the documents or statements referred to herein or therein, nor the Settlement, nor the fact of the Settlement, nor the settlement proceedings, nor any statements in connection therewith, (a) shall (i) be argued to be, used or construed as, offered or received in evidence as, or otherwise constitute an admission, concession, presumption, proof, evidence, or a finding of any liability, fault, wrongdoing, injury or damages, or of any wrongful conduct, acts or omissions on the part of any of the Released Parties, or of any infirmity of any defense, or of any damage to any Plaintiff or Class Member, or (ii) otherwise be used to create or give rise to any inference or presumption against any of the Released Parties concerning any fact alleged or that could have been alleged, or any claim asserted or that could have been asserted in the Consolidated Action, or of any purported liability, fault, or wrongdoing of the Released Parties or of any injury or damages to any person or entity, or (b) shall otherwise be admissible,referred to or used in any proceeding of any nature, for any purpose whatsoever; provided, however, that (x) the Stipulation and/or Order and Final Judgment may be introduced in any proceeding, whether in the Court or otherwise, as may be necessary to argue that the Stipulation and/or Order and Final Judgment has res judicata, collateral estoppel or other issue or claim preclusion effect or to otherwise consummate or enforce the Settlement and/or Order and Final Judgment and (y) Plaintiffs and Plaintiffs’ counsel may refer to the final, executed version only of this Stipulation in connection with the Fee Application.

28.In the event that the Court or any other court is called upon to interpret this Stipulation, no one party or group of parties shall be deemed to have drafted this Stipulation.

29.To the extent permitted by law and any applicable Court Rules, all agreements made and orders entered during the course of the Consolidated Action relating to the confidentiality of documents or information shall survive this Stipulation and the Effective Date.

30.The waiver by any Party of any breach of this Stipulation by any other Party shall not be deemed a waiver of that or any other prior or subsequent breach of any provision of this Stipulation by any other Party.

31.This Stipulation and the Exhibits constitute the entire agreement among the Parties and supersede any prior agreements among the Parties with respect to the subject matter hereof. No representations, warranties or inducements have been made to or relied upon by any Party concerning this Stipulation or its Exhibits, other than the representations, warranties and covenants expressly set forth in such documents.

32.This Stipulation may be executed in one or more counterparts, including by facsimile, authorized electronic signature, or in portable document format (.pdf), and as executed, shall constitute one agreement.

33.The Parties and their respective counsel of record agree that they will use their best efforts to obtain (and, if necessary, defend on appeal) all necessary approvals of the Court required by this Stipulation (including, but not limited to, using their best efforts to resolve any objections raised to the Settlement).

34.Plaintiffs and Plaintiffs’ counsel represent and warrant that Plaintiffs are Class Members and that none of the Plaintiffs’ claims or causes of action referred to in this Stipulation have been assigned, encumbered, or otherwise transferred in any manner in whole or in part.

35.Each counsel signing this Stipulation represents and warrants that such counsel has been duly empowered and authorized to sign this Stipulation.

36.This Stipulation shall be binding upon and shall inure to the benefit of the Parties and the Class (and, in the case of the releases, all Released Parties) and the respective legal representatives, heirs, executors, administrators, transferees, successors and assigns of all such foregoing Persons and upon any corporation, partnership, or other entity into or with which any party may merge, consolidate or reorganize.

37.Plaintiffs agree that within thirty (30) calendar days of the Effective Date, they will return to the producing party all discovery material obtained from such producing party, including all deposition transcripts and all documents produced by any of Defendants (including, without limitation, their employees, affiliates, agents, representatives, attorneys, and third party advisors) and any materials containing or reflecting discovery material (“Discovery Material”), or destroy all such Discovery Material and certify to that fact; provided, however, that Plaintiffs’ counsel shall be entitled to retain all filings, court papers, trial transcripts, and attorney work product containing or reflecting Discovery Material, subject to the requirement that Plaintiffs’ counsel shall not disclose any Discovery Material contained or referenced in such materials to any person except pursuant to court order or agreement with Defendants. The Parties agree to submit to the Court any dispute concerning the return or destruction of Discovery Material.

38.The Stipulation, the Settlement, and any and all disputes arising out of or relating in any way to any of them, whether in contract, tort or otherwise, shall be governed by and construed in accordance with the laws of the state of Delaware, without regard to conflict of laws principles. Each of the Parties (a) irrevocably submits to the personal jurisdiction of any state or federal court sitting in Wilmington, Delaware, as well as to the jurisdiction of all courts to which an appeal may be taken from such courts, in any suit, action or proceeding arising out of or relating to the Settlement and/or the Stipulation, (b) agrees that all claims in respect of such suit, action or proceeding shall be brought, heard and determined exclusively in this Court (provided that, in the event that subject matter jurisdiction is unavailable in the Court, then all such claims shall be brought, heard and determined exclusively in any other state or federal court sitting in Wilmington, Delaware), (c) agrees that it shall not attempt to deny or defeat such personal jurisdiction by motion or other request for leave from such court, (d) agrees not to bring any action or proceeding arising out of or relating to the Settlement or the Stipulation in any other court, and (e) expressly waives, and agrees not to plead or to make any claim that any such action or proceeding is subject (in whole or in part) to a jury trial.

POTTER, ANDERSON      & CORROON LLP	RIGRODSKY & LONG, P.A.
/s/ Brian C. Ralston	/s/ Seth D. Rigrodsky
Donald J. Wolfe, Jr. (#285) Brian C. Ralston (#3770) 1313 North Market Street Wilmington, DE 19801 (302) 651-7700 Attorneys for Defendants CONSOL Energy, Inc., CNX Gas Corp., J. Brett Harvey, Philip W. Baxter, and Raj K. Gupta OF COUNSEL:WACHTELL, LIPTON, ROSEN & KATZ Paul K. Rowe Graham W. Meli51 West 52nd Street New York, NY 10019 (212) 403-1000	Seth D. Rigrodsky (#3147) Brian D. Long (#4347) 2 Righter Parkway, Suite 120 Wilmington, DE 19803 (302) 295-5310 Lead Counsel for Plaintiffs OF COUNSEL:LEVI & KORSINSKY LLP Donald J. Enright 1101 30th Street, N.W. Suite 115 Washington DC 20007 (202) 524-4290       Member of Plaintiffs’ Executive      Committee

Dated: May 8, 2013

IN THE COURT OF CHANCERY OF THE STATE OF DELAWARE

IN RE CNX GAS CORPORATION SHAREHOLDERS LITIGATION ) ) CONSOLIDATED C.A. No. 5377-VCL

SCHEDULING ORDER ON APPROVAL OF CLASS ACTION SETTLEMENT AND CLASS CERTIFICATION

WHEREAS, the Parties to the above-captioned consolidated class action (the “Consolidated Action”) have agreed to settle the Consolidated Action; and

WHEREAS, Plaintiffs in the Consolidated Action and Defendants are applying pursuant to Court of Chancery Rule 23(e) for an Order approving the proposed Settlement of the Consolidated Action and determining certain matters in accordance with the Stipulation and Agreement of Compromise and Settlement entered into by the Parties, dated May 8, 2013 (the “Stipulation” or “Settlement Agreement”), and for the dismissal of the Consolidated Action upon the terms and conditions set forth in the Stipulation;

NOW, after review and consideration of the Stipulation filed with the Court and the Exhibits annexed thereto, and after due deliberation,

IT IS HEREBY ORDERED AND ADJUDGED this ___ day of __________, 2013, that:

1.A hearing (the “Settlement Hearing”) will be held on __________ __, 2013, at __:__ _.m., in the Court of Chancery (the “Court”) in the New Castle County Courthouse, 500 North King Street, Wilmington, Delaware 19801, to: (a) determine whether to amend the Stipulated Order Granting Plaintiffs’ Motion for Class Certification, dated January 20, 2011, to provide for the recertification of the Class permanently, for settlement purposes, pursuant to Court of Chancery Rules 23(a) and 23(b)(1) and/or (b)(2); (b) determine whether Plaintiffs and Class Counsel have adequately represented the interests of the Class in the Consolidated Action; (c) determine whether the Stipulation and the terms and conditions of the Settlement proposed in the Stipulation are fair, reasonable and adequate to the Class and should be approved by the Court; (d) determine whether the Order and Final Judgment should be entered dismissing the Consolidated Action and Released Claims with prejudice as against Plaintiffs and the Class, releasing and discharging with respect to Plaintiffs and all Class Members the Released Claims against the Released Parties, and permanently barring and enjoining prosecution of any and all Released Claims in any forum; (e) hear and rule on any objections to the Settlement; (f) consider the application of Plaintiffs’ counsel for an award of attorneys’ fees and reimbursement of expenses, and any objections thereto; and (g) rule on other such matters as the Court may deem appropriate. The Court may adjourn and reconvene the Settlement Hearing, including with respect to the consideration of the Fee Application, without further notice to Class Members other than by oral announcement at the Settlement Hearing or any adjournment thereof.

2.The Court may approve the Settlement, according to the terms and conditions of the Stipulation, as it may be modified by the Parties thereto, with or without further notice to Class Members. Further, the Court may enter the Order and Final Judgment dismissing the Consolidated Action against Defendants and the Released Claims with prejudice (as provided in the Stipulation), approving releases by Plaintiffs and the Class of all of the Released Claims against the Released Parties, and ordering the payment of attorneys’ fees and expenses, all without further notice.

3.The Court approves, in form and substance, the Notice of Pendency of Class Action, Proposed Settlement of Class Action and Settlement Hearing (the “Notice”) substantially in the form attached as Exhibit B to the Stipulation. The Court finds the mailing of the Notice in substantially the manner set forth in Paragraph 4 of this Order constitutes the best notice practicable under the circumstances to all persons entitled to such notice of the Settlement Hearing and the proposed Settlement, and meets the requirements of Rule 23 of the Rules of the Court of Chancery and of due process.

4.At least forty-five (45) days before the Settlement Hearing, Plaintiffs shall cause the Notice, along with a Proof of Claim form substantially in the form attached as Exhibit C to the Stipulation, to be mailed by United States mail, first class, postage pre-paid, to each person who is shown on the records of CNX Gas, its successors-in-interest or their respective transfer agents, to be a record holder of any shares who held any such shares at any time during the period beginning on and including March 21, 2010 through and including May 28, 2010, at his, her or its last known address appearing in the stock transfer records maintained by or on behalf of CNX Gas. All record holders in the Class who were not also the beneficial owners of any shares of common stock held by them of record shall be requested in the Notice to forward the Notice to such beneficial owners of those shares. Plaintiffs shall use reasonable efforts to give notice to such beneficial owners by causing additional copies of the Notice (a) to be made available to any record holder who, prior to the Settlement Hearing, requests the same for distribution to beneficial owners, or (b) to be mailed to beneficial owners whose names and addresses Plaintiffs receive from record owners.

5.At least twenty (20) calendar days before the date of the Settlement Hearing, Plaintiffs’ counsel in the Consolidated Action shall file with the Court papers in support of final approval of the Settlement and the Fee Application. Any objection to the Settlement or Fee Application shall be filed at least ten (10) calendar days before the date of the Settlement Hearing. Any reply papers in support of final approval of the Settlement and the Fee Application shall be filed at least five (5) calendar days before the date of the Settlement Hearing.

6.At least ten (10) calendar days before the date of the Settlement Hearing, counsel for Plaintiffs shall file with the Court an appropriate declaration or affidavit with respect to the preparation and mailing of the Notice.

7.At the Settlement Hearing, any member of the Class who desires to do so may appear personally or by counsel, and show cause, if any, why the Class should not be permanently certified, pursuant to Court of Chancery Rules 23(a) and 23(b)(1) and/or (b)(2), for settlement purposes only; why the settlement of this Consolidated Action in accordance with and as set forth in the Stipulation should not be approved as fair, reasonable and adequate to the Class; why the Order and Final Judgment should not be entered in accordance with and as set forth in the Stipulation; or why the Court should not grant an award of reasonable attorneys’ fees and expenses to Plaintiffs’ counsel in the Consolidated Action for their services and actual expenses incurred in the Consolidated Action; provided, however, that unless the Court in its discretion otherwise directs, no Class Member, or any other person, shall be entitled to contest the approval of the terms and conditions of the Settlement or (if approved) the Order and Final Judgment to be entered thereon, or the allowance of fees and expenses to Plaintiffs’ counsel in the Consolidated Action, and no papers, briefs, pleadings or other documents submitted by any Class Member or any other person (excluding a party to the Stipulation) shall be received or considered, except by order of the Court for good cause shown, unless, no later than ten (10) calendar days prior to the Settlement Hearing, such person files with the Register in Chancery, Court of Chancery, 500 North King Street, Wilmington, Delaware 19801, and serves upon the attorneys listed below: (a) a written notice of intention to appear; (b) proof of membership in the Class; (c) a detailed summary of the objections to any matter before the Court; (d) the grounds therefor or the reasons for wanting to appear and be heard; and (e) all documents or writings the Court shall be asked to consider. These papers must be served upon the following attorneys by hand delivery, overnight mail, or electronic filing and service:

Rigrodsky & Long, P.A. Seth D. Rigrodsky Brian D. Long 2 Righter Parkway, Suite 120 Wilmington, DE 19803 Potter, Anderson & Corroon LLP Donald J. Wolfe, Jr. Brian C. Ralston 1313 North Market Street
Wilmington, DE 19801

8.Any person who fails to object in the manner described above shall be deemed to have waived the right to object (including any right of appeal) and shall be forever barred from raising such objection in this or any other action or proceeding. Class Members who do not object need not appear at the Settlement Hearing or take any other action to indicate their approval.

9.Pending final determination of whether the Settlement should be approved and further order of the Court, Plaintiffs, and all members of the Class, are barred and enjoined from commencing or prosecuting, either directly, representatively or in any other capacity, any action asserting any claims that are, or relate in any way to, Released Claims against Released Parties.

10.All proceedings in the Consolidated Action, other than proceedings as may be necessary to carry out the terms and conditions of the Stipulation, are hereby stayed and suspended until further order of this Court.

_____________________________

Vice Chancellor

IN THE COURT OF CHANCERY OF THE STATE OF DELAWARE

IN RE CNX GAS CORPORATION SHAREHOLDERS LITIGATION ) ) CONSOLIDATED C.A. No. 5377-VCL

NOTICE OF PENDENCY OF CLASS ACTION, PROPOSED SETTLEMENT OF CLASS ACTION AND SETTLEMENT HEARING

TO: ALL RECORD HOLDERS AND BENEFICIAL OWNERS OF ANY SHARES OF COMMON STOCK OF CNX GAS CORPORATION (“CNX GAS” OR THE “COMPANY”) WHO HELD OR OWNED ANY SUCH STOCK AT ANY TIME DURING THE PERIOD BEGINNING ON AND INCLUDING MARCH 21, 2010 THROUGH AND INCLUDING MAY 28, 2010, INCLUDING ANY AND ALL OF THEIR RESPECTIVE SUCCESSORS-IN-INTEREST, SUCCESSORS, PREDECESSORS-IN-INTEREST, PREDECESSORS, REPRESENTATIVES, TRUSTEES, EXECUTORS, ADMINISTRATORS, ESTATES, HEIRS, ASSIGNS OR TRANSFEREES, IMMEDIATE AND REMOTE, AND ANY PERSON OR ENTITY ACTING FOR OR ON BEHALF OF, OR CLAIMING UNDER, ANY OF THEM, AND EACH OF THEM, TOGETHER WITH THEIR PREDECESSORS-IN-INTEREST, PREDECESSORS, SUCCESSORS-IN-INTEREST, SUCCESSORS, AND ASSIGNS, BUT EXCLUDING DEFENDANTS (DEFINED BELOW), T. ROWE PRICE (DEFINED BELOW), AND ANY PERSON, FIRM, TRUST, CORPORATION OR OTHER ENTITY RELATED TO OR AFFILIATED WITH ANY DEFENDANT OR T. ROWE PRICE (OTHER THAN EMPLOYEES OF SUCH ENTITIES WHO WERE NOT DIRECTORS OR OFFICERS DURING THE CLASS PERIOD (DEFINED BELOW)), AS WELL AS THE STOCKHOLDERS WHO SUBMITTED THE EXCLUSION REQUEST (DEFINED BELOW).

PLEASE READ THIS NOTICE CAREFULLY AND IN ITS ENTIRETY. YOUR RIGHTS WILL BE AFFECTED BY THE LEGAL PROCEEDINGS IN THIS ACTION. IF THE COURT APPROVES THE PROPOSED SETTLEMENT, YOU WILL BE FOREVER BARRED FROM CONTESTING THE FAIRNESS OF THE PROPOSED SETTLEMENT OR PURSUING THE “RELEASED CLAIMS” (DEFINED BELOW).

IF YOU ARE A NOMINEE WHO HELD CNX GAS COMMON STOCK FOR THE BENEFIT OF ANOTHER, READ THE SECTION BELOW ENTITLED “NOTICE TO PERSONS OR ENTITIES HOLDING RECORD OWNERSHIP ON BEHALF OF OTHERS.”

PURPOSE OF THIS NOTICE

The purpose of this Notice is to inform you of the proposed settlement (the “Settlement”) of the above-captioned lawsuit (the “Consolidated Action”) pending in the Court of Chancery of the State of Delaware (the “Court”). Pursuant to the Settlement, plaintiffs Harold L. Hurwitz (“Hurwitz”) and James R. Gummel (“Gummel”) (together, “Plaintiffs”), on their own behalf and on behalf of all members of the Class (defined herein), have agreed to dismiss with prejudice their claims against CNX Gas, CONSOL Energy Inc. (“CONSOL”), J. Brett Harvey (“Harvey”), Raj K. Gupta (“Gupta”), and Philip W. Baxter (“Baxter”) (collectively, “Defendants”), which relate to the transaction pursuant to which CONSOL commenced a tender offer to acquire all of the outstanding shares of CNX Gas it did not already own for $38.25 per share in cash, and, subsequently, CNX Gas merged with and into a subsidiary of CONSOL via a short-form merger. In consideration of the Settlement, Defendants have agreed to cause the sum of $42,730,913.50 (the “Settlement Amount”) to be paid for benefit of the Class.

This Notice also informs you of your right to participate in a hearing to be held on ____________ __, 2013, at __:__ _.m., before the Court in the New Castle County Courthouse, 500 North King Street, Wilmington, Delaware 19801 (the “Settlement Hearing”) to (a) determine whether the Consolidated Action may be maintained as a class action and whether the Class (defined below) should be recertified permanently, for settlement purposes, pursuant to Delaware Court of Chancery Rules 23(a) and 23(b)(1) and/or (b)(2); (b) determine whether Plaintiffs and Class Counsel have adequately represented the interests of the Class in the Consolidated Action; (c) determine whether a Stipulation and Agreement of Compromise and Settlement dated, May 8, 2013 (the “Settlement Agreement” or the “Stipulation”), and the terms and conditions of the Settlement proposed in the Stipulation, are fair, reasonable and adequate to the members of the Class and should be approved by the Court; (d) determine whether the Order and Final Judgment should be entered dismissing the Consolidated Action and Released Claims with prejudice as against Plaintiffs and the Class, releasing and discharging with respect to Plaintiffs and all Class Members the Released Claims against the Released Parties, and permanently barring and enjoining prosecution of any and all Released Claims in any forum; (e) hear and rule on any objections to the Settlement; (f) consider the application of Plaintiffs’ counsel for an award of attorneys’ fees and reimbursement of expenses, and any objections thereto; and (g) rule on other such matters as the Court may deem appropriate.

BACKGROUND OF THE LAWSUIT

THE DESCRIPTION OF THE CONSOLIDATED ACTION AND SETTLEMENT THAT FOLLOWS HAS BEEN PREPARED BY COUNSEL FOR THE PARTIES (DEFINED BELOW). THE COURT HAS MADE NO FINDINGS WITH RESPECT TO SUCH MATTERS, AND THIS NOTICE IS NOT AN EXPRESSION OR STATEMENT BY THE COURT OF FINDINGS OF FACT.

1.As of March 20, 2010, CONSOL was the largest single stockholder of CNX Gas, owning approximately 83% of the Company’s shares issued and outstanding at that time.

2.On March 20, 2010, CONSOL entered into an agreement with CNX Gas’s largest public stockholder (other than CONSOL), T. Rowe Price Associates, Inc. (“T. Rowe Price”), pursuant to which CONSOL agreed to commence a tender offer to acquire all of the shares of CNX Gas common stock that CONSOL did not already own at a price of $38.25, in cash, per share (the “Tender Offer”).

3.T. Rowe Price was also CONSOL’s third largest stockholder, owning approximately 11,809,600 shares of CONSOL common stock, or 6.51% of CONSOL’s shares issued and outstanding at that time.

4.On March 21, 2010, CONSOL announced that it had entered into the agreement with T. Rowe Price and that it had agreed to commence the Tender Offer. CONSOL subsequently announced that, in the event the conditions of the Tender Offer were satisfied, CONSOL would effect a short-form merger between CNX Gas and a subsidiary of CONSOL (the “Merger,” and together with the Tender Offer, the “Transaction”).

5.On March 29, 2010, Gummel filed a putative class action lawsuit in the Court, captioned Gummel v. CONSOL Energy, Inc., C.A. No. 5377-VCL (“Gummel Action”), against CONSOL alleging, among other things, that it breached its fiduciary duties by attempting to acquire the remaining outstanding shares of CNX Gas not already owned by CONSOL through a coercive and unfair process and for an unfair price.

6.On March 29, 2010, Daniel Schurr filed a putative class action lawsuit in the Court of Common Pleas of Washington County, Pennsylvania (“Pennsylvania Court”), captioned Schurr v. CNX Gas Corporation, Case No. 2010-2333 (“Schurr Action”), against the Company, members of the Company’s Board of Directors (“Board”), certain officers of the Company and CONSOL, and CONSOL, alleging that the Company’s directors and officers breached their fiduciary duties by, among other things, placing their own interests and the interests of the Company’s majority stockholder ahead of those of the Company’s public stockholders, and further alleging that CNX Gas and CONSOL aided and abetted those breaches of fiduciary duty.

7.On March 30, 2010, Ira Gaines (“Gaines”) filed a putative class action lawsuit in the Court, captioned Gaines v. CNX Gas Corporation, C.A. No. 5378-VCL (“Gaines Action”), against the Company, members of the Board, and CONSOL, alleging that the Company’s directors breached their fiduciary duties by, among other things, (i) engaging in a flawed process and failing to act in the interests of CNX Gas’s public stockholders, and (ii) agreeing to an inadequate offer price, and further alleging that CONSOL aided and abetted those breaches of fiduciary duty.

8.On April 12, 2010, Samuel S. Polen filed a putative class action lawsuit in the Pennsylvania Court, captioned Polen v. CNX Gas Corporation, Case No. 2010-2626 (together with the Schurr Action, the “Pennsylvania Actions”), against the Company, members of the Company’s Board, and CONSOL, alleging, among other things, that the Company’s directors breached their fiduciary duties by agreeing to sell CNX Gas to CONSOL through an unfair process and for an unfair price, and that CNX Gas and CONSOL aided and abetted those breaches of fiduciary duty.

9.On April 12, 13, and 20, 2010, Defendants filed motions to stay the Pennsylvania Actions.

10.On April 13, 2010, Hurwitz filed a putative class action lawsuit in the Court, captioned Hurwitz v. CNX Gas Corporation, C.A. No. 5405-VCL (“Hurwitz Action”), against the Company, members of the Board, and CONSOL, alleging that the directors breached their fiduciary duties because they, among other things, (i) had material conflicts of interest by virtue of Defendants Harvey, Gupta, and Baxter all being members of CONSOL’s board of directors, and (ii) as directors of the Company, agreed to accept an inadequate and unfair price, and further alleging that CNX Gas aided and abetted those breaches of fiduciary duty.

11.On April 15, 2010, the CNX Gas Board formed a special committee (“Special Committee”) consisting of the Company’s independent director, John R. Pipski (“Pipski”), to evaluate the Tender Offer.

12.Plaintiffs Gaines and Hurwitz jointly served their First Request for the Production of Documents and Things to All Defendants on April 16, 2010.

13.On April 21, 2010, the Court entered an Order of Consolidation and Appointment of Lead Counsel, which consolidated the Gummel, Gaines, and Hurwitz Actions under the caption In re CNX Gas Corporation Shareholders Litigation, C.A. No. 5377-VCL (as previously defined, the “Consolidated Action”), designated Rigrodsky & Long, P.A. as Plaintiffs’ Co-Lead Counsel, and designated Levi & Korsinsky, LLP as a member of Plaintiffs’ Executive Committee.

14.On April 26, 2010, the Pennsylvania Court entered an Order granting Defendants’ motions to stay the Pennsylvania Actions.

15.On April 28, 2010, CONSOL announced it was commencing the Tender Offer. The Offer to Purchase was filed with the United States Securities and Exchange Commission (“SEC”) on April 28, 2010 on Schedule TO (“Schedule TO”). The Tender Offer was scheduled to expire on May 26, 2010.

16.Plaintiffs filed a Motion for Expedited Proceedings on April 28, 2010, which sought expedited discovery and an expedited hearing and briefing schedule with respect to Plaintiffs’ concomitantly-filed Motion for Preliminary Injunction.

17.On April 30, 2010, Plaintiffs filed a Motion for Commission directed to T. Rowe Price, which was granted on May 3, and on May 3, Plaintiffs filed a Motion for Commission directed to Lazard Ltd. (“Lazard”), the Special Committee’s financial advisor, which was granted the same day.

18.On May 3, 2010, Plaintiffs served a subpoena ad testificandum and duces tecum directed to Stifel Nicolaus & Company, Inc. (“Stifel”), CONSOL’s financial advisor in connection with the Transaction.

19.The parties subsequently came to an agreement regarding a schedule for expedited proceedings and the presentation of Plaintiffs’ Motion for Preliminary Injunction, and a stipulated Order Regarding Expedited Proceedings was entered by the Court on May 5, 2010.

20.On May 11, 2010, the Special Committee filed its Solicitation/Recommendation Statement on Schedule 14D-9 (“14D-9”). In the 14D-9, the Special Committee stated that it expressed no opinion with respect to the Tender Offer and that it was remaining neutral regarding the Tender Offer.

21.On May 12, 2010, Plaintiffs’ counsel took the deposition of Defendant Harvey.

22.On May 12, 2010, Plaintiffs’ counsel took the deposition of Albert Garner, a managing director of Lazard.

23.On May 13, 2010, Plaintiffs’ counsel took the deposition of David Giroux, a portfolio manager at T. Rowe Price.

24.On May 14, 2010, Plaintiffs’ counsel took the deposition of Christopher Shebby (“Shebby”), a managing director at Stifel.

25.On May 14, 2010, Plaintiffs’ counsel took the deposition of Pipski, the sole member of the Special Committee and the independent director of CNX Gas.

26.On May 18, 2010, Plaintiffs filed their Verified Consolidated Class Action Complaint (“Consolidated Complaint”), alleging, among other things, that (i) the Special Committee was unable to perform its function of fully evaluating the Tender Offer because the Special Committee was not granted the authority to consider other alternatives, (ii) the valuation analysis performed by Lazard was flawed and skewed in favor of CONSOL, and (iii) negotiations between CONSOL and T. Rowe Price failed to afford the Company’s minority stockholders any protection. The Consolidated Complaint also alleged numerous omissions of material fact in the 14D-9 and in the Schedule TO filed by CONSOL.

27.Also on May 18, 2010, Plaintiffs filed their Opening Brief in Support of Their Motion for Preliminary Injunction.

28.On May 21, 2010, Defendants filed their Answering Briefs in Opposition to Plaintiffs’ Motion for a Preliminary Injunction.

29.On May 22, 2010, Plaintiffs filed their Reply Brief in Support of Their Motion for a Preliminary Injunction.

30.On May 24, 2010, the Court held an oral argument on the Motion for Preliminary Injunction.

31.On May 25, 2010, the Court entered an Order denying Plaintiffs’ Motion for Preliminary Injunction and issued its accompanying Opinion. Among other things, the Opinion stated that the Transaction would be reviewed for entire fairness. The Court found that Plaintiffs had demonstrated a reasonable likelihood of success on the merits of their claims regarding the fairness of the Tender Offer, but found that Plaintiffs’ disclosure claims were meritless. The Court ultimately denied Plaintiffs’ Motion for Preliminary Injunction because Plaintiffs had not shown any threat of irreparable harm that could not be remedied by an award of post-closing damages.

32.On May 26, 2010, the Tender Offer expired. Approximately 95% of the outstanding CNX Gas shares not already owned by CONSOL were tendered in the offer. A subsidiary of CONSOL then consummated the Merger with CNX Gas on May 28, 2010.

33.On June 4, 2010, Defendants filed their Application for Certification of Interlocutory Appeal.

34.On June 25, 2010, Plaintiffs filed a brief in support of their Opposition to the Application for Certification of Interlocutory Appeal.

35.On July 5, 2010, the Court certified the interlocutory appeal. The Delaware Supreme Court declined to accept the interlocutory appeal in an Order dated July 8, 2010.

36.On June 7, 2010, Pipski, CNX Gas, CONSOL and the Individual Defendants filed separate Motions to Dismiss the Consolidated Complaint. On June 30, 2010, Pipski filed his Opening Brief in support of his Motion to Dismiss.

37.On July 20, 2010, Plaintiffs filed a second Motion for Commission directed to T. Rowe Price, which was granted the same day.

38.On July 23, 2010, the Court dismissed Pipski from the case pursuant to a Stipulation and Order of Dismissal. On July 28, 2010, the Court entered a Stipulation and Order of Partial Dismissal, which dismissed Plaintiffs’ disclosure claims.

39.On August 6, 2010, the remaining Defendants filed their Answer to the Consolidated Complaint.

40.Plaintiffs served their Second Request for the Production of Documents and Things to All Defendants on August 19, 2010.

41.On September 15, 2010, Plaintiffs’ counsel took the deposition of John Wakeman, a portfolio manager at T. Rowe Price.

42.On September 17, 2010, Plaintiffs’ counsel took the deposition of Shawn Driscoll, a research analyst at T. Rowe Price.

43.On September 21, 2010, Plaintiffs’ counsel took the deposition of John Linehan, T. Rowe Price’s Director of U.S. Equity.

44.On September 29, 2010, Plaintiffs filed a Motion for Commission directed to Dominion Resources, Inc., which was granted on October 4, 2010.

45.On November 9, 2010, Gaines voluntarily dismissed his claims against Defendants, while the remaining Plaintiffs continued to prosecute their claims.

46.On December 3, 2010, Defendants’ counsel took the deposition of Plaintiff Gummel.

47.On December 9, 2010, Defendants’ counsel took the deposition of Plaintiff Hurwitz.

48.On December 17, 2010, Plaintiffs filed a Motion for Class Certification.

49.On January 20, 2011, the Court entered a Stipulated Order Granting Plaintiffs’ Motion for Class Certification (the “Certification Order”), which certified a class pursuant to Court of Chancery Rule 23(b)(3) consisting of:

Any and all record holders and beneficial owners of common stock of CNX Gas at any time from March 21, 2010 through and including May 28, 2010. Excluded from the Class are Defendants, T. Rowe Price, and any person, firm, trust, corporation, or other entity related to or affiliated with any Defendant or T. Rowe Price.

50.On February 18, 2011, Plaintiffs’ counsel continued their deposition of Defendant Harvey.

51.On March 10, 2011, Plaintiffs’ counsel continued their deposition of Shebby.

52.On March 11, 2011, Plaintiffs’ counsel took the deposition of Defendant Baxter.    

53.On March 25, 2011, Plaintiffs’ counsel took the deposition of Defendant Gupta.

54.On March 29, 2011, Plaintiffs’ counsel took the deposition of Patrick Keeley, co-head of investment banking at Stifel.

55.On April 1, 2011, Plaintiffs’ counsel took the deposition of Jerome Richey, Chief Legal Officer and Secretary for CONSOL and CNX Gas at the time of the Tender Offer.

56.Plaintiffs filed with the Court and served upon Defendants the expert reports of Daniel Beaulne (“Beaulne”), Plaintiffs’ valuation expert, on April 29, 2011, May 27, 2011, and May 21, 2012.

57.Defendants served expert reports of Dr. Scott T. Jones (“Jones”), Defendants’ valuation expert, on April 29, 2011, May 27, 2011, and June 20, 2012.

58.On May 4, 2011, the Court granted a Stipulation whereby counsel for plaintiff Gaines withdrew from the Consolidated Action.

59.On September 7, 2011, Plaintiffs served their Third Request for the Production of Documents and Things to All Defendants.

60.On November 23, 2011, Plaintiffs filed a Motion to Extend the Fact Discovery Deadline and to Compel Production of Responsive Documents.

61.On December 6, 2011, the Court entered a Briefing Schedule Regarding Plaintiffs’ Motion to Extend the Fact Discovery Deadline and to Compel Production of Responsive Documents.

62.On July 19, 2012, Plaintiffs’ counsel took the deposition of Jones.

63.On July 20, 2012, Defendants’ counsel took the deposition of Beaulne.

64.On January 9, 2013, Plaintiffs’ counsel took the deposition of Stephen M. Kenney, an employee of CONSOL.

65.Throughout the course of the Consolidated Action, Defendants and third parties produced, and Plaintiffs’ counsel reviewed, over 95,000 pages of documents, including, inter alia, Board meeting minutes, Board presentations, and banker books.

66.On January 9, 2013, the Court entered the Stipulated Fifth Amended Pre-Trial Scheduling Order that, among other things, scheduled a four-day trial to commence on March 11, 2013.

67.On January 22, 2013, Plaintiffs filed their Opening Pre-Trial Brief, which argued, inter alia, that the process by which Defendants agreed to the Tender Offer was unfair, that the price paid in the Transaction was unfairly low and did not reflect the fair value of the Company, and that Defendants should bear the burden of proof to show the Transaction was entirely fair. Plaintiffs further argued that the negotiations between CONSOL and T. Rowe Price were not at arms’ length and the Special Committee was rendered powerless to negotiate a better deal, adopt other defensive measures, or seek alternative bidders.

68.On January 28, 2013, Plaintiffs filed an Unopposed Motion for Approval of Class Notice, which was granted by the Court on January 31, 2013.

69.Beginning on or about February 13, 2013, the Notice of Pendency of Class Action and Class Certification (“Class Notice”) was disseminated to the Class, which notified stockholders of, among other things, their right to request exclusion from the Class and the procedure to do so. To Plaintiffs’ counsel’s knowledge, only one exclusion request has been received to date, which request was filed prior to the March 4, 2013 deadline for doing so (the “Exclusion Request”).

