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 March 31, 2012

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 April 18, 2012
Common stock, $0.01 par value	227,545,200

TABLE OF CONTENTS
		Page
PART I FINANCIAL INFORMATION
ITEM 1.	Condensed Financial Statements
	Consolidated Statements of Income for the three months ended March 31, 2012 and 2011	3
	Consolidated Statements of Comprehensive Income for the three months ended March 31, 2012 and 2011	4
	Consolidated Balance Sheets at March 31, 2012 and December 31, 2011	5
	Consolidated Statement of Stockholders’ Equity for the three months ended March 31, 2012	7
	Consolidated Statements of Cash Flows for the three months ended March 31, 2012 and 2011	8
	Notes to Unaudited Consolidated Financial Statements	9
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	35
ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	61
ITEM 4.	Controls and Procedures	63
PART II OTHER INFORMATION
ITEM 1.	Legal Proceedings	64
ITEM 6.	Exhibits	64

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
	March 31,
	2012		2011
Sales—Outside	$	1,311,471	$	1,385,478
Sales—Gas Royalty Interests	12,206		18,835
Sales—Purchased Gas	839		980
Freight—Outside	49,293		36,868
Other Income	52,961		23,216
Total Revenue and Other Income	1,426,770		1,465,377
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	904,041		813,709
Gas Royalty Interests Costs	10,249		16,807
Purchased Gas Costs	517		676
Freight Expense	49,293		36,679
Selling, General and Administrative Expenses	38,999		40,196
Depreciation, Depletion and Amortization	155,347		149,062
Interest Expense	58,120		66,482
Taxes Other Than Income	91,627		90,689
Total Costs	1,308,193		1,214,300
Earnings Before Income Taxes	118,577		251,077
Income Taxes	21,381		58,928
Net Income	$	97,196	$	192,149
Earnings Per Share:
Basic	$	0.43	$	0.85
Dilutive	$	0.42	$	0.84
Weighted Average Number of Common Shares Outstanding:
Basic	227,269,269		226,350,594
Dilutive	230,124,011		228,814,838
Dividends Paid Per Share	$	0.125	$	0.100

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
	March 31,
	2012			2011
Net Income	$	97,196		$	192,149
Other Comprehensive Income (Loss):
Treasury Rate Lock (Net of tax: $-, $12)	—			(20		)
Actuarially Determined Long-Term Liability Adjustments
Change in Prior Service Cost (Net of tax: ($30,295))	50,276			—
Amortization of Prior Service Cost (Net of tax: $4,552, $4,583)	(7,554		)	(7,365		)
Amortization of Net Loss (Net of tax: ($10,154), ($9,766))	16,851			15,692
Net Increase in the Value of Cash Flow Hedge (Net of tax: ($49,008), ($2,814))	76,076			4,371
Reclassification of Cash Flow Hedges from OCI to Earnings (Net of tax: $31,380, $12,615)	(47,941		)	(18,840		)
Other Comprehensive Income (Loss):	87,708			(6,162		)
Comprehensive Income	$	184,904		$	185,987

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

4

CONSOL ENERGY INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Dollars in thousands)

	(Unaudited)
	March 31, 2012		December 31, 2011
ASSETS
Current Assets:
Cash and Cash Equivalents	$	287,313	$	375,736
Accounts and Notes Receivable:
Trade	463,258		462,812
Notes Receivables	314,514		314,950
Other Receivables	126,931		105,708
Inventories	284,997		258,335
Deferred Income Taxes	128,904		141,083
Prepaid Expenses	260,818		239,353
Total Current Assets	1,866,735		1,897,977
Property, Plant and Equipment:
Property, Plant and Equipment	14,357,246		14,087,319
Less—Accumulated Depreciation, Depletion and Amortization	4,915,809		4,760,903
Total Property, Plant and Equipment—Net	9,441,437		9,326,416
Other Assets:
Deferred Income Taxes	467,753		507,724
Restricted Cash	22,158		22,148
Investment in Affiliates	200,221		182,036
Notes Receivable	300,382		300,492
Other	296,925		288,907
Total Other Assets	1,287,439		1,301,307
TOTAL ASSETS	$	12,595,611	$	12,525,700

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)
	March 31, 2012			December 31, 2011
LIABILITIES AND EQUITY
Current Liabilities:
Accounts Payable	$	471,921		$	522,003
Current Portion of Long-Term Debt	20,879			20,691
Accrued Income Taxes	50,313			75,633
Other Accrued Liabilities	856,858			770,070
Total Current Liabilities	1,399,971			1,388,397
Long-Term Debt:
Long-Term Debt	3,122,234			3,122,234
Capital Lease Obligations	54,484			55,189
Total Long-Term Debt	3,176,718			3,177,423
Deferred Credits and Other Liabilities:
Postretirement Benefits Other Than Pensions	2,976,181			3,059,671
Pneumoconiosis Benefits	174,559			173,553
Mine Closing	409,778			406,712
Gas Well Closing	125,557			124,051
Workers’ Compensation	150,377			151,034
Salary Retirement	242,727			269,069
Reclamation	36,148			39,969
Other	129,483			124,936
Total Deferred Credits and Other Liabilities	4,244,810			4,348,995
TOTAL LIABILITIES	8,821,499			8,914,815
Stockholders’ Equity:
Common Stock, $.01 Par Value; 500,000,000 Shares Authorized, 227,542,426 Issued and 227,507,671 Outstanding at March 31, 2012; 227,289,426 Issued and 227,056,212 Outstanding at December 31, 2011	2,275			2,273
Capital in Excess of Par Value	2,250,516			2,234,775
Preferred Stock, 15,000,000 shares authorized, None issued and outstanding	—			—
Retained Earnings	2,235,776			2,184,737
Accumulated Other Comprehensive Loss	(713,846		)	(801,554		)
Common Stock in Treasury, at Cost—34,755 Shares at March 31, 2012 and 233,214 Shares at December 31, 2011	(609		)	(9,346		)
Total Stockholders’ Equity	3,774,112			3,610,885
TOTAL LIABILITIES AND EQUITY	$	12,595,611		$	12,525,700