70.On February 19, 2013, CNX Gas, CONSOL and the Individual Defendants filed their Pretrial Brief, arguing that the Court’s preliminary injunction Opinion holding that the unified standard was the appropriate standard by which to review the Tender Offer departed from existing Delaware Court of Chancery and Supreme Court precedent. Defendants also argued that they structured the Transaction in good-faith compliance with then-existing Delaware law. Defendants further argued that, even if the Transaction were to be subject to entire fairness review, the price offered by CONSOL was entirely fair and Plaintiffs and the Class sustained no damages.

71.On February 21, 2013, Plaintiffs and Defendants engaged in a one-day in-person mediation session in Washington, D.C., conducted in good faith with arm’s-length negotiations under the supervision and with the assistance of JAMS mediators and arbitrators.

72.Following mediation, Plaintiffs’ counsel prepared a Pre-Trial Stipulation and Order and continued to prepare for trial.

73.Good faith, arm’s-length mediated negotiations continued telephonically following the one-day in-person mediation session.

74.On February 28, 2013, the Parties reached an agreement in principle to settle the Consolidated Action and resolve Plaintiffs’ claims on the basis that Defendants would pay $42,730,913.50, to be distributed to the Class, which amount approximated the difference between $38.25 per share and $41.00 per share for each share owned by members of the Class at the time of the Closing (as defined below).

75.On March 1, 2013, counsel for the Parties informed the Court of the agreement in principle to settle the Consolidated Action, and requested adjournment of the upcoming deadlines and trial dates.

76.Defendants acknowledge that negotiations with Plaintiffs’ counsel were the sole cause of the assumption by Defendants of the obligation to make the Settlement Payment (defined below) pursuant to the Settlement.

77.Defendants have denied, and continue to deny, all allegations of wrongdoing, fault, liability or damage with respect to all claims asserted in the Consolidated Action and the Pennsylvania Actions, including that they have committed any violations of law, that they have acted improperly in any way, and that they have any liability or owe any damages of any kind to Plaintiffs and/or the Class, but are entering into the Stipulation solely because they consider it desirable that the Consolidated Action be settled and dismissed with prejudice in order to, among other things, (i) eliminate the uncertainty, burden, inconvenience, expense, and distraction of further litigation, and (ii) finally put to rest and terminate all the claims that were or could have been asserted by Plaintiffs or any other member of the Class against Defendants in the Consolidated Action, the Pennsylvania Actions, or in any other action, in any court or tribunal, relating to the Transaction.

78.The entry by Plaintiffs into the Stipulation is not an admission as to the lack of any merit of any claims asserted in the Consolidated Action. In negotiating and evaluating the terms of the Stipulation, Plaintiffs’ counsel considered the legal and factual defenses to Plaintiffs’ claims that Defendants raised and might have raised throughout the pendency of the Consolidated Action. In addition, Plaintiffs considered the benefits to be provided to the Class through the Settlement Payment. Based upon their evaluation, Plaintiffs and Plaintiffs’ counsel have determined that the Settlement set forth in the Stipulation is fair, reasonable and adequate to Plaintiffs and the Class, and that it confers substantial benefits upon the Class.

79.The Parties recognize the time and expense that would be incurred by further litigation and the uncertainties inherent in such litigation.

80.The Settlement of the Consolidated Action on the terms and conditions set forth in the Stipulation includes, but is not limited to, a release of all claims that were or could have been asserted in the Consolidated Action.

81.The Court has not finally determined the merits of the claims made by Plaintiffs against, or the defenses of, the Defendants. This Notice does not imply that there has been or would be any finding of violation of the law or that relief in any form or recovery in any amount could be had if the Consolidated Action was not settled.

THE SETTLEMENT TERMS

1.The Settlement of the Consolidated Action has been reached among Plaintiffs, acting in their individual capacities and as representatives of the Class, and Defendants. The terms and conditions of the Settlement are set forth in detail in the Stipulation, which has been filed with the Court. The Settlement is subject to and becomes effective only upon approval by the Court. This Notice only includes a summary of various terms of the Settlement, and does not purport to be a comprehensive description of its terms, which are available for review as described below.

2.The Stipulation provides, among other things, that the Settlement Payment has been agreed to and provided in consideration for the full and final settlement and dismissal with prejudice of the Consolidated Action and the release of any and all Released Claims, including claims asserted in the Pennsylvania Actions, and that no Defendant or other Released Party shall have any obligation to pay or bear any additional amounts, expenses, costs, damages, or fees to or for the benefit of Plaintiffs or any Class Member in connection with the Settlement, including but not limited to attorneys’ fees and expenses for any counsel to any Class Member.

3.If the Court approves the Settlement, each of the following will occur:

a.The Consolidated Action and Released Claims will be dismissed with prejudice on the merits. This dismissal on the merits will be binding as to all Class Members.

b.As of the Effective Date, Plaintiffs and all Class Members, on behalf of themselves, and any and all of their respective successors-in-interest, successors, predecessors-in-interest, predecessors, representatives, trustees, executors, administrators, estates, heirs, assigns or transferees, immediate and remote, and any person or entity acting for or on behalf of, or claiming under, any of them, and each of them, agree to release and forever discharge, and by operation of the Order and Final Judgment shall release and forever discharge, all Released Claims (as defined below) as against all Released Parties (as defined below).

c.As of the Effective Date, Defendants and all Released Parties agree to fully, completely, finally, and forever release, relinquish and discharge Plaintiffs and Plaintiffs’ counsel from all claims, including Unknown Claims, arising out of or relating to the institution, prosecution, settlement, or resolution of the Consolidated Action (provided, however, that this release, relinquishment and discharge shall not include claims by the Parties to enforce the terms of the Settlement or Settlement Agreement).

d.As of the Effective Date, the Released Parties shall be deemed to be released and forever discharged from all of the Released Claims.

e.As of the Effective Date, Plaintiffs and all Class Members, on behalf of themselves, and any and all of their respective successors-in-interest, successors, predecessors-in-interest, predecessors, representatives, trustees, executors, administrators, estates, heirs, assigns or transferees, immediate and remote, and any person or entity acting for or on behalf of, or claiming under, any of them, and each of them, will be forever barred and enjoined from commencing, instituting, maintaining, prosecuting or asserting, either directly or in any other capacity, in any forum, any Released Claims against any of the Released Parties.

f.The Settlement Payment shall be paid as specified below:

i.Within five (5) business days after the Court’s entry of the Scheduling Order (defined herein), $400,000 of the Settlement Amount (the “Administration Fund”) was deposited into the Account (defined in paragraph 12(a) below). The Administration Fund shall be used by Class Counsel or its designees only to pay reasonable and necessary Administrative Costs.

ii.Within ten (10) business days after the Effective Date, the remaining Settlement Amount shall be deposited (net of the $400,000 Administration Fund advancement provided for above) into the Account, provided that Class Counsel has timely provided complete wire transfer information and instructions to Defendants. The Account shall be administered by a paying agent chosen by Class Counsel (the “Paying Agent”) and shall be used (i) to pay any Fee and Expense Award, (ii) to pay Administrative Costs, and (iii) following the payment of the foregoing (i) and (ii), for subsequent disbursement of the Net Settlement Amount to the Settlement Payment Recipients as further described herein.

4.Apart from the payment of the Settlement Amount as described above, Defendants shall have no further monetary obligation to Plaintiffs, the Class, any Class Member, Class Counsel, or any other Plaintiffs’ counsel. The Settlement Amount shall be paid without waiver of any right of Defendants to pursue claims against any insurers who have not reached separate settlements with Defendants regarding their contribution to the Settlement Amount.

5.Class Counsel shall be solely responsible for determining whether any taxes of any kind are due on income earned by the Account, for filing any necessary tax returns, and for causing any necessary taxes to be paid. Any such taxes, as well as any expenses incurred by Class Counsel in connection with determining the amount of, and paying, such taxes shall be considered Administrative Costs and shall be paid out of the Settlement Amount.

6.As soon as reasonably practicable after the Effective Date, the Net Settlement Amount will be disbursed by the Paying Agent to the Settlement Payment Recipients and will be allocated on a per-share basis amongst the Settlement Payment Recipients who have submitted to the Paying Agent a valid Proof of Claim by the deadline provided herein based on the number of shares of CNX Gas common stock held by the applicable Settlement Payment Recipient upon the Closing (provided that if a Settlement Payment Recipient held shares of CNX Gas common stock in registered form and has not submitted a letter of transmittal as of the Effective Date, such payment shall be allocated to such Settlement Payment Recipient but will not be remitted until such Settlement Payment Recipient has submitted its letter of transmittal or other satisfactory proof sufficient to determine whether such Class Member is a Settlement Payment Recipient (the “Initial Distribution”). Defendants shall have no input, responsibility or liability for any claims, payments or determinations by the Paying Agent in respect of Class Member claims for payment under the Settlement. If Plaintiffs and/or the Paying Agent have made reasonable efforts to have Settlement Payment Recipients claim their payments, and the amount of the Net Settlement Amount that remains unclaimed by the Settlement Payment Recipients (the “Unclaimed Amount”) exceeds $100,000 after a period of six (6) months after the Initial Distribution, then the Unclaimed Amount will be re-disbursed by the Paying Agent for payment to all Settlement Payment Recipients, who claimed their payments in the Initial Distribution, on a pro rata basis. If, however, after a period of six (6) months after the Initial Distribution, the amount of the Unclaimed Amount is equal to or less than $100,000, or if any of the Unclaimed Amount remains unclaimed after the re-disbursement described in the preceding sentence, then any such unclaimed amount of the Net Settlement Amount shall be donated to the Delaware Combined Campaign for Justice.

7.Plaintiffs or their designee shall pay out of the Account any and all costs associated with the allocation and distribution of the Net Settlement Amount (including the costs of any re-distribution of the Net Settlement Amount and the costs associated with any charitable donation).

8.Other than as provided in the Stipulation, Defendants, their insurers, and the Released Parties shall have no involvement in, responsibility for, or liability relating to the distribution of the Net Settlement Payment to Class Members. No Class Member shall have any claim against any Plaintiff, Plaintiffs’ counsel, any Defendant, any of the Released Parties, or any of their counsel or insurers based on the distributions made substantially in accordance with the Stipulation and/or orders of the Court.

PROOF OF CLAIM

9.Only Class Members who were beneficial holders of CNX Gas common stock on May 26, 2010, or if they did not tender their shares in the Tender Offer, at the time of the consummation of the short-form merger on May 28, 2010, and who received consideration for shares of CNX Gas common stock in the Transaction, are eligible to participate in the distribution of the Net Settlement Amount. Any Class Member who satisfies one of these criteria, who wishes to participate in the distribution of the Net Settlement Amount, shall submit to the Paying Agent a completed Proof of Claim in the form attached hereto no later than ____________ __, 2013. Any Proof of Claim submitted to the Paying Agent after such date may be rejected as untimely.

10.The Settlement and any Order and Final Judgment entered by the Court, including the releases described herein, shall be binding on all Class Members even if (i) they are ineligible to submit a Proof of Claim because they sold their shares prior to the Closing, or (ii) they fail to submit a valid and timely Proof of Claim.

DISMISSAL AND RELEASE

11.It is the intent of the Parties to the Consolidated Action that the proposed Settlement, if the Court approves it, shall extinguish for all time completely, fully, finally and shall forever compromise, settle, release, discharge, extinguish and dismiss on the merits and with prejudice, upon and subject to the terms and conditions set forth in the Stipulation, all rights, claims and causes of action that are or relate to the Released Claims against any of the Released Parties and that each of the Defendants and each of the other Released Parties shall be deemed to be released and forever discharged from all of the Released Claims.

DEFINITIONS

12. For purposes of the Settlement:

a.“Account” means an account at PNC Bank, NA, with Class Counsel (defined herein) as escrow agent, which is to be maintained by the Paying Agent (defined herein) and into which the Settlement Amount shall be deposited. The funds deposited into the Account shall be invested in instruments backed by the full faith and credit of the United States Government or an agency thereof, or if the yield on such instruments is negative, in an account fully insured by the United States Government or an agency thereof.

b.“Administrative Costs” means all costs and expenses associated with providing notice of the Settlement to the Class or otherwise administering or carrying out the terms of the Settlement.

c.“Class” means any and all record holders and beneficial owners of common stock of CNX Gas Corporation at any time from March 21, 2010 through and including May 28, 2010 (the “Class Period”). Excluded from the Class are Defendants, T. Rowe Price, and any person, firm, trust, corporation, or other entity related to or affiliated with any Defendant or T. Rowe Price (other than employees of such entities who were not directors or officers during the Class Period), as well as the stockholders who submitted the Exclusion Request.

d.“Class Counsel” means Rigrodsky & Long, P.A.

e.“Class Member” or “Class Members” mean a member or members of the Class.

f.“Effective Date” means the first business day following the date on which all of the conditions set forth in Paragraph 14 of the Stipulation shall have occurred.

g.“Fee and Expense Award” means an award to Class Counsel of fees and expenses to be paid from the Settlement Amount (defined herein) approved by the Court in accordance with the Stipulation and in full satisfaction of any and all claims for attorneys’ fees that have been, could be or could have been asserted by Plaintiffs’ counsel or any other counsel for any member of the Class.

h.“Final,” when referring to the Order and Final Judgment, means that the Order and Final Judgment has been entered by the Court and one of the following has occurred: (i) the time for the filing or noticing of any motion for reconsideration, appeal, or other review of the Order and Final Judgment has expired without any such filing or notice, or (ii) the Order and Final Judgment has been affirmed in all material respects on an appeal or after reconsideration or other review and is no longer subject to review upon appeal, reconsideration, or other review, and the time for any petition for reconsideration, reargument, appeal or review of the Order and Final Judgment or any order affirming the Order and Final Judgment has expired; provided, however, that any disputes or appeals relating solely to the amount, payment or allocation of attorneys’ fees and expenses shall have no effect on finality for purposes of determining the date on which the Order and Final Judgment became final, and shall not otherwise prevent, limit, or otherwise affect the Order and Final Judgment or prevent, limit, delay or hinder the Order and Final Judgment’s becoming final.

i.“Final Approval of the Fee Application” shall be deemed to occur on the first business day following the date any award of attorneys’ fees and expenses in connection with the Fee Application (defined herein) becomes final and no longer subject to further appeal or review, whether by affirmance on or exhaustion of any possible appeal or review, lapse of time or otherwise.

j.“Net Settlement Amount” means the Settlement Amount as defined herein less any Fee and Expense Award and Administrative Costs.

k.“Order and Final Judgment” means the Order and Final Judgment to be entered in the Consolidated Action substantially in the form attached as Exhibit D to the Stipulation or as modified by the Court with the written consent of the Parties or as modified by agreement of the Parties in writing.

l.“Parties” means Plaintiffs and Defendants.

m.“Person” means any individual, corporation, partnership, limited liability company, association, affiliate, joint stock company, estate, trust, unincorporated association, entity, government and any political subdivision thereof, or any other type of business or legal entity.

n.“Released Claims” means any and all manner of claims, demands, rights, liabilities, losses, obligations, duties, damages, costs, debts, expenses, interest, penalties, sanctions, fees, attorneys’ fees, actions, potential actions, causes of action, suits, agreements, judgments, decrees, matters, issues and controversies of any kind, nature or description whatsoever, whether known or unknown, disclosed or undisclosed, accrued or unaccrued, apparent or not apparent, foreseen or unforeseen, matured or not matured, suspected or unsuspected, liquidated or not liquidated, fixed or contingent, including Unknown Claims (defined below), that Plaintiffs or any or all other Class Members ever had, now have, or may have, whether direct, derivative, individual, class, representative, legal, equitable or of any other type, or in any other capacity, against any of the Released Parties (defined below), whether based on state, local, foreign, federal, statutory, regulatory, common or other law or rule (including, but not limited to, any claims under federal securities laws, including such claims within the exclusive jurisdiction of the federal courts, or state disclosure law or any claims that could be asserted derivatively on behalf of CNX Gas), which, now or hereafter, are based upon, arise out of, relate in any way to, or involve, directly or indirectly, (i) the Transaction (including either or both of the Tender Offer and the Merger), (ii) any deliberations or negotiations in connection with the Transaction, (iii) the consideration received by Class Members or by any other Person in connection with the Transaction, (iv) the Schedule TO, the 14D-9 or any other disclosures, public filings, periodic reports, press releases, proxy statements or other statements issued, made available or filed relating, directly or indirectly, to the Transaction, (v) the fiduciary duties and obligations of the Released Parties in connection with the Transaction, (vi) any of the allegations in any complaint or amendment(s) thereto filed in the Consolidated Action, including in any of its constituent actions, or the Pennsylvania Actions, or (vii) any other actions, transactions, occurrences, statements, representations, misrepresentations, omissions, allegations, facts, practices, events, claims or any other matters, things or causes whatsoever, or any series thereof, that were, could have been, or in the future can or might be alleged, asserted, set forth, claimed, embraced, involved, or referred to in, or otherwise related, directly or indirectly, in any way to, the Consolidated Action or the Pennsylvania Actions, or the subject matter of those actions; provided, however, that the Released Claims shall not include claims to enforce the Settlement.

k.Whether or not any or all of the following Persons were named, served with process or appeared in the Consolidated Action, “Released Parties” means (i) Defendants (i.e., CNX Gas, CONSOL, Harvey, Baxter, and Gupta), (ii) any Person which is, was, or will be related to or affiliated with any or all of Defendants or in which any or all of Defendants has, had, or will have a controlling interest, and (iii) each and all of the foregoing’s respective past, present, or future family members, spouses, heirs, trusts, trustees, executors, estates, administrators, beneficiaries, distributees, foundations, agents, employees, fiduciaries, general or limited partners or partnerships, joint ventures, member firms, limited liability companies, corporations, parents, subsidiaries, divisions, affiliates, associated entities, stockholders, principals, officers, managers, directors, managing directors, members, managing members, managing agents, predecessors, predecessors-in-interest, successors, successors-in-interest, assigns, financial or investment advisors, advisors, consultants, investment bankers, entities providing any fairness opinion, underwriters, brokers, dealers, lenders, commercial bankers, attorneys, personal or legal representatives, accountants, insurers, co-insurers, reinsurers, and associates.

l.“Settlement” means the settlement of the Consolidated Action between and among Plaintiffs, on behalf of themselves and the Class, and Defendants, as set forth in the Stipulation.

m.“Settlement Amount” means a total of forty-two million, seven hundred thirty thousand nine hundred thirteen dollars and fifty cents in cash ($42,730,913.50). Defendants and/or their insurers will fund in its entirety the Settlement Amount. Nothing in this paragraph shall have an effect on the respective rights and obligations between or among Defendants or their respective insurers, or upon any separate agreements concerning the claims, defenses, debts, obligations or payments between or among Defendants.

n.“Settlement Payment Recipients” means all Class Members who were beneficial holders of CNX Gas common stock on May 26, 2010, or if they did not tender their shares in the Tender Offer, at the time of the consummation of the short-form merger on May 28, 2010 (the “Closing”), and who received consideration for shares of CNX Gas common stock in the Transaction, and who submitted a valid claim form in the form attached hereto (the “Proof of Claim”) to the Paying Agent.

PROCEDURE

13.If the Stipulation is terminated pursuant to Paragraph 20 thereof, (a) Plaintiffs shall within ten (10) business days cause to be refunded to CONSOL all amounts held in the Account as of the date of termination (i.e., the Administration Fund, plus any interest earned thereon and less any reasonable and necessary Administrative Costs incurred prior to such date), and (b) all of the Parties to the Stipulation shall be deemed to have reverted to their respective litigation status immediately prior to the execution of the Stipulation, and they shall proceed in all respects as if the Stipulation had not been executed (except for Paragraphs 20, 21, 27, and 28 thereof, which shall survive the occurrence of any such event) and the related orders had not been entered, and in that event all of their respective claims and defenses as to any issue in the Consolidated Action shall be preserved without prejudice in any way. Furthermore, in the event of such termination, Plaintiffs and Plaintiffs’ counsel agree that neither the Stipulation, nor any statements made in connection with the negotiation of the Stipulation, may be used or entitle any Party to recover any fees, costs or expenses incurred in connection with the Consolidated Action or in connection with any other litigation or judicial proceeding.

14.If the Court approves the Settlement, the Consolidated Action and the Released Claims will be dismissed on the merits with respect to all Released Parties and with prejudice against Plaintiffs and all Class Members. Such release and dismissal will bar the institution or prosecution by any of the Plaintiffs or any Class Member of any other action asserting any Released Claim against any of the Released Parties

15.In the event that the Stipulation is terminated pursuant to its terms or is not
approved in all material respects by the Court, Defendants withdraw from the Settlement pursuant to the terms of the Stipulation, the Effective Date does not occur, the proposed Settlement otherwise does not become final for any reason, or any judgment or order entered pursuant to the Stipulation is reversed, vacated, or modified in any material respect by the Court or any other court, no reference to the Stipulation or any documents related thereto shall be made by the Parties for any purpose, except as expressly authorized by the terms of the Stipulation. If any of the foregoing events occur, Defendants reserve the right to oppose certification of any plaintiff class in any proceeding.

RELEASE OF UNKNOWN CLAIMS

16.The releases contemplated in the Settlement and Stipulation extend to Unknown Claims, as defined in the following paragraph.

17.“Unknown Claims” means any claim that any Plaintiff or any other Class Member does not know or suspect exists in his, her or its favor at the time of the release of the Released Claims as against the Released Parties, including without limitation those which, if known, might have affected the decision to enter into the Settlement or to object or to not object to the Settlement. With respect to any of the Released Claims, the Parties have stipulated and agreed that upon the occurrence of the Effective Date, Plaintiffs shall expressly and each Class Member shall be deemed to have, and by operation of the Order and Final Judgment shall have, expressly waived, relinquished and released any and all provisions, rights and benefits conferred by or under Cal. Civ. Code § 1542 or any law of the United States or any state of the United States or territory of the United States, or principle of common law, which is similar, comparable or equivalent to Cal. Civ. Code § 1542, which provides:

A GENERAL RELEASE DOES NOT EXTEND TO CLAIMS WHICH THE CREDITOR DOES NOT KNOW OR SUSPECT TO EXIST IN HIS OR HER FAVOR AT THE TIME OF EXECUTING THE RELEASE, WHICH IF KNOWN BY HIM OR HER MUST HAVE MATERIALLY AFFECTED HIS OR HER SETTLEMENT WITH THE DEBTOR.

18.Plaintiffs acknowledge, and the Class Members by operation of law shall be deemed to have acknowledged, that they may discover facts in addition to or different from those now known or believed to be true with respect to the Released Claims, but that it is the intention of Plaintiffs, and by operation of law the Class Members, to completely, fully, finally and forever extinguish any and all Released Claims, known or unknown, suspected or unsuspected, which now exist, or heretofore existed, or may hereafter exist, and without regard to the subsequent discovery of additional or different facts. Plaintiffs acknowledge, and the Class Members by operation of law shall be deemed to have acknowledged, that the inclusion of “Unknown Claims” in the definition of “Released Claims” was separately bargained for and was a material element of the Settlement and was relied upon by each and all of Defendants in entering into the Settlement Agreement.

ATTORNEYS’ FEES

19.Plaintiffs’ counsel intend to petition the Court for an award of attorneys’ fees in an aggregate amount of 27.5% of the Settlement Amount plus reimbursement of expenses incurred in connection with the Consolidated Action (the “Fee Application”), which petition will be wholly inclusive of any request for attorneys’ fees and expenses on behalf of any Class Member or his, her or its counsel in connection with the Settlement. Defendants agree not to oppose this request and shall take no position as to the Fee Application. The Parties acknowledge and agree that any attorneys’ fees and expenses awarded by the Court in the Consolidated Action to Plaintiffs’ counsel shall be paid solely from the Settlement Payment. The Fee Application shall be the only petition for attorneys’ fees and expenses filed by or on behalf of Plaintiffs and Plaintiffs’ counsel. The Parties shall cooperate in opposing any other petition for an award of attorneys’ fees or reimbursement of expenses in connection with any other litigation concerning the Transaction. In the event that the Court awards any attorney’s fees or reimbursement of expenses to counsel for any Class Member other than Class Counsel in connection with the Settlement, including counsel for any plaintiff in the Pennsylvania Actions, such fees and/or expenses shall be paid out of the Settlement Amount and no Defendant shall have any further responsibility therefor.

20.Final resolution by the Court of the Fee Application shall not be a precondition to the Settlement or the dismissal of the Consolidated Action in accordance with the Settlement and the Stipulation, and the Fee Application may be considered separately from the Settlement. Neither any failure of the Court or any other court (including any appellate court) to approve the Fee Application in whole or in part, nor any other reduction, modification, or reversal of the award order or failure of the award order to become final, shall have any impact on the effectiveness of the Settlement, provide any of the Parties with the right to terminate the Settlement or the Stipulation, or affect or delay the binding effect or finality of the Order and Final Judgment and the release of the Released Claims. Notwithstanding any other provision of the Stipulation, no fees or expenses shall be paid to Plaintiffs’ counsel in the absence of the occurrence of Final Approval of the Fee Application.

CLASS CERTIFICATION

21.On _________ __, 2013, the Court entered an Order (the “Scheduling Order”) providing for, among other things, the mailing of this Notice to the Class Members and the scheduling of the Settlement Hearing.

22.At the Settlement Hearing, the Court will determine, among other things,
whether (i) the Class contemplated in the Consolidated Action is so numerous that joinder of all members is impracticable; (ii) there are questions of law or fact common to the Class; (iii) the claims of the representative Plaintiffs are typical of the claims of the Class; (iv) the class representatives and Class Counsel have fairly and adequately protected the interests of the Class; and (v) the Consolidated Action otherwise complies with Delaware Court of Chancery Rules 23(a) and (b)(1) and/or (b)(2).

THE SETTLEMENT HEARING

23.The Court has scheduled a Settlement Hearing which will be held on __________ __, 2013 at __:__ _.m., in the Court of Chancery in the New Castle County Courthouse, 500 North King Street, Wilmington, Delaware 19801 to:

a.Determine whether the Certification Order may be amended to provide that the Consolidated Action may be maintained as a class action and that the Class should be recertified, for settlement purposes, pursuant to Delaware Court of Chancery Rules 23(a) and 23(b)(1) and/or (b)(2);

b.Determine whether Plaintiffs and Class Counsel have adequately represented the interests of the Class in the Consolidated Action;

c.Determine whether the Stipulation, and the terms and conditions of the Settlement proposed in the Stipulation, are fair, reasonable and adequate to the Class Members and should be approved by the Court;

d.Determine whether the Order and Final Judgment should be entered dismissing the Consolidated Action and Released Claims with prejudice as against Plaintiffs and the Class, releasing and discharging with respect to Plaintiffs and all Class Members the Released Claims against the Released Parties, and permanently barring and enjoining prosecution of any and all Released Claims in any forum;

e.Hear and rule on any objections to the Settlement;

f.Consider the Fee Application, and any objections thereto; and

g.Rule on other such matters as the Court may deem appropriate.

RIGHT TO APPEAR AT SETTLEMENT HEARING

24.Any Class Member who objects to the Stipulation, the Settlement, the class action determination, the Order and Final Judgment to be entered therein, and/or the Fee Application, or who otherwise wishes to be heard, may appear in person or through counsel at the Settlement Hearing and present any evidence or argument that may be proper and relevant. To do so, you must, no later than ten (10) calendar days prior to the Settlement Hearing (unless the Court otherwise directs for good cause shown), serve the following documents on the attorneys listed below: (a) a written notice of the intention to appear; (b) proof of membership in the Class, (c) a detailed summary of the objections to any matter before the Court; (d) the grounds therefor or the reasons for wanting to appear and to be heard; and (e) all documents and writings the Court shall be asked to consider. These papers must be served upon the following attorneys by hand delivery, overnight mail, or electronic filing and service:

Rigrodsky & Long, P.A. Seth D. Rigrodsky Brian D. Long 2 Righter Parkway, Suite 120 Wilmington, DE 19803 Potter, Anderson & Corroon LLP Donald J. Wolfe, Jr. Brian C. Ralston 1313 North Market Street
Wilmington, DE 19801

25.You must also contemporaneously deliver a copy to the Register in Chancery, Court of Chancery, 500 North King Street, Wilmington, Delaware 19801. Even if you do not appear at the Settlement Hearing, the Court will consider your written submission if it is served and filed in accordance with the foregoing procedures. ANY PERSON WHO FAILS TO OBJECT IN THE MANNER PRESCRIBED ABOVE SHALL BE DEEMED TO HAVE WAIVED SUCH OBJECTION AND SHALL FOREVER BE BARRED FROM RAISING SUCH OBJECTION IN THE CONSOLIDATED ACTION OR ANY OTHER ACTION OR PROCEEDING.

ORDER AND FINAL JUDGMENT OF THE COURT

26.If the Settlement is approved by the Court, the Parties will promptly request the Court to enter an Order and Final Judgment, which will, among other things:

a.Make final the Court’s determination to recertify the Class pursuant to Court of Chancery Rules 23(a) and 23(b)(1) and/or (b)(2) for purposes of the Settlement;

b.Approve the Settlement, adjudge the terms of the Settlement to be fair, reasonable, and adequate to the Class, and direct consummation of the Settlement in accordance with the terms and conditions of the Stipulation;

c.Determine that the requirements of the Court of Chancery Rules and due process have been satisfied in connection with notice to the Class;

d.Dismiss the Consolidated Action and the Released Claims with prejudice, said dismissal subject only to compliance by the Parties with the terms of the Stipulation and any Order of the Court concerning the Stipulation;

e.Release, settle, and discharge the Released Parties from and with respect to all Released Claims;

f.Permanently bar and enjoin Plaintiffs and all other Class Members, and any and all of their respective successors-in-interest, successors, predecessors-in-interest, predecessors, representatives, trustees, executors, administrators, estates, heirs, assigns or transferees, immediate and remote, and any person or entity acting for or on behalf of, or claiming under, any of them, and each of them, from commencing, instituting, maintaining, prosecuting or asserting, either directly or in any other capacity, in any forum, any Released Claims against any of the Released Parties;

g.Release, settle, and discharge Plaintiffs and Plaintiffs’ counsel from all claims, including Unknown Claims, arising out of or relating to the institution, prosecution, settlement, or resolution of the Consolidated Action (other than claims by the Parties to the Stipulation to enforce the terms of the Stipulation or Settlement); and

h.Provide that the Order and Final Judgment, including the release of all Released Claims against all Released Parties, shall have res judicata and other preclusive effect in all pending and future lawsuits, arbitrations or other proceedings maintained by or on behalf of, any of the Plaintiffs and all other Class Members, as well as any and all of their respective successors-in-interest, successors, predecessors-in-interest, predecessors, representatives, trustees, executors, administrators, estates, heirs, assigns or transferees, immediate and remote, and any person or entity acting for or on behalf of, or claiming under, any of them, and each of them.

SCOPE OF THIS NOTICE AND FURTHER INFORMATION

27.This Notice does not purport to be a comprehensive description of the Consolidated Action, the allegations or transactions related thereto, the Settlement Payment, the terms of the Stipulation and Settlement, or the Settlement Hearing. For a more detailed statement of the matters involved in this litigation, you may inspect the pleadings, the Stipulation, the Orders entered by the Court, and other papers filed in the Consolidated Action, unless sealed, at the Office of the Register in Chancery, Court of Chancery, 500 North King Street, Wilmington, Delaware 19801, during regular business hours of each business day. DO NOT WRITE OR TELEPHONE THE COURT. Questions regarding the Settlement should be directed to Plaintiffs’ counsel as follows:

Rigrodsky & Long, P.A.

Seth D. Rigrodsky

Brian D. Long

Gina M. Serra

2 Righter Parkway, Suite 120

Wilmington, DE 19803

(302) 295-5310

NOTICE TO PERSONS OR ENTITIES HOLDING RECORD OWNERSHIP ON BEHALF OF OTHERS

28.Brokerage firms, banks, and other persons or entities who are members of the Class in their capacities as record holders, but not as beneficial holders, are requested to send this Notice promptly to beneficial holders. Additional copies of this Notice for transmittal to beneficial holders are available by writing to the Notice Administrator, as follows:

IN RE CNX GAS CORPORATION SHAREHOLDERS LITIGATION

NOTICE ADMINISTRATOR

ATTENTION: FULFILLMENT DEPARTMENT

c/o A.B. DATA, LTD.

3410 WEST HOPKINS STREET

PO BOX 170500

MILWAUKEE, WI 53217-8091

866-561-6065

1-414-961-4888 outside the United States or Canada

1-414-961-6588 fax

fulfillment@abdata.com

abdataclassaction.com

18.You may also furnish the names and addresses of your beneficial holders in writing to the Notice Administrator, which will then be responsible for sending the Notice to such beneficial holders, by sending such names and addresses to the Notice Administrator, at the following address:

IN RE CNX GAS CORPORATION SHAREHOLDERS LITIGATION

NOTICE ADMINISTRATOR

ATTENTION: FULFILLMENT DEPARTMENT

c/o A.B. DATA, LTD.

3410 WEST HOPKINS STREET

PO BOX 170500

MILWAUKEE, WI 53217-8091

866-561-6065

1-414-961-4888 outside the United States or Canada

1-414-961-6588 fax

fulfillment@abdata.com

abdataclassaction.com

BY ORDER OF THE COURT

Register in Chancery

Dated: ________ __, 2013

IN THE COURT OF CHANCERY OF THE STATE OF DELAWARE

IN RE CNX GAS CORPORATION SHAREHOLDERS LITIGATION Consolidated C.A. No. 5377-VCL For Official Use Only
*CNX Gas*

PROOF OF CLAIM

Please complete the Proof of Claim below if you were a record holder or beneficial owner of CNX Gas Corporation (“CNX Gas”) common stock at the closing of the Tender Offer consummated by CONSOL Energy Inc. (“CONSOL”) on May 26, 2010 (“Tender Offer”), or if you were a record holder or beneficial owner of CNX Gas and did not tender your shares in the Tender Offer, at the time of the consummation of the short-form merger on May 28, 2010. Excluded persons and entities include CNX Gas; CONSOL; T. Rowe Price Associates, Inc. (“T. Rowe Price”); J. Brett Harvey (“Harvey”), Phillip W. Baxter (“Baxter”), and Raj K. Gupta (“Gupta”) (CNX Gas, CONSOL, Harvey, Baxter, and Gupta are collectively referred to as “Defendants”); and any person, firm, trust, corporation, or other entity related to or affiliated with any Defendant or T. Rowe Price (other than employees of such entities who were not directors or officers during the period from March 21, 2010 through and including May 28, 2010), as well as the stockholders who submitted the Exclusion Request (as defined in the Notice of Pendency of Class Action, Proposed Settlement of Class Action and Settlement Hearing (“Notice”)).

This Proof of Claim must contain the name, address, and taxpayer identification number (TIN) of the beneficial owner(s). The TIN, consisting of a valid Social Security number (SSN) for individuals or employer identification number (EIN) for business entities, trusts, estates, etc., and telephone number of the beneficial owner(s) may be used in verifying this claim; this information is required.

You must also provide the quantity of shares and the stock certificate numbers (if shares were held in certificate form; if shares were held through a brokerage account, certificate numbers would not be needed). You must sign the Proof of Claim in the space provided in order to make a valid claim. Please also provide your brokerage statement for May 2010 or a letter from your bank, broker, or other nominee indicating the quantity of shares held at the closing of the Tender Offer on May 26, 2010, or if you did not tender your shares in the Tender Offer, the quantity of shares held at the time of the consummation of the short-form merger on May 28, 2010. If you held shares in certificate form, please provide confirmation from the transfer agent of surrender.

Proof of Claim forms must be postmarked no later than    and mailed to:

IN RE CNX GAS CORPORATION SHAREHOLDERS LITIGATION

NOTICE ADMINISTRATOR

ATTENTION: FULFILLMENT DEPARTMENT

c/o A.B. DATA, LTD.

3410 WEST HOPKINS STREET

PO BOX 170500

MILWAUKEE, WI 53217-8091

1. Please sign the below release and certification. If this Proof of Claim is being submitted on behalf of multiple claimants, then all claimants must sign.

2.Remember to attach only copies of acceptable supporting documentation.

3.Please do not highlight any portion of the Proof of Claim or any supporting documents.

4.Do not send original stock certificates or documentation. These items cannot be returned to you by the Paying Agent.

5.Keep copies of the completed Proof of Claim and documentation for your own records.

6.You will not receive confirmation of receipt of your Proof of Claim; if confirmation is desired, please send your Proof of Claim Certified Mail, Return Receipt requested.

7. If your address changes in the future, or if this Proof of Claim was sent to an old or incorrect address, please send the Paying Agent written notification of your new address. If you change your name, please inform the Paying Agent.

8. If you have any questions or concerns regarding your Proof of Claim, please contact the Paying Agent at the above address or call ___________________ or visit abdataclassaction.com/cases.aspx.

PART I—CLAIMANT INFORMATION

Last Name (Claimant)                                     First Name (Claimant)

Last Name (Beneficial Owner If Different from Claimant)                     First Name (Beneficial Owner)

Last Name (Co-Beneficial Owner)                                  First Name (Co-Beneficial Owner)

Company/Other Entity (If Claimant Is Not an Individual)                     Contact Person (If Claimant Is Not an Individual)

Record Owner’s Name (If Different From Beneficial Owner Listed Above (e.g., Trust, Nominee, Other, etc.))

Account Number (If Claimant Is Not an Individual)                     Trust/Other Date (If Applicable)

Address Line 1

Address Line 2 (If Applicable)

City                                                 State         Zip Code

Foreign Province                         Foreign Zip Code                 Foreign Country                    

□ Check Here to Use Alternate Address for Distribution (Optional)

Distribution Address Line 1

Distribution Address Line 2 (If Applicable)

City                                                 State         Zip Code

Foreign Province                         Foreign Zip Code                 Foreign Country                    

Telephone Number (Day)                                 Telephone Number (Night)

Beneficial Owner’s Employer Identification Number or Social Security Number                            

E-mail Address (an e-mail address is not required, but if you provide it, you authorize the Paying Agent to use it in providing you with information relevant to this claim.)

IDENTITY OF CLAIMANT (check only one):□Individual□ Corporation□ Joint Owners□ Estate□ Trust□ Partnership□ Private Pension Fund□ Legal Representative□ IRA, Keogh, or other type of individual retirement plan (indicate type of plan, mailing address, and name of current custodian on separate sheet)□ Other (specify, describe on separate sheet)

PART II—HOLDINGS ON MAY 26, 2010 OR MAY 28, 2010

HOLDINGS ON MAY 26, 2010 OR MAY 28, 2010:

State the number of shares of CNX Gas common stock surrendered at the closing of the Tender Offer on May 26, 2010, or if you did not tender your shares in the Tender

Offer, the number of shares at the time of the consummation of the short-form merger on May 28, 2010. Documentation includes brokerage statements from May 2010 showing the quantity of shares surrendered, a letter from your bank, broker, or other nominee indicating the quantity of shares surrendered, or proof of stock certificate surrender (see below for more details if your shares were held in certificate form).

    Proof enclosed: □ Y □ N

STOCK CERTIFICATE NUMBERS (If applicable)

List below the stock certificate numbers for all CNX Gas common stock surrendered pursuant to the Tender Offer on May 26, 2010      Proof of surrender enclosed? □ Y □ N

or the merger on May 28, 2010, for all shares NOT HELD IN A BROKERAGE ACCOUNT. Be sure to attach documentation of surrender such as a letter

accompanying a payment for surrendered shares from the transfer agent or your broker.

CERTIFICATE 1:

CERTIFICATE 2:

CERTIFICATE 3:

CERTIFICATE 4:

CERTIFICATE 5:

IF YOU REQUIRE ADDITIONAL SPACE, ATTACH EXTRA SCHEDULES IN THE SAME FORMAT AS ABOVE. PRINT THE BENEFICIAL OWNER’S FULL NAME AND TAXPAYER IDENTIFICATION NUMBER ON EACH ADDITIONAL PAGE.

YOU MUST SIGN THE PROOF OF CLAIM ON PAGE __.

PART III—RELEASE AND CERTIFICATION

On behalf of myself (ourselves) or the beneficial owner, I (we) am (are) authorized to file this Proof of Claim, and on behalf of each of my (our, his, her, its) heirs, agents, executors, trustees, administrators, predecessors, successors, and assigns, I (we, he, she, it) hereby acknowledge that as of the Effective Date, I (we, he, she, it) shall (i) be deemed to have fully, finally, and forever waived, released, discharged, and dismissed each and every one of the Released Claims (as defined in the Notice), as against each and every one of the Released Parties; (ii) forever be barred and enjoined from commencing, instituting, prosecuting, or maintaining any of the Released Claims against any of the Released Parties; and (iii) be deemed to have covenanted not to sue any Released Party on the basis of any Released Claim or, unless compelled by operation of law, to assist any person in commencing or maintaining any suit relating to any Released Claim against any Released Party.

□ By checking this box I certify that I (we) am (are) or, if I am filing on behalf of another, that party, is not an excluded party under the terms of the Stipulation. Excluded parties include: CNX Gas, CONSOL, T. Rowe Price, Harvey, Baxter, Gupta, and any person, firm, trust, corporation, or other entity related to or affiliated with any Defendant or T. Rowe Price (other than employees of such entities who were not directors or officers during the period from March 21, 2010 through and including May 28, 2010), as well as the stockholders who submitted the Exclusion Request.

By signing and submitting this Proof of Claim, the claimant(s) or the person(s) who represent(s) the claimant(s) certifies (certify) as follows:

1. That I (we) have read the Notice, and the Proof of Claim, including the releases provided for in the settlement;

2.That the claimant(s) is (are) a Class Member(s), as defined in the Notice, and is (are) not excluded from the Class;

3. That the claimant(s) owned the CNX Gas common stock identified in the Proof of Claim and has (have) not assigned the claim against the Released Parties to another, or that, in signing and submitting this Proof of Claim, the claimant(s) has (have) the authority to act on behalf of the owner(s) thereof;

4. That the claimant(s) has (have) not submitted any other claim covering the same purchases, acquisitions, sales, or holdings of CNX Gas common stock and knows (know) of no other person having done so on his/her/its/their behalf;

5. That the claimant(s) submits (submit) to the jurisdiction of the Court with respect to his/her/its/their claim and for purposes of enforcing the releases provided for in the settlement;

6. That I (we) agree to furnish such additional information with respect to this Proof of Claim as the Paying Agent or the Court may require;

7. That I (we) acknowledge that the claimant(s) will be bound by and subject to the terms of the Stipulation and Agreement of Compromise and Settlement and any judgment that may be entered in the litigation, including the releases and covenants set forth therein; and

8. That I (we) certify that I am (we are) not subject to backup withholding under the provisions of Section 3406(a)(1)(c) of the Internal Revenue Code.

NOTE: If you have been notified by the Internal Revenue Service that you are subject to backup withholding, please strike the language that you are not subject to backup withholding in the certification above. The Internal Revenue Service does not require your consent to any provision other than the certification required to avoid backup withholding.

UNDER THE PENALTIES OF PERJURY, I (WE) CERTIFY THAT ALL OF THE INFORMATION PROVIDED BY ME (US) ON THIS FORM IS TRUE, CORRECT, AND COMPLETE AND THAT THE DOCUMENTS SUBMITTED HEREWITH ARE TRUE AND CORRECT COPIES OF WHAT THEY PURPORT TO BE.

Signature of Claimant    Date    Print Name of Claimant

Signature of Joint Claimant (if any)    Date    Print Name of Joint Claimant

Capacity of Person(s) Signing, e.g., beneficial owner(s), executor, administrator, trustee, etc.

THIS PROOF OF CLAIM MUST BE MAILED TO THE PAYING AGENT POSTMARKED BY _____________________________.

IN THE COURT OF CHANCERY OF THE STATE OF DELAWARE

IN RE CNX GAS CORPORATION SHAREHOLDERS LITIGATION ) ) CONSOLIDATED C.A. No. 5377-VCL

ORDER AND FINAL JUDGMENT

On this ____ day of _____________, 2013, a hearing having been held before this Court to determine whether the terms and conditions of the Stipulation and Agreement of Compromise and Settlement, dated May 8, 2013 (the “Stipulation” or the “Settlement Agreement”), which is incorporated herein by reference, and the terms and conditions of the settlement proposed in the Stipulation (the “Settlement”) are fair, reasonable and adequate for the settlement of all claims asserted; and whether the Settlement should be approved by this Court and the Order and Final Judgment should be entered in the above-captioned consolidated class action (the “Consolidated Action”); and the Court having considered all matters submitted to it at the hearing and otherwise;

NOW, THEREFORE, IT IS HEREBY ORDERED, ADJUDGED AND DECREED AS FOLLOWS:

1.This Order and Final Judgment incorporates and makes part hereof the Stipulation filed with this Court on May 8, 2013, including Exhibits A-D thereto. Unless otherwise defined in this Order and Final Judgment, the capitalized terms herein have the same meaning as they have in the Stipulation.

2.The mailing of the Notice of Pendency of Class Action, Proposed Settlement of Class Action and Settlement Hearing (the “Notice”) pursuant to and in the manner prescribed in the Scheduling Order on Approval of Class Action Settlement and Class Certification entered on ___________ __, 2013 (the “Scheduling Order”), which was mailed by first class mail on ____________ __, 2013, according to the proof of such mailing of the Notice to the Class filed with the Court by counsel for Plaintiffs, is hereby determined to be the best notice practicable under the circumstances and in full compliance with Rule 23 of the Rules of the Court of Chancery, the requirements of due process, and applicable law.

3.The Court hereby amends the Stipulated Order Granting Plaintiffs’ Motion for Class Certification, dated January 20, 2011, to provide that the Consolidated Action is a proper class action, for settlement purposes only, pursuant to Rules 23(a) and 23(b)(1) and/or (b)(2) of the Rules of the Court of Chancery, and hereby recertifies a Class as consisting of:

Any and all record holders and beneficial owners of common stock of CNX Gas at any time from March 21, 2010 through and including May 28, 2010 (the “Class Period”). Excluded from the Class are Defendants, T. Rowe Price, and any person, firm, trust, corporation, or other entity related to or affiliated with any Defendant or T. Rowe Price (other than employees of such entities who were not directors or officers during the Class Period), as well as the stockholders who submitted the Exclusion Request.

4.Specifically, the Court finds that the Class satisfies the numerosity requirement of Rule 23(a)(1). As of May 13, 2010, there were over 15.5 million public shares of CNX Gas common stock issued and outstanding held by numerous stockholders that comprise the Class. There are common issues of fact and law sufficient to satisfy Rule 23(a)(2), including whether Defendants breached their fiduciary duties to members of the Class, and whether Plaintiffs and the members of the Class were damaged as a consequence of Defendants’ actions. The claims of the representative Plaintiffs are typical of the claims of absent members of the Class in that they all arise from the same allegedly wrongful course of conduct and are based on the same legal theories, satisfying Rule 23(a)(3). The representative Plaintiffs and Class Counsel are adequate representatives of the Class, satisfying Rule 23(a)(4). In addition, the prosecution of separate actions by Class Members would create a risk of inconsistent or varying adjudications with respect to individual Class Members which would establish incompatible standards of conduct for Defendants; the prosecution of separate actions by Class Members would create a risk of adjudications with respect to individual Class Members which would, as a practical matter, be dispositive of the interests of the other Class Members not parties to the adjudications or substantially impair or impede their ability to protect their interests; and Defendants have allegedly acted or refused to act on grounds generally applicable to the Class, thereby making appropriate final injunctive relief or declaratory relief with respect to the Class as a whole.

5.The Settlement of this Consolidated Action as provided for in the Stipulation is approved as fair, reasonable and adequate to Plaintiffs and the Class.

6.The Parties to the Stipulation are hereby authorized and directed to consummate the Settlement in accordance with the terms and provisions of the Stipulation.

7.This Consolidated Action and all Released Claims are hereby dismissed on the merits and with prejudice, and without costs, in full and final discharge of any and all claims or obligations that were or could have been asserted in the Consolidated Action against Defendants.

8.All Class Members shall be and are deemed bound by the Stipulation and this Order and Final Judgment. This Order and Final Judgment, including the release of all Released Claims against all Released Parties, shall have res judicata and other preclusive effect in all pending and future lawsuits, arbitrations or other proceedings maintained by or on behalf of any of the Plaintiffs and all other Class Members, as well as any and all of their respective successors-in-interest, successors, predecessors-in-interest, predecessors, representatives, trustees, executors, administrators, estates, heirs, assigns or transferees, immediate and remote, and any person or entity acting for or on behalf of, or claiming under, any of them, and each of them.

9.Plaintiffs and the Class Members, on behalf of themselves, and any and all of their respective successors-in-interest, successors, predecessors-in-interest, predecessors, representatives, trustees, executors, administrators, estates, heirs, assigns or transferees, immediate and remote, and any person or entity acting for or on behalf of, or claiming under, any of them, and each of them, but excluding Defendants and any firm, trust, corporation or other entity controlled by any Defendant, for good and sufficient consideration received, hereby shall be deemed to have, and by operation of this Order and Final Judgment shall have, fully, completely and forever released and discharged (i) Defendants (i.e., CNX Gas, CONSOL, Harvey, Baxter, and Gupta), (ii) any Person which is, was, or will be related to or affiliated with any or all of Defendants or in which any or all of Defendants has, had, or will have a controlling interest, and (iii) each and all of the foregoing’s respective past, present, or future family members, spouses, heirs, trusts, trustees, executors, estates, administrators, beneficiaries, distributees, foundations, agents, employees, fiduciaries, general or limited partners or partnerships, joint ventures, member firms, limited liability companies, corporations, parents, subsidiaries, divisions, affiliates, associated entities, stockholders, principals, officers, managers, directors, managing directors, members, managing members, managing agents, predecessors, predecessors-in-interest, successors, successors-in-interest, assigns, financial or investment advisors, advisors, consultants, investment bankers, entities providing any fairness opinion, underwriters, brokers, dealers, lenders, commercial bankers, attorneys, personal or legal representatives, accountants, insurers, co-insurers, reinsurers, and associates (consistent with the Stipulation, the “Released Parties”) of and from any and all manner of claims, demands, rights, liabilities, losses, obligations, duties, damages, costs, debts, expenses, interest, penalties, sanctions, fees, attorneys’ fees, actions, potential actions, causes of action, suits, agreements, judgments, decrees, matters, issues and controversies of any kind, nature or description whatsoever, whether known or unknown, disclosed or undisclosed, accrued or unaccrued, apparent or not apparent, foreseen or unforeseen, matured or not matured, suspected or unsuspected, liquidated or not liquidated, fixed or contingent, including Unknown Claims (defined in the Stipulation), that Plaintiffs or any or all other Class Members ever had, now have, or may have, whether direct, derivative, individual, class, representative, legal, equitable or of any other type, or in any other capacity, against any of the Released Parties, whether based on state, local, foreign, federal, statutory, regulatory, common or other law or rule (including, but not limited to, any claims under federal securities laws, including such claims within the exclusive jurisdiction of the federal courts, or state disclosure law or any claims that could be asserted derivatively on behalf of CNX Gas), which, now or hereafter, are based upon, arise out of, relate in any way to, or involve, directly or indirectly, (i) the Transaction (including either or both of the Tender Offer and the Merger), (ii) any deliberations or negotiations in connection with the Transaction, (iii) the consideration received by Class Members or by any other Person in connection with the Transaction, (iv) the Schedule TO, the 14D-9 or any other disclosures, public filings, periodic reports, press releases, proxy statements or other statements issued, made available or filed relating, directly or indirectly, to the Transaction, (v) the fiduciary duties and obligations of the Released Parties in connection with the Transaction, (vi) any of the allegations in any complaint or amendment(s) thereto filed in the Consolidated Action, including in any of its constituent actions, or the Pennsylvania Actions, or (vii) any other actions, transactions, occurrences, statements, representations, misrepresentations, omissions, allegations, facts, practices, events, claims or any other matters, things or causes whatsoever, or any series thereof, that were, could have been, or in the future can or might be alleged, asserted, set forth, claimed, embraced, involved, or referred to in, or otherwise related, directly or indirectly, in any way to, the Consolidated Action or the Pennsylvania Actions, or the subject matter of those actions (consistent with the Stipulation, the “Released Claims”); provided, however, that the Released Claims shall not include claims to enforce the Settlement.

10.Defendants and all Released Parties hereby shall be deemed to have, and by operation of this Order and Final Judgment shall have, fully, completely, finally, and forever released, relinquished and discharged Plaintiffs and Plaintiffs’ counsel from all claims, including Unknown Claims, arising out of or relating to the institution, prosecution, settlement, or resolution of the Consolidated Action (provided, however, that this release, relinquishment and discharge shall not include claims by the Parties to enforce the terms of the Settlement or Settlement Agreement).

11.Plaintiffs and all Class Members, and any and all of their respective successors-in-interest, successors, predecessors-in-interest, predecessors, representatives, trustees, executors, administrators, estates, heirs, assigns or transferees, immediate and remote, and any person or entity acting for or on behalf of, or claiming under, any of them, and each of them, are hereby permanently barred and enjoined from commencing, instituting, maintaining, prosecuting or asserting, either directly or in any other capacity, in any forum, any Released Claims against any of the Released Parties.

12.Neither the Stipulation nor this Order and Final Judgment, nor the facts or any terms of the Settlement, is to be considered in this or any other proceeding as evidence, or a presumption, admission or concession by any Party in the Consolidated Action, any signatory to the Stipulation or any Released Party, of any fault, liability or wrongdoing whatsoever, or lack of any fault, liability or wrongdoing, as to any facts or claims alleged or asserted in the Consolidated Action, or any other actions or proceedings. Neither the Stipulation nor this Order and Final Judgment is a finding or evidence of the validity or invalidity of any claims or defenses in the Consolidated Action or any other actions or proceedings, or any wrongdoing by any of the Defendants named therein or any damages or injury to any Class Member. Neither the Stipulation nor this Order and Final Judgment, nor any of the terms and provisions thereof, nor any of the negotiations or proceedings in connection therewith, nor any of the documents or statements referred to herein or therein, nor the Settlement, nor the fact of the Settlement, nor the settlement proceedings, nor any statements in connection therewith, may (i) be argued to be, used or construed as, offered or received in evidence as, or otherwise constitute an admission, concession, presumption, proof, evidence, or a finding of any liability, fault, wrongdoing, injury or damages, or of any wrongful conduct, acts or omissions on the part of any of the Released Parties, or of any infirmity of any defense, or of any damage to any Plaintiff or Class Member, (ii) otherwise be used to create or give rise to any inference or presumption against any of the Released Parties concerning any fact alleged or that could have been alleged, or any claim asserted or that could have been asserted in the Consolidated Action, or of any purported liability, fault, or wrongdoing of the Released Parties or of any injury or damages to any person or entity, or (iii) otherwise be admissible, referred to or used in any proceeding of any nature, for any purpose whatsoever; provided, however, that (x) the Stipulation and/or this Order and Final Judgment may be introduced in any proceeding, whether in this Court or otherwise, as may be necessary to argue that the Stipulation and/or this Order and Final Judgment has res judicata, collateral estoppel or other issue or claim preclusion effect or to otherwise consummate or enforce the Settlement and/or this Order and Final Judgment and (y) Plaintiffs and Plaintiffs’ counsel may refer to the final, executed version only of the Stipulation in connection with the Fee Application.

13.Plaintiffs’ counsel in the Consolidated Action are hereby awarded attorneys’ fees in the sum of $______________ in connection with the Consolidated Action, which sum the Court finds to be fair and reasonable, and reimbursement of expenses in the amount of $______________. Such sums shall be paid solely from the Settlement Payment pursuant to the provisions of the Stipulation. No counsel representing any Plaintiff in the Consolidated Action shall make any further or additional application for fees and expenses to the Court or any other court, nor shall counsel for any other Class Member (including counsel for plaintiffs in the Pennsylvania Actions) make any further or additional application for fees and expenses to the Court pursuant to the Settlement.

14.    The Court hereby finds and concludes that the procedures and plan for allocating the Settlement Payment provides a fair, reasonable, and adequate basis upon which to allocate the net settlement proceeds among Settlement Payment Recipients.

15.    Without further order of this Court, the Parties may agree in writing to reasonable extensions of time to carry out any of the provisions of the Stipulation.

16.    If the Effective Date does not occur or Defendants withdraw from the Settlement pursuant to Paragraph 20 of the Stipulation, this Order and Final Judgment shall be rendered null and void and shall be vacated and, in such event, all orders entered and releases delivered in connection herewith except for Paragraph 12 hereof and Paragraphs 20, 21, 27, and 28 of the Stipulation, which shall survive any such termination or vacatur, shall be null and void, and the Parties returned, without prejudice in any way, to their respective litigation positions immediately prior to the execution of the Stipulation.

18.    The binding effect of this Order and Final Judgment and the obligations of Plaintiffs and Defendants under the Settlement shall not be conditioned upon or subject to the resolution of any appeal from this Order and Final Judgment that relates solely to the issue of the Fee Application.

19.    Without affecting the finality of this Order and Final Judgment in any way, this Court reserves jurisdiction over all matters relating to the administration, consummation and enforcement of the Settlement and this Order and Final Judgment.

20.    The Register in Chancery is directed to enter and docket this Order and Final Judgment.

____________________________________

Vice Chancellor

Dated: _____________________, 2013

1

EX-10.2

April 19, 2013

CNX Gas Company LLC

CNX Center

1000 CONSOL Energy Drive

Canonsburg, PA 15317

Attention: Nicholas J. DeIuliis

Re:     Amendment No. 1 to the Asset Acquisition Agreement to Extend Time for the Title Dispute Date and establish the Title Defect Notice Date

Dear Mr. DeIuliis:

Reference is made to the Asset Acquisition Agreement (“AAA”), dated August 17, 2011, between CNX Gas Company LLC (“CONSOL”) and Noble Energy, Inc. (“Noble”). Capitalized terms used herein and not otherwise defined herein shall have the respective meanings assigned thereto in the AAA.

Whereas, Noble has submitted to CONSOL Title Defect Notices from the time of Closing through April 1, 2013, and pursuant to Section 5.3 of the AAA, the Title Dispute Date (as defined in the AAA) was sixty (60) days from the date of each Title Defect Notice.

Whereas, due to the volume of Title Defects that have been submitted to CONSOL, Noble and CONSOL agree that both parties would benefit from an extension of the Title Dispute Date in order to adequately address these Title Defects.

Therefore, CONSOL and Noble hereby agree to amend the AAA to extend the Title Dispute Date, for Title Defects which were submitted prior to or on April 1, 2013 (including but not limited to those Title Defects referenced in Noble’s letter to CONSOL dated March 28, 2013, regarding Preliminary Title Defect Notices (a copy of which is attached hereto as Exhibit “A”)), from 60 days to 120 days after April 1, 2013 (the “Extension”). Additionally, CONSOL and Noble hereby agree to amend the AAA to make the Title Defect Notice Date April 1, 2013 for all Title Defects asserted by Noble, regardless of when any particular Title Defect Notice was asserted by Noble (the “New Title Defect Notice Date”). As such, CONSOL will have the right, but not the obligation to cure any Title Defects asserted by Noble for a period of 180 days after April 1, 2013 (the “New Cure Period”). However, the Extension, New Title Defect Notice

Date and the New Cure Period shall not apply to Title Defects that have already been conceded by CONSOL. Except as amended hereby, the AAA shall remain unchanged and in full force and effect.

Best Regards,

Noble Energy, Inc.

By: /s/ Shawn E. Conner    

Name: Shawn E. Conner

Title: Vice President

Acknowledged and agreed as of the date first set forth above

CNX Gas Company LLC

By: /s/ Stephen W. Johnson    

Name:    Stephen W. Johnson

Title:    Senior Vice President

Cc:     Gary Willingham

Donnie Moore

John Lewis

Aaron Carlson

EX-31.1

Exhibit 31.1

CERTIFICATIONS

I, J. Brett Harvey, certify that:

1. I have reviewed this report on Form 10-Q of CONSOL Energy Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	August 5, 2013
/s/ J. Brett Harvey
J. Brett Harvey
Chairman of the Board and Chief Executive Officer
(Principal Executive Officer)

EX-31.2

Exhibit 31.2

CERTIFICATIONS

I, David M. Khani, certify that:

1. I have reviewed this report on Form 10-Q of CONSOL Energy Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information;

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	August 5, 2013
/s/ David M. Khani
David M. Khani
Chief Financial Officer and Executive Vice President (Principal Financial Officer)

EX-32.1

Exhibit 32.1

CERTIFICATION

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002,

18 U.S.C. Section 1350

I, J. Brett Harvey, President and Chief Executive Officer (principal executive officer) of CONSOL Energy Inc. (the “Registrant”), certify that to my knowledge, based upon a review of the Quarterly Report on Form 10-Q for the period ended June 30, 2013, of the Registrant (the “Report”):

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Registrant.

Date:	August 5, 2013
/s/ J. Brett Harvey
J. Brett Harvey
Chairman of the Board and Chief Executive Officer

EX-32.2

Exhibit 32.2

CERTIFICATION

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002,

18 U.S.C. Section 1350

I, David M. Khani, Chief Financial Officer (principal financial officer) of CONSOL Energy Inc. (the “Registrant”), certify that to my knowledge, based upon a review of the Quarterly Report on Form 10-Q for the period ended June 30, 2013, of the Registrant (the “Report”):

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Registrant.

Date:	August 5, 2013
/s/ David M. Khani
David M. Khani
Chief Financial Officer and Executive Vice President

EX-95

Mine Safety and Health Administration Safety Data

We believe that CONSOL Energy is one of the safest mining companies in the world. The Company has in place health and safety programs that include extensive employee training, accident prevention, workplace inspection, emergency response, accident investigation, regulatory compliance and program auditing. The objectives of our health and safety programs are to eliminate workplace incidents, comply with all mining-related regulations and provide support for both regulators and the industry to improve mine safety.

The operation of our mines is subject to regulation by the federal Mine Safety and Health Administration (MSHA) under the Federal Mine Safety and Health Act of 1977 (Mine Act). MSHA inspects our mines on a regular basis and issues various citations, orders and violations when it believes a violation has occurred under the Mine Act. We present information below regarding certain mining safety and health violations, orders and citations, issued by MSHA and related assessments and legal actions and mine-related fatalities with respect to our coal mining operations. In evaluating this information, consideration should be given to factors such as: (i) the number of violations, orders and citations will vary depending on the size of the coal mine, (ii) the number of violations, orders and citations issued will vary from inspector to inspector and mine to mine, and (iii) violations, orders and citations can be contested and appealed, and in that process, are often reduced in severity and amount, and are sometimes dismissed.

The table below sets forth for the three months ended June 30, 2013 for each coal mine of CONSOL Energy and its subsidiaries, the total number of:  (i) violations of mandatory health or safety standards that could significantly and substantially contribute to the cause and effect of a coal or other mine safety or health hazard under section 104 of the Mine Act for which the operator received a citation from MSHA; (ii) orders issued under section 104(b) of the Mine Act; (iii) citations and orders for unwarrantable failure of the mine operator to comply with mandatory health or safety standards under section 104(d) of the Mine Act; (iv) flagrant violations under section 110(b)(2) of the Mine Act; (v) imminent danger orders issued under section 107(a) of the Mine Act; (vi) proposed assessments from MHSA (regardless of whether CONSOL Energy has challenged or appealed the assessment); (vii) mining-related fatalities; (viii) notices from MSHA of a pattern of violations of mandatory health or safety standards that are of such nature as could have significantly and substantially contributed to the cause and effect of coal or other mine health or safety hazards under section 104(e) of the Mine Act; (ix) notices from MSHA regarding the potential to have a pattern of violations as referenced in (viii) above; and (x) pending legal actions before the Federal Mine Safety and Health Review Commission (as of June 30, 2013) involving such coal or other mine, as well as the aggregate number of legal actions instituted and the aggregate number of legal actions resolved during the reporting period.

1

										Received
										Notice
									Received	of	Legal
								Total	Notice of	Potential	Actions
				Section			Total Dollar	Number	Pattern of	to have	Pending	Legal	Legal
		Section		104(d)			Value of	of	Violations	Pattern	as of	Actions	Actions
Mine or Operating		104	Section	Citations	Section	Section	MSHA	Mining	Under	Under	Last	Initiated	Resolved
Name/MSHA		S&S	104(b)	and	110(b)(2)	107(a)	Assessments	Related	Section	Section	Day of	During	During
Identification Number		Citations	Orders	Orders	Violations	Orders	Proposed	Fatalities	104(e)	104(e)	Period (1)	Period	Period
Active Operations
Alma No. 1 Mine	46-09277	1	—	—	—	—	943	—	No	No	—	—	—
Bailey	36-07230	20	—	—	—	—	111,820	—	No	No	7	3	4
Blacksville 2	46-01968	27	—	—	—	—	166,845	—	No	No	24	2	4
Buchanan	44-04856	21	—	—	—	—	95,510	—	No	No	28	1	9
Central Repair Shop	46-03240	—	—	—	—	—	—	—	No	No	—	—	—
Enlow Fork	36-07416	14	—	—	—	—	11,237	—	No	No	5	1	4
Ireland Dock Loadout	46-01438	—	—	—	—	—	—	—	No	No	5	—	—
Keystone Cleaning Plant	36-08540	—	—	—	—	—	217	—	No	No	—	—	—
Loveridge	46-01433	79	2	—	—	—	299,670	—	No	No	24	4	6
McElroy	46-01437	80	—	2	—	—	254,708	—	No	No	28	6	5
Miller Creek PP #1	46-05890	—	—	—	—	—	4,690	—	No	No	1	1	—
Robinson Run	46-01318	32	—	—	—	—	122,848	—	No	No	33	5	4
Shoemaker	46-01436	20	—	—	—	—	202,422	—	No	No	22	4	9
Twin Branch Surface	46-09075	1	—	—	—	—	—	—	No	No	—	—	—
Inactive Operations
Amonate Plant	46-05449	—	—	—	—	—	—	—	No	No	—	—	—
Big Branch #1Belt/Spruce Creek	46-09177	—	—	—	—	—	—	—	No	No	—	—	—
Big Fork	44-06859	—	—	—	—	—	—	—	No	No	—	—	—
Bronzite II (MT-41)	46-09307	—	—	—	—	—	—	—	No	No	1	—	—
Bronzite III (Jacobs)	46-05978	—	—	—	—	—	—	—	No	No	—	—	—
Elk Creek Prep Plant (Sold)	46-02444	—	—	—	—	—	—	—	No	No	—	—	—
Emery	42-00079	—	—	—	—	—	—	—	No	No	1	—	—
Fola Surface	46-08377	—	—	—	—	—	—	—	No	No	1	—	—
Ike Fork 5 Block	46-09420	—	—	—	—	—	—	—	No	No	1	—	1
Impoundment 14-N	36-08094	—	—	—	—	—	—	—	No	No	—	—	—
Jones Fork Prep Plant (Sold)	15-17021	—	—	—	—	—	—	—	No	No	—	—	—
Laurel Fork	46-09084	2	—	—	—	—	821	—	No	No	—	—	—

2

Lick Branch	46-08676	—	—	—	—	—	138	—	No	No	—	—	1
Little Eagle Mine #1	46-08560	—	—	—	—	—	—	—	No	No	—	—	—
Meigs #31 Mine	33-01172	—	—	—	—	—	—	—	No	No	—	—	—
Miles Branch	44-03932	—	—	—	—	—	—	—	No	No	—	—	—
Mine 84	36-00958	—	—	—	—	—	—	—	No	No	—	—	—
Minway Surface	46-06089	—	—	—	—	—	—	—	No	No	—	—	—
MT-34 UG	46-09424	—	—	—	—	—	996	—	No	No	—	—	—
Muskingum	33-00989	—	—	—	—	—	—	—	No	No	—	—	—
Peach Orchard Prep Plant	46-08376	—	—	—	—	—	100	—	No	No	—	—	—
Powellton/Bridge Fork	46-08889	—	—	—	—	—	—	—	No	No	—	—	—
Reclamation #061	33-00962	—	—	—	—	—	—	—	No	No	—	—	—
Rend Lake	11-00601	—	—	—	—	—	—	—	No	No	—	—	—
Robena Prep	36-04175	—	—	—	—	—	—	—	No	No	—	—	—
Rock Lick	46-09171	—	—	—	—	—	—	—	No	No	1	—	1
Squire Jim #2	46-09211	—	—	—	—	—	—	—	No	No	—	—	—
Terry Eagle PP #1	46-02295	—	—	—	—	—	—	—	No	No	—	—	—
Wiley (MT-11)	46-09138	—	—	—	—	—	—	—	No	No	—	—	—
Wiley Area 80	15-18477	—	—	—	—	—	—	—	No	No	—	—	—
Wiley Creek (MT-13/500)	46-09185	—	—	—	—	—	362	—	No	No	2	—	—
Wiley Surface(MT34/Peg Fork)	46-09035	—	—	—	—	—	—	—	No	No	1	1	1
Winoc Prep Plant	46-08172	—	—	—	—	—	—	—	No	No	—	—	—
		297	2	2	—	—	1,273,327	—			185	28	49

(1) See table below for additional detail regarding Legal Actions Pending as of June 30, 2013.  With respect to Contests of Proposed Penalties, we have included the number of dockets (as opposed to citations) when counting the number of Legal Actions Pending as of June 30, 2013.