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 Stockholders’ Equity
Balance at December 31, 2011	$	2,273	$	2,234,775		$	2,184,737		$	(801,554	)	$	(9,346	)	$	3,610,885
(Unaudited)
Net Income	—		—			97,196			—			—			97,196
Other Comprehensive Income	—		—			—			87,708			—			87,708
Comprehensive Income	—		—			97,196			87,708			—			184,904
Issuance of Common Stock	2		52			—			—			—			54
Issuance of Treasury Stock	—		—			(17,770		)	—			8,737			(9,033		)
Tax Cost From Stock-Based Compensation	—		(563		)	—			—			—			(563		)
Amortization of Stock-Based Compensation Awards	—		16,252			—			—			—			16,252
Dividends ($0.125 per share)	—		—			(28,387		)	—			—			(28,387		)
Balance at March 31, 2012	$	2,275	$	2,250,516		$	2,235,776		$	(713,846	)	$	(609	)	$	3,774,112

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)

	Three Months Ended
	March 31,
	2012			2011
Operating Activities:
Net Income	$	97,196		$	192,149
Adjustments to Reconcile Net Income to Net Cash Provided By Operating Activities:
Depreciation, Depletion and Amortization	155,347			149,062
Stock-Based Compensation	16,252			13,446
Gain on Sale of Assets	(19,713		)	(323		)
Amortization of Mineral Leases	1,886			2,468
Deferred Income Taxes	(2,265		)	23,099
Equity in Earnings of Affiliates	(7,935		)	(5,481		)
Changes in Operating Assets:
Accounts and Notes Receivable	(17,990		)	(26,901		)
Inventories	(26,662		)	(29,435		)
Prepaid Expenses	6,231			7,585
Changes in Other Assets	10,837			9,449
Changes in Operating Liabilities:
Accounts Payable	(39,312		)	7,279
Other Operating Liabilities	62,233			75,863
Changes in Other Liabilities	(8,928		)	13,521
Other	2,309			3,463
Net Cash Provided by Operating Activities	229,486			435,244
Investing Activities:
Capital Expenditures	(306,446		)	(254,778		)
Proceeds from Sales of Assets	28,611			300
Distributions, net of (Investments In), From Equity Affiliates	(10,250		)	1,470
Net Cash Used in Investing Activities	(288,085		)	(253,008		)
Financing Activities:
Payments on Short-Term Borrowings	—			(113,500		)
Payments on Miscellaneous Borrowings	(2,330		)	(3,698		)
Payments on Securitization Facility	—			(200,000		)
Proceeds from Issuance of Long-Term Notes	—			250,000
Tax Benefit from Stock-Based Compensation	750			3,306
Dividends Paid	(28,387		)	(22,625		)
Issuance of Common Stock	54			—
Issuance of Treasury Stock	109			3,699
Debt Issuance and Financing Fees	(20		)	(4,517		)
Net Cash Used In Financing Activities	(29,824		)	(87,335		)
Net (Decrease) Increase in Cash and Cash Equivalents	(88,423		)	94,901
Cash and Cash Equivalents at Beginning of Period	375,736			32,794
Cash and Cash Equivalents at End of Period	$	287,313		$	127,695

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 months ended March 31, 2012 are not necessarily indicative of the results that may be expected for future periods.

The balance sheet at December 31, 2011 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, 2011 included in CONSOL Energy Inc.'s Form 10-K.

Basic earnings per share are computed by dividing net income by the weighted average shares outstanding during the reporting period. Dilutive earnings per share are computed similarly to basic earnings per share except that the weighted average shares outstanding are increased to include additional shares from the assumed exercise of stock options and performance stock options and the assumed vesting of restricted and performance share units, if dilutive. The number of additional shares is calculated by assuming that outstanding stock options and performance share options were exercised, that outstanding restricted 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 March 31,
	2012	2011
Anti-Dilutive Options	1,574,922	1,157,937
Anti-Dilutive Restricted Stock Units	12,203	—
Anti-Dilutive Performance Share Options	100,350	—
	1,687,475	1,157,937

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

	Three Months Ended March 31,
	2012	2011
Options	11,716	180,396
Restricted Stock Units	458,018	341,141
Performance Share Units	229,730	40,752
	699,464	562,289

The weighted average exercise price per share of the options exercised during the three months ended March 31, 2012 and 2011 was $13.81 and $20.51, respectively.