3

Mine or Operating Name/MSHA Identification Number		Contests of Citations, Orders (as of 6.30.13) (a)	Contests of Proposed Penalties (as of 6.30.13) (b)		Complaints for Compensation (as of 6.30.13) (c)	Complaints of Discharge, Discrimination or Interference (as of 6.30.13) (d)	Applications for Temporary Relief (as of 6.30.13) (e)	Appeals of Judges' Decisions or Order (as of 6.30.13) (f)
			Dockets	Citations
Active Operations
Alma No. 1 Mine	46-09277	—	—	—	—	—	—	—
Bailey	36-07230	—	7	21	—	1	—	—
Blacksville 2	46-01968	—	24	311	—	—	—	—
Buchanan	44-04856	—	28	262	—	2	—	—
Central Repair Shop	46-03240	—	—	—	—	—	—	—
Enlow Fork	36-07416	—	5	15	—	—	—	—
Ireland Dock Loadout	46-01438	—	5	6	—	—	—	—
Keystone Cleaning Plant	36-08540	—	—	—	—	—	—	—
Loveridge	46-01433	—	24	124	—	—	—	—
McElroy	46-01437	—	28	463	—	—	—	—
Miller Creek PP #1	46-05890	—	1	2	—	—	—	—
Robinson Run	46-01318	—	33	377	—	—	—	1
Shoemaker	46-01436	—	22	211	—	1	—	—
Twin Branch Surface	46-09075	—	—	—	—	—	—	—
Inactive Operations
Amonate Plant	46-05449	—	—	—	—	—	—	—
Big Branch #1Belt/Spruce Creek	46-09177	—	—	—	—	—	—	—
Big Fork	44-06859	—	—	—	—	—	—	—
Bronzite II (MT‑41)	46-09307	—	1	1	—	—	—	—
Bronzite III (Jacobs)	46-05978	—	—	—	—	—	—	—
Elk Creek Prep Plant (Sold)	46-02444	—	—	—	—	—	—	—
Emery	42-00079	—	1	1	—	—	—	—
Fola Surface	46-08377	—	1	3	—	—	—	—
Ike Fork 5 Block	46-09420	—	1	1	—	—	—	—
Impoundment 14‑N	36-08094	—	—	—	—	—	—	—
Jones Fork Prep Plant(Sold)	15-17021	—	—	—	—	—	—	—

4

Laurel Fork	46-09084	—	—	—	—	—	—	—
Lick Branch	46-08676	—	—	—	—	—	—	—
Little Eagle Mine #1	46-08560	—	—	—	—	—	—	—
Meigs #31 Mine	33-01172	—	—	—	—	—	—	—
Miles Branch	44-03932	—	—	—	—	—	—	—
Mine 84	36-00958	—	—	—	—	—	—	—
Minway Surface	46-06089	—	—	—	—	—	—	—
MT-34 UG	46-09424	—	—	—	—	—	—	—
Muskingum	33-00989	—	—	—	—	—	—	—
Peach Orchard Prep Plant	46-08376	—	—	—	—	—	—	—
Powellton/Bridge Fork	46-08889	—	—	—	—	—	—	—
Reclamation #061	33-00962	—	—	—	—	—	—	—
Rend Lake	11-00601	—	—	—	—	—	—	—
Robena Prep	36-04175	—	—	—	—	—	—	—
Rock Lick	46-09171	—	1	2	—	—	—	—
Squire Jim #2	46-09211	—	—	—	—	—	—	—
Terry Eagle PP #1	46-02295	—	—	—	—	—	—	—
Wiley (MT‑11)	46-09138	—	—	—	—	—	—	—
Wiley Area 80	15-18477	—	—	—	—	—	—	—
Wiley Creek (MT‑13/500)	46-09185	—	2	2	—	—	—	—
Wiley Surface(MT34/Peg Fork)	46-09035	—	1	1	—	—	—	—
Winoc Prep Plant	46-08172	—	—	—	—	—	—	—
		—	185	1,803	—	4	—	1

5

(a) Represents (if any) contests of citations and orders, which typically are filed prior to an operator's receipt of a proposed penalty assessment from MSHA or relate to orders for which penalties are not assessed (such as imminent danger orders under Section 107 of the Mine Act). This category includes: (i) contests of citations or orders issued under section 104 of the Mine Act, (ii) contests of imminent danger withdrawal orders under section 107 of the Mine Act, and (iii) Emergency response plan dispute proceedings (as required under the Mine Improvement and New Emergency Response Act of 2006, Pub. L. No. 109-236, 120 Stat. 493).

(b) Represents (if any) contests of proposed penalties, which are administrative proceedings before the Federal Mine Safety and Health Review Commission (“FMSHRC”) challenging a civil penalty that MSHA has proposed for the violation contained in a citation or order. This column includes four actions involving civil penalties against agents of the operator that have been contested.

(c) Represents (if any) complaints for compensation, which are cases under section 111 of the Mine Act that may be filed with the FMSHRC by miners idled by a closure order issued by MSHA who are entitled to compensation.

(d) Represents (if any) complaints of discharge, discrimination or interference under section 105 of the Mine Act, which cover: (i) discrimination proceedings involving a miner's allegation that he or she has suffered adverse employment action because he or she engaged in activity protected under the Mine Act, such as making a safety complaint, and (ii) temporary reinstatement proceedings involving cases in which a miner has filed a complaint with MSHA stating that he or she has suffered such discrimination and has lost his or her position. Complaints of Discharge, Discrimination, or Interference are also included in Contests of Proposed Penalties, Column B.

(e) Represents (if any) applications for temporary relief, which are applications under section 105(b)(2) of the Mine Act for temporary relief from any modification or termination of any order or from any order issued under section 104 of the Mine Act (other than citations issued under section 104(a) or (f) of the Mine Act).

(f) Represents (if any) appeals of judges' decisions or orders to the FMSHRC, including petitions for discretionary review and review by the FMSHRC on its own motion.

6

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Short-Term Notes Payable

6 Months Ended

Jun. 30, 2013

Short-term Debt, Other Disclosures [Abstract]

Short-Term Notes Payable:

SHORT-TERM NOTES PAYABLE:

CONSOL Energy's $1,500,000 Senior Secured Credit Agreement expires April 12, 2016. 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 $1,500,000 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 2.50 to 1.00, measured quarterly. The interest coverage ratio was 3.44 to 1.00 at June 30, 2013. The facility includes a maximum leverage ratio covenant of no more than 4.50 to 1.00, measured quarterly. The leverage ratio was 3.65 to 1.00 at June 30, 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 0.12 to 1.00 at June 30, 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 June 30, 2013 and December 31, 2012, the $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 for 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 unlimited 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 Gathering, LLC (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 1.20 to 1.00 at June 30, 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 36.85 to 1.00 at June 30, 2013. At June 30, 2013, the $1,000,000 facility had $173,000 borrowings outstanding and $70,051 of letters of credit outstanding, leaving $756,949 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. The average interest rate for the three months and six months ended June 30, 2013 was 1.69% and 1.76%, respectively. Accrued interest of $62 and $29 is included in Other Accrued Liabilities in the Consolidated Balance Sheet at June 30, 2013 and December 31, 2012, respectively.

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 June 30, 2013.

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Property, Plant and Equipment Joint Venture Activity (Details) (USD $)	3 Months Ended	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2013	Jun. 30, 2013 Noble JV[Member] [Member]	Jun. 30, 2013 Hess [Member]	Jun. 30, 2013 Noble JV[Member] [Member] acre	Dec. 31, 2011 Noble JV[Member] [Member] acre	Sep. 30, 2011 Noble JV[Member] [Member]	Dec. 31, 2011 Hess [Member] Rate acre
Joint Venture Interest Percentage						50.00%		50.00%
Drilling commitment carry							$ 2,100,000,000	$ 534,000,000
Three Month Average Price Carry for carry not to be suspended							4.00
Joint Venture Percent of Carry in Drilling Obligations								0.50
Significant Acquisitions and Disposals, Gain (Loss) on Sale or Disposal, Net of Tax						64,142,000		53,095,000
Acres in Joint Venture primarily focused on								73,000,000
Acres in Joint Venture to be sold								63,000,000
Maximum Annual Drilling Commitment Carry							400,000,000
Acres w/ Asserted Title Defects					75,000,000			39,000,000
Gas and Oil Acreage, Unproved, Net						628,000		200,000
Cash Proceeds Related to Joint Venture Activity						485,464,000		54,254,000
Joint Venture Transaction Fees						34,998,000		5,719,000
Note Receivable 1 year - joint venture proceed						311,754,000
Note receivable 2 year - joint venture proceeds						296,344,000
Cash Proceeds Related to 1 year Note						327,964,000
Oil and Gas Joint Interest Billing Receivables						16,703,000
Payable Related to Joint Venture Activity						980,000
Cash Proceeds Related to Receivable						15,598,000
Carry Value of Acres w/ Asserted Title Defects					481,000,000			153,000,000
Total Value of Asserted Title Defects		57,000,000
Tentative Acres w/ Asserted Title Defects								26,000,000
Acres to be reassigned by Joint Venture								65,000,000
drill carry remaining			2,034,785,000	279,248,000				335,000,000
Transaction Value of Asserted Title Defects	$ 2,470,000	$ 8,780,000

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Consolidated Statements of Comprehensive Income (Parentheticals) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Other Comprehensive Income (Loss), Tax	$ 10,542	$ 36,697	$ 22,526	$ 68,077
Adjustment For Actuarially Determined Liabilities [Member]
Other Comprehensive Income (Loss), Tax	(26,489)	(4,570)	(54,739)	(40,467)
Cash Flow Hedging [Member]
Other Comprehensive Income (Loss), Tax	$ (31,466)	$ (6,869)	$ (17,500)	$ (55,877)

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Acquisitions and Dispositions

6 Months Ended

Jun. 30, 2013

ACQUISITIONS AND DISPOSITIONS: [Abstract]

Acquisitions and Dispositions:

ACQUISITIONS AND DISPOSITIONS:

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 May 2013, CONSOL Energy completed a sale-leaseback of longwall shields for the Robinson Run Mine. Cash proceeds for the sale were $68,337. A loss of $236 was recognized due to transaction fees and is 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.

In April 2013, the Company and the Commonwealth of Pennsylvania (Commonwealth) entered into a Settlement Agreement and Release Settlement settling all of the Commonwealth's claims regarding the Ryerson Park Dam (Dam) and the Ryerson Park Lake (Lake).   The Settlement provides 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 provides 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.

On March 31, 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 50% of the acreage and accordingly, reimbursed CNX Gas Company for 50% of the associated costs during the three months ended June 30, 2013.

In March 2013, CONSOL Energy completed a sale-leaseback of longwall shields for the Shoemaker Mine. Cash proceeds for the sale were $63,839. A loss of $279 was recognized due to transaction fees and is 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.

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 is 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, of which $48,294 was restricted, were received related to this transaction. These proceeds were net of $637 in transaction fees. The restrictions on the cash were removed during the three months ended March 31, 2013 and are reflected as a Change in Restricted Cash in the Investing section of the Consolidated Statement of Cash Flows. Additionally, a note receivable was recognized in 2012 related to the two additional cash payments to be received in June 2013 and June 2014. One payment of $25,500 was received in June 2013. A note receivable of $24,500 is included in Accounts and Notes Receivables - Notes Receivables in the Consolidated Balance Sheet at June 30, 2013. The second payment is due June 2014. 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 Statements of Income for the year ended December 31, 2012.

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Recent Accounting Pronouncements (Notes)

6 Months Ended

Jun. 30, 2013

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

Description of New Accounting Pronouncements Not yet Adopted [Text Block]

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.

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Guarantor Subsidiaries Income Statement (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	$ 1,125,776	$ 1,189,293	$ 2,351,941	$ 2,500,764
Sales-Gas Royalty Interests	17,028	9,533	31,232	21,739
Sales-Purchased Gas	1,406	651	2,764	1,490
Freight-Outside	10,125	49,472	24,186	98,765
Other Income (including equity earnings)	62,345	205,538	96,197	258,499
Total Revenue and Other Income	1,216,680	1,454,487	2,506,320	2,881,257
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	855,878	856,889	1,788,841	1,760,930
Gas Royalty Interests Costs	13,534	7,124	25,340	17,373
Purchased Gas Costs	1,061	869	2,020	1,386
Related Party Activity	0	0	0	0
Freight Expense	10,125	49,472	24,186	98,765
Selling, General and Administrative Expenses	37,123	33,732	70,793	72,731
Depreciation, Depletion and Amortization	159,307	153,824	320,622	309,171
Interest Expense	54,518	56,593	107,896	114,713
Taxes Other Than Income	83,325	84,329	166,112	175,956
Total Costs	1,214,871	1,242,832	2,505,810	2,551,025
Earnings Before Income Taxes	1,809	211,655	510	330,232
Income Tax Expense (Benefit)	14,622	58,945	15,144	80,326
Net Income (Loss) Attributable to Noncontrolling Interest	287	29	544	29
Net Income (Loss) Available to Common Stockholders, Basic	(12,526)	152,739	(14,090)	249,935
Net Income (Loss)	(12,813)	152,710	(14,634)	249,906
Parent Issuer [Member]
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Sales-Purchased Gas	0	0	0	0
Freight-Outside	0	0	0	0
Other Income (including equity earnings)	198,207	249,780	276,183	417,765
Total Revenue and Other Income	198,207	249,780	276,183	417,765
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	4,249	22,351	80,239	71,531
Gas Royalty Interests Costs	0	0	0	0
Purchased Gas Costs	0	0	0	0
Related Party Activity	35,231	(14,013)	22,675	(7,000)
Freight Expense	0	0	0	0
Selling, General and Administrative Expenses	0	0	0	0
Depreciation, Depletion and Amortization	3,252	2,895	6,447	5,816
Interest Expense	50,807	52,932	100,976	107,694
Taxes Other Than Income	88	27	265	663
Total Costs	93,627	64,192	210,602	178,704
Earnings Before Income Taxes	104,580	185,588	65,581	239,061
Income Tax Expense (Benefit)	117,106	32,849	79,671	(10,874)
Net Income (Loss) Attributable to Noncontrolling Interest	0	0	0	0
Net Income (Loss) Available to Common Stockholders, Basic	(12,526)	152,739	(14,090)	249,935
Net Income (Loss)	(12,526)	152,739	(14,090)	249,935
CNX Gas Guarantor [Member]
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	172,161	148,459	340,840	309,128
Sales-Gas Royalty Interests	17,028	9,533	31,232	21,739
Sales-Purchased Gas	1,406	651	2,764	1,490
Freight-Outside	0	0	0	0
Other Income (including equity earnings)	11,235	18,098	24,459	34,403
Total Revenue and Other Income	201,830	176,741	399,295	366,760
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	125,632	101,695	239,984	200,340
Gas Royalty Interests Costs	13,544	7,131	25,361	17,386
Purchased Gas Costs	1,061	869	2,020	1,386
Related Party Activity	0	0	0	0
Freight Expense	0	0	0	0
Selling, General and Administrative Expenses	11,717	9,313	21,829	19,293
Depreciation, Depletion and Amortization	52,236	47,326	104,635	96,129
Interest Expense	2,136	1,191	3,797	2,409
Taxes Other Than Income	0	8,164	6,698	16,364
Total Costs	206,326	175,689	404,324	353,307
Earnings Before Income Taxes	(4,496)	1,052	(5,029)	13,453
Income Tax Expense (Benefit)	(1,747)	326	(1,955)	5,273
Net Income (Loss) Attributable to Noncontrolling Interest	287	29	544	29
Net Income (Loss) Available to Common Stockholders, Basic	(2,462)	755	(2,530)	8,209
Net Income (Loss)	(2,749)	726	(3,074)	8,180
Other Guarantors Subsidiaries [Member]
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	897,541	976,515	1,901,698	2,058,803
Sales-Gas Royalty Interests	0	0	0	0
Sales-Purchased Gas	0	0	0	0
Freight-Outside	10,125	49,472	24,186	98,765
Other Income (including equity earnings)	45,706	30,352	60,961	60,055
Total Revenue and Other Income	953,372	1,056,339	1,986,845	2,217,623
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	660,137	662,457	1,341,842	1,345,213
Gas Royalty Interests Costs	0	0	0	0
Purchased Gas Costs	0	0	0	0
Related Party Activity	(50,571)	22,782	(58,349)	24,040
Freight Expense	10,125	49,472	24,186	98,765
Selling, General and Administrative Expenses	25,058	24,185	48,305	52,757
Depreciation, Depletion and Amortization	103,321	103,085	208,558	206,185
Interest Expense	1,679	2,560	3,323	4,789
Taxes Other Than Income	82,507	75,425	157,513	157,396
Total Costs	832,256	939,966	1,725,378	1,889,145
Earnings Before Income Taxes	121,116	116,373	261,467	328,478
Income Tax Expense (Benefit)	(96,692)	23,788	(59,883)	81,577
Net Income (Loss) Attributable to Noncontrolling Interest	0	0	0	0
Net Income (Loss) Available to Common Stockholders, Basic	217,808	92,585	321,350	246,901
Net Income (Loss)	217,808	92,585	321,350	246,901
Non-Guarantors [Member]
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	53,610	64,785	107,663	133,807
Sales-Gas Royalty Interests	0	0	0	0
Sales-Purchased Gas	0	0	0	0
Freight-Outside	0	0	0	0
Other Income (including equity earnings)	5,404	5,215	10,777	11,172
Total Revenue and Other Income	59,014	70,000	118,440	144,979
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	53,467	62,811	107,193	129,227
Gas Royalty Interests Costs	0	0	0	0
Purchased Gas Costs	0	0	0	0
Related Party Activity	436	447	840	949
Freight Expense	0	0	0	0
Selling, General and Administrative Expenses	348	234	659	681
Depreciation, Depletion and Amortization	498	518	982	1,041
Interest Expense	10	11	21	22
Taxes Other Than Income	730	713	1,636	1,533
Total Costs	55,489	64,734	111,331	133,453
Earnings Before Income Taxes	3,525	5,266	7,109	11,526
Income Tax Expense (Benefit)	(4,045)	1,982	(2,689)	4,350
Net Income (Loss) Attributable to Noncontrolling Interest	0	0	0	0
Net Income (Loss) Available to Common Stockholders, Basic	7,570	3,284	9,798	7,176
Net Income (Loss)	7,570	3,284	9,798	7,176
Consolidation, Eliminations [Member]
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	2,464	(466)	1,740	(974)
Sales-Gas Royalty Interests	0	0	0	0
Sales-Purchased Gas	0	0	0	0
Freight-Outside	0	0	0	0
Other Income (including equity earnings)	(198,207)	(97,907)	(276,183)	(264,896)
Total Revenue and Other Income	(195,743)	(98,373)	(274,443)	(265,870)
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	12,393	7,575	19,583	14,619
Gas Royalty Interests Costs	(10)	(7)	(21)	(13)
Purchased Gas Costs	0	0	0	0
Related Party Activity	14,904	(9,216)	34,834	(17,989)
Freight Expense	0	0	0	0
Selling, General and Administrative Expenses	0	0	0	0
Depreciation, Depletion and Amortization	0	0	0	0
Interest Expense	(114)	(101)	(221)	(201)
Taxes Other Than Income	0	0	0	0
Total Costs	27,173	(1,749)	54,175	(3,584)
Earnings Before Income Taxes	(222,916)	(96,624)	(328,618)	(262,286)
Income Tax Expense (Benefit)	0	0	0	0
Net Income (Loss) Attributable to Noncontrolling Interest	0	0	0	0
Net Income (Loss) Available to Common Stockholders, Basic	(222,916)	(96,624)	(328,618)	(262,286)
Net Income (Loss)	$ (222,916)	$ (96,624)	$ (328,618)	$ (262,286)

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Commitments and Contingencies Additional Information (Details) (USD $)				3 Months Ended	6 Months Ended	3 Months Ended					6 Months Ended	12 Months Ended	3 Months Ended			3 Months Ended
	Jun. 30, 2013	Dec. 31, 2012	Jun. 30, 2013 Subsidiaries	Jun. 30, 2013 Commonwealth Park Property	Jun. 30, 2013 South Carolina Electric Gas Company [Member]	Jun. 30, 2012 South Carolina Electric Gas Company [Member] Counterclaim [Member]	Jun. 30, 2012 South Carolina Electric Gas Company [Member] Award Amount [Member]	Jun. 30, 2012 South Carolina Electric Gas Company [Member] Interest Rate on Amount Awarded [Member]	Jun. 30, 2012 South Carolina Electric Gas Company [Member] Attorney Fees [Member]	Jun. 30, 2013 PCB Soil Removal Action	Jun. 30, 2013 American electric corp [Member]	Dec. 31, 2012 American electric corp [Member]	Dec. 31, 2007 Earl Kennedy	Jun. 30, 2013 Cnx Gas Stock Acquisition [Member]	Dec. 31, 2012 Cnx Gas Stock Acquisition [Member]	Jun. 30, 2013 Ratliff [Member]
Commitments and Contingencies Disclosure [Line Items]
Loss Contingency, Range of Possible Loss, Portion Not Accrued	$ 792,000,000
Claims by plaintiff				The Commonwealth claimed that the Company is liable for dam reconstruction costs, lake restoration costs and natural resource damages totaling $58,000.	36000								The complaint, as amended, seeks injunctive relief, including removing CNX Gas Company from the property, and compensatory damages of $20,000.			$4,000 to $8,000
The current estimated cost of remedial action for the area CONSOL Energy was originally named a PRP, including payment of the EPA's past and future cost, is approximately				36,000,000						65,000,000	5,400,000			20,200
Litigation Settlement, Gross												250,000
Counterclaim by the company						9400	9735	8.75	1873		408
Sale of Stock, Price Per Share															$ 38.25
Loss Contingency, Settlement Agreement, Court														42730
Loss Contingency, Estimate of Possible Loss				20,000,000						11,000,000
Loss Contingency, Range of Possible Loss, Minimum				13,728,000							2,000,000
CONSOL Energy's portion of probable recoveries from settled claims										4,369,000
Remaining liability in PCB soil removal action	798,645,000	768,494,000								2,762,000
Loss Contingency, Damages Sought, Value											$ 384,000
Commitments and Contingent, number of asbestos claims			6,900

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Long-Term Debt

6 Months Ended

Jun. 30, 2013

Long-term Debt, Other Disclosures [Abstract]

Long-term Debt

LONG-TERM DEBT:

	June 30, 2013		December 31, 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 (7.43% weighted average interest rate for June 30, 2013 and December 31, 2012)	20,394		20,394
Other long-term notes maturing at various dates through 2031 (total value of $6,612 and $7,300 less unamortized discount of $1,286 and $1,542 at June 30, 2013 and December 31, 2012, respectively).	5,326		5,758
	3,128,585		3,129,017
Less amounts due in one year *	4,585		4,544
Long-Term Debt	$	3,124,000	$	3,124,473

* Excludes current portion of Capital Lease Obligations of $8,837 and $8,941 at June 30, 2013 and December 31, 2012, respectively.

Accrued interest related to Long-Term Debt of $63,269 and $63,363 was included in Other Accrued Liabilities in the Consolidated Balance Sheets at June 30, 2013 and December 31, 2012, respectively.

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Income Taxes Tax Examinations (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Income Tax Examination [Line Items]
Income Tax Reconciliation, Nondeductible Expense, Depletion	$ 25,471	$ 39,275

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Unrecorded Unconditional Purchase Obligation (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 1,099,252
Purchase Commitment [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Less than 1 year	258,380
1 - 3 years	164,240
3 - 5 years	131,751
More than 5 years	405,934
Total Purchase Obligations	960,305
Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	935,185
More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	164,066
More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	1
Standby Letters of Credit [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	329,697
Standby Letters of Credit [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	181,428
Standby Letters of Credit [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	148,269
Standby Letters of Credit [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Standby Letters of Credit [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Surety Bonds [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	769,555
Surety Bonds [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	753,757
Surety Bonds [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	15,797
Surety Bonds [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Surety Bonds [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	1
Employee Related Commitments [Member] | Standby Letters of Credit [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	190,157
Employee Related Commitments [Member] | Standby Letters of Credit [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	95,847
Employee Related Commitments [Member] | Standby Letters of Credit [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	94,310
Employee Related Commitments [Member] | Standby Letters of Credit [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Employee Related Commitments [Member] | Standby Letters of Credit [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Employee Related Commitments [Member] | Surety Bonds [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	204,884
Employee Related Commitments [Member] | Surety Bonds [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	194,884
Employee Related Commitments [Member] | Surety Bonds [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	10,000
Employee Related Commitments [Member] | Surety Bonds [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Employee Related Commitments [Member] | Surety Bonds [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Environment Related Commitments [Member] | Standby Letters of Credit [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	56,294
Environment Related Commitments [Member] | Standby Letters of Credit [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	54,566
Environment Related Commitments [Member] | Standby Letters of Credit [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	1,728
Environment Related Commitments [Member] | Standby Letters of Credit [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Environment Related Commitments [Member] | Standby Letters of Credit [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Environment Related Commitments [Member] | Surety Bonds [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	533,725
Environment Related Commitments [Member] | Surety Bonds [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	527,938
Environment Related Commitments [Member] | Surety Bonds [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	5,787
Environment Related Commitments [Member] | Surety Bonds [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Environment Related Commitments [Member] | Surety Bonds [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Other Commitments [Member] | Standby Letters of Credit [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	83,246
Other Commitments [Member] | Standby Letters of Credit [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	31,015
Other Commitments [Member] | Standby Letters of Credit [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	52,231
Other Commitments [Member] | Standby Letters of Credit [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Other Commitments [Member] | Standby Letters of Credit [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Other Commitments [Member] | Surety Bonds [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	30,946
Other Commitments [Member] | Surety Bonds [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	30,935
Other Commitments [Member] | Surety Bonds [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	10
Other Commitments [Member] | Surety Bonds [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Other Commitments [Member] | Surety Bonds [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 1

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Basis of Presentation Share-based Compensation (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures	249,751	104,007	972,482	803,471
Performance Share Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity awards other than options, vested	0	0	159,228	229,730
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options Exercised	160,119	39,418	245,113	51,134
Share-based comp Options Granted Weighted average exercise price	$ 9.90	$ 10.26	$ 10.16	$ 11.07
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity awards other than options, vested	89,632	64,589	568,141	522,607

XML

CWP and Workers Comp - Net Periodic Costs (Tables)

6 Months Ended

Jun. 30, 2013

CWP And Workers Comp Net Periodic Costs [Abstract]

Components of Net Periodic Benefit Costs

Components of net periodic costs (benefits) for the three and six months ended June 30 are as follows:

	CWP												Workers' Compensation
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2013			2012			2013			2012			2013			2012			2013			2012
Service cost	$	2,135		$	1,928		$	4,270		$	3,856		$	3,533		$	3,634		$	7,066		$	7,268
Interest cost	1,808			1,991			3,616			3,982			1,655			1,778			3,310			3,556
Amortization of actuarial gain	(4,212		)	(4,933		)	(8,425		)	(9,867		)	(699		)	(986		)	(1,398		)	(1,972		)
State administrative fees and insurance bond premiums	—			—			—			—			1,345			1,635			3,004			3,545
Legal and administrative costs	—			—			—			—			591			648			1,182			1,296
Net periodic (benefit) cost	$	(269	)	$	(1,014	)	$	(539	)	$	(2,029	)	$	6,425		$	6,709		$	13,164		$	13,693

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Pension and OPEB - Periodic Cost (Tables)

6 Months Ended

Jun. 30, 2013

PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS NET PERIODIC BENEFIT COSTS: [Abstract]

Components of Net Periodic Costs

Components of net periodic costs (benefits) for the three and six months ended June 30 are as follows:

	Pension Benefits												Other Postretirement Benefits
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2013			2012			2013			2012			2013			2012			2013			2012
Service cost	$	5,581		$	4,850		$	11,287		$	10,003		$	4,849		$	4,566		$	9,698		$	9,766
Interest cost	8,909			9,415			17,752			18,793			29,619			32,795			59,237			68,322
Expected return on plan assets	(12,711		)	(11,452		)	(24,855		)	(23,079		)	—			—			—			—
Amortization of prior service cost (credits)	(407		)	(407		)	(815		)	(815		)	(7,804		)	(13,410		)	(15,608		)	(25,009		)
Recognized net actuarial loss	10,547			11,654			22,722			23,917			17,595			20,020			35,190			40,365
Settlement loss	5,087			—			32,202			—			—			—			—			—
Net periodic benefit cost	$	17,006		$	14,060		$	58,293		$	28,819		$	44,259		$	43,971		$	88,517		$	93,444

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Income Taxes Income Tax Reconciliation (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Amount
Income Tax Reconciliation, Nondeductible Expense, Depletion	$ 25,471	$ 39,275
Percent
Statutory U.S. Federal Income Tax Rate	35.00%	35.00%
Income Tax Expense / Effective Rate	2969.40%	24.30%

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Segment Information (Tables)

3 Months Ended

6 Months Ended

Jun. 30, 2013

Jun. 30, 2012

Jun. 30, 2013

Jun. 30, 2012

Segment Reporting [Abstract]

Industry segment results

	Thermal		Low Volatile Metallurgical		High Volatile Metallurgical		Other Coal			Total Coal		Coalbed Methane		Marcellus Shale		Shallow Oil and Gas			Other Gas			Total Gas			All Other			Corporate, Adjustments & Eliminations			Consolidated
Sales—outside	$	697,945	$	111,006	$	57,115	$	5,005		$	871,071	$	87,799	$	46,577	$	33,745		$	3,115		$	171,236		$	83,469		$	—		$	1,125,776	(A)
Sales—purchased gas	—		—		—		—			—		—		—		—			1,406			1,406			—			—			1,406
Sales—gas royalty interests	—		—		—		—			—		—		—		—			17,028			17,028			—			—			17,028
Freight—outside	—		—		—		10,125			10,125		—		—		—			—			—			—			—			10,125
Intersegment transfers	—		—		—		—			—		—		—		—			926			926			32,428			(33,354		)	—
Total Sales and Freight	$	697,945	$	111,006	$	57,115	$	15,130		$	881,196	$	87,799	$	46,577	$	33,745		$	22,475		$	190,596		$	115,897		$	(33,354	)	$	1,154,335
Earnings (Loss) Before Income Taxes	$	103,768	$	30,819	$	17,245	$	(86,354	)	$	65,478	$	22,124	$	11,680	$	(5,576	)	$	(32,838	)	$	(4,610	)	$	(883	)	$	(58,176	)	$	1,809	(B)
Segment assets										$	5,600,934											$	6,170,531		$	363,819		$	617,644		$	12,752,928	(C)
Depreciation, depletion and amortization										$	100,751											$	52,236		$	6,320		$	—		$	159,307
Capital expenditures										$	157,558											$	188,463		$	6,007		$	—		$	352,028

(A)    Included in the Coal segment are sales of $157,318 to First Energy and $138,700 to Xcoal Energy & Resources each comprising over 10% of sales.

(B)     Includes equity in earnings of unconsolidated affiliates of $11,526, $1,030 and $(686) for Coal, Gas and All Other, respectively.

(C)    Includes investments in unconsolidated equity affiliates of $22,119, $170,589 and $63,389 for Coal, Gas and All Other, respectively.

	Thermal		Low Volatile Metallurgical		High Volatile Metallurgical		Other Coal		Total Coal		Coalbed Methane		Marcellus Shale		Shallow Oil and Gas			Other Gas			Total Gas		All Other			Corporate, Adjustments & Eliminations			Consolidated
Sales—outside	$	748,303	$	120,481	$	71,250	$	4,736	$	944,770	$	88,080	$	23,730	$	34,207		$	2,082		$	148,099	$	96,424		$	—		$	1,189,293	(D)
Sales—purchased gas	—		—		—		—		—		—		—		—			651			651		—			—			651
Sales—gas royalty interests	—		—		—		—		—		—		—		—			9,533			9,533		—			—			9,533
Freight—outside	—		—		—		49,472		49,472		—		—		—			—			—		—			—			49,472
Intersegment transfers	—		—		—		—		—		—		—		—			360			360		36,136			(36,496		)	—
Total Sales and Freight	$	748,303	$	120,481	$	71,250	$	54,208	$	994,242	$	88,080	$	23,730	$	34,207		$	12,626		$	158,643	$	132,560		$	(36,496	)	$	1,248,949
Earnings (Loss) Before Income Taxes	$	133,697	$	42,780	$	19,418	$	61,286	$	257,181	$	24,344	$	4,835	$	(2,410	)	$	(25,625	)	$	1,144	$	14,962		$	(61,632	)	$	211,655	(E)
Segment assets									$	5,445,502											$	5,970,939	$	360,673		$	820,782		$	12,597,896	(F)
Depreciation, depletion and amortization									$	100,684											$	47,326	$	(5,782	)	$	11,596		$	153,824
Capital expenditures									$	253,587											$	143,206	$	11,160		$	—		$	407,953

(D) Included in the Coal segment are sales of $136,576 to First Energy and $181,566 to Xcoal Energy & Resources each comprising over 10% of sales.

(E) Includes equity in earnings of unconsolidated affiliates of $1,483, $2,037 and $3,648 for Coal, Gas and All Other, respectively.

(F)    Includes investments in unconsolidated equity affiliates of $21,090, $132,545 and $55,638 for Coal, Gas and All Other, respectively.