9

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

	Three Months Ended March 31,
	2012		2011
Net income attributable to CONSOL Energy Inc. shareholders	$	97,196	$	192,149
Weighted average shares of common stock outstanding:
Basic	227,269,269		226,350,594
Effect of stock-based compensation awards	2,854,742		2,464,244
Dilutive	230,124,011		228,814,838
Earnings per share:
Basic	$	0.43	$	0.85
Dilutive	$	0.42	$	0.84

NOTE 2—ACQUISITIONS AND DISPOSITIONS:

On February 9, 2012, CONSOL Energy completed the disposition of its Burning Star No. 4 property, 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.

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 its nearly 200 thousand net Utica Shale acres in Ohio. Cash proceeds related to this transaction were $54,254, which are 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 net gain on the transaction was $53,095 and was recognized in the three months ended December 31, 2011.

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 the three months ended December 31, 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. The net loss on the transaction was $64,142 and was recognized in the three months ended September 30, 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 will remain suspended until average natural gas prices are above $4.00/MMBtu for three consecutive months. Restrictions also include a $400,000 annual maximum on Noble's carried cost obligation.

The following unaudited pro forma combined financial statements are based on CONSOL Energy's historical consolidated financial statements and adjusted to give effect to the September 30, 2011 sale of a 50% interest in certain Marcellus Shale assets. The unaudited pro forma results for the period presented below are prepared as if the transaction occurred as of January 1, 2011 and do not include material, non-recurring charges.

10

	Three Months Ended
	March 31,
	2011
Total Revenue and Other Income	$	1,455,126
Earnings Before Income Taxes	$	247,418
Net Income	$	189,330
Basic Earnings Per Share	$	0.84
Dilutive Earnings Per Share	$	0.83

The pro forma results are not necessarily indicative of what actually would have occurred if the transaction had been completed as of January 1, 2011, nor are they necessarily indicative of future consolidated results.

On September 30 2011, CNX Gas Company and Noble formed CONE Gathering LLC (CONE), a joint venture established to develop and operate each company's gas gathering system needs in the Marcellus Shale play. CNX Gas Company's 50% ownership interest in CONE is accounted for under the equity method of accounting. CNX Gas contributed its existing Marcellus Shale gathering infrastructure which had a net book value of $119,740 and Noble contributed cash of approximately $67,545. CONE made a cash distribution to CNX Gas in the amount of $67,545. The cash proceeds were recognized as cash inflows of $59,870 and $7,675 in Distributions from Equity Affiliates and Proceeds from the Sale of Assets, respectively, in CONSOL Energy's 2011 third quarter results. The gain on the transaction was $7,161 and was recognized in the three months ended September 30, 2011.

On September 21, 2011 CONSOL Energy entered into an agreement with Antero Resources Appalachian Corp. (Antero), pursuant to which CONSOL Energy assigned to Antero overriding royalty interests (ORRI) of approximately 7% in approximately 116 thousand net acres of Marcellus Shale located in nine counties in southwestern Pennsylvania and north central West Virginia, in exchange for $193,000. The net gain on the transaction was $41,057 was recognized in the three months ended September 30, 2011.

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

Components of net periodic costs for the three months ended March 31 are as follows:

	Pension Benefits						Other Postretirement Benefits
	Three Months Ended						Three Months Ended
	March 31,						March 31,
	2012			2011			2012			2011
Service cost	$	5,153		$	4,289		$	5,200		$	3,977
Interest cost	9,378			9,078			35,527			42,204
Expected return on plan assets	(11,627		)	(9,630		)	—			—
Amortization of prior service cost (credits)	(408		)	(167		)	(11,599		)	(11,599		)
Recognized net actuarial loss	12,263			9,146			20,345			22,364
Net periodic benefit cost	$	14,759		$	12,716		$	49,473		$	56,946

For the three months ended March 31, 2012, $29,746 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 $110,000 to the pension trust in 2012.

On March 31, 2012, the salaried OPEB plan was remeasured to reflect an announced plan amendment that will reduce medical and prescription drug benefits as of January 1, 2014. The plan amendment calls for a fixed annual retiree medical contribution into a Health Reimbursement Account for eligible employees. The amount of contribution is dependent on several

11

factors. The money in the account can be used to help pay for a commercial medical plan, Medicare Part B or Part D premiums, and other qualified expenses. Employees who work or worked in corporate or operational support positions at retirement and who are age 50 or above at December 31, 2013 will receive the revised benefit in lieu of the current retiree medical and prescription drug benefits. Employees who work or worked in corporate or operational support positions who are under age 50 at December 31, 2013 will receive no medical or prescription drug benefits. The remeasurement reflects the reduction in benefits and the change in discount rate to 4.57% at March 31, 2012 from 4.51% at December 31, 2011. The remeasurement resulted in an $80,570 reduction in the OPEB liability with a corresponding adjustment of $50,275 in other comprehensive income, net of $30,295 in deferred taxes. The change was made to align our corporate and operational support compensation package with our peer group. OPEB expense is expected to be $9,425 lower than the $148,419 that was expected to be recognized over the remaining nine months of 2012.

CONSOL Energy does not expect to contribute to the other postemployment benefit plan in 2012. We intend to pay benefit claims as they become due. For the three months ended March 31, 2012, $42,378 of other postemployment benefits have been paid.

For the three months ended March 31, 2011, CONSOL Energy received proceeds of $7,781 under the Patient Protection and Affordable Care Act (PPACA) related to reimbursement from the Federal government for retiree health spending. This amount is included as a reduction of benefit and other payments in the reconciliation of changes in benefit obligation. There is no guarantee that additional proceeds will be received under this program.

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

Components of net periodic costs (benefits) for the three months ended March 31 are as follows:

	CWP						Workers’ Compensation
	Three Months Ended						Three Months Ended
	March 31,						March 31,
	2012			2011			2012			2011
Service cost	$	1,178		$	1,155		$	3,634		$	4,468
Interest cost	1,991			2,333			1,778			2,060
Amortization of actuarial gain	(4,934		)	(5,478		)	(986		)	(977		)
State administrative fees and insurance bond premiums	—			—			1,910			1,222
Legal and administrative costs	750			750			648			718
Net periodic (benefit) cost	$	(1,015	)	$	(1,240	)	$	6,984		$	7,491

CONSOL Energy does not expect to contribute to the CWP plan in 2012. We intend to pay benefit claims as they become due. For the three months ended March 31, 2012, $2,850 of CWP benefit claims have been paid.

CONSOL Energy does not expect to contribute to the workers’ compensation plan in 2012. We intend to pay benefit claims as they become due. For the three months ended March 31, 2012, $9,050 of workers’ compensation benefits, state administrative fees and surety bond premiums have been paid.

12

NOTE 5—INCOME TAXES:

The following is a reconciliation, stated in dollars and as a percentage of pretax income, of the U.S. statutory federal income tax rate to CONSOL Energy’s effective tax rate:

	For the Three Months Ended March 31,
	2012					2011
	Amount			Percent		Amount			Percent
Statutory U.S. federal income tax rate	$	41,502		35.0	%	$	87,877		35.0	%
Excess tax depletion	(26,514		)	(22.4	)	(39,169		)	(15.6	)
Effect of domestic production activities	—			—		(1,916		)	(0.8	)
Net effect of state income taxes	3,510			3.0		8,818			3.5
Other	2,883			2.4		3,318			1.4
Income Tax Expense / Effective Rate	$	21,381		18.0	%	$	58,928		23.5	%

The effective rates for the three months ended March 31, 2012 and 2011 were calculated using the annual effective rate projection on recurring earnings and include tax liabilities related to certain discrete transactions which are described below.

During the three months ended March 31, 2012, CONSOL Energy reached an agreement with the Internal Revenue Service Appeals Division on its Extraterritorial Income Exclusion refund claim for tax years 2004-2005. As a result of the agreement, the Company reflected $983 as a discrete reduction to income tax expense. The discrete transaction was reflected in the Other line of the rate reconciliation.

The total amounts of uncertain tax positions at March 31, 2012 and 2011 were $25,570 and $65,510, respectively. If these uncertain tax positions were recognized, approximately $3,891 and $16,802, respectively, would affect CONSOL Energy’s effective tax rate. There were no additions to the liability for unrecognized tax benefits during the three months ended March 31, 2012 and 2011.

CONSOL Energy recognizes interest accrued related to uncertain tax positions in its interest expense. As of March 31, 2012 and 2011, the Company reported an accrued interest liability relating to uncertain tax positions of $5,741 and $11,895, respectively. The accrued interest liability includes $368 of interest income and $1,121 of interest expense that is reflected in the Company’s Consolidated Statements of Income for the three months ended March 31, 2012 and 2011, respectively.

CONSOL Energy recognizes penalties accrued related to uncertain tax positions in its income tax expense. As of March 31, 2012 and 2011, CONSOL Energy had no accrued liability for tax penalties.

CONSOL Energy and its subsidiaries file federal income tax returns with the United States and returns within various states and Canadian jurisdictions. With few exceptions, the Company is no longer subject to United States federal, state, local, or non-U.S. income tax determinations by tax authorities for the years before 2008.

NOTE 6—INVENTORIES:

Inventory components consist of the following:

	March 31, 2012		December 31, 2011
Coal	$	125,308	$	105,378
Merchandise for resale	43,130		43,639
Supplies	116,559		109,318
Total Inventories	$	284,997	$	258,335

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 $23,093 and $22,406 at March 31, 2012 and December 31, 2011, respectively.

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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 March 31, 2012, there were letters of credit outstanding against the facility of $160,779. 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. 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 $419 and $724 for the three months ended March 31, 2012 and 2011, respectively. These costs have been recorded as financing fees which are included in Cost of Goods Sold and Other Operating Charges in the Consolidated Statements of Income. No servicing asset or liability has been recorded. The receivables facility expires in March 2017 with the underlying liquidity agreement renewing annually each March.

At March 31, 2012 and December 31, 2011, eligible accounts receivable totaled $200,000 and $192,700, respectively. There was subordinated retained interest of $39,221 at March 31, 2012 and $192,700 at December 31, 2011. There were no borrowings under the Securitization Facility recorded on the Consolidated Balance Sheet as of March 31, 2012 and December 31, 2011. 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:

	March 31, 2012		December 31, 2011
Coal & Other Plant and Equipment	$	5,301,715	$	5,160,759
Proven Gas Properties	1,542,838		1,542,837
Coal Properties and Surface Lands	1,352,159		1,340,757
Intangible Drilling Cost	1,344,207		1,277,678
Unproven Gas Properties	1,269,083		1,258,027
Gas Gathering Equipment	970,552		963,494
Airshafts	666,334		659,736
Leased Coal Lands	541,577		540,817
Mine Development	474,859		457,179
Gas Wells and Related Equipment	410,245		408,814
Coal Advance Mining Royalties	396,682		393,340
Other Gas Assets	80,459		79,816
Gas Advance Royalties	6,536		4,065
Total Property Plant and Equipment	14,357,246		14,087,319
Less: Accumulated DD&A	4,915,809		4,760,903
Total Net PP&E	$	9,441,437	$	9,326,416