Industry segment results for the six months ended June 30, 2013 are:

	Thermal		Low Volatile Metallurgical		High Volatile Metallurgical		Other Coal			Total Coal		Coalbed Methane		Marcellus Shale		Shallow Oil and Gas			Other Gas			Total Gas			All Other			Corporate, Adjustments & Eliminations			Consolidated
Sales—outside	$	1,459,217	$	257,834	$	115,737	$	10,668		$	1,843,456	$	171,439	$	94,988	$	66,181		$	6,470		$	339,078		$	169,407		$	—		$	2,351,941	(G)
Sales—purchased gas	—		—		—		—			—		—		—		—			2,764			2,764			—			—			2,764
Sales—gas royalty interests	—		—		—		—			—		—		—		—			31,232			31,232			—			—			31,232
Freight—outside	—		—		—		24,186			24,186		—		—		—			—			—			—			—			24,186
Intersegment transfers	—		—		—		—			—		—		—		—			1,762			1,762			67,905			(69,667		)	—
Total Sales and Freight	$	1,459,217	$	257,834	$	115,737	$	34,854		$	1,867,642	$	171,439	$	94,988	$	66,181		$	42,228		$	374,836		$	237,312		$	(69,667	)	$	2,410,123
Earnings (Loss) Before Income Taxes	$	232,200	$	85,536	$	30,597	$	(189,353	)	$	158,980	$	43,436	$	25,448	$	(9,737	)	$	(64,397	)	$	(5,250	)	$	(41,435	)	$	(111,785	)	$	510	(H)
Segment assets										$	5,600,934											$	6,170,531		$	363,819		$	617,644		$	12,752,928	(I)
Depreciation, depletion and amortization										$	203,462											$	104,635		$	12,525		$	—		$	320,622
Capital expenditures										$	354,896											$	395,593		$	7,511		$	—		$	758,000

(G)    Included in the Coal segment are sales of $328,300 to First Energy and $321,821 to Xcoal Energy & Resources each comprising over 10% of sales.

(H)     Includes equity in earnings of unconsolidated affiliates of $12,343, $4,212 and $112 for Coal, Gas and All Other, respectively.

(I)    Includes investments in unconsolidated equity affiliates of $22,119, $170,589 and $63,389 for Coal, Gas and All Other, respectively.

Industry segment results for the six months ended June 30, 2012 are:

	Thermal		Low Volatile Metallurgical		High Volatile Metallurgical		Other Coal		Total Coal		Coalbed Methane		Marcellus Shale		Shallow Oil and Gas			Other Gas			Total Gas		All Other		Corporate, Adjustments & Eliminations			Consolidated
Sales—outside	$	1,560,356	$	293,221	$	131,818	$	13,691	$	1,999,086	$	187,615	$	47,521	$	68,580		$	4,586		$	308,302	$	193,376	$	—		$	2,500,764	(J)
Sales—purchased gas	—		—		—		—		—		—		—		—			1,490			1,490		—		—			1,490
Sales—gas royalty interests	—		—		—		—		—		—		—		—			21,739			21,739		—		—			21,739
Freight—outside	—		—		—		98,765		98,765		—		—		—			—			—		—		—			98,765
Intersegment transfers	—		—		—		—		—		—		—		—			826			826		73,345		(74,171		)	—
Total Sales and Freight	$	1,560,356	$	293,221	$	131,818	$	112,456	$	2,097,851	$	187,615	$	47,521	$	68,580		$	28,641		$	332,357	$	266,721	$	(74,171	)	$	2,622,758
Earnings (Loss) Before Income Taxes	$	262,146	$	122,121	$	35,354	$	30	$	419,651	$	60,734	$	8,086	$	(6,132	)	$	(49,044	)	$	13,644	$	19,045	$	(122,108	)	$	330,232	(K)
Segment assets									$	5,445,502											$	5,970,939	$	360,673	$	820,782		$	12,597,896	(L)
Depreciation, depletion and amortization									$	201,446											$	96,129	$	—	$	11,596		$	309,171
Capital expenditures									$	448,016											$	241,661	$	24,722	$	—		$	714,399

(J) Included in the Coal segment are sales of $280,731 to First Energy and $319,907 to Xcoal Energy & Resources each comprising over 10% of sales.

(K) Includes equity in earnings of unconsolidated affiliates of $6,290, $3,981 and $4,832 for Coal, Gas and All Other, respectively.

(L)    Includes investments in unconsolidated equity affiliates of $21,090, $132,545 and $55,638 for Coal, Gas and All Other, respectively.

Reconciliation of Revenue and Operating Income from Segments to Consolidated

Earnings Before Income Taxes:

	For the Three Months Ended June 30,						For the Six Months Ended June 30,
	2013			2012			2013			2012
Segment Earnings Before Income Taxes for total reportable business segments	$	60,868		$	258,325		$	153,730		$	433,295
Segment (Loss) Earnings Before Income Taxes for all other businesses	(883		)	14,962			(41,435		)	19,045
Interest expense, net and other non-operating activity (M)	(56,406		)	(58,943		)	(109,066		)	(118,985		)
Other Corporate Items (M)	(1,770		)	(2,689		)	(2,719		)	(3,123		)
Earnings Before Income Taxes	$	1,809		$	211,655		$	510		$	330,232

Reconciliation of Assets and Liabilities from Segment to Consolidated

Total Assets:	June 30,
	2013		2012
Segment assets for total reportable business segments	$	11,771,465	$	11,416,441
Segment assets for all other businesses	363,819		360,673
Items excluded from segment assets:
Cash and other investments (M)	45,905		186,611
Recoverable income taxes	1,930		—
Deferred tax assets	531,707		588,722
Bond issuance costs	38,102		45,449
Total Consolidated Assets	$	12,752,928	$	12,597,896

_________________________ 

(M) Excludes amounts specifically related to the gas segment.

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Basis of Presentation Changes in Accumulated Other Comprehensive Income / (Loss) by component (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012	Dec. 31, 2012
Natural Gas Swaps	$ (20,070)	$ (94,544)	$ (54,767)	$ (173,865)
Accumulated Other Comprehensive Income (Loss), Net of Tax	(663,768)		(663,768)		(747,342)
Other Comprehensive Income (Loss), Net of Tax	79,125	(39,598)	83,574	48,110
Tax Benefit of Natural Gas Swaps	10,542	36,697	22,526	68,077
Natural Gas Swaps, Net of Tax	(9,528)	(57,847)	(32,241)	(105,788)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	(8,211)	(13,915)	(16,423)	(26,021)
Defined Benefit Plan, Amortization of Gains (Losses)	23,559	26,072	48,747	53,077
Other Comprehensive Income (Loss), Finalization of Pension and Non-Pension Postretirement Plan Valuation, Net of Tax	(5,087)		32,202
Defined Benefit Plan, Net Periodic Benefit Cost	20,435	12,157	64,526	27,056
Tax Expense on Actuarially Determined Long-Term Liabilities	7,800	4,571	(24,631)	(10,173)
Actuarially Determined Long-Term Liability Adjustments, Net of Tax	12,635	7,586	39,895	16,883
Accumulated Other Comprehensive Income (Loss)
Accumulated Other Comprehensive Income (Loss), Net of Tax	(663,768)		(663,768)		(747,342)
Other Comprehensive Income (Loss), Net of Tax			83,574
Amounts reclassified from accumulated other comprehensive income			7,654
Other comprehensive income before reclassifications			75,920
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax	71,674		71,674		76,761
Other Comprehensive Income (Loss), Net of Tax			(5,087)
Amounts reclassified from accumulated other comprehensive income			(32,241)
Other comprehensive income before reclassifications			27,154
Accumulated Defined Benefit Plans Adjustment [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax	(735,442)		(735,442)		(824,103)
Other Comprehensive Income (Loss), Net of Tax			88,661
Amounts reclassified from accumulated other comprehensive income			39,895
Other comprehensive income before reclassifications			48,766
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	(407)	(407)	(815)	(815)
Defined Benefit Plan, Amortization of Gains (Losses)	(10,547)	(11,654)	(22,722)	(23,917)
Other Comprehensive Income (Loss), Finalization of Pension and Non-Pension Postretirement Plan Valuation, Net of Tax	(5,087)	0	(32,202)	0
Defined Benefit Plan, Net Periodic Benefit Cost	$ 17,006	$ 14,060	$ 58,293	$ 28,819

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Income Taxes Discrete Items (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2013 State and Local Jurisdiction [Member]
Other Tax Carryforward [Line Items]
Unusual or Infrequent, Tax Effect	$ 8,269
Tax Adjustments, Settlements, and Unusual Provisions		$ 1,585

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Commitments and Contingencies (Tables)

3 Months Ended

Jun. 30, 2013

Long-term Purchase Commitment [Table Text Block]

At June 30, 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. No amounts related to these financial guarantees and letters of credit are recorded as liabilities on the financial statements. CONSOL Energy management believes that these guarantees will expire without being funded, and therefore the commitments will not have a material adverse effect on financial condition.

	Amount of Commitment Expiration Per Period
	Total Amounts Committed		Less Than 1  Year		1-3 Years		3-5 Years		Beyond 5  Years
Letters of Credit:
Employee-Related	$	190,157	$	95,847	$	94,310	$	—	$	—
Environmental	56,294		54,566		1,728		—		—
Other	83,246		31,015		52,231		—		—
Total Letters of Credit	329,697		181,428		148,269		—		—
Surety Bonds:
Employee-Related	204,884		194,884		10,000		—		—
Environmental	533,725		527,938		5,787		—		—
Other	30,946		30,935		10		—		1
Total Surety Bonds	769,555		753,757		15,797		—		1
Total Commitments	$	1,099,252	$	935,185	$	164,066	$	—	$	1

Unrecorded Unconditional Purchase Obligations Disclosure

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 June 30, 2013, the purchase obligations for each of the next five years and beyond were as follows:

Obligations Due	Amount
Less than 1 year	$	258,380
1 - 3 years	164,240
3 - 5 years	131,751
More than 5 years	405,934
Total Purchase Obligations	$	960,305

Supply Commitment [Table Text Block]

Costs related to these purchase obligations include:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2013		2012		2013		2012
Major equipment purchases	$	15,116	$	31,989	$	48,542	$	45,175
Firm transportation expense	31,017		15,822		59,542		30,867
Gas drilling obligations	25,904		28,517		54,768		58,093
Other	—		129		—		427
Total costs related to purchase obligations	$	72,037	$	76,457	$	162,852	$	134,562

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Reconciliation of Segment Information, Revenue and Other Income (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012	Dec. 31, 2012
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	$ 1,125,776	$ 1,189,293	$ 2,351,941	$ 2,500,764
Earnings Before Income Taxes:
Earnings Before Income Taxes	1,809	211,655	510	330,232
Revenue from Purchased Oil and Gas	1,406	651	2,764	1,490
Sales-Gas Royalty Interests	17,028	9,533	31,232	21,739
Freight-Outside	10,125	49,472	24,186	98,765
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Segment Reporting Information, Revenue for Reportable Segment	1,154,335	1,248,949	2,410,123	2,622,758
Total Assets	12,752,928	12,597,896	12,752,928	12,597,896	12,670,909
Depreciation, Depletion and Amortization	159,307	153,824	320,622	309,171
Capital Expenditures	352,028	407,953	758,000	714,399
Total Reportable Business Segments
Earnings Before Income Taxes:
Earnings Before Income Taxes	60,868	258,325	153,730	433,295
Total Assets	11,771,465	11,416,441	11,771,465	11,416,441
Coal
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	871,071	944,770	1,843,456	1,999,086
Earnings Before Income Taxes:
Earnings Before Income Taxes	65,478	257,181	158,980	419,651
Revenue from Purchased Oil and Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	10,125	49,472	24,186	98,765
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Segment Reporting Information, Revenue for Reportable Segment	881,196	994,242	1,867,642	2,097,851
Total Assets	5,600,934	5,445,502	5,600,934	5,445,502
Depreciation, Depletion and Amortization	100,751	100,684	203,462	201,446
Capital Expenditures	157,558	253,587	354,896	448,016
Gas
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	171,236	148,099	339,078	308,302
Earnings Before Income Taxes:
Earnings Before Income Taxes	(4,610)	1,144	(5,250)	13,644
Revenue from Purchased Oil and Gas	1,406	651	2,764	1,490
Sales-Gas Royalty Interests	17,028	9,533	31,232	21,739
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	926	360	1,762	826
Segment Reporting Information, Revenue for Reportable Segment	190,596	158,643	374,836	332,357
Total Assets	6,170,531	5,970,939	6,170,531	5,970,939
Depreciation, Depletion and Amortization	52,236	47,326	104,635	96,129
Capital Expenditures	188,463	143,206	395,593	241,661
All Other Segments [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	83,469	96,424	169,407	193,376
Earnings Before Income Taxes:
Earnings Before Income Taxes	(883)	14,962	(41,435)	19,045
Revenue from Purchased Oil and Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	32,428	36,136	67,905	73,345
Segment Reporting Information, Revenue for Reportable Segment	115,897	132,560	237,312	266,721
Total Assets	363,819	360,673	363,819	360,673
Depreciation, Depletion and Amortization	6,320	(5,782)	12,525	0
Capital Expenditures	6,007	11,160	7,511	24,722
Excludes Gas Segment [Member]
Earnings Before Income Taxes:
Interest Income (Expense), Net and Other Non-operating Activity	(56,406)	(58,943)	(109,066)	(118,985)
Fees for Disposing Non-core Assets	(1,770)	(2,689)	2,719	3,123
Intersegment Elimination [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	0	0	0	0
Earnings Before Income Taxes:
Earnings Before Income Taxes	(58,176)	(61,632)	(111,785)	(122,108)
Revenue from Purchased Oil and Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	(33,354)	(36,496)	(69,667)	(74,171)
Segment Reporting Information, Revenue for Reportable Segment	(33,354)	(36,496)	(69,667)	(74,171)
Total Assets	617,644	820,782	617,644	820,782
Depreciation, Depletion and Amortization	0	11,596	0	11,596
Capital Expenditures	0	0	0	0
Steam [Member] | Coal
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	697,945	748,303	1,459,217	1,560,356
Earnings Before Income Taxes:
Earnings Before Income Taxes	103,768	133,697	232,200	262,146
Revenue from Purchased Oil and Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Segment Reporting Information, Revenue for Reportable Segment	697,945	748,303	1,459,217	1,560,356
High Volatile Metallurgical [member] | Coal
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	57,115	71,250	115,737	131,818
Earnings Before Income Taxes:
Earnings Before Income Taxes	17,245	19,418	30,597	35,354
Revenue from Purchased Oil and Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Segment Reporting Information, Revenue for Reportable Segment	57,115	71,250	115,737	131,818
Low Volatile Metallurgical [Member] | Coal
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	111,006	120,481	257,834	293,221
Earnings Before Income Taxes:
Earnings Before Income Taxes	30,819	42,780	85,536	122,121
Revenue from Purchased Oil and Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Segment Reporting Information, Revenue for Reportable Segment	111,006	120,481	257,834	293,221
Other Coal [Member] | Coal
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	5,005	4,736	10,668	13,691
Earnings Before Income Taxes:
Earnings Before Income Taxes	(86,354)	61,286	(189,353)	30
Revenue from Purchased Oil and Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	10,125	49,472	24,186	98,765
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Segment Reporting Information, Revenue for Reportable Segment	15,130	54,208	34,854	112,456
Coalbed Methane [Member] | Gas
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	87,799	88,080	171,439	187,615
Earnings Before Income Taxes:
Earnings Before Income Taxes	22,124	24,344	43,436	60,734
Revenue from Purchased Oil and Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Segment Reporting Information, Revenue for Reportable Segment	87,799	88,080	171,439	187,615
Marcellus Shale [Member] | Gas
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	46,577	23,730	94,988	47,521
Earnings Before Income Taxes:
Earnings Before Income Taxes	11,680	4,835	25,448	8,086
Revenue from Purchased Oil and Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Segment Reporting Information, Revenue for Reportable Segment	46,577	23,730	94,988	47,521
Conventional Gas [Member] | Gas
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	33,745	34,207	66,181	68,580
Earnings Before Income Taxes:
Earnings Before Income Taxes	(5,576)	(2,410)	(9,737)	(6,132)
Revenue from Purchased Oil and Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Segment Reporting Information, Revenue for Reportable Segment	33,745	34,207	66,181	68,580
Other Gas | Gas
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	3,115	2,082	6,470	4,586
Earnings Before Income Taxes:
Earnings Before Income Taxes	(32,838)	(25,625)	(64,397)	(49,044)
Revenue from Purchased Oil and Gas	1,406	651	2,764	1,490
Sales-Gas Royalty Interests	17,028	9,533	31,232	21,739
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	926	360	1,762	826
Segment Reporting Information, Revenue for Reportable Segment	22,475	12,626	42,228	28,641
First Energy [Member] | Coal
Segment Reporting, Revenue Reconciling Item [Line Items]
Entity-Wide Revenue, Major Customer, Amount	$ 157,318	$ 136,576	$ 328,300	$ 280,731

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Industry Segment Results (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012	Dec. 31, 2012
Segment Reporting Information [Line Items]
Sales-Outside	$ 1,125,776	$ 1,189,293	$ 2,351,941	$ 2,500,764
Sales-Purchased Gas	1,406	651	2,764	1,490
Sales-Gas Royalty Interests	17,028	9,533	31,232	21,739
Freight-Outside	10,125	49,472	24,186	98,765
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Total Sales and Freight	1,154,335	1,248,949	2,410,123	2,622,758
Earnings Before Income Taxes	1,809	211,655	510	330,232
Total Assets	12,752,928	12,597,896	12,752,928	12,597,896	12,670,909
Depreciation, Depletion and Amortization	159,307	153,824	320,622	309,171
Capital Expenditures	352,028	407,953	758,000	714,399
Equity in Earnings of Unconsolidated Affiliates			(16,667)	(15,103)
Investments in Unconsolidated Equity Affiliates	256,097		256,097		222,830
Total Reportable Business Segments
Segment Reporting Information [Line Items]
Earnings Before Income Taxes	60,868	258,325	153,730	433,295
Total Assets	11,771,465	11,416,441	11,771,465	11,416,441
Coal
Segment Reporting Information [Line Items]
Sales-Outside	871,071	944,770	1,843,456	1,999,086
Sales-Purchased Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	10,125	49,472	24,186	98,765
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Total Sales and Freight	881,196	994,242	1,867,642	2,097,851
Earnings Before Income Taxes	65,478	257,181	158,980	419,651
Total Assets	5,600,934	5,445,502	5,600,934	5,445,502
Depreciation, Depletion and Amortization	100,751	100,684	203,462	201,446
Capital Expenditures	157,558	253,587	354,896	448,016
Equity in Earnings of Unconsolidated Affiliates	11,526	1,483	12,343	6,290
Investments in Unconsolidated Equity Affiliates	22,119	21,090	22,119	21,090
Gas
Segment Reporting Information [Line Items]
Sales-Outside	171,236	148,099	339,078	308,302
Sales-Purchased Gas	1,406	651	2,764	1,490
Sales-Gas Royalty Interests	17,028	9,533	31,232	21,739
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	926	360	1,762	826
Total Sales and Freight	190,596	158,643	374,836	332,357
Earnings Before Income Taxes	(4,610)	1,144	(5,250)	13,644
Total Assets	6,170,531	5,970,939	6,170,531	5,970,939
Depreciation, Depletion and Amortization	52,236	47,326	104,635	96,129
Capital Expenditures	188,463	143,206	395,593	241,661
Equity in Earnings of Unconsolidated Affiliates	1,030	2,037	4,212	3,981
Investments in Unconsolidated Equity Affiliates	170,589	132,545	170,589	132,545
All Other Segments [Member]
Segment Reporting Information [Line Items]
Sales-Outside	83,469	96,424	169,407	193,376
Sales-Purchased Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	32,428	36,136	67,905	73,345
Total Sales and Freight	115,897	132,560	237,312	266,721
Earnings Before Income Taxes	(883)	14,962	(41,435)	19,045
Total Assets	363,819	360,673	363,819	360,673
Depreciation, Depletion and Amortization	6,320	(5,782)	12,525	0
Capital Expenditures	6,007	11,160	7,511	24,722
Intersegment Elimination [Member]
Segment Reporting Information [Line Items]
Sales-Outside	0	0	0	0
Sales-Purchased Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	(33,354)	(36,496)	(69,667)	(74,171)
Total Sales and Freight	(33,354)	(36,496)	(69,667)	(74,171)
Earnings Before Income Taxes	(58,176)	(61,632)	(111,785)	(122,108)
Total Assets	617,644	820,782	617,644	820,782
Depreciation, Depletion and Amortization	0	11,596	0	11,596
Capital Expenditures	0	0	0	0
All Other
Segment Reporting Information [Line Items]
Equity in Earnings of Unconsolidated Affiliates	(686)	3,648	112	4,832
Investments in Unconsolidated Equity Affiliates	63,389	55,638	63,389	55,638
Steam [Member] | Coal
Segment Reporting Information [Line Items]
Sales-Outside	697,945	748,303	1,459,217	1,560,356
Sales-Purchased Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Total Sales and Freight	697,945	748,303	1,459,217	1,560,356
Earnings Before Income Taxes	103,768	133,697	232,200	262,146
Low Volatile Metallurgical [Member] | Coal
Segment Reporting Information [Line Items]
Sales-Outside	111,006	120,481	257,834	293,221
Sales-Purchased Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Total Sales and Freight	111,006	120,481	257,834	293,221
Earnings Before Income Taxes	30,819	42,780	85,536	122,121
High Volatile Metallurgical [member] | Coal
Segment Reporting Information [Line Items]
Sales-Outside	57,115	71,250	115,737	131,818
Sales-Purchased Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Total Sales and Freight	57,115	71,250	115,737	131,818
Earnings Before Income Taxes	17,245	19,418	30,597	35,354
Other Coal [Member] | Coal
Segment Reporting Information [Line Items]
Sales-Outside	5,005	4,736	10,668	13,691
Sales-Purchased Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	10,125	49,472	24,186	98,765
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Total Sales and Freight	15,130	54,208	34,854	112,456
Earnings Before Income Taxes	(86,354)	61,286	(189,353)	30
Coalbed Methane [Member] | Gas
Segment Reporting Information [Line Items]
Sales-Outside	87,799	88,080	171,439	187,615
Sales-Purchased Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Total Sales and Freight	87,799	88,080	171,439	187,615
Earnings Before Income Taxes	22,124	24,344	43,436	60,734
Marcellus Shale [Member] | Gas
Segment Reporting Information [Line Items]
Sales-Outside	46,577	23,730	94,988	47,521
Sales-Purchased Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Total Sales and Freight	46,577	23,730	94,988	47,521
Earnings Before Income Taxes	11,680	4,835	25,448	8,086
Conventional Gas [Member] | Gas
Segment Reporting Information [Line Items]
Sales-Outside	33,745	34,207	66,181	68,580
Sales-Purchased Gas	0	0	0	0
Sales-Gas Royalty Interests	0	0	0	0
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	0	0	0	0
Total Sales and Freight	33,745	34,207	66,181	68,580
Earnings Before Income Taxes	(5,576)	(2,410)	(9,737)	(6,132)
Other Gas | Gas
Segment Reporting Information [Line Items]
Sales-Outside	3,115	2,082	6,470	4,586
Sales-Purchased Gas	1,406	651	2,764	1,490
Sales-Gas Royalty Interests	17,028	9,533	31,232	21,739
Freight-Outside	0	0	0	0
Segment Reporting Information, Intersegment Revenue	926	360	1,762	826
Total Sales and Freight	22,475	12,626	42,228	28,641
Earnings Before Income Taxes	(32,838)	(25,625)	(64,397)	(49,044)
First Energy [Member] | Coal
Segment Reporting Information [Line Items]
Entity-Wide Revenue, Major Customer, Amount	157,318	136,576	328,300	280,731
XCoal Energy and Resources [Member] | Coal
Segment Reporting Information [Line Items]
Entity-Wide Revenue, Major Customer, Amount	$ 138,700	$ 181,566	$ 321,821	$ 319,907

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Acquisitions (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013
Allegheny County Airport – Allegheny County Airport [Member]
Business Acquisition [Line Items]
Bonus Payment in Escrow	7.60%
Bonus Payment	$ 46,315
Ryerson Dam and Lake [Member]
Business Acquisition [Line Items]
Business Acquisition, Contingent Consideration, Potential Cash Payment	36,000
Gas and Oil Area, Undeveloped, Gross	506,000
Bonus Payment	$ 13,728
Allegheny County Airport – Pittsburgh International Airport [Member] [Member]
Business Acquisition [Line Items]
Gas and Oil Area, Undeveloped, Gross	9,300

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Guarantor Subsidiaries, Condensed Statement of Cash Flows (Details) (USD $)	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	$ 393,394,000	$ 367,949,000
Investing Activities:
Capital Expenditures	(758,000,000)	(714,399,000)
Net Cash Used in Investing Activities	(465,126,000)	(484,009,000)
Financing Activities:
Dividends Paid	(28,601,000)	(56,833,000)
Proceeds from Issuance of Common Stock	2,497,000	457,000
(Payments on) Proceeds from Short-Term Borrowings	173,000,000
Other Financing Activities	2,185,000	(2,636,000)
Payments on Securitization Facility	2,873,000
Repayments of Other Debt	(30,162,000)	(4,662,000)
Net Cash (Used in) Provided by Financing Activities	121,792,000	(59,469,000)
Equity Method Investment, Dividends or Distributions	(16,600,000)	(35,900,000)
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions		14,061,000
Proceeds from Sale of Property, Plant, and Equipment		252,229,000
Increase (Decrease) in Restricted Cash	68,673,000	0
Payments for (Proceeds from) Other Investing Activities	(240,801,000)
Parent Issuer [Member]
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	35,486,000	271,127,000
Investing Activities:
Capital Expenditures	(7,511,000)	(24,722,000)
Net Cash Used in Investing Activities	(7,511,000)	144,778,000
Financing Activities:
Dividends Paid	21,399,000	143,167,000
Proceeds from Issuance of Common Stock	2,497,000
(Payments on) Proceeds from Short-Term Borrowings	0
Other Financing Activities	2,185,000	1,580,000
Payments on Securitization Facility	0
Repayments of Other Debt	(26,280,000)
Net Cash (Used in) Provided by Financing Activities	(199,000)	144,747,000
Equity Method Investment, Dividends or Distributions	0	0
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions		0
Proceeds from Sale of Property, Plant, and Equipment		169,500,000
Increase (Decrease) in Restricted Cash	0
Payments for (Proceeds from) Other Investing Activities	0
CNX Gas Guarantor [Member]
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	263,284,000	124,367,000
Investing Activities:
Capital Expenditures	(395,593,000)	(241,661,000)
Net Cash Used in Investing Activities	(412,450,000)	(243,062,000)
Financing Activities:
Dividends Paid	(50,000,000)	(200,000,000)
Proceeds from Issuance of Common Stock	0
(Payments on) Proceeds from Short-Term Borrowings	224,800,000
Other Financing Activities	0	(3,751,000)
Payments on Securitization Facility	0
Repayments of Other Debt	0
Net Cash (Used in) Provided by Financing Activities	174,800,000	(203,751,000)
Equity Method Investment, Dividends or Distributions	(22,501,000)	(35,150,000)
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions		3,500,000
Proceeds from Sale of Property, Plant, and Equipment		30,249,000
Increase (Decrease) in Restricted Cash	0
Payments for (Proceeds from) Other Investing Activities	(5,644,000)
Other Guarantors Subsidiaries [Member]
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	46,545,000	(28,281,000)
Investing Activities:
Capital Expenditures	(354,896,000)	(448,016,000)
Net Cash Used in Investing Activities	(45,178,000)	(385,736,000)
Financing Activities:
Dividends Paid	0	0
Proceeds from Issuance of Common Stock	0
(Payments on) Proceeds from Short-Term Borrowings	0
Other Financing Activities	0	2,000
Payments on Securitization Facility	0
Repayments of Other Debt	(3,555,000)
Net Cash (Used in) Provided by Financing Activities	(3,555,000)	2,000
Equity Method Investment, Dividends or Distributions	5,901,000	(750,000)
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions		10,561,000
Proceeds from Sale of Property, Plant, and Equipment		52,469,000
Increase (Decrease) in Restricted Cash	68,673,000
Payments for (Proceeds from) Other Investing Activities	(235,144,000)
Non-Guarantors [Member]
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	(3,721,000)	736,000
Investing Activities:
Capital Expenditures	0	0
Net Cash Used in Investing Activities	13,000	11,000
Financing Activities:
Dividends Paid	0	0
Proceeds from Issuance of Common Stock	0
(Payments on) Proceeds from Short-Term Borrowings	0
Other Financing Activities	0	(467,000)
Payments on Securitization Facility	2,873,000
Repayments of Other Debt	(327,000)
Net Cash (Used in) Provided by Financing Activities	2,546,000	(467,000)
Equity Method Investment, Dividends or Distributions	0	0
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions		0
Proceeds from Sale of Property, Plant, and Equipment		11,000
Increase (Decrease) in Restricted Cash	0
Payments for (Proceeds from) Other Investing Activities	(13,000)
Consolidation, Eliminations [Member]
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	51,800,000	0
Investing Activities:
Capital Expenditures	0	0
Net Cash Used in Investing Activities	0	0
Financing Activities:
Dividends Paid	0	0
Proceeds from Issuance of Common Stock	0
(Payments on) Proceeds from Short-Term Borrowings	(51,800,000)
Other Financing Activities	0	0
Payments on Securitization Facility	0
Repayments of Other Debt	0
Net Cash (Used in) Provided by Financing Activities	(51,800,000)	0
Equity Method Investment, Dividends or Distributions	0	0
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions		0
Proceeds from Sale of Property, Plant, and Equipment		0
Increase (Decrease) in Restricted Cash	0
Payments for (Proceeds from) Other Investing Activities	$ 0

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Basis of Presentation (Tables)

6 Months Ended

Jun. 30, 2013

BASIS OF PRESENTATION: [Abstract]

Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]

The computations for basic and dilutive earnings per share are as follows:

	Three Months Ended June 30,					Six Months Ended June 30,
	2013			2012		2013			2012
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(12,526	)	$	152,739	$	(14,090	)	$	249,935
Weighted average shares of common stock outstanding:
Basic	228,721,980			227,548,394		228,520,886			227,408,832
Effect of stock-based compensation awards	—			1,703,791		—			1,713,762
Dilutive	228,721,980			229,252,185		228,520,886			229,122,594
Earnings per share:
Basic	$	(0.05	)	$	0.67	$	(0.06	)	$	1.10
Dilutive	$	(0.05	)	$	0.67	$	(0.06	)	$	1.09

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:

	Three Months Ended June 30,		Six Months Ended June 30,
	2013	2012	2013	2012
Anti-Dilutive Options	4,845,029	2,421,923	4,845,029	2,418,983
Anti-Dilutive Restricted Stock Units	1,383,908	2,642	1,383,908	13,552
Anti-Dilutive Performance Share Units	83,356	91,340	83,356	91,340
Anti-Dilutive Performance Share Options	602,101	501,744	602,101	501,744
	6,914,394	3,017,649	6,914,394	3,025,619

Schedule of Changes in Accumulated Other Comprehensive Income/(Loss) by Component [Table Text Block]

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	27,154			48,766			75,920
Amounts reclassified from accumulated other comprehensive income	(32,241		)	39,895			7,654
New current period other comprehensive income	(5,087		)	88,661			83,574
Balance at June 30, 2013	$	71,674		$	(735,442	)	$	(663,768	)

Schedule of Reclassification of Adjustments to Accumulated Other Comprehensive Income [Table Text Block]

The following table shows the reclassification of adjustments out of Accumulated Other Comprehensive Loss:

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Derivative Instruments (Note 12)
Natural gas price swaps	$	(20,070	)	$	(94,544	)	$	(54,767	)	$	(173,865	)
Tax benefit	10,542			36,697			22,526			68,077
Net of tax	$	(9,528	)	$	(57,847	)	$	(32,241	)	$	(105,788	)
Actuarially Determined Long-Term Liability Adjustments*(Note 3 and Note 4)
Amortization of prior service costs	$	(8,211	)	$	(13,915	)	$	(16,423	)	$	(26,021	)
Recognized net actuarial loss	23,559			26,072			48,747			53,077
Settlement loss	5,087			—			32,202			—
Total	20,435			12,157			64,526			27,056
Tax expense	(7,800		)	(4,571		)	(24,631		)	(10,173		)
Net of tax	$	12,635		$	7,586		$	39,895		$	16,883

Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block]

The table below sets forth the share-based awards that have been exercised or released:

	Three Months Ended June 30,		Six Months Ended June 30,
	2013	2012	2013	2012
Options	160,119	39,418	245,113	51,134
Restricted Stock Units	89,632	64,589	568,141	522,607
Performance Share Units	—	—	159,228	229,730
	249,751	104,007	972,482	803,471

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Consolidated Balance Sheets (Parentheticals) (USD $)	Jun. 30, 2013	Dec. 31, 2012
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	228,834,765	228,129,467
Common Stock, Shares, Outstanding	228,800,010	228,094,712
Treasury Stock, Shares	34,755	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

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Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Operating Activities:
Net Income (Loss)	$ (14,634)	$ 249,906
Adjustments to Reconcile Net Income to Net Cash Provided By Operating Activities:
Depreciation, Depletion and Amortization	320,622	309,171
Stock-Based Compensation	39,241	26,935
(Gain) Loss on Sale of Assets	(32,958)	(189,981)
Amortization of Mineral Leases	761	3,631
Deferred Income Taxes	6,998	30,625
Equity in Earnings of Affiliates	(16,667)	(15,103)
Changes in Operating Assets:
Accounts and Notes Receivable	25,360	40,034
Inventories	19,772	(46,726)
Prepaid Expenses	24,433	19,709
Changes in Other Assets	24,512	10,604
Changes in Operating Liabilities:
Accounts Payable	(13,470)	(41,266)
Other Operating Liabilities	(6,019)	(65,693)
Changes in Other Liabilities	2,807	23,456
Other	12,636	12,647
Net Cash Provided by Operating Activities	393,394	367,949
Investing Activities:
Capital Expenditures	(758,000)	(714,399)
Increase (Decrease) in Restricted Cash	68,673	0
Proceeds from Sales of Assets	240,801	252,229
Net Investment in Equity Affiliates	(16,600)	(21,839)
Net Cash Used in Investing Activities	(465,126)	(484,009)
Financing Activities:
(Payments on) Proceeds from Short-Term Borrowings	173,000
Payments on Miscellaneous Borrowings	(30,162)	(4,662)
Payments on Securitzation Facility	2,873	0
Tax Benefit from Stock-Based Compensation	2,185	1,608
Dividends Paid	(28,601)	(56,833)
Proceeds from Issuance of Common Stock	2,497	457
Issuance of Treasury Stock	0	109
Debt Issuance and Financing Fees	0	(148)
Net Cash (Used in) Provided by Financing Activities	121,792	(59,469)
Net Increase in Cash and Cash Equivalents	50,060	(175,529)
Cash and Cash Equivalents at Beginning of Period	21,878	375,736
Cash and Cash Equivalents at End of Period	$ 71,938	$ 200,207

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Pension and OPEB - Periodic Cost

6 Months Ended

Jun. 30, 2013

PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS NET PERIODIC BENEFIT COSTS: [Abstract]

Components of Pension and Other Postretirement Benefit Plans:

COMPONENTS OF PENSION AND OTHER POSTRETIREMENT BENEFIT (OPEB) PLANS NET PERIODIC BENEFIT COSTS:

Components of net periodic costs (benefits) for the three and six months ended June 30 are as follows:

	Pension Benefits												Other Postretirement Benefits
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2013			2012			2013			2012			2013			2012			2013			2012
Service cost	$	5,581		$	4,850		$	11,287		$	10,003		$	4,849		$	4,566		$	9,698		$	9,766
Interest cost	8,909			9,415			17,752			18,793			29,619			32,795			59,237			68,322
Expected return on plan assets	(12,711		)	(11,452		)	(24,855		)	(23,079		)	—			—			—			—
Amortization of prior service cost (credits)	(407		)	(407		)	(815		)	(815		)	(7,804		)	(13,410		)	(15,608		)	(25,009		)
Recognized net actuarial loss	10,547			11,654			22,722			23,917			17,595			20,020			35,190			40,365
Settlement loss	5,087			—			32,202			—			—			—			—			—
Net periodic benefit cost	$	17,006		$	14,060		$	58,293		$	28,819		$	44,259		$	43,971		$	88,517		$	93,444

For the six months ended June 30, 2013, $34,376 was paid to the pension trust for pension benefits from operating 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 $50,000 to the pension trust in 2013. Net periodic benefit costs are allocated to Costs of Goods Sold and Other Operating Charges and Selling, General and Administrative Expenses in the Consolidated Statements of Income.