Industry Participation Agreements

As of March 31, 2012, CONSOL Energy had entered into two significant industry participation agreements (referred to as "joint ventures" or "JVs") that provided drilling and completion carries for our retained interests. The following table provides information about our industry participation agreements as of March 31, 2012:

Shale Play	Industry Participation Agreement Partner	Industry Participation Agreement Date	Total Drilling Carries		Drilling Carries Billed to Partner		Drilling Carries Remaining
Marcellus	Noble Energy, Inc.	September 30, 2011	$	2,100,000	$	10,204	$	2,089,796
Utica	Hess Ohio Developments, LLC	October 21, 2011	$	534,000	$	3,348	$	530,652

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 (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 5.84 to 1.00 at March 31, 2012. The facility includes a maximum leverage ratio covenant of not more than 4.75 to 1.00, measured quarterly through March 31, 2013, and no more than 4.50 to 1.00 thereafter. The leverage ratio was 2.10 to 1.00 at March 31, 2012. 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 0.07 to 1.00 at March 31, 2012. 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 March 31, 2012, the $1,500,000 facility had no borrowings outstanding and $101,013 of letters of credit outstanding, leaving $1,398,987 of capacity available for borrowings and the issuance of letters of credit. The facility had no borrowings outstanding at December 31, 2011.

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

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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 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 the CONE Gathering Company are unrestricted. The facility includes a maximum leverage ratio covenant of not more than 3.50 to 1.00, measured quarterly. The leverage ratio was 0.00 to 1.00 at March 31, 2012. The facility also includes a minimum interest coverage ratio covenant of no less than 3.00 to 1.00, measured quarterly. This ratio was 35.79 to 1.00 at March 31, 2012. At March 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 facility had no borrowings outstanding at December 31, 2011.

NOTE 10—LONG-TERM DEBT:

	March 31, 2012		December 31, 2011
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
Baltimore Port Facility revenue bonds in series due September 2025 at 5.75%	102,865		102,865
Advance royalty commitments (6.73% weighted average interest rate for March 31, 2012 and December 31, 2011, respectively)	31,053		31,053
Other long-term note maturing in 2031	75		75
	3,133,993		3,133,993
Less amounts due in one year	11,759		11,759
Long-Term Debt	$	3,122,234	$	3,122,234

Accrued interest related to Long-Term Debt of $113,891 and $63,577 was included in Other Accrued Liabilities in the Consolidated Balance Sheets at March 31, 2012 and December 31, 2011, 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 amount 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 $1,562,000.

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

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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. It is likely that the AOC will be executed in the second quarter of 2012. If the AOC is signed by April 30, 2012 the EPA will grant 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%. CONSOL Energy has established an initial accrual based on its percentage share of the costs at the high end of the range. 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 United States Environmental Protection Agency (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. 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. Also, in September 2008, the EPA notified CONSOL Energy and sixty other PRPs that there were additional areas of potential contamination allegedly related to the Ward Transformer Site. Current estimates of the cost or potential range of cost for this area are not yet available. CONSOL Energy recognized no expense in Cost of Goods Sold and Other charges in the three months ended March 31, 2012 and 2011, respectively. As of March 31, 2012, 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 $4,477. Accordingly, the liability reflected in Other Accrued Liabilities was reduced by these settled claims. The remaining net liability at March 31, 2012 is $3,483.

Asbestos-Related Litigation: One of our subsidiaries, Fairmont Supply Company (Fairmont), which distributes industrial supplies, currently is named as a defendant in approximately 7,300 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). On February 16, 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 has appealed the DEP's findings to the Pennsylvania Environmental Hearing Board (PEHB), which will consider the case de novo, meaning without regard to the DEP's decision, as to any finding of causation of damage and/or the amount of damages. Either party may appeal the decision of the PEHB to the Pennsylvania Commonwealth Court, and then, as may be allowed, to the Pennsylvania Supreme Court. A hearing on the merits of the case will not occur until sometime in the spring or summer of 2013. As to the underlying claim, CONSOL Energy believes it is not responsible for the damage to the dam and that numerous grounds exist upon which to attack the propriety of the claims. If CONSOL Energy is ultimately found to be liable for damages to the dam, we believe the range of loss would be between $9,000 and $30,000. There have been settlement discussions and we have established an accrual to cover our estimated settlement 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.

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C. L. Ritter: On March 1, 2011, the Company was served with a complaint instituted by C. L. Ritter Lumber Company Incorporated against Consolidation Coal Company (CCC), Island Creek Coal Company, (ICCC), CNX Gas Company LLC, subsidiaries of CONSOL Energy Inc., as well as CONSOL Energy itself in the Circuit Court of Buchanan County, Virginia, seeking damages and injunctive relief in connection with the deposit of untreated water from mining activities at CCC's Buchanan Mine into nearby void spaces at one of the mines of ICCC. The suit alleges damages of between $34,000 and $430,000 for alleged damage to coal and coalbed methane, as well as breach of contract damages. We have removed the case to federal court and filed a motion to dismiss, largely predicated on the statute of limitations bar. The trial judge ruled that the issue of the applicability of the statute of limitations bar can only be addressed after discovery. There have been settlement discussions and we have established an accrual to cover our estimated settlement 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 U.S. District Court in Abingdon, Virginia styled Hale v. CNX Gas Company LLC et. al. The lawsuit alleges that the plaintiff class consists of oil and gas owners, that the Virginia Supreme Court has decided that coalbed methane (CBM) belongs to the owner of the oil and gas estate, that the Virginia Gas and Oil Act of 1990 unconstitutionally allows force pooling of CBM, that the Act unconstitutionally provides only a 1/8 royalty to CBM owners for gas produced under the force pooling orders, and that the Company only relied upon control of the coal estate in force pooling the CBM notwithstanding the Virginia Supreme Court decision holding that if only the coal estate is controlled, the CBM is not thereby controlled. 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 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, and that CNX Gas need not distribute the net proceeds to class members. The Magistrate Judge recommended against the dismissal of certain other claims, none of which are believed to have any significance. The District Judge affirmed the Magistrate Judge's Recommendations in their entirety. The plaintiffs and CNX Gas have agreed to stay this litigation. CONSOL Energy believes that the case is without merit 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 Federal court in Virginia styled Addison v. CNX Gas Company LLC. The case involves two primary claims: (i) the plaintiff and similarly situated CNX Gas lessors identified as conflicting claimants during the force pooling process before the Virginia Gas and Oil Board are the owners of the CBM and, accordingly, the owners of the escrowed royalty payments being held by the Commonwealth of Virginia; and (ii) 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. Plaintiffs seek a declaratory judgment regarding ownership and compensatory and punitive damages for breach of contract; conversion; negligence (voluntary undertaking), for force pooling coal owners after the Ratliff decision declared coal owners did not own the CBM; negligent breach of duties as an operator; breach of fiduciary duties; and unjust enrichment. We filed a Motion to Dismiss in this case, and the Magistrate Judge recommended dismissing some claims and allowing others to proceed. The District Judge affirmed the Magistrate Judge's Recommendations in their entirety. The plaintiffs and CNX Gas Company have agreed to stay this litigation. CONSOL Energy believes that the case is without merit 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.

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

South Carolina Gas & Electric Company Arbitration: South Carolina Electric & Gas Company (SCE&G), a utility, has demanded arbitration, seeking $36,000 in damages against CONSOL of Kentucky and CONSOL Energy Sales Company, both wholly owned subsidiaries of CONSOL Energy. SCE&G claims it suffered 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 which SCE&G had agreed could be made up in 2009.  A hearing on the claims is scheduled for April 30, 2012. The named CONSOL Energy defendants deny all liability and intend to vigorously defend the action filed against them. For that reason, we have not accrued a liability for this claim. If liability is ultimately imposed on the named CONSOL Energy defendants, we believe the range of loss would be between $17,000 and $29,000.

CNX Gas Shareholders Litigation: CONSOL Energy has been named as a defendant in five putative class actions brought by alleged shareholders of CNX Gas challenging the tender offer by CONSOL Energy to acquire all of the shares of

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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 three cases filed in the Delaware Chancery Court have been consolidated under the caption In Re CNX Gas Shareholders Litigation (C.A. No. 5377-VCL).  All five 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. The lawsuit will likely go to trial, possibly in 2013. CONSOL Energy believes that these actions are without merit and intends to defend them vigorously. For that reason, we have not accrued a liability for this claim; however, if liability is ultimately imposed, based on the expert reports that have been exchanged by the parties, we believe the range of loss could be up to $221,000.

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 which were instituted by four individuals against Consolidation Coal Company (CCC), Island Creek Coal Company, (ICCC), CNX Gas Company LLC, subsidiaries of CONSOL Energy, as well as CONSOL Energy itself in the Circuit Court of Russell County, Virginia, seeking damages and injunctive relief in connection with the deposit of untreated water from mining activities at CCC's Buchanan Mine into nearby void spaces at some of the mines of ICCC. The suits each allege damages of between $25,750 and $119,500 for alleged damage to coal and coalbed methane, as well as breach of contract and assumpsit damages. We have removed the cases to federal court and filed a motion to dismiss, largely predicated on the statute of limitations bar. Three similar lawsuits were filed recently, one in federal court and two in the Circuit Court of Buchanan County, Virginia, by other plaintiffs that collectively allege damages of between $100,000 and $622,000. One of the three suits which claimed damages of $22,000 was dismissed in federal court and has been appealed. Another which claimed damages of $312,000 was settled for an amount immaterial to the overall financial position of CONSOL Energy. The Company intends to file a motion to dismiss the remaining case. CCC believes that it had, and continues to have, the right to store water in these void areas. CCC and the other named CONSOL Energy defendants deny all liability and intend to vigorously defend the actions filed against them in connection with the removal and deposit of water from the Buchanan Mine. Consequently, we have not recognized any liability related to these actions.