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 six months ended June 30, 2013. Accordingly, CONSOL Energy recognized expense of $5,087 and $32,202 for the three and six months ended June 30, 2013, respectively, in Costs of Goods Sold and Other Operating Charges in the Consolidated Statements 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 a remeasurement of the pension plan at June 30 and March 31, 2013. The June 30, 2013 remeasurement resulted in a change to the discount rate to 4.84% from 4.12% at March 31, 2013. The June remeasurement reduced the pension liability by $48,957. The June settlement and corresponding remeasurement of the pension plan resulted in an adjustment of $33,414 in other comprehensive income, net of $20,630 in deferred taxes. The March 31, 2013 remeasurement resulted in a change to the discount rate to 4.12% from 4.00% at December 31, 2012. The March remeasurement reduced the pension liability by $29,916. The March settlement and corresponding remeasurement of the pension plan resulted in an adjustment of $35,261 in other comprehensive income, net of $21,770 in deferred taxes. Currently, the settlement and remeasurement of the pension plan will result in a $10,960 reduction to pension expense compared to what was originally expected to be recognized for the remaining six months of 2013. It is reasonably possible that CONSOL Energy will incur additional settlement charges in 2013, which would require the pension plan to be remeasured using updated assumptions.

CONSOL Energy does not expect to contribute to the other postretirement benefit plan in 2013. We intend to pay benefit claims as they become due. For the six months ended June 30, 2013, $83,106 of other postretirement benefits have been paid.

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Basis of Presentation

6 Months Ended

Jun. 30, 2013

BASIS OF PRESENTATION: [Abstract]

Basis of Presentation

NOTE 1—BASIS OF PRESENTATION:

The accompanying Unaudited Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by generally accepted accounting principles for complete financial statements. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included. Operating results for the three and six months ended June 30, 2013 are not necessarily indicative of the results that may be expected for future periods.

The balance sheet at December 31, 2012 has been derived from the Audited Consolidated Financial Statements at that date but does not include all the notes required by generally accepted accounting principles for complete financial statements. For further information, refer to the Consolidated Financial Statements and related notes for the year ended December 31, 2012 included in CONSOL Energy Inc.'s Form 10-K.

Certain amounts in prior periods have been reclassified to conform with the report classifications of the year ended December 31, 2012, with no effect on previously reported net income or stockholders' equity.

Basic earnings per share are computed by dividing net (loss) income attributable to shareholders by the weighted average shares outstanding during the reporting period. Dilutive earnings per share are computed similarly to basic earnings per share except that the weighted average shares outstanding are increased to include additional shares from the assumed exercise of stock options, performance stock options, and CONSOL share units, and the assumed vesting of restricted and performance share units, if dilutive. The number of additional shares is calculated by assuming that outstanding stock options, performance share options, and CONSOL share units were exercised, that outstanding restricted stock units and performance share units were released, and that the proceeds from such activities were used to acquire shares of common stock at the average market price during the reporting period. CONSOL Energy Inc. (CONSOL Energy or the Company) 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:

	Three Months Ended June 30,		Six Months Ended June 30,
	2013	2012	2013	2012
Anti-Dilutive Options	4,845,029	2,421,923	4,845,029	2,418,983
Anti-Dilutive Restricted Stock Units	1,383,908	2,642	1,383,908	13,552
Anti-Dilutive Performance Share Units	83,356	91,340	83,356	91,340
Anti-Dilutive Performance Share Options	602,101	501,744	602,101	501,744
	6,914,394	3,017,649	6,914,394	3,025,619

The table below sets forth the share-based awards that have been exercised or released:

	Three Months Ended June 30,		Six Months Ended June 30,
	2013	2012	2013	2012
Options	160,119	39,418	245,113	51,134
Restricted Stock Units	89,632	64,589	568,141	522,607
Performance Share Units	—	—	159,228	229,730
	249,751	104,007	972,482	803,471

The weighted average exercise price per share of the options exercised during the three months ended June 30, 2013 and 2012 was $9.90 and $10.26, respectively. The weighted average exercise price per share of the options exercised during the six months ended June 30, 2013 and 2012 was $10.16 and $11.07, respectively.

The computations for basic and dilutive earnings per share are as follows:

	Three Months Ended June 30,					Six Months Ended June 30,
	2013			2012		2013			2012
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(12,526	)	$	152,739	$	(14,090	)	$	249,935
Weighted average shares of common stock outstanding:
Basic	228,721,980			227,548,394		228,520,886			227,408,832
Effect of stock-based compensation awards	—			1,703,791		—			1,713,762
Dilutive	228,721,980			229,252,185		228,520,886			229,122,594
Earnings per share:
Basic	$	(0.05	)	$	0.67	$	(0.06	)	$	1.10
Dilutive	$	(0.05	)	$	0.67	$	(0.06	)	$	1.09

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	27,154			48,766			75,920
Amounts reclassified from accumulated other comprehensive income	(32,241		)	39,895			7,654
New current period other comprehensive income	(5,087		)	88,661			83,574
Balance at June 30, 2013	$	71,674		$	(735,442	)	$	(663,768	)

The following table shows the reclassification of adjustments out of Accumulated Other Comprehensive Loss:

	Three Months Ended June 30,						Six Months Ended June 30,
	2013			2012			2013			2012
Derivative Instruments (Note 12)
Natural gas price swaps	$	(20,070	)	$	(94,544	)	$	(54,767	)	$	(173,865	)
Tax benefit	10,542			36,697			22,526			68,077
Net of tax	$	(9,528	)	$	(57,847	)	$	(32,241	)	$	(105,788	)
Actuarially Determined Long-Term Liability Adjustments*(Note 3 and Note 4)
Amortization of prior service costs	$	(8,211	)	$	(13,915	)	$	(16,423	)	$	(26,021	)
Recognized net actuarial loss	23,559			26,072			48,747			53,077
Settlement loss	5,087			—			32,202			—
Total	20,435			12,157			64,526			27,056
Tax expense	(7,800		)	(4,571		)	(24,631		)	(10,173		)
Net of tax	$	12,635		$	7,586		$	39,895		$	16,883

*Excludes amounts related to the remeasurement of the Actuarially Determined Long-Term Liabilities for the three months and six months ended June 30, 2013 and June 30, 2012.

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Basis of Presentation Reclassification of adjustments out of Accumulated Other Comprehensive Loss (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Natural Gas Swaps	$ (20,070)	$ (94,544)	$ (54,767)	$ (173,865)
Tax Benefit of Natural Gas Swaps	10,542	36,697	22,526	68,077
Natural Gas Swaps, Net of Tax	(9,528)	(57,847)	(32,241)	(105,788)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	(8,211)	(13,915)	(16,423)	(26,021)
Defined Benefit Plan, Amortization of Gains (Losses)	23,559	26,072	48,747	53,077
Other Comprehensive Income (Loss), Finalization of Pension and Non-Pension Postretirement Plan Valuation, Net of Tax	5,087		(32,202)
Defined Benefit Plan, Net Periodic Benefit Cost	20,435	12,157	64,526	27,056
Tax Expense on Actuarially Determined Long-Term Liabilities	7,800	4,571	(24,631)	(10,173)
Actuarially Determined Long-Term Liability Adjustments, Net of Tax	12,635	7,586	39,895	16,883
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	(407)	(407)	(815)	(815)
Defined Benefit Plan, Amortization of Gains (Losses)	(10,547)	(11,654)	(22,722)	(23,917)
Other Comprehensive Income (Loss), Finalization of Pension and Non-Pension Postretirement Plan Valuation, Net of Tax	5,087	0	32,202	0
Defined Benefit Plan, Net Periodic Benefit Cost	$ 17,006	$ 14,060	$ 58,293	$ 28,819

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Inventories (Tables)

6 Months Ended

Jun. 30, 2013

Inventory Disclosure [Abstract]

Inventory components

	June 30, 2013		December 31, 2012
Coal	$	52,406	$	78,825
Merchandise for resale	36,476		35,363
Supplies	139,112		133,578
Total Inventories	$	227,994	$	247,766

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Derivative Instruments (Tables)

6 Months Ended

Jun. 30, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Derivative Instruments

The effect of derivative instruments in cash flow hedging relationships on the Consolidated Statements of Income and the Consolidated Statements of Stockholders' Equity were as follows:

	For the Three Months Ended June 30,
	2013			2012
Natural Gas Price Swaps
Beginning Balance – Accumulated OCI	$	35,453		$	179,915
Gain/(Loss) recognized in Accumulated OCI	$	45,749		$	10,663
Less: Gain reclassified from Accumulated OCI into Outside Sales	$	9,528		$	57,847
Ending Balance – Accumulated OCI	$	71,674		$	132,731
Gain/(Loss) recognized in Outside Sales for ineffectiveness	$	(3,753	)	$	882

	For the Six Months Ended June 30,
	2013			2012
Natural Gas Price Swaps
Beginning Balance – Accumulated OCI	$	76,761		$	151,780
Gain/(Loss) recognized in Accumulated OCI	$	27,154		$	86,739
Less: Gain reclassified from Accumulated OCI into Outside Sales	$	32,241		$	105,788
Ending Balance – Accumulated OCI	$	71,674		$	132,731
Gain/(Loss) recognized in Outside Sales for ineffectiveness	$	(2,712	)	$	47

There were no amounts excluded from the assessment of hedge effectiveness in 2013 or 2012.

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Related Party Transaction (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012	Dec. 31, 2012
Related Party Transaction [Line Items]
Equity Method Investment, Ownership Percentage	50.00%		50.00%
CONE [Member]
Related Party Transaction [Line Items]
Due from Related Parties	$ 1,509		$ 1,509		$ 3,142
Related Party Transaction, Expenses from Transactions with Related Party	6,129	4,262	13,456	7,724
CONE [Member] | CONE Capital Reimbursement [Member]
Related Party Transaction [Line Items]
Due from Related Parties	0		0		(18)
CONE [Member] | Reimbursement for CONE Expenses [Member]
Related Party Transaction [Line Items]
Due from Related Parties	(733)		(733)		(1,336)
CONE [Member] | Reimbursement for Services Provided to Cone [Member]
Related Party Transaction [Line Items]
Due from Related Parties	(153)		(153)		(341)
CONE [Member] | CONE Gathering Fees [Member]
Related Party Transaction [Line Items]
Due to Related Parties, Current	$ 2,395		$ 2,395		$ 4,837

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Basis of Presentation Anti-Dilutive Options and Units Exluded from Earnings Per Share (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of diluted earnings per share	6,914,394	3,017,649	6,914,394	3,025,619
Antidilutive Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of diluted earnings per share	4,845,029	2,421,923	4,845,029	2,418,983
Restricted Stock Units (RSUs) [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of diluted earnings per share	1,383,908	2,642	1,383,908	13,552
Performance Share Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of diluted earnings per share	83,356	91,340	83,356	91,340
Performance Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of diluted earnings per share	602,101	501,744	602,101	501,744

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Guarantor Subsidiaries Financial Information Gurantor Subsidiaries Statement of Comprehensive Income (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Condensed Financial Statements, Captions [Line Items]
Net Income (Loss)	$ (12,813)	$ 152,710	$ (14,634)	$ 249,906
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	42,904	7,586	88,661	67,159
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	45,749	10,663	27,154	86,739
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, Net	(9,528)	(57,847)	(32,241)	(105,788)
Other Comprehensive Income (Loss), Net of Tax	79,125	(39,598)	83,574	48,110
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	66,312	113,112	68,940	298,016
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	287	29	544	29
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	66,599	113,141	69,484	298,045
Parent Issuer [Member]
Condensed Financial Statements, Captions [Line Items]
Net Income (Loss)	(12,526)	152,739	(14,090)	249,935
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	(42,904)	(7,586)	(88,661)	(67,159)
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	(45,749)	(10,663)	(27,154)	(86,739)
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, Net	9,528	57,847	32,241	105,788
Other Comprehensive Income (Loss), Net of Tax	(79,125)	39,598	(83,574)	(48,110)
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	66,599	113,141	69,484	298,045
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	66,599	113,141	69,484	298,045
CNX Gas Guarantor [Member]
Condensed Financial Statements, Captions [Line Items]
Net Income (Loss)	(2,749)	726	(3,074)	8,180
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	0	0	0	0
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	(45,749)	(10,663)	(27,154)	(86,739)
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, Net	9,528	57,847	32,241	105,788
Other Comprehensive Income (Loss), Net of Tax	(36,221)	47,184	5,087	19,049
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	33,472	(46,458)	(8,161)	(10,869)
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	287	29	544	29
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	33,759	(46,429)	(7,617)	(10,840)
Other Guarantors Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net Income (Loss)	217,808	92,585	321,350	246,901
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	(42,904)	(7,586)	(88,661)	(67,159)
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	0	0	0	0
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, Net	0	0	0	0
Other Comprehensive Income (Loss), Net of Tax	(42,904)	(7,586)	(88,661)	(67,159)
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	260,712	100,171	410,011	314,060
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	260,712	100,171	410,011	314,060
Non-Guarantors [Member]
Condensed Financial Statements, Captions [Line Items]
Net Income (Loss)	7,570	3,284	9,798	7,176
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	0	0	0	0
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	0	0	0	0
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, Net	0	0	0	0
Other Comprehensive Income (Loss), Net of Tax	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	7,570	3,284	9,798	7,176
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	7,570	3,284	9,798	7,176
Consolidation, Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Net Income (Loss)	(222,916)	(96,624)	(328,618)	(262,286)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	42,904	7,586	88,661	67,159
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	45,749	10,663	27,154	86,739
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, Net	(9,528)	(57,847)	(32,241)	(105,788)
Other Comprehensive Income (Loss), Net of Tax	79,125	(39,598)	83,574	48,110
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(302,041)	(57,026)	(412,192)	(310,396)
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$ (302,041)	$ (57,026)	$ (412,192)	$ (310,396)

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Long-Term Debt (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012	Jun. 30, 2012	Dec. 31, 2010
Debt Instrument [Line Items]
Capital Lease Obligations, Current	$ 8,837		$ 8,941
Debt	3,128,585	3,129,017
Less amounts due in one year	(4,585)	(4,544)
Long-Term Debt	3,124,000	3,124,473
Accrued interest	63,269			63,363
Senior Notes Due April 2017 at 8.00%
Debt Instrument [Line Items]
Debt	1,500,000	1,500,000
Senior notes due April 2020 at 8.25%
Debt Instrument [Line Items]
Debt	1,250,000	1,250,000
Senior notes due March 2021 at 6.375%
Debt Instrument [Line Items]
Debt	250,000	250,000
Baltimore Port Facility revenue bonds in series due September 2025 at 5.75%
Debt Instrument [Line Items]
Debt	102,865	102,865
Advance royalty commitments
Debt Instrument [Line Items]
Debt	20,394	20,394
Other long-term notes maturing at various dates through 2031
Debt Instrument [Line Items]
Debt	$ 5,326	$ 5,758

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Inventory Components (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Inventory Disclosure [Abstract]
Coal	$ 52,406	$ 78,825
Merchandise for resale	36,476	35,363
Supplies	139,112	133,578
Total Inventories	227,994	247,766
Excess of replacement cost of merchandise for resl inventories over carrying LIFO value	$ 18,734	$ 19,700

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CWP and Workers Comp - Net Periodic Costs (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Schedule of Net Periodic Benefit Costs and Assumptions for Defined Benefit Postretirement Plans [Line Items]
Amortization of actuarial gain	$ (23,559)	$ (26,072)	$ (48,747)	$ (53,077)
Net periodic (benefit) cost	20,435	12,157	64,526	27,056
Coal Workers Pneumoconiosis [Member]
Schedule of Net Periodic Benefit Costs and Assumptions for Defined Benefit Postretirement Plans [Line Items]
Service cost	2,135	1,928	4,270	3,856
Interest cost	1,808	1,991	3,616	3,982
Amortization of actuarial gain	(4,212)	(4,933)	(8,425)	(9,867)
State administrative fees and insurance bond premiums	0	0	0	0
Legal and administrative costs	0	0	0	0
Net periodic (benefit) cost	(269)	(1,014)	(539)	(2,029)
Payments for Coal Workers Pnenumoconiosis			5,372
Workers Compensation [Member]
Schedule of Net Periodic Benefit Costs and Assumptions for Defined Benefit Postretirement Plans [Line Items]
Service cost	3,533	3,634	7,066	7,268
Interest cost	1,655	1,778	3,310	3,556
Amortization of actuarial gain	(699)	(986)	(1,398)	(1,972)
State administrative fees and insurance bond premiums	1,345	1,635	3,004	3,545
Legal and administrative costs	591	648	1,182	1,296
Net periodic (benefit) cost	6,425	6,709	13,164	13,693
Payments for workers compensation benefits, state administrative fees and surety bond premiums			$ 14,946

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Consolidated Statements of Comprehensive Income (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest [Abstract]
Net Income (Loss)	$ (12,813)	$ 152,710	$ (14,634)	$ 249,906
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	42,904	7,586	88,661	67,159
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	45,749	10,663	27,154	86,739
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Abstract]
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, Net	(9,528)	(57,847)	(32,241)	(105,788)
Other Comprehensive Income (Loss), Net of Tax	79,125	(39,598)	83,574	48,110
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	66,312	113,112	68,940	298,016
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	(287)	(29)	(544)	(29)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$ 66,599	$ 113,141	$ 69,484	$ 298,045

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Inventories

6 Months Ended

Jun. 30, 2013

Inventory Disclosure [Abstract]

Inventories

INVENTORIES:

Inventory components consist of the following:

	June 30, 2013		December 31, 2012
Coal	$	52,406	$	78,825
Merchandise for resale	36,476		35,363
Supplies	139,112		133,578
Total Inventories	$	227,994	$	247,766

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 $18,734 and $19,700 at June 30, 2013 and December 31, 2012, respectively.

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Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Current Assets:
Cash and Cash Equivalents	$ 71,938	$ 21,878
Accounts and Notes Receivable:
Trade	347,367	428,328
Notes, Loans and Financing Receivable, Net, Current	350,977	318,387
Other Receivables	151,269	131,131
Accounts Receivable - Securitized	40,719	37,846
Inventories	227,994	247,766
Deferred Income Taxes	143,004	148,104
Recoverable Income Taxes	1,930	0
Restricted Cash and Cash Equivalents, Current	0	48,294
Prepaid Expenses	137,643	157,360
Total Current Assets	1,472,841	1,539,094
Property, Plant and Equipment:
Property, Plant and Equipment	16,194,251	15,545,204
Less-Accumulated Depreciation, Depletion and Amortization	5,770,506	5,354,237
Total Property, Plant and Equipment-Net	10,423,745	10,190,967
Other Assets:
Deferred Income Taxes	388,703	444,585
Restricted Cash	0	20,379
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	256,097	222,830
Notes, Loans and Financing Receivable, Net, Noncurrent	1,512	25,977
Other	210,030	227,077
Total Other Assets	856,342	940,848
Total Assets	12,752,928	12,670,909
Current Liabilities:
Accounts Payable	461,415	507,982
Current Portion of Long-Term Debt	13,422	13,485
Short-Term Notes Payable	173,000	25,073
Accrued Income Taxes, Current	0	34,219
Secured Debt, Current	40,719	37,846
Other Accrued Liabilities	798,645	768,494
Total Current Liabilities	1,487,201	1,387,099
Long-Term Debt:
Long-Term Debt	3,124,000	3,124,473
Capital Lease Obligations	47,750	50,113
Total Long-Term Debt	3,171,750	3,174,586
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	2,820,186	2,832,401
Pneumoconiosis Benefits	177,146	174,781
Mine Closing	459,392	446,727
Gas Well Closing	193,946	148,928
Workers' Compensation	155,518	155,648
Salary Retirement	109,691	218,004
Reclamation	50,051	47,965
Other	102,987	131,025
Total Deferred Credits and Other Liabilities	4,068,917	4,155,479
TOTAL LIABILITIES	8,727,868	8,717,164
Stockholders' Equity:
Common Stock, $.01 Par Value; 500,000,000 Shares Authorized, 228,834,765 Issued and 228,800,010 Outstanding at June 30, 2013; 228,129,467 Issued and 228,094,712 Outstanding at December 31, 2012	2,291	2,284
Capital in Excess of Par Value	2,336,417	2,296,908
Preferred Stock, 15,000,000 shares authorized, None issued and outstanding	0	0
Retained Earnings	2,351,320	2,402,551
Accumulated Other Comprehensive Loss	(663,768)	(747,342)
Common Stock in Treasury, at Cost—34,755 Shares at June 30, 2013 and 34,755 Shares at December 31, 2012	(609)	(609)
Stockholders' Equity Attributable to Parent	4,025,651	3,953,792
Stockholders' Equity Attributable to Noncontrolling Interest	(591)	(47)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	4,025,060	3,953,745
TOTAL LIABILITIES AND EQUITY	$ 12,752,928	$ 12,670,909

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Costs Related to Purchase Obligations (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	$ 72,037	$ 76,457
Major equipment purchases
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	15,116	31,989
Firm transportation expense
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	31,017	15,822
Gas drilling obligations
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	25,904	28,517
Other Obligations
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	$ 0	$ 129

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Consolidated Statements of Income (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Income Statement [Abstract]
Sales-Outside	$ 1,125,776	$ 1,189,293	$ 2,351,941	$ 2,500,764
Sales-Gas Royalty Interests	17,028	9,533	31,232	21,739
Sales-Purchased Gas	1,406	651	2,764	1,490
Freight-Outside	10,125	49,472	24,186	98,765
Other Income (including equity earnings)	62,345	205,538	96,197	258,499
Total Revenue and Other Income	1,216,680	1,454,487	2,506,320	2,881,257
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	855,878	856,889	1,788,841	1,760,930
Gas Royalty Interests Costs	13,534	7,124	25,340	17,373
Purchased Gas Costs	1,061	869	2,020	1,386
Freight Expense	10,125	49,472	24,186	98,765
Selling, General and Administrative Expenses	37,123	33,732	70,793	72,731
Depreciation, Depletion and Amortization	159,307	153,824	320,622	309,171
Interest Expense	54,518	56,593	107,896	114,713
Taxes Other Than Income	83,325	84,329	166,112	175,956
Total Costs	1,214,871	1,242,832	2,505,810	2,551,025
Earnings Before Income Taxes	1,809	211,655	510	330,232
Income Tax Expense (Benefit)	14,622	58,945	15,144	80,326
Net Income (Loss)	(12,813)	152,710	(14,634)	249,906
Add: Net Loss Attributable to Noncontrolling Interest	(287)	(29)	(544)	(29)
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$ (12,526)	$ 152,739	$ (14,090)	$ 249,935
Earnings Per Share:
Basic	$ (0.05)	$ 0.67	$ (0.06)	$ 1.10
Dilutive	$ (0.05)	$ 0.67	$ (0.06)	$ 1.09
Weighted Average Number of Common Shares Outstanding:
Basic	228,721,980	227,548,394	228,520,886	227,408,832
Dilutive	228,721,980	229,252,185	228,520,886	229,122,594
Dividends Paid Per Share	$ 0.125	$ 0.125	$ 0.125	$ 0.250

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Accounts Receivable Securitization (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012	Dec. 31, 2012
Accounts Receivable - Securitized	$ 40,719		$ 40,719		$ 37,846
Increase (Decrease) in Accounts Receivable from Securitization	2,873
AR securitization facility [Member]
Line of Credit Facility, Maximum Borrowing Capacity	200,000		200,000
Current borrowing capacity of receivable facility	181,000		181,000		200,000
Letters of credit amount outstanding	159,281		159,281
Costs associated with the receivables facility	$ 440	$ 437	$ 913	$ 856
Expiration date of receivables facility			Mar. 30, 2017

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Property, Plant and Equipment (Tables)

6 Months Ended

Jun. 30, 2013

Property, Plant and Equipment [Abstract]

Collaborative Arrangement Disclosure [Text Block]

Shale Play	Industry Participation Agreement Partner	Industry Participation Agreement Date	Drilling Carries Remaining*
Marcellus	Noble Energy, Inc.	September 30, 2011	$	2,034,785
Utica	Hess Ohio Developments, LLC	October 21, 2011	$	279,248

Property, Plant and Equipment

	June 30, 2013		December 31, 2012
Coal and other plant and equipment	$	6,086,734	$	6,030,620
Intangible drilling cost	1,721,384		1,550,297
Proven gas properties	1,597,626		1,596,838
Coal properties and surface lands	1,455,541		1,346,151
Unproven gas properties	1,371,532		1,266,017
Gas gathering equipment	1,034,927		1,006,882
Airshafts	727,674		706,388
Mine development	583,494		537,939
Leased coal lands	529,700		529,758
Gas wells and related equipment	542,284		492,367
Coal advance mining royalties	396,034		391,501
Other gas assets	125,194		82,217
Gas advance royalties	22,127		8,229
Total Property Plant and Equipment	16,194,251		15,545,204
Less: Accumulated DD&A	5,770,506		5,354,237
Total Net PP&E	$	10,423,745	$	10,190,967

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Related Party Transaction

3 Months Ended

Jun. 30, 2013

Related Party Transaction [Line Items]

Related Party Transactions Disclosure [Text Block]

RELATED PARTY TRANSACTIONS:

CONE Gathering LLC Related Party Transactions

During the six months ended June 30, 2013, 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 $6,129 and $13,456 for the three and six months ended June 30, 2013, respectively, and were $4,262 and $7,724 for the three and six months ended June 30, 2012, respectively, which were included in Cost of Goods Sold on the Consolidated Statements of Income.

As of June 30, 2013 and December 31, 2012, CONSOL Energy and CNX Gas Company had a net payable of $1,509 and $3,142, respectively, due CONE which was comprised of the following items:

	June 30,			December 31,
	2013			2012			Location on Balance Sheet
Reimbursement for CONE Expenses	$	(733	)	$	(1,336	)	Accounts Receivable–Other
Reimbursement for Services Provided to CONE	(153		)	(341		)	Accounts Receivable–Other
CONE Gathering Capital Reimbursement	—			(18		)	Accounts Receivable–Other
CONE Gathering Fee Payable	2,395			4,837			Accounts Payable
Net Payable due CONE	$	1,509		$	3,142

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Pension and OPEB - Periodic Cost (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended			3 Months Ended		6 Months Ended		3 Months Ended		6 Months Ended		3 Months Ended		6 Months Ended	12 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012	Dec. 31, 2012	Jun. 30, 2013 Pension Plans, Defined Benefit [Member]	Jun. 30, 2012 Pension Plans, Defined Benefit [Member]	Jun. 30, 2013 Pension Plans, Defined Benefit [Member]	Jun. 30, 2012 Pension Plans, Defined Benefit [Member]	Jun. 30, 2013 Other Postretirement Benefit Plans, Defined Benefit [Member]	Jun. 30, 2012 Other Postretirement Benefit Plans, Defined Benefit [Member]	Jun. 30, 2013 Other Postretirement Benefit Plans, Defined Benefit [Member]	Jun. 30, 2012 Other Postretirement Benefit Plans, Defined Benefit [Member]	Jun. 30, 2013 Change in Assumptions for Pension Plans [Member] Pension Plans, Defined Benefit [Member] Rate	Mar. 31, 2013 Change in Assumptions for Pension Plans [Member] Pension Plans, Defined Benefit [Member]	Jun. 30, 2013 Change in Assumptions for Pension Plans [Member] Pension Plans, Defined Benefit [Member] Rate	Dec. 31, 2012 Change in Assumptions for Pension Plans [Member] Pension Plans, Defined Benefit [Member] Rate
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost						$ 5,581	$ 4,850	$ 11,287	$ 10,003	$ 4,849	$ 4,566	$ 9,698	$ 9,766
Interest cost						8,909	9,415	17,752	18,793	29,619	32,795	59,237	68,322
Expected return on plan assets						(12,711)	(11,452)	(24,855)	(23,079)	0	0	0	0
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	(8,211)	(13,915)	(16,423)	(26,021)		(407)	(407)	(815)	(815)	(7,804)	(13,410)	(15,608)	(25,009)
Amortization of actuarial gain	(23,559)	(26,072)	(48,747)	(53,077)		10,547	11,654	22,722	23,917	17,595	20,020	35,190	40,365
Other Comprehensive Income (Loss), Finalization of Pension and Non-Pension Postretirement Plan Valuation, Net of Tax	5,087		(32,202)			5,087	0	32,202	0	0	0	0	0
Net periodic (benefit) cost	20,435	12,157	64,526	27,056		17,006	14,060	58,293	28,819	44,259	43,971	88,517	93,444			10,960
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate														4.84%		4.12%	4.00%
Pension Contributions								34,376
Total anticipated contributions to pension trust								50,000
Defined Benefit Plan, Plan Amendments														48,957	29,916
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	(42,904)	(7,586)	(88,661)	(67,159)										33,414	35,261
Deferred Income Taxes	143,004		143,004		148,104									20,630	21,770	20,630
Defined Benefit Plan, Benefits Paid												$ 83,106

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Short-Term Notes Payable (Details) (USD $) In Thousands, unless otherwise specified			3 Months Ended		6 Months Ended
	Jun. 30, 2013	Dec. 31, 2010	Jun. 30, 2013 Senior Secured Credit Facility April122016 Member [Member]	Jun. 30, 2013 CNX Gas Senior Secured Credit Facility April122016 Member [Member]	Jun. 30, 2013 CNX Gas Senior Secured Credit Facility April122016 Member [Member]	Dec. 31, 2012 CNX Gas Senior Secured Credit Facility April122016 Member [Member]	Jun. 30, 2012 CNX Gas Senior Secured Credit Facility April122016 Member [Member]	Jun. 30, 2013 Interim Funding for Longwall Shields [Member]
Short-term Debt [Line Items]
Credit facility, face amount			$ 1,500,000	$ 1,000,000	$ 1,000,000
Short-term Debt				173,000	173,000			25,073
Additional Capacity Available On Credit Lines At Request			250,000	250,000	250,000
Minimum interest coverage ratio			2.50	3.00
Interest coverage ratio			3.44	36.85	36.85
Maximum leverage ratio			4.50	3.50
Current maximum leverage ratio			3.65	1.20
Senior secured leverage ratio, maximum			2.00
Current secured leverage ratio			0.12
Letters of credit outstanding			100,292	70,051	70,051	70,203
Borrowings and issuance of letters of credit remaining capacity			1,399,708	756,949	756,949	929,797
Debt Instrument, Interest Rate During Period				1.69%	1.76%
Interest Payable, Current	$ 63,269	$ 63,363		$ 62	$ 62		$ 29
Debt Instrument, Interest Rate, Stated Percentage								2.46%

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Reconciliation of Segment Information, Total Assets (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012	Jun. 30, 2012
Assets:
Assets	$ 12,752,928	$ 12,670,909	$ 12,597,896
Items excluded from segment assets:
Recoverable Income Taxes	1,930	0
Total Reportable Business Segments
Assets:
Assets	11,771,465		11,416,441
Coal
Assets:
Assets	5,600,934		5,445,502
Gas
Assets:
Assets	6,170,531		5,970,939
All Other Segments [Member]
Assets:
Assets	363,819		360,673
Excludes Gas Segment [Member]
Items excluded from segment assets:
Cash and Other Investments	45,905		186,611
Intersegment Elimination [Member]
Assets:
Assets	617,644		820,782
Items excluded from segment assets:
Recoverable Income Taxes	1,930		0
Deferred Tax Assets	531,707		588,722
Bond Issuance Costs	$ 38,102		$ 45,449

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Basis of Presentation Earnings Per Share (Details) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$ (12,526)	$ 152,739	$ (14,090)	$ 249,935
Weighted average shares of common stock outstanding:
Basic	228,721,980	227,548,394	228,520,886	227,408,832
Effect of stock-based compensation awards	0	1,703,791	0	1,713,762
Dilutive	228,721,980	229,252,185	228,520,886	229,122,594
Earnings Per Share:
Basic	$ (0.05)	$ 0.67	$ (0.06)	$ 1.10
Dilutive	$ (0.05)	$ 0.67	$ (0.06)	$ 1.09

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Guarantor Subsidiaries Financial Information (Tables)

3 Months Ended

6 Months Ended

12 Months Ended

Jun. 30, 2013

Jun. 30, 2012

Jun. 30, 2013

Jun. 30, 2012

Dec. 31, 2012

Condensed Financial Statements, Captions [Line Items]

Guarantor FInancial Statements [Table Text Block] [Table Text Block]

Income Statement for the Three Months Ended June 30, 2013 (unaudited):

	Parent Issuer			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination			Consolidated
Sales—Outside	$	—		$	172,161		$	897,541		$	53,610		$	2,464		$	1,125,776
Sales—Gas Royalty Interests	—			17,028			—			—			—			17,028
Sales—Purchased Gas	—			1,406			—			—			—			1,406
Freight—Outside	—			—			10,125			—			—			10,125
Other Income	198,207			11,235			45,706			5,404			(198,207		)	62,345
Total Revenue and Other Income	198,207			201,830			953,372			59,014			(195,743		)	1,216,680
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	4,249			125,632			660,137			53,467			12,393			855,878
Gas Royalty Interests Costs	—			13,544			—			—			(10		)	13,534
Purchased Gas Costs	—			1,061			—			—			—			1,061
Related Party Activity	35,231			—			(50,571		)	436			14,904			—
Freight Expense	—			—			10,125			—			—			10,125
Selling, General and Administrative Expenses	—			11,717			25,058			348			—			37,123
Depreciation, Depletion and Amortization	3,252			52,236			103,321			498			—			159,307
Interest Expense	50,807			2,136			1,679			10			(114		)	54,518
Taxes Other Than Income	88			—			82,507			730			—			83,325
Total Costs	93,627			206,326			832,256			55,489			27,173			1,214,871
Earnings (Loss) Before Income Taxes	104,580			(4,496		)	121,116			3,525			(222,916		)	1,809
Income Tax Expense (Benefit)	117,106			(1,747		)	(96,692		)	(4,045		)	—			14,622
Net (Loss) Income	(12,526		)	(2,749		)	217,808			7,570			(222,916		)	(12,813		)
Add: Net Loss Attributable to Noncontrolling Interest	—			287			—			—			—			287
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(12,526	)	$	(2,462	)	$	217,808		$	7,570		$	(222,916	)	$	(12,526	)

Income Statement for the Three Months Ended June 30, 2012 (unaudited):

	Parent Issuer			CNX Gas Guarantor		Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Sales—Outside	$	—		$	148,459	$	976,515	$	64,785	$	(466	)	$	1,189,293
Sales—Gas Royalty Interests	—			9,533		—		—		—			9,533
Sales—Purchased Gas	—			651		—		—		—			651
Freight—Outside	—			—		49,472		—		—			49,472
Other Income	249,780			18,098		30,352		5,215		(97,907		)	205,538
Total Revenue and Other Income	249,780			176,741		1,056,339		70,000		(98,373		)	1,454,487
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	22,351			101,695		662,457		62,811		7,575			856,889
Gas Royalty Interests Costs	—			7,131		—		—		(7		)	7,124
Purchased Gas Costs	—			869		—		—		—			869
Related Party Activity	(14,013		)	—		22,782		447		(9,216		)	—
Freight Expense	—			—		49,472		—		—			49,472
Selling, General and Administrative Expenses	—			9,313		24,185		234		—			33,732
Depreciation, Depletion and Amortization	2,895			47,326		103,085		518		—			153,824
Interest Expense	52,932			1,191		2,560		11		(101		)	56,593
Taxes Other Than Income	27			8,164		75,425		713		—			84,329
Total Costs	64,192			175,689		939,966		64,734		(1,749		)	1,242,832
Earnings (Loss) Before Income Taxes	185,588			1,052		116,373		5,266		(96,624		)	211,655
Income Tax Expense (Benefit)	32,849			326		23,788		1,982		—			58,945
Net (Loss) Income	152,739			726		92,585		3,284		(96,624		)	152,710
Add: Net Loss Attributable to Noncontrolling Interest	—			29		—		—		—			29
Net Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	152,739		$	755	$	92,585	$	3,284	$	(96,624	)	$	152,739

	Parent Issuer			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination			Consolidated
Sales—Outside	$	—		$	340,840		$	1,901,698		$	107,663		$	1,740		$	2,351,941
Sales—Gas Royalty Interests	—			31,232			—			—			—			31,232
Sales—Purchased Gas	—			2,764			—			—			—			2,764
Freight—Outside	—			—			24,186			—			—			24,186
Other Income	276,183			24,459			60,961			10,777			(276,183		)	96,197
Total Revenue and Other Income	276,183			399,295			1,986,845			118,440			(274,443		)	2,506,320
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	80,239			239,984			1,341,842			107,193			19,583			1,788,841
Gas Royalty Interests Costs	—			25,361			—			—			(21		)	25,340
Purchased Gas Costs	—			2,020			—			—			—			2,020
Related Party Activity	22,675			—			(58,349		)	840			34,834			—
Freight Expense	—			—			24,186			—			—			24,186
Selling, General and Administrative Expenses	—			21,829			48,305			659			—			70,793
Depreciation, Depletion and Amortization	6,447			104,635			208,558			982			—			320,622
Interest Expense	100,976			3,797			3,323			21			(221		)	107,896
Taxes Other Than Income	265			6,698			157,513			1,636			—			166,112
Total Costs	210,602			404,324			1,725,378			111,331			54,175			2,505,810
Earnings (Loss) Before Income Taxes	65,581			(5,029		)	261,467			7,109			(328,618		)	510
Income Tax Expense (Benefit)	79,671			(1,955		)	(59,883		)	(2,689		)	—			15,144
Net (Loss) Income	(14,090		)	(3,074		)	321,350			9,798			(328,618		)	(14,634		)
Add: Net Loss Attributable to Noncontrolling Interest	—			544			—			—			—			544
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(14,090	)	$	(2,530	)	$	321,350		$	9,798		$	(328,618	)	$	(14,090	)

	Parent Issuer			CNX Gas Guarantor		Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Sales—Outside	$	—		$	309,128	$	2,058,803	$	133,807	$	(974	)	$	2,500,764
Sales—Gas Royalty Interests	—			21,739		—		—		—			21,739
Sales—Purchased Gas	—			1,490		—		—		—			1,490
Freight—Outside	—			—		98,765		—		—			98,765
Other Income	417,765			34,403		60,055		11,172		(264,896		)	258,499
Total Revenue and Other Income	417,765			366,760		2,217,623		144,979		(265,870		)	2,881,257
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	71,531			200,340		1,345,213		129,227		14,619			1,760,930
Gas Royalty Interests Costs	—			17,386		—		—		(13		)	17,373
Purchased Gas Costs	—			1,386		—		—		—			1,386
Related Party Activity	(7,000		)	—		24,040		949		(17,989		)	—
Freight Expense	—			—		98,765		—		—			98,765
Selling, General and Administrative Expenses	—			19,293		52,757		681		—			72,731
Depreciation, Depletion and Amortization	5,816			96,129		206,185		1,041		—			309,171
Interest Expense	107,694			2,409		4,789		22		(201		)	114,713
Taxes Other Than Income	663			16,364		157,396		1,533		—			175,956
Total Costs	178,704			353,307		1,889,145		133,453		(3,584		)	2,551,025
Earnings (Loss) Before Income Taxes	239,061			13,453		328,478		11,526		(262,286		)	330,232
Income Tax Expense (Benefit)	(10,874		)	5,273		81,577		4,350		—			80,326
Net (Loss) Income	249,935			8,180		246,901		7,176		(262,286		)	249,906
Add: Net Loss Attributable to Noncontrolling Interest	—			29		—		—		—			29
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	249,935		$	8,209	$	246,901	$	7,176	$	(262,286	)	$	249,935

Guarantor Condensed Cash Flow [Table Text Block]

Cash Flow for the Six Months EndedJune 30, 2013 (unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination			Consolidated
Net Cash Provided by Operating Activities	$	35,486		$	263,284		$	46,545		$	(3,721	)	$	51,800		$	393,394
Cash Flows from Investing Activities:
Capital Expenditures	$	(7,511	)	$	(395,593	)	$	(354,896	)	$	—		$	—		$	(758,000	)
Change in Restricted Cash	—			—			68,673			—			—			68,673
Proceeds from Sales of Assets	—			5,644			235,144			13			—			240,801
Net Investments In Equity Affiliates	—			(22,501		)	5,901			—			—			(16,600		)
Net Cash (Used in) Provided by Investing Activities	$	(7,511	)	$	(412,450	)	$	(45,178	)	$	13		$	—		$	(465,126	)
Cash Flows from Financing Activities:
Proceeds from (Payments on) Short-Term Borrowings	$	—		$	224,800		$	—		$	—		$	(51,800	)	$	173,000
Payments on Miscellaneous Borrowings	(26,280		)	—			(3,555		)	(327		)	—			(30,162		)
Proceeds from Securitization Facility	—			—			—			2,873			—			2,873
Dividends (Paid) Received	21,399			(50,000		)	—			—			—			(28,601		)
Proceeds from Issuance of Common Stock	2,497			—			—			—			—			2,497
Other Financing Activities	2,185			—			—			—			—			2,185
Net Cash Provided by (Used in) Financing Activities	$	(199	)	$	174,800		$	(3,555	)	$	2,546		$	(51,800	)	$	121,792

Cash Flow for the Six Months EndedJune 30, 2012 (unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination		Consolidated
Net Cash Provided by Operating Activities	$	271,127		$	124,367		$	(28,281	)	$	736		$	—	$	367,949
Cash Flows from Investing Activities:
Capital Expenditures	$	(24,722	)	$	(241,661	)	$	(448,016	)	$	—		$	—	$	(714,399	)
Investments in Equity Affiliates	—			(35,150		)	(750		)	—			—		(35,900		)
Distributions from Equity Affiliates	—			3,500			10,561			—			—		14,061
Proceeds from Sales of Assets	169,500			30,249			52,469			11			—		252,229
Net Cash (Used in) Provided by Investing Activities	$	144,778		$	(243,062	)	$	(385,736	)	$	11		$	—	$	(484,009	)
Cash Flows from Financing Activities:
Dividends Paid	$	143,167		$	(200,000	)	$	—		$	—		$	—	$	(56,833	)
Other Financing Activities	1,580			(3,751		)	2			(467		)	—		(2,636		)
Net Cash Provided by (Used in) Financing Activities	$	144,747		$	(203,751	)	$	2		$	(467	)	$	—	$	(59,469	)

Guarantor Condensed Comprehensive Income [Table Text Block]

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Net (Loss) Income	$	(12,526	)	$	(2,749	)	$	217,808	$	7,570	$	(222,916	)	$	(12,813	)
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	42,904			—			42,904		—		(42,904		)	42,904
Net (Decrease) Increase in the Value of Cash Flow Hedge	45,749			45,749			—		—		(45,749		)	45,749
Reclassification of Cash Flow Hedge from OCI to Earnings	(9,528		)	(9,528		)	—		—		9,528			(9,528		)
Other Comprehensive (Loss) Income:	79,125			36,221			42,904		—		(79,125		)	79,125
Comprehensive Income (Loss)	66,599			33,472			260,712		7,570		(302,041		)	66,312
Add: Comprehensive Loss Attributable to Noncontrolling Interest	—			287			—		—		—			287
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	66,599		$	33,759		$	260,712	$	7,570	$	(302,041	)	$	66,599

Statement of Comprehensive Income for the Three Months Ended June 30, 2012 (Unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Net Income (Loss)	$	152,739		$	726		$	92,585	$	3,284	$	(96,624	)	$	152,710
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	7,586			—			7,586		—		(7,586		)	7,586
Net Increase (Decrease) in the Value of Cash Flow Hedge	10,663			10,663			—		—		(10,663		)	10,663
Reclassification of Cash Flow Hedge from OCI to Earnings	(57,847		)	(57,847		)	—		—		57,847			(57,847		)
Other Comprehensive Income (Loss):	(39,598		)	(47,184		)	7,586		—		39,598			(39,598		)
Comprehensive Income (Loss)	113,141			(46,458		)	100,171		3,284		(57,026		)	113,112
Add: Comprehensive Loss Attributable to Noncontrolling Interest	—			29			—		—		—			29
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	113,141		$	(46,429	)	$	100,171	$	3,284	$	(57,026	)	$	113,141

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Net (Loss) Income	$	(14,090	)	$	(3,074	)	$	321,350	$	9,798	$	(328,618	)	$	(14,634	)
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	88,661			—			88,661		—		(88,661		)	88,661
Net (Decrease) Increase in the Value of Cash Flow Hedge	27,154			27,154			—		—		(27,154		)	27,154
Reclassification of Cash Flow Hedge from OCI to Earnings	(32,241		)	(32,241		)	—		—		32,241			(32,241		)
Other Comprehensive Income (Loss):	83,574			(5,087		)	88,661		—		(83,574		)	83,574
Comprehensive Income (Loss)	69,484			(8,161		)	410,011		9,798		(412,192		)	68,940
Add: Comprehensive Loss Attributable to Noncontrolling Interest	—			544			—		—		—			544
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	69,484		$	(7,617	)	$	410,011	$	9,798	$	(412,192	)	$	69,484

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Net Income (Loss)	$	249,935		$	8,180		$	246,901	$	7,176	$	(262,286	)	$	249,906
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	67,159			—			67,159		—		(67,159		)	67,159
Net Increase (Decrease) in the Value of Cash Flow Hedge	86,739			86,739			—		—		(86,739		)	86,739
Reclassification of Cash Flow Hedge from OCI to Earnings	(105,788		)	(105,788		)	—		—		105,788			(105,788		)
Other Comprehensive Income (Loss):	48,110			(19,049		)	67,159		—		(48,110		)	48,110
Comprehensive Income (Loss)	298,045			(10,869		)	314,060		7,176		(310,396		)	298,016
Add: Comprehensive Loss Attributable to Noncontrolling Interest	—			29			—		—		—			29
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	298,045		$	(10,840	)	$	314,060	$	7,176	$	(310,396	)	$	298,045

Guarantor Balance Sheet [Table Text Block]

Balance Sheet at June 30, 2013 (unaudited):

	Parent Issuer		CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination			Consolidated
Assets:
Current Assets:
Cash and Cash Equivalents	$	45,267	$	26,851		$	122		$	(302	)	$	—		$	71,938
Accounts and Notes Receivable:
Trade	—		62,013			—			285,354			—			347,367
Notes Receivable	234		323,835			26,908			—			—			350,977
Other Receivables	4,449		133,895			8,436			4,489			—			151,269
Accounts Receivable—Securitized	—		—			—			40,719			—			40,719
Inventories	—		14,619			176,899			36,476			—			227,994
Deferred Income Taxes	169,905		(26,901		)	—			—			—			143,004
Recoverable Income Taxes	16,038		(14,108		)	—			—			—			1,930
Prepaid Expenses	12,795		86,893			36,494			1,461			—			137,643
Total Current Assets	248,688		607,097			248,859			368,197			—			1,472,841
Property, Plant and Equipment:
Property, Plant and Equipment	221,174		6,368,437			9,578,914			25,726			—			16,194,251
Less-Accumulated Depreciation, Depletion and Amortization	134,785		1,064,498			4,552,589			18,634			—			5,770,506
Total Property, Plant and Equipment-Net	86,389		5,303,939			5,026,325			7,092			—			10,423,745
Other Assets:
Deferred Income Taxes	820,406		(431,703		)	—			—			—			388,703
Investment in Affiliates	10,128,714		170,589			764,618			—			(10,807,824		)	256,097
Notes Receivable	184		—			1,328			—			—			1,512
Other	112,660		47,888			39,568			9,914			—			210,030
Total Other Assets	11,061,964		(213,226		)	805,514			9,914			(10,807,824		)	856,342
Total Assets	$	11,397,041	$	5,697,810		$	6,080,698		$	385,203		$	(10,807,824	)	$	12,752,928
Liabilities and Equity:
Current Liabilities:
Accounts Payable	$	193,082	$	208,852		$	48,729		$	10,752		$	—		$	461,415
Accounts Payable (Recoverable)—Related Parties	3,847,815		65,771			(4,118,674		)	153,288			51,800			—
Current Portion Long-Term Debt	1,562		5,972			5,081			807			—			13,422
Short-Term Notes Payable	—		224,800			—			—			(51,800		)	173,000
Borrowings Under Securitization Facility	—		—			—			40,719			—			40,719
Other Accrued Liabilities	140,353		64,908			582,911			10,473			—			798,645
Total Current Liabilities	4,182,812		570,303			(3,481,953		)	216,039			—			1,487,201
Long-Term Debt:	3,005,012		43,897			121,252			1,589			—			3,171,750
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	—		—			2,820,186			—			—			2,820,186
Pneumoconiosis Benefits	—		—			177,146			—			—			177,146
Mine Closing	—		—			459,392			—			—			459,392
Gas Well Closing	—		115,802			78,144			—			—			193,946
Workers’ Compensation	—		—			155,199			319			—			155,518
Salary Retirement	109,691		—			—			—			—			109,691
Reclamation	—		—			50,051			—			—			50,051
Other	73,875		11,703			17,409			—			—			102,987
Total Deferred Credits and Other Liabilities	183,566		127,505			3,757,527			319			—			4,068,917
Total CONSOL Energy Inc. Stockholders’ Equity	4,025,651		4,956,696			5,683,872			167,256			(10,807,824		)	4,025,651
Noncontrolling Interest	—		(591		)	—			—			—			(591		)
Total Liabilities and Equity	$	11,397,041	$	5,697,810		$	6,080,698		$	385,203		$	(10,807,824	)	$	12,752,928

Balance Sheet at December 31, 2012:

	Parent Issuer		CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Assets:
Current Assets:
Cash and Cash Equivalents	$	17,491	$	3,352		$	175		$	860	$	—		$	21,878
Accounts and Notes Receivable:
Trade	—		58,126			—			370,202		—			428,328
Notes Receivable	154		315,730			2,503			—		—			318,387
Other Receivables	6,335		214,748			33,289			5,159		(128,400		)	131,131
Accounts Receivable—Securitized	—		—			—			37,846		—			37,846
Inventories	—		14,133			198,269			35,364		—			247,766
Deferred Income Taxes	174,176		(26,072		)	—			—		—			148,104
Restricted Cash	—		—			48,294			—		—			48,294
Prepaid Expenses	29,589		86,186			40,215			1,370		—			157,360
Total Current Assets	227,745		666,203			322,745			450,801		(128,400		)	1,539,094
Property, Plant and Equipment:
Property, Plant and Equipment	216,448		5,956,207			9,347,370			25,179		—			15,545,204
Less-Accumulated Depreciation, Depletion and Amortization	126,048		960,613			4,249,507			18,069		—			5,354,237
Total Property, Plant and Equipment-Net	90,400		4,995,594			5,097,863			7,110		—			10,190,967
Other Assets:
Deferred Income Taxes	884,310		(439,725		)	—			—		—			444,585
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			32,016			10,188		—			227,077
Total Other Assets	10,920,537		(229,914		)	847,191			10,188		(10,607,154		)	940,848
Total Assets	$	11,238,682	$	5,431,883		$	6,267,799		$	468,099	$	(10,735,554	)	$	12,670,909
Liabilities and Equity:
Current Liabilities:
Accounts Payable	$	177,734	$	166,182		$	154,936		$	9,130	$	—		$	507,982
Accounts Payable (Recoverable)-Related Parties	3,599,216		23,981			(3,749,584		)	254,787		(128,400		)	—
Current Portion of Long-Term Debt	1,554		5,953			5,222			756		—			13,485
Short-Term Notes Payable	25,073		—			—			—		—			25,073
Accrued Income Taxes	20,488		13,731			—			—		—			34,219
Borrowings Under Securitization Facility	—		—			—			37,846		—			37,846
Other Accrued Liabilities	135,407		57,074			566,485			9,528		—			768,494
Total Current Liabilities	3,959,472		266,921			(3,022,941		)	312,047		(128,400		)	1,387,099
Long-Term Debt:	3,005,515		46,081			121,523			1,467		—			3,174,586
Deferred Credits and Other Liabilities:
Postretirement Benefits Other Than Pensions	—		—			2,832,401			—		—			2,832,401
Pneumoconiosis Benefits	—		—			174,781			—		—			174,781
Mine Closing	—		—			446,727			—		—			446,727
Gas Well Closing	—		80,097			68,831			—		—			148,928
Workers’ Compensation	—		—			155,342			306		—			155,648
Salary Retirement	218,004		—			—			—		—			218,004
Reclamation	—		—			47,965			—		—			47,965
Other	101,899		24,518			4,608			—		—			131,025
Total Deferred Credits and Other Liabilities	319,903		104,615			3,730,655			306		—			4,155,479
Total CONSOL Energy Inc. Stockholders’ Equity	3,953,792		5,014,313			5,438,562			154,279		(10,607,154		)	3,953,792
Noncontrolling Interest	—		(47		)	—			—		—			(47		)
Total Liabilities and Equity	$	11,238,682	$	5,431,883		$	6,267,799		$	468,099	$	(10,735,554	)	$	12,670,909

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Related Party Transaction (Tables)

3 Months Ended

Jun. 30, 2013

NOTE 16- RELATED PARTY TRANSACTIONS [Abstract]

Related Party Receivables Payables [Table Text Block]

	June 30,			December 31,
	2013			2012			Location on Balance Sheet
Reimbursement for CONE Expenses	$	(733	)	$	(1,336	)	Accounts Receivable–Other
Reimbursement for Services Provided to CONE	(153		)	(341		)	Accounts Receivable–Other
CONE Gathering Capital Reimbursement	—			(18		)	Accounts Receivable–Other
CONE Gathering Fee Payable	2,395			4,837			Accounts Payable
Net Payable due CONE	$	1,509		$	3,142

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Income Taxes

6 Months Ended

Jun. 30, 2013

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES:

The effective tax rate for the 2013 and 2012 six-month periods was 2,969.4% and 24.3%, respectively.

The rate for the six months ended June 30, 2013 differs from the U.S. federal statutory rate of 35% primarily due to a $25,471 income tax charge for excess depletion, $8,269 discrete income tax charge related to the gain on sale of the Potomac coal reserves and a $1,585 income tax benefit due to a refund claim related to prior year Commonwealth of Pennsylvania taxes.

The rate for the six months ended June 30, 2012 differs from the U.S. federal statutory rate of 35% primarily due to a $39,275 benefit recorded for excess depletion.

The total amounts of uncertain tax positions at June 30, 2013 and 2012 were $22,770 and $25,570, respectively. If these uncertain tax positions were recognized, approximately $2,071 and $3,891, respectively, would affect CONSOL Energy’s effective tax rate. There were no additions to the liability for unrecognized tax benefits during the six months ended June 30, 2013 and 2012.

CONSOL Energy recognizes interest accrued related to uncertain tax positions in its interest expense. As of June 30, 2013 and 2012, the Company reported an accrued interest liability relating to uncertain tax positions of $5,505 and $6,429, respectively. The accrued interest liability includes $675 and $1,055 of interest expense that is reflected in the Company’s Consolidated Statements of Income for the six months ended June 30, 2013 and 2012, respectively.

CONSOL Energy recognizes penalties accrued related to uncertain tax positions in its income tax expense. As of June 30, 2013 and 2012, CONSOL Energy had no accrued liability for tax penalties.

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Carrying Amounts and Fair Values of Financial Instruments for Which the Fair Value Option Was Not Elected (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012	Jun. 30, 2012	Dec. 31, 2011
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]
Restricted Cash and Cash Equivalents, Current	$ 0	$ 48,294
Cash and Cash Equivalents	71,938	21,878	200,207	375,736
Notes and Loans Payable, Current	(173,000)	(25,073)
Secured Debt, Current	(40,719)	(37,846)
Long-term debt	(3,128,585)	(3,129,017)
Restricted Cash and Cash Equivalents, Noncurrent	0	20,379
Carrying Amount
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]
Restricted Cash and Cash Equivalents, Current	48,294
Cash and Cash Equivalents	71,938	21,878
Restricted cash	0	68,673
Long-term debt	(3,128,585)	(3,129,017)
Restricted Cash and Cash Equivalents, Noncurrent	20,379
Fair Value
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]
Cash and Cash Equivalents	71,938	21,878
Restricted cash	0	68,673
Long-term debt	$ (3,270,812)	$ (3,378,058)

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Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2013

Long-term Debt, Other Disclosures [Abstract]

Schedule of Long-term Debt

	June 30, 2013		December 31, 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 (7.43% weighted average interest rate for June 30, 2013 and December 31, 2012)	20,394		20,394
Other long-term notes maturing at various dates through 2031 (total value of $6,612 and $7,300 less unamortized discount of $1,286 and $1,542 at June 30, 2013 and December 31, 2012, respectively).	5,326		5,758
	3,128,585		3,129,017
Less amounts due in one year *	4,585		4,544
Long-Term Debt	$	3,124,000	$	3,124,473

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Dispositions (Details) (USD $)	6 Months Ended	3 Months Ended			12 Months Ended		3 Months Ended		12 Months Ended	3 Months Ended	12 Months Ended
	Jun. 30, 2012	Jun. 30, 2013 Potamac Coal Reserves [Member]	Jun. 30, 2013 Robinson Run Longwall Shields [Member] [Member]	Mar. 31, 2012 Burning Star Disposal [Member]	Dec. 31, 2012 Ram River [Member] acre	Dec. 31, 2012 Burning Start No.4 [Member] acre	Jun. 30, 2013 Shoemaker Longwall Shields [Member]	Jun. 30, 2013 Bailey Longwall Shields [Member]	Dec. 31, 2012 Youngs Creek [Member] acre	Jun. 30, 2012 Elk Creek [Member]	Dec. 31, 2012 Elk Creek [Member] acre
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Sale Leaseback Transaction, Net Proceeds			$ 68,337,000				$ 63,839,000	$ 71,166,000
Coal Lands and or Surface Rights					36,000	4,300			200,000,000		20
Proceeds from Sale of Property, Plant, and Equipment	252,229,000	25,000,000		13,023,000	51,869,000				169,500	26,000
Disposal Group, Including Discontinued Operation, Assets of Disposal Group									.5
Gain (Loss) on Disposition of Assets		24,663,000		11,261,000	89,943,000				150,677,000
Gain (Loss) on Sale of Property Plant Equipment			(236,000)				279,000	358,000		(11,235)
royalty percentage retained									.08
Note Receivable 1 year - PPE Sale					25,500,000
Note Receivable 2 year - PPE Sale					24,500,000
Restricted Cash and Cash Equivalents					48,294,000
Transaction and Financing Fees					$ 637,000

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Property, Plant and Equipment

6 Months Ended

Jun. 30, 2013

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

PROPERTY, PLANT AND EQUIPMENT:

	June 30, 2013		December 31, 2012
Coal and other plant and equipment	$	6,086,734	$	6,030,620
Intangible drilling cost	1,721,384		1,550,297
Proven gas properties	1,597,626		1,596,838
Coal properties and surface lands	1,455,541		1,346,151
Unproven gas properties	1,371,532		1,266,017
Gas gathering equipment	1,034,927		1,006,882
Airshafts	727,674		706,388
Mine development	583,494		537,939
Leased coal lands	529,700		529,758
Gas wells and related equipment	542,284		492,367
Coal advance mining royalties	396,034		391,501
Other gas assets	125,194		82,217
Gas advance royalties	22,127		8,229
Total Property Plant and Equipment	16,194,251		15,545,204
Less: Accumulated DD&A	5,770,506		5,354,237
Total Net PP&E	$	10,423,745	$	10,190,967

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 LLC (CNX Gas Company), a wholly owned subsidiary of CONSOL Energy, completed a sale to Hess Ohio Developments, LLC (Hess) of 50% of nearly 200 thousand net Utica Shale acres in Ohio. Cash proceeds related to this transaction were $54,254, which were net of $5,719 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 aggregate amount of the drilling carry can be adjusted downward under provisions of the joint venture agreements in certain events. 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 announced, 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 will be 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 itself 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. The discounted notes receivable of $311,754 and $296,344 were recorded in Accounts and Notes Receivables-Notes Receivable and Other Assets-Notes Receivable, respectively. 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 aggregate amount of the drilling carry may also be adjusted downward under provisions of the joint venture agreements in certain events.

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 then can review and respond to the asserted title defects, or cure them, and ultimately, if the claim is not resolved, either party can submit the defect to an arbitrator for resolution. If they establish any title defects which are not resolved in favor of CONSOL Energy or if the subject acreage is reassigned to us at our request, then subject to certain deductibles, Noble's aggregate carried cost obligation under the joint venture agreements will be reduced by the value the parties previously allocated to the affected acreage in the transaction. If a significant percentage of the oil and gas interests we contributed have title defects, the carried costs could be materially reduced and our aggregate share of the drilling and completion costs for wells in these joint ventures could materially increase. Noble Energy has submitted a final title defect notice to CONSOL Energy. Based on our review of the title defect notice, Noble has asserted title defects with respect to approximately 75,000 gross deal acres, having a carry value of approximately $481,000, which have not yet been addressed. We are working closely with Noble to address these alleged defects and we believe that we will resolve most of those defects favorably to CONSOL Energy. To date, we have conceded defects which have an aggregate value of approximately $57,000 in excess of the applicable deductibles. The impact of these conceded defects was $2,470 and $8,780 of expense for the three and six months ended June 30, 2013 and is included in Cost of Goods Sold and Other Charges in the Consolidated Statement of Income.

The following table provides information about our industry participation agreements as of June 30, 2013:

Shale Play	Industry Participation Agreement Partner	Industry Participation Agreement Date	Drilling Carries Remaining*
Marcellus	Noble Energy, Inc.	September 30, 2011	$	2,034,785
Utica	Hess Ohio Developments, LLC	October 21, 2011	$	279,248

*See above for a description of the impact on the drilling carries of title defects that have been asserted by Noble Energy.

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CWP and Workers Comp - Net Periodic Costs

6 Months Ended

Jun. 30, 2013

CWP And Workers Comp Net Periodic Cost [Abstract]

Coal Workers' Pneumoconiosis (CWP) and Workers' Compensation:

COMPONENTS OF COAL WORKERS’ PNEUMOCONIOSIS (CWP) AND WORKERS’ COMPENSATION NET PERIODIC BENEFIT COSTS:

Components of net periodic costs (benefits) for the three and six months ended June 30 are as follows:

	CWP												Workers' Compensation
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2013			2012			2013			2012			2013			2012			2013			2012
Service cost	$	2,135		$	1,928		$	4,270		$	3,856		$	3,533		$	3,634		$	7,066		$	7,268
Interest cost	1,808			1,991			3,616			3,982			1,655			1,778			3,310			3,556
Amortization of actuarial gain	(4,212		)	(4,933		)	(8,425		)	(9,867		)	(699		)	(986		)	(1,398		)	(1,972		)
State administrative fees and insurance bond premiums	—			—			—			—			1,345			1,635			3,004			3,545
Legal and administrative costs	—			—			—			—			591			648			1,182			1,296
Net periodic (benefit) cost	$	(269	)	$	(1,014	)	$	(539	)	$	(2,029	)	$	6,425		$	6,709		$	13,164		$	13,693

CONSOL Energy does not expect to contribute to the CWP plan in 2013. We intend to pay benefit claims as they become due. For the six months ended June 30, 2013, $5,372 of CWP benefit claims have been paid.

CONSOL Energy does not expect to contribute to the workers’ compensation plan in 2013. We intend to pay benefit claims as they become due. For the six months ended June 30, 2013, $14,946 of workers’ compensation benefits, state administrative fees and surety bond premiums have been paid.

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Consolidated Statements of Stockholders' Equity (USD $) In Thousands, unless otherwise specified	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
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest 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	(14,090)	0	0	(14,090)	0	0	(14,090)	(544)
Net Income (Loss)	(14,634)
Other Comprehensive Income (Loss), Net of Tax	83,574	0	0	0	83,574	0	83,574	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	68,940	0	0	(14,090)	83,574	0	69,484	(544)
Proceeds from Issuance of Common Stock	2,497	7	2,490	0	0	0	2,497	0
Stock Issued During Period, Value, Treasury Stock Reissued	(8,540)	0	0	(8,540)	0	0	(8,540)	0
Adjustments to Additional Paid in Capital, Income Tax Benefit from Share-based Compensation	(2,222)	0	(2,222)	0	0	0	(2,222)	0
Adjustments to Additional Paid in Capital, Share-based Compensation, Requisite Service Period Recognition	39,241	0	39,241	0	0	0	39,241	0
Dividends, Cash	(28,601)	0	0	(28,601)	0	0	(28,601)	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest at Jun. 30, 2013	$ 4,025,060	$ 2,291	$ 2,336,417	$ 2,351,320	$ (663,768)	$ (609)	$ 4,025,651	$ (591)

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Property, Plant and Equipment (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
Property, Plant and Equipment [Line Items]
Coal and other plant and equipment	$ 6,086,734	$ 6,030,620
Drilling Cost	1,721,384	1,550,297
Proven gas properties	1,597,626	1,596,838
Coal properties and surface lands	1,455,541	1,346,151
Unproven gas properties	1,371,532	1,266,017
Gas gathering equipment	1,034,927	1,006,882
Airshafts	727,674	706,388
Mine development	583,494	537,939
Leased coal lands	529,700	529,758
Gas wells and related equipment	542,284	492,367
Coal advance mining royalties	396,034	391,501
Other gas assets	125,194	82,217
Gas advance royalties	22,127	8,229
Total property plant and equipment	16,194,251	15,545,204
Less Accumulated depreciation, depletion and amortization	5,770,506	5,354,237
Total Property, Plant and Equipment-Net	$ 10,423,745	$ 10,190,967

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Income Taxes Additional Information (Details) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012
Deferred Tax Liability Not Recognized [Line Items]
Uncertain tax positions	$ 22,770	$ 25,570
Uncertain tax positions that, if recognized, would impact effective tax rate	2,071	3,891
Accrued interest liability relating to uncertain tax positions	5,505	6,429
Interest expense included in accrued interest liability	$ 675	$ 1,055

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Fair Value of Financial Instruments (Tables)

6 Months Ended

Jun. 30, 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 June 30, 2013						Fair Value Measurements at December 31, 2012
Description	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Gas Cash Flow Hedges	$	—	$	116,119	$	—	$	—	$	128,945	$	—

Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Table Text Block]

	June 30, 2013						December 31, 2012
	Carrying Amount			Fair Value			Carrying Amount			Fair Value
Cash and Cash Equivalents	$	71,938		$	71,938		$	21,878		$	21,878
Restricted Cash (a)	$	—		$	—		$	68,673		$	68,673
Short-Term Notes Payable	$	(173,000	)	$	(173,000	)	$	(25,073	)	$	(25,073	)
Borrowings Under Securitization Facility	$	(40,719	)	$	(40,719	)	$	(37,846	)	$	(37,846	)
Long-Term Debt	$	(3,128,585	)	$	(3,270,812	)	$	(3,129,017	)	$	(3,378,058	)

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Guarantor Subsidiaries Financial Information Additional Information (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012	Jun. 30, 2012	Dec. 31, 2011
Condensed Financial Statements, Captions [Line Items]
Cash and Cash Equivalents	$ 71,938	$ 21,878	$ 200,207	$ 375,736
Trade	347,367	428,328
Notes Receivable, Related Parties, Current	350,977	318,387
Other Receivables	151,269	131,131
Accounts Receivable - Securitized	40,719	37,846
Inventories	227,994	247,766
Deferred Income Taxes	143,004	148,104
Senior Notes Due April 2017 at 8.00%
Condensed Financial Statements, Captions [Line Items]
Debt Instrument, Face Amount	1,500,000
Debt Instrument, 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
Debt Instrument, 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
Debt Instrument, Interest Rate, Stated Percentage	6.375%

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Derivative Instruments (Details) (Cash Flow Hedging [Member], Price Swaps, Natural Gas, USD $) In Thousands, unless otherwise specified	3 Months Ended
	Jun. 30, 2013 MMcf	Dec. 31, 2010
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Notional Amount of Outstanding Natural Gas Forward Contracts (in MMcf)	197,700,000
Unrealized Gain Expected to be Reclassified from Other Comprehensive Income and into Earnings During the Next Twelve Months	$ 49,614
Derivative Assets Designated as Hedging Instruments	120,973	135,969
Derivative Liabilities Designated as Hedging Instruments	4,854	7,024
Prepaid Expenses
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative Assets, Current	82,061	80,057
Other Assets
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative Assets, Noncurrent	38,912	55,912
Other Accrued Liabilities [Member]
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative Assets, Current	860	970
Other Liabilities [Member]
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative Liabilities, Noncurrent	$ 3,994	$ 6,054

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Commitments and Contingencies

3 Months Ended

Jun. 30, 2013

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES:

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 $792,000.