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. 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 briefing will take place before a decision is rendered. CNX Gas Company and CONSOL Energy believe this lawsuit to be without merit and intend to vigorously defend it. Consequently, we

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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, 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 they farmed out the development of the lease to Dominion, in exchange for an overriding royalty. Dominion 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's 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 (ii) the subsequent merger of the subsidiary into CNX Gas Company was an assignment that required its consent under the lease. Rowland alleges that the failure to obtain the required consent constitutes a breach of the lease and it seeks damages and a forfeiture of the lease. CONSOL Energy and CNX Gas Company have filed a motion to dismiss the complaint, arguing among other things, that Dominion's sale of the indirect subsidiary was not a change in control; that even if the sale constituted a change in control, the purchase agreement between Dominion and CONSOL Energy did not give effect to the transfer so the transfer never occurred; that the mergers did not require consent; and that Rowland did not provide timely notice of breach of the lease in accordance with its terms. Rowland is amending its complaint to include allegations that CONSOL Energy and Dominion Resources are liable for their subsidiaries' actions. We will file a motion to dismiss in response. 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. 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. 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. The trial court has dismissed this case. The dismissal is being appealed.

At March 31, 2012, 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.

20

	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	$	194,566	$	130,826	$	63,740	$	—	$	—
Environmental	56,994		35,046		21,948		—		—
Other	80,508		43,561		36,947		—		—
Total Letters of Credit	332,068		209,433		122,635		—		—
Surety Bonds:
Employee-Related	204,895		179,515		25,380		—		—
Environmental	447,858		436,545		11,313		—		—
Other	27,729		27,663		65		—		1
Total Surety Bonds	680,482		643,723		36,758		—		1
Guarantees:
Coal	24,802		16,501		3,301		1,000		4,000
Gas	123,418		72,811		19,985		—		30,622
Other	456,389		83,388		137,314		87,975		147,712
Total Guarantees	604,609		172,700		160,600		88,975		182,334
Total Commitments	$	1,617,159	$	1,025,856	$	319,993	$	88,975	$	182,335

Employee-related financial guarantees have primarily been provided to support the United Mine Workers’ of America’s 1992 Benefit Plan and various state 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 March 31, 2012, the purchase obligations for each of the next five years and beyond were as follows:

Obligations Due	Amount
Less than 1 year	$	563,134
1 - 3 years	403,906
3 - 5 years	498,271
More than 5 years	1,639,535
Total Purchase Obligations	$	3,104,846

Costs related to these purchase obligations include:

	Three Months Ended
	March 31,
	2012		2011
Major equipment purchases	$	13,166	$	7,655
Firm transportation expense	15,045		12,818
Gas drilling obligations	29,576		25,818
Other	298		101
Total costs related to purchase obligations	$	58,085	$	46,392

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NOTE 12—DERIVATIVE INSTRUMENTS:

CONSOL Energy enters into financial derivative instruments to manage our exposure to commodity price volatility. We measure each derivative instrument at fair value and record it on the balance sheet as either an asset or liability. 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 fair value of the derivative are reported in Other Comprehensive Income or Loss (OCI) and reclassified into earnings 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.

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 March 31, 2012, the total notional amount of the Company’s outstanding natural gas swap contracts was 160.0 billion cubic feet. These swap contracts are forecasted to settle through December 31, 2015 and meet the criteria for cash flow hedge accounting. During the next twelve months, $110,024 of unrealized gain is expected to be reclassified from Other Comprehensive Income and into earnings, as a result of the settlement of cash flow hedges. No gains or losses have been reclassified into earnings as a result of the discontinuance of cash flow hedges.

The fair value at March 31, 2012 of CONSOL Energy's derivative instruments, which were all natural gas swaps and qualify as cash flow hedges, was an asset of $297,708 and a liability of $1,505. The total asset is comprised of $181,072 and $116,636 which were included in Prepaid Expense and Other Assets, respectively, on the Consolidated Balance Sheets. The total liability is included in Other Liabilities on the Consolidated Balance Sheets.

The fair value at December 31, 2011 of CONSOL Energy's derivative instruments, which were all natural gas swaps and qualify as cash flow hedges, was an asset of $251,277. The total asset is comprised of $153,376 and $97,901 which were included in Prepaid Expense and Other Assets, 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:

	Three Months Ended March 31,
	2012			2011
Natural Gas Price Swaps
Gain recognized in Accumulated OCI	$	76,076		$	4,371
Gain reclassified from Accumulated OCI into Outside Sales	$	47,941		$	18,840
Loss recognized in Outside Sales for ineffectiveness	$	(835	)	$	(108	)

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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 March 31, 2012						Fair Value Measurements at December 31, 2011
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	$	—	$	296,203	$	—	$	—	$	251,277	$	—

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.

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:

	March 31, 2012						December 31, 2011
	Carrying Amount			Fair Value			Carrying Amount			Fair Value
Cash and cash equivalents	$	287,313		$	287,313		$	375,736		$	375,736
Restricted cash	$	22,158		$	22,158		$	22,148		$	22,148
Long-term debt	$	(3,133,993	)	$	(3,270,880	)	$	(3,133,993	)	$	(3,422,452	)

23

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 steam 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 three months ended March 31, 2012, 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 three months ended March 31, 2012, the Low Volatile Metallurgical aggregated segment includes the Buchanan Mine and Amonate Complex. For the three months ended March 31, 2012, 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.