The following lawsuits and claims include those for which a loss is probable and an accrual has been recognized.

American Electric Corp: On August 8, 2011, the United States Environmental Protection Agency, Region IV, sent Consolidation Coal Company a General Notice and Offer to Negotiate regarding the Ellis Road/American Electric Corp. Superfund Site in Jacksonville, Florida. The General Notice was sent to approximately 180 former customers of American Electric Corp. CONSOL Energy has confirmed that it did business with American Electric Corp. in 1983 and 1984. The General Notice indicated that the Environmental Protection Agency (EPA) has determined that polychlorinated biphenyls (PCBs) and other contaminants in the soils and sediments at and near the site require a removal action. The Offer to Negotiate invited the potentially responsible parties (PRPs) to enter into an Administrative Settlement Agreement and Order on Consent (AOC) to provide for conducting the removal action under the EPA oversight and to reimburse the EPA for its past costs, in the amount of $384 and for its future costs. CONSOL Energy responded to the EPA indicating its willingness to participate in such negotiations, and CONSOL Energy is participating in a group of potentially responsible parties to conduct the removal action. The AOC was signed on July 20, 2012, and as a result, the EPA granted the performing parties a $408 orphan share credit, which will offset the EPA's past costs. The actual scope of the work has yet to be determined, but the current estimate of the total costs of the removal action is in the range of $2,000 to $5,400, with CONSOL Energy's share of such costs at approximately 8%. In 2011, CONSOL Energy established an initial accrual based on its allocated share of the costs among the viable former customers of American Electric Corp. During the year ended December 31, 2012, CONSOL Energy funded $250 to an independent trust established for the remediation, which is 50% of CONSOL Energy's allocated share of the trust fund. The liability is immaterial to the overall financial position of CONSOL Energy and is included in Other Accrued Liabilities on the Consolidated Balance Sheet.

Ward Transformer Superfund Site: CONSOL Energy was notified in November 2004 by the EPA that it is a potentially responsible party (PRP) under the Superfund program established by the Comprehensive Environmental Response, Compensation and Liability Act of 1980, as amended (CERCLA), with respect to the Ward Transformer site in Wake County, North Carolina. The EPA, CONSOL Energy and two other PRPs entered into an administrative Settlement Agreement and Order of Consent, requiring those PRPs to undertake and complete a PCB soil removal action, at and in the vicinity of the Ward Transformer property. In June 2008, while conducting the PCB soil excavation on the Ward property, it was determined that PCBs have migrated onto adjacent properties and in September 2008, the EPA notified CONSOL Energy and 60 other companies that they are PRPs for these additional areas. The current estimated cost of remedial action for the area CONSOL Energy was originally named a PRP, including payment of the EPA's past and future cost, is approximately $65,000. The current estimated cost of the most likely remediation plan for the additional areas discovered is approximately $11,000. CONSOL Energy recognized no expense in Cost of Goods Sold and Other charges in the three or six months ended June 30, 2013 and 2012, respectively. Also, CONSOL Energy has provided funding to an independent trust established for this remediation. CONSOL Energy funded $430 in the six months ended June 30, 2013. No funding was made in the six months ended June 30, 2012. As of June 30, 2013, CONSOL Energy and the other participating PRPs had asserted CERCLA cost recovery and contribution claims against approximately 225 nonparticipating PRPs to recover a share of the costs incurred and to be incurred to conduct the removal actions at the Ward Site. CONSOL Energy's portion of recoveries from settled claims is $4,369. Accordingly, the liability reflected in Other Accrued Liabilities was reduced by these settled claims. The remaining net liability at June 30, 2013 is $2,762.

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 is included in Other Accrued Liabilities on the Consolidated Balance Sheet. Past payments by Fairmont with respect to asbestos cases have not been material.

Ryerson Dam Litigation: In 2008, the Pennsylvania Department of Conservation and Natural Resources (the Commonwealth) filed a six-count Complaint in the Court of Common Pleas of Allegheny County, Pennsylvania, claiming that the Company's underground longwall mining activities at its Bailey Mine caused cracks and seepage damage to the Ryerson Park Dam. The Commonwealth subsequently breached the dam, thereby eliminating the Ryerson Park Lake. The Commonwealth claimed that the Company is liable for dam reconstruction costs, lake restoration costs and natural resource damages totaling $58,000. In October 2008, the Common Pleas Court ruled that natural resource damages were not recoverable and referred the Commonwealth's claim to the Pennsylvania Department of Environmental Protection (DEP). In February 2010, the DEP issued an interim report, concluding that the alleged damage was subsidence related. The DEP estimated the cost of repair to be approximately $20,000. The Company appealed the DEP's findings to the Pennsylvania Environmental Hearing Board (PEHB). In April 2013, this Company and the Commonwealth entered into a Settlement Agreement and Release settling all of the Commonwealth's claims regarding the Dam and the Lake. The Settlement provides 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 provides 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 certain coal and mining rights in an area of the Bailey Mine where a mining permit application is currently pending.

South Carolina Electric & Gas Company Arbitration: In April, 2009, South Carolina Electric & Gas Company (SCE&G), a public utility, filed an arbitration complaint, against CONSOL of Kentucky Inc. and CONSOL Energy Sales Company, both wholly owned subsidiaries of CONSOL Energy, seeking $36,000 in damages. SCE&G claimed it suffered those damages in obtaining cover coal to replace coal which was not delivered in 2008 under a coal sales agreement.  CONSOL Energy counterclaimed against SCE&G for $9,400 for terminating coal shipments under the sales agreement, alleging that SCE&G had agreed that shortfalls could be made up in 2009.  A four day hearing on the claims commenced on April 30, 2012. On December 21, 2012, the Arbitration Panel awarded SCE&G $9,735, plus interest at 8.75% from January 9, 2011, and attorney fees. The Award is against CONSOL of Kentucky only. The Panel is currently considering SCE&G's attorney fee claim of $1,873, which has been vigorously opposed by CONSOL Energy. 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.

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 conflicting claimant, 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, and the District Judge has scheduled argument on the Objections on September 12, 2013. Discovery is proceeding in this litigation. 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, and the District Judge has scheduled argument on the Objections on September 12, 2013. Discovery is proceeding in this litigation. 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.

CNX Gas Shareholders Litigation: CONSOL Energy was named as a defendant in four putative class actions brought by alleged shareholders of CNX Gas Corporation challenging the tender offer by CONSOL Energy to acquire all of the shares of CNX Gas common stock that CONSOL Energy did not already own for $38.25 per share. The two cases filed in Pennsylvania Common Pleas Court have been stayed and the two cases filed in the Delaware Chancery Court have been consolidated under the caption In Re CNX Gas Shareholders Litigation (C.A. No. 5377-VCL).  (A third case filed in Delaware was voluntarily dismissed by the plaintiff in 2010.) All four actions generally allege that CONSOL Energy breached and/or aided and abetted in the breach of fiduciary duties purportedly owed to CNX Gas public shareholders, essentially alleging that the $38.25 per share price that CONSOL Energy paid to CNX Gas shareholders in the tender offer and subsequent short-form merger was unfair. Among other things, the actions sought a permanent injunction against or rescission of the tender offer, damages, and attorneys' fees and expenses. Following a mediation, the parties to the Delaware litigation have agreed in principle to a settlement and release of all of the claims of the plaintiff class (as defined in a January 20, 2011 order of certification) in exchange for defendants' agreement to establish a settlement fund in the amount of $42,730 for distribution to class members, of which CONSOL Energy is responsible for $20,200. On May 8, 2013, the parties executed and filed with the Court a Stipulation and Agreement of Compromise and Settlement. A Settlement Hearing has been scheduled by the Court on August 23, 2013.

The following lawsuits and claims include those for which a loss is reasonably possible, but not probable, and accordingly no accrual has been recognized.

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: 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. Service was effected on April 1, 2013 by waiver. A Motion to Dismiss Plaintiffs' Complaint and, in the Alternative, Motion for More Definitive Statement was filed by the defendants on May 31, 2013. Plaintiffs' Response in opposition to the Motion to Dismiss was filed on June 20, 2013, and the defendants on July 1, 2013, filed their Reply to the Response. Without first seeking the required leave of Court, plaintiffs filed a Sur Reply brief on July 8, 2013, for the first time arguing the interpretation of the Virginia Mine Void Statute urged by defendants was unconstitutional. The defendants have moved to strike the Sur Reply and have asked the Court to deny plaintiffs' after-the-fact Motion for Leave to file the Sur Reply brief. CONSOL Energy intends to vigorously defend the suit.

Hall Litigation: A purported class action lawsuit was filed on December 23, 2010 styled Hall v. CONSOL Gas Company in Allegheny County Pennsylvania Common Pleas Court.  The named plaintiff is Earl D. Hall.  The purported class plaintiffs are all Pennsylvania oil and gas lessors to Dominion Exploration and Production Company, whose leases were acquired by CONSOL Energy.  The complaint alleges more than 1,000 similarly situated lessors.  The lawsuit alleges that CONSOL Energy incorrectly calculated royalties by (i) calculating line loss on the basis of allocated volumes rather than on a well-by-well basis, (ii) possibly calculating the royalty on the basis of an incorrect price, (iii) possibly taking unreasonable deductions for post-production costs and costs that were not arms-length, (iv) not paying royalties on gas lost or used before the point of sale, and (v) not paying royalties on oil production. The complaint also alleges that royalty statements were false and misleading.  The complaint seeks damages, interest and an accounting on a well-by-well basis. The case has been inactive since December 2011. 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.

    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 trial on the issue of whether a drilling that deviates from the coal seam results in damage to the gas owner is now scheduled for October 21, 2013. CNX Gas Company and CONSOL Energy believe this lawsuit to be without merit and intend 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 amended its complaint twice to include allegations that CONSOL Energy and Dominion Resources are liable for their subsidiaries' actions and that Rowland's title has been slandered. Motions to dismiss have been denied, discovery is proceeding but stayed pending mediation. Initial mediation efforts have been unsuccessful but settlement discussions are continuing. 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.

Majorsville Storage Field Declaratory Judgment: On March 3, 2011, an attorney sent a letter to CNX Gas Company regarding certain leases that CNX Gas Company obtained from Columbia Gas in Greene County, Pennsylvania involving the Majorsville Storage Field. The letter was written on behalf of three lessors alleging that the leases totaling 525 acres are invalid, and had expired by their terms. The plaintiffs' theory is that the rights of storage and production are severable under the leases. Ignoring the fact that the leases have been used for gas storage, they claim that since there has been no production or development of production, the right to produce gas expired at the end of the primary terms. On June 16, 2011, in the Court of Common Pleas of Greene County, Pennsylvania, the Company filed a declaratory judgment action, seeking to have a court confirm the validity of the leases. Discovery is proceeding in this litigation. We believe that we will prevail in this litigation based on the language of the leases and the current status of the law. Consequently, we have not recognized any liability related to these actions.

The following lawsuit and claims include those for which a loss is remote and accordingly, no accrual has been recognized, although if a non-favorable verdict were received the impact could be material.

Comer Litigation: In 2005, plaintiffs Ned Comer and others filed a purported class action lawsuit in the U.S. District Court for the Southern District of Mississippi against a number of companies in energy, fossil fuels and chemical industries, including CONSOL Energy styled, Comer, et al. v. Murphy Oil, et al. (Comer I). The plaintiffs, residents and owners of property along the Mississippi Gulf coast, alleged that the defendants caused the emission of greenhouse gases that contributed to global warming, which in turn caused a rise in sea levels and added to the ferocity of Hurricane Katrina, which combined to destroy the plaintiffs' property. The District Court dismissed the case and the plaintiffs appealed. The Circuit Court panel reversed and the defendants sought a rehearing before the entire court. A rehearing before the entire court was granted, which had the effect of vacating the panel's reversal, but before the case could be heard on the merits, a number of judges recused themselves and there was no longer a quorum. As a result, the District Court's dismissal was effectively reinstated. The plaintiffs asked the U.S. Supreme Court to require the Circuit Court to address the merits of their appeal. On January 11, 2011, the Supreme Court denied that request. Although that should have resulted in the dismissal being final, the plaintiffs filed a lawsuit on May 27, 2011, in the same jurisdiction against essentially the same defendants making nearly identical allegations as in the original lawsuit (Comer II). The trial court dismissed this case, and the dismissal was appealed. On May 14, 2013, a panel of the U.S. Court of Appeals for the Fifth Circuit affirmed, holding res judicata arising from Comer I bars the plaintiffs' claims in Comer II. On June 5, 2013, the Fifth Circuit issued its mandate. If they wish to do so, plaintiffs have until August 12, 2013, to file a certiorari petition with the Supreme Court of the United States.

At June 30, 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. No amounts related to these financial guarantees and letters of credit are recorded as liabilities on the financial statements. CONSOL Energy management believes that these guarantees will expire without being funded, and therefore the commitments will not have a material adverse effect on financial condition.

	Amount of Commitment Expiration Per Period
	Total Amounts Committed		Less Than 1  Year		1-3 Years		3-5 Years		Beyond 5  Years
Letters of Credit:
Employee-Related	$	190,157	$	95,847	$	94,310	$	—	$	—
Environmental	56,294		54,566		1,728		—		—
Other	83,246		31,015		52,231		—		—
Total Letters of Credit	329,697		181,428		148,269		—		—
Surety Bonds:
Employee-Related	204,884		194,884		10,000		—		—
Environmental	533,725		527,938		5,787		—		—
Other	30,946		30,935		10		—		1
Total Surety Bonds	769,555		753,757		15,797		—		1
Total Commitments	$	1,099,252	$	935,185	$	164,066	$	—	$	1

Employee-related financial guarantees have primarily been provided to support the United Mine Workers’ of America’s 1992 Benefit Plan and various state and federal workers’ compensation self-insurance programs. Environmental financial guarantees have primarily been provided to support various performance bonds related to reclamation and other environmental issues. Coal and Gas financial guarantees have primarily been provided to support various sales contracts. Other guarantees have also been extended to support insurance policies, legal matters, full and timely payments of mining equipment leases, and various other items necessary in the normal course of business.

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 June 30, 2013, the purchase obligations for each of the next five years and beyond were as follows:

Obligations Due	Amount
Less than 1 year	$	258,380
1 - 3 years	164,240
3 - 5 years	131,751
More than 5 years	405,934
Total Purchase Obligations	$	960,305

Costs related to these purchase obligations include:

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2013		2012		2013		2012
Major equipment purchases	$	15,116	$	31,989	$	48,542	$	45,175
Firm transportation expense	31,017		15,822		59,542		30,867
Gas drilling obligations	25,904		28,517		54,768		58,093
Other	—		129		—		427
Total costs related to purchase obligations	$	72,037	$	76,457	$	162,852	$	134,562

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Accounts Receivable Securitization

6 Months Ended

Jun. 30, 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 June 30, 2013, there were letters of credit outstanding against the facility of $159,281. 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 Topics 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 commercial paper rates, plus a charge for administrative services paid to the financial institutions. Costs associated with the receivables facility totaled $440 and $913 for three and six months ended June 30, 2013, respectively. Costs associated with the receivables facility totaled $437 and $856 for three and six months ended June 30, 2012, 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 June 30, 2013 and December 31, 2012, eligible accounts receivable totaled $181,000 and $200,000, respectively. There was no subordinated retained interest at June 30, 2013 and at December 31, 2012. There were $40,719 borrowings under the Securitization Facility recorded on the Consolidated Balance Sheet as of June 30, 2013 and $37,846 at December 31, 2012. The accounts receivable securitization program increased $2,873in the six months ended June 30, 2013 and there was no change in the six months ended June 30, 2012. The increase is reflected in the Net Cash Provided by (Used in) Financing Activities in the Consolidated Statement of Cash Flows. In accordance with the facility agreement, the Company is able to receive proceeds based upon the eligible accounts receivable at the previous month end.

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Guarantor Subsidiaries Balance Sheet (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012	Jun. 30, 2012	Dec. 31, 2011
Current Assets:
Cash and Cash Equivalents	$ 71,938	$ 21,878	$ 200,207	$ 375,736
Accounts and Notes Receivable:
Trade	347,367	428,328
Notes Receivable, Related Parties, Current	350,977	318,387
Other Receivables	151,269	131,131
Accounts Receivable - Securitized	40,719	37,846
Inventories	227,994	247,766
Recoverable Income Taxes	1,930	0
Deferred Income Taxes	143,004	148,104
Restricted Cash and Cash Equivalents, Current	0	48,294
Prepaid Expenses	137,643	157,360
Total Current Assets	1,472,841	1,539,094
Property, Plant and Equipment:
Property, Plant and Equipment	16,194,251	15,545,204
Less-Accumulated Depreciation, Depletion and Amortization	5,770,506	5,354,237
Total Property, Plant and Equipment-Net	10,423,745	10,190,967
Other Assets:
Deferred Income Taxes	388,703	444,585
Restricted Cash and Cash Equivalents, Noncurrent	0	20,379
Investments in Unconsolidated Equity Affiliates	256,097	222,830
Notes, Loans and Financing Receivable, Net	1,512	25,977
Other	210,030	227,077
Total Other Assets	856,342	940,848
Total Assets	12,752,928	12,670,909	12,597,896
Current Liabilities:
Accounts Payable	461,415	507,982
Accounts Payable (Recoverable)- Related Parties	0	0
Short-Term Notes Payable		25,073
Current Portion Long-Term Debt	13,422	13,485
Short-Term Notes Payable	173,000	25,073
Secured Debt, Current	40,719	37,846
Accrued Income Taxes, Current	0	34,219
Other Accrued Liabilities	798,645	768,494
Total Current Liabilities	1,487,201	1,387,099
Long-Term Debt:	3,171,750	3,174,586
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	2,820,186	2,832,401
Pneumoconiosis	177,146	174,781
Mine Closing	459,392	446,727
Gas Well Closing	193,946	148,928
Workers' Compensation	155,518	155,648
Salary Retirement	109,691	218,004
Reclamation	50,051	47,965
Other	102,987	131,025
Total Deferred Credits and Other Liabilities	4,068,917	4,155,479
Total CONSOL Energy Inc. Stockholders' Equity	4,025,651	3,953,792
Noncontrolling Interest	(591)	(47)
TOTAL LIABILITIES AND EQUITY	12,752,928	12,670,909
Parent Issuer [Member]
Current Assets:
Cash and Cash Equivalents	45,267	17,491
Accounts and Notes Receivable:
Trade	0	0
Notes Receivable, Related Parties, Current	234	154
Other Receivables	4,449	6,335
Accounts Receivable - Securitized	0	0
Inventories	0	0
Recoverable Income Taxes	16,038
Deferred Income Taxes	169,905	174,176
Restricted Cash and Cash Equivalents, Current		0
Prepaid Expenses	12,795	29,589
Total Current Assets	248,688	227,745
Property, Plant and Equipment:
Property, Plant and Equipment	221,174	216,448
Less-Accumulated Depreciation, Depletion and Amortization	134,785	126,048
Total Property, Plant and Equipment-Net	86,389	90,400
Other Assets:
Deferred Income Taxes	820,406	884,310
Restricted Cash and Cash Equivalents, Noncurrent		0
Investments in Unconsolidated Equity Affiliates	10,128,714	9,917,050
Notes, Loans and Financing Receivable, Net	184	239
Other	112,660	118,938
Total Other Assets	11,061,964	10,920,537
Total Assets	11,397,041	11,238,682
Current Liabilities:
Accounts Payable	193,082	177,734
Accounts Payable (Recoverable)- Related Parties	3,847,815	3,599,216
Short-Term Notes Payable		25,073
Current Portion Long-Term Debt	1,562	1,554
Short-Term Notes Payable	0
Secured Debt, Current	0	0
Accrued Income Taxes, Current		20,488
Other Accrued Liabilities	140,353	135,407
Total Current Liabilities	4,182,812	3,959,472
Long-Term Debt:	3,005,012	3,005,515
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	109,691	218,004
Reclamation	0	0
Other	73,875	101,899
Total Deferred Credits and Other Liabilities	183,566	319,903
Total CONSOL Energy Inc. Stockholders' Equity	4,025,651	3,953,792
Noncontrolling Interest	0	0
TOTAL LIABILITIES AND EQUITY	11,397,041	11,238,682
CNX Gas Guarantor [Member]
Current Assets:
Cash and Cash Equivalents	26,851	3,352
Accounts and Notes Receivable:
Trade	62,013	58,126
Notes Receivable, Related Parties, Current	323,835	315,730
Other Receivables	133,895	214,748
Accounts Receivable - Securitized	0	0
Inventories	14,619	14,133
Recoverable Income Taxes	(14,108)
Deferred Income Taxes	(26,901)	(26,072)
Restricted Cash and Cash Equivalents, Current		0
Prepaid Expenses	86,893	86,186
Total Current Assets	607,097	666,203
Property, Plant and Equipment:
Property, Plant and Equipment	6,368,437	5,956,207
Less-Accumulated Depreciation, Depletion and Amortization	1,064,498	960,613
Total Property, Plant and Equipment-Net	5,303,939	4,995,594
Other Assets:
Deferred Income Taxes	(431,703)	(439,725)
Restricted Cash and Cash Equivalents, Noncurrent		0
Investments in Unconsolidated Equity Affiliates	170,589	143,876
Notes, Loans and Financing Receivable, Net	0	0
Other	47,888	65,935
Total Other Assets	(213,226)	(229,914)
Total Assets	5,697,810	5,431,883
Current Liabilities:
Accounts Payable	208,852	166,182
Accounts Payable (Recoverable)- Related Parties	65,771	23,981
Short-Term Notes Payable		0
Current Portion Long-Term Debt	5,972	5,953
Short-Term Notes Payable	224,800
Secured Debt, Current	0	0
Accrued Income Taxes, Current		13,731
Other Accrued Liabilities	64,908	57,074
Total Current Liabilities	570,303	266,921
Long-Term Debt:	43,897	46,081
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	0	0
Pneumoconiosis	0	0
Mine Closing	0	0
Gas Well Closing	115,802	80,097
Workers' Compensation	0	0
Salary Retirement	0	0
Reclamation	0	0
Other	11,703	24,518
Total Deferred Credits and Other Liabilities	127,505	104,615
Total CONSOL Energy Inc. Stockholders' Equity	4,956,696	5,014,313
Noncontrolling Interest	(591)	(47)
TOTAL LIABILITIES AND EQUITY	5,697,810	5,431,883
Other Guarantors Subsidiaries [Member]
Current Assets:
Cash and Cash Equivalents	122	175
Accounts and Notes Receivable:
Trade	0	0
Notes Receivable, Related Parties, Current	26,908	2,503
Other Receivables	8,436	33,289
Accounts Receivable - Securitized	0	0
Inventories	176,899	198,269
Recoverable Income Taxes	0
Deferred Income Taxes	0	0
Restricted Cash and Cash Equivalents, Current		48,294
Prepaid Expenses	36,494	40,215
Total Current Assets	248,859	322,745
Property, Plant and Equipment:
Property, Plant and Equipment	9,578,914	9,347,370
Less-Accumulated Depreciation, Depletion and Amortization	4,552,589	4,249,507
Total Property, Plant and Equipment-Net	5,026,325	5,097,863
Other Assets:
Deferred Income Taxes	0	0
Restricted Cash and Cash Equivalents, Noncurrent		20,379
Investments in Unconsolidated Equity Affiliates	764,618	769,058
Notes, Loans and Financing Receivable, Net	1,328	25,738
Other	39,568	32,016
Total Other Assets	805,514	847,191
Total Assets	6,080,698	6,267,799
Current Liabilities:
Accounts Payable	48,729	154,936
Accounts Payable (Recoverable)- Related Parties	(4,118,674)	(3,749,584)
Short-Term Notes Payable		0
Current Portion Long-Term Debt	5,081	5,222
Short-Term Notes Payable	0
Secured Debt, Current	0	0
Accrued Income Taxes, Current		0
Other Accrued Liabilities	582,911	566,485
Total Current Liabilities	(3,481,953)	(3,022,941)
Long-Term Debt:	121,252	121,523
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	2,820,186	2,832,401
Pneumoconiosis	177,146	174,781
Mine Closing	459,392	446,727
Gas Well Closing	78,144	68,831
Workers' Compensation	155,199	155,342
Salary Retirement	0	0
Reclamation	50,051	47,965
Other	17,409	4,608
Total Deferred Credits and Other Liabilities	3,757,527	3,730,655
Total CONSOL Energy Inc. Stockholders' Equity	5,683,872	5,438,562
Noncontrolling Interest	0	0
TOTAL LIABILITIES AND EQUITY	6,080,698	6,267,799
Non-Guarantors [Member]
Current Assets:
Cash and Cash Equivalents	(302)	860
Accounts and Notes Receivable:
Trade	285,354	370,202
Notes Receivable, Related Parties, Current	0	0
Other Receivables	4,489	5,159
Accounts Receivable - Securitized	40,719	37,846
Inventories	36,476	35,364
Recoverable Income Taxes	0
Deferred Income Taxes	0	0
Restricted Cash and Cash Equivalents, Current		0
Prepaid Expenses	1,461	1,370
Total Current Assets	368,197	450,801
Property, Plant and Equipment:
Property, Plant and Equipment	25,726	25,179
Less-Accumulated Depreciation, Depletion and Amortization	18,634	18,069
Total Property, Plant and Equipment-Net	7,092	7,110
Other Assets:
Deferred Income Taxes	0	0
Restricted Cash and Cash Equivalents, Noncurrent		0
Investments in Unconsolidated Equity Affiliates	0	0
Notes, Loans and Financing Receivable, Net	0	0
Other	9,914	10,188
Total Other Assets	9,914	10,188
Total Assets	385,203	468,099
Current Liabilities:
Accounts Payable	10,752	9,130
Accounts Payable (Recoverable)- Related Parties	153,288	254,787
Short-Term Notes Payable		0
Current Portion Long-Term Debt	807	756
Short-Term Notes Payable	0
Secured Debt, Current	40,719	37,846
Accrued Income Taxes, Current		0
Other Accrued Liabilities	10,473	9,528
Total Current Liabilities	216,039	312,047
Long-Term Debt:	1,589	1,467
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	319	306
Salary Retirement	0	0
Reclamation	0	0
Other	0	0
Total Deferred Credits and Other Liabilities	319	306
Total CONSOL Energy Inc. Stockholders' Equity	167,256	154,279
Noncontrolling Interest	0	0
TOTAL LIABILITIES AND EQUITY	385,203	468,099
Consolidation, Eliminations [Member]
Current Assets:
Cash and Cash Equivalents	0	0
Accounts and Notes Receivable:
Trade	0	0
Notes Receivable, Related Parties, Current	0	0
Other Receivables	0	(128,400)
Accounts Receivable - Securitized	0	0
Inventories	0	0
Recoverable Income Taxes	0
Deferred Income Taxes	0	0
Restricted Cash and Cash Equivalents, Current		0
Prepaid Expenses	0	0
Total Current Assets	0	(128,400)
Property, Plant and Equipment:
Property, Plant and Equipment	0	0
Less-Accumulated Depreciation, Depletion and Amortization	0	0
Total Property, Plant and Equipment-Net	0	0
Other Assets:
Deferred Income Taxes	0	0
Restricted Cash and Cash Equivalents, Noncurrent		0
Investments in Unconsolidated Equity Affiliates	(10,807,824)	(10,607,154)
Notes, Loans and Financing Receivable, Net	0	0
Other	0	0
Total Other Assets	(10,807,824)	(10,607,154)
Total Assets	(10,807,824)	(10,735,554)
Current Liabilities:
Accounts Payable	0	0
Accounts Payable (Recoverable)- Related Parties	51,800	(128,400)
Short-Term Notes Payable		0
Current Portion Long-Term Debt	0	0
Short-Term Notes Payable	(51,800)
Secured Debt, Current	0	0
Accrued Income Taxes, Current		0
Other Accrued Liabilities	0	0
Total Current Liabilities	0	(128,400)
Long-Term Debt:	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
Total Deferred Credits and Other Liabilities	0	0
Total CONSOL Energy Inc. Stockholders' Equity	(10,807,824)	(10,607,154)
Noncontrolling Interest	0	0
TOTAL LIABILITIES AND EQUITY	$ (10,807,824)	$ (10,735,554)

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Segment Information

6 Months Ended

Jun. 30, 2013

Segment Reporting Information [Line Items]

Segment Reporting Disclosure [Text Block]

SEGMENT INFORMATION:

CONSOL Energy has two principal business divisions: Coal and Gas. 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 six months ended June 30, 2013, the Thermal aggregated segment includes the following mines: Bailey, Blacksville #2, Enlow Fork, Fola Complex, Loveridge, McElroy, Miller Creek Complex, Robinson Run and Shoemaker. For the six months ended June 30, 2013, the Low Volatile Metallurgical aggregated segment includes the Buchanan Mine and Amonate Complex. For the six months ended June 30, 2013, the High Volatile Metallurgical aggregated segment includes: Bailey, Blacksville #2, Enlow Fork, Fola Complex, Loveridge and Robinson Run 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. 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 Coalbed Methane, Marcellus, 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. CONSOL Energy’s All Other segment includes terminal services, river and dock services, industrial supply services, general and administrative activities and other business activities. 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.

Annually, the preparation of our gas reserve estimates are completed in accordance with CONSOL Energy's prescribed internal control procedures, which include verification of input data into a gas reserve 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 2012 gas reserve results, which are reported in the Supplemental Gas Data year ended December 31, 2012 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 14 years of experience in the oil and gas industry.

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Derivative Instruments

6 Months Ended

Jun. 30, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments:

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 requires 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.  

                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 revenues from the underlying commodity. As of June 30, 2013, the total notional amount of the Company’s outstanding natural gas swap contracts was 197.7 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. During the next twelve months, $49,614 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 settlements 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 June 30, 2013 of CONSOL Energy's derivative instruments, which were all natural gas swaps and qualify as cash flow hedges, was an asset of $120,973 and a liability of $4,854. The total asset is comprised of $82,061 and $38,912 which were included in Prepaid Expense and Other Assets, respectively, on the Consolidated Balance Sheets. The total liability is comprised of $860 and $3,994 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 were as follows:

	For the Three Months Ended June 30,
	2013			2012
Natural Gas Price Swaps
Beginning Balance – Accumulated OCI	$	35,453		$	179,915
Gain/(Loss) recognized in Accumulated OCI	$	45,749		$	10,663
Less: Gain reclassified from Accumulated OCI into Outside Sales	$	9,528		$	57,847
Ending Balance – Accumulated OCI	$	71,674		$	132,731
Gain/(Loss) recognized in Outside Sales for ineffectiveness	$	(3,753	)	$	882

	For the Six Months Ended June 30,
	2013			2012
Natural Gas Price Swaps
Beginning Balance – Accumulated OCI	$	76,761		$	151,780
Gain/(Loss) recognized in Accumulated OCI	$	27,154		$	86,739
Less: Gain reclassified from Accumulated OCI into Outside Sales	$	32,241		$	105,788
Ending Balance – Accumulated OCI	$	71,674		$	132,731
Gain/(Loss) recognized in Outside Sales for ineffectiveness	$	(2,712	)	$	47

There were no amounts excluded from the assessment of hedge effectiveness in 2013 or 2012.

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Document and Entity Information	6 Months Ended
	Jun. 30, 2013	Jul. 18, 2013
Document Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2013
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q2
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		228,848,942

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Fair Value of Financial Instruments

6 Months Ended

Jun. 30, 2013

Notes to Financial Statements [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 June 30, 2013						Fair Value Measurements at December 31, 2012
Description	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Gas Cash Flow Hedges	$	—	$	116,119	$	—	$	—	$	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 amount reported in the balance sheets for restricted cash approximates its fair value due to the short-term maturity of these instruments.

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:

	June 30, 2013						December 31, 2012
	Carrying Amount			Fair Value			Carrying Amount			Fair Value
Cash and Cash Equivalents	$	71,938		$	71,938		$	21,878		$	21,878
Restricted Cash (a)	$	—		$	—		$	68,673		$	68,673
Short-Term Notes Payable	$	(173,000	)	$	(173,000	)	$	(25,073	)	$	(25,073	)
Borrowings Under Securitization Facility	$	(40,719	)	$	(40,719	)	$	(37,846	)	$	(37,846	)
Long-Term Debt	$	(3,128,585	)	$	(3,270,812	)	$	(3,129,017	)	$	(3,378,058	)

(a) The 2012 restricted cash balance includes $48,294 and $20,379 located in current assets and other assets of the Consolidated Balance Sheet, respectively.

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Financial Instruments Measured at Fair Value on a Recurring Basis (Details) (USD $) In Thousands, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2012
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	116,119	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

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The Effect of Derivative Instruments on the Consolidated Statement of Income (Details) (Price Swaps, Derivative in Cash Flow Hedging Relationship, Natural Gas, USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Jun. 30, 2013	Jun. 30, 2012	Jun. 30, 2013	Jun. 30, 2012	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012	Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	$ 71,674	$ 132,731	$ 71,674	$ 132,731	$ 76,761	$ 35,453	$ 151,780	$ 179,915
Amount of Gain (Loss) Recognized in OCI on Derivative	45,749	10,663	27,154	86,739
Outside Sales
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from Accumulated OCI into Income	9,528	57,847	32,241	105,788
Derivative Instruments, Gain (Loss) Recognized in Income, Net	$ (3,753)	$ 882	$ (2,712)	$ 47