24

Industry segment results for the three months ended March 31, 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	$	812,053	$	172,740	$	60,568	$	8,955		$	1,054,316	$	99,535	$	23,791	$	34,373		$	2,504		$	160,203	$	96,952	$	—		$	1,311,471	(A)
Sales—purchased gas	—		—		—		—			—		—		—		—			839			839		—		—			839
Sales—gas royalty interests	—		—		—		—			—		—		—		—			12,206			12,206		—		—			12,206
Freight—outside	—		—		—		49,293			49,293		—		—		—			—			—		—		—			49,293
Intersegment transfers	—		—		—		—			—		—		—		—			466			466		37,209		(37,675		)	—
Total Sales and Freight	$	812,053	$	172,740	$	60,568	$	58,248		$	1,103,609	$	99,535	$	23,791	$	34,373		$	16,015		$	173,714	$	134,161	$	(37,675	)	$	1,373,809
Earnings (Loss) Before Income Taxes	$	128,855	$	79,361	$	15,611	$	(61,357	)	$	162,470	$	36,390	$	3,251	$	(3,722	)	$	(23,419	)	$	12,500	$	4,083	$	(60,476	)	$	118,577	(B)
Segment assets										$	5,360,577											$	6,110,585	$	358,746	$	765,703		$	12,595,611	(C)
Depreciation, depletion and amortization										$	100,762											$	48,803	$	5,782	$	—		$	155,347
Capital expenditures										$	194,429											$	98,455	$	13,562	$	—		$	306,446

(A) Included in the Coal segment are sales of $144,155 to First Energy and $138,341 to Xcoal Energy & Resources each comprising over 10% of sales.

(B) Includes equity in earnings of unconsolidated affiliates of $4,807, $1,944 and $1,184 for Coal, Gas and All Other, respectively.

(C) Includes investments in unconsolidated equity affiliates of $39,373, $108,858 and $51,990 for Coal, Gas and All Other, respectively.

25

Industry segment results for the three months ended March 31, 2011 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	$	801,952	$	236,895	$	78,233	$	13,364		$	1,130,444	$	113,774	$	21,042	$	38,745		$	2,648		$	176,209	$	78,825		$	—		$	1,385,478
Sales—purchased gas	—		—		—		—			—		—		—		—			980			980		—			—			980
Sales—gas royalty interests	—		—		—		—			—		—		—		—			18,835			18,835		—			—			18,835
Freight—outside	—		—		—		36,868			36,868		—		—		—			—			—		—			—			36,868
Intersegment transfers	—		—		—		—			—		—		—		—			993			993		53,396			(54,389		)	—
Total Sales and Freight	$	801,952	$	236,895	$	78,233	$	50,232		$	1,167,312	$	113,774	$	21,042	$	38,745		$	23,456		$	197,017	$	132,221		$	(54,389	)	$	1,442,161
Earnings (Loss) Before Income Taxes	$	194,044	$	142,594	$	40,893	$	(78,839	)	$	298,692	$	50,003	$	8,503	$	(2,750	)	$	(31,580	)	$	24,176	$	(1,849	)	$	(69,942	)	$	251,077	(D)
Segment assets										$	5,092,682											$	5,966,395	$	341,613		$	823,051		$	12,223,741	(E)
Depreciation, depletion and amortization										$	95,081											$	49,664	$	4,317		$	—		$	149,062
Capital expenditures										$	100,530											$	150,638	$	3,610		$	—		$	254,778

(D) Includes equity in earnings of unconsolidated affiliates of $4,462, $484 and $535 for Coal, Gas and All Other, respectively.

(E)    Includes investments in unconsolidated equity affiliates of $24,455, $24,053 and $49,012 for Coal, Gas and All Other, respectively.

26

Reconciliation of Segment Information to Consolidated Amounts:

Earnings Before Income Taxes:

	For the Three Months Ended March 31,
	2012			2011
Segment Earnings Before Income Taxes for total reportable business segments	$	174,970		$	322,868
Segment Earnings Before Income Taxes for all other businesses	4,083			(1,849		)
Interest income (expense), net and other non-operating activity (F)	(60,042		)	(69,286		)
Evaluation fees for non-core asset dispositions (F)	(434		)	(656		)
Earnings Before Income Taxes	$	118,577		$	251,077

Total Assets:	March, 31
	2012		2011
Segment assets for total reportable business segments	$	11,471,162	$	11,059,077
Segment assets for all other businesses	358,746		341,613
Items excluded from segment assets:
Cash and other investments (F)	121,807		126,613
Recoverable income taxes	—		5,031
Deferred tax assets	596,657		636,636
Bond issuance costs	47,239		54,771
Total Consolidated Assets	$	12,595,611	$	12,223,741

_________________________ 

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

27

NOTE 15—GUARANTOR SUBSIDIARIES FINANCIAL INFORMATION:

The payment obligations under the $1,500,000, 8.000% per annum notes due April 1, 2017, the $1,250,000, 8.250% per annum notes due April 1, 2020, and the $250,000, 6.375% per annum 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 March 31, 2012 (unaudited):

	Parent Issuer			CNX Gas Guarantor		Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Sales—Outside	$	—		$	160,669	$	1,082,288	$	69,022	$	(508	)	$	1,311,471
Sales—Gas Royalty Interests	—			12,206		—		—		—			12,206
Sales—Purchased Gas	—			839		—		—		—			839
Freight—Outside	—			—		49,293		—		—			49,293
Other Income (including equity earnings)	170,023			16,305		29,703		5,957		(169,027		)	52,961
Total Revenue and Other Income	170,023			190,019		1,161,284		74,979		(169,535		)	1,426,770
Cost of Goods Sold and Other Operating Charges	49,180			98,701		682,700		66,416		7,044			904,041
Gas Royalty Interests’ Costs	—			10,255		—		—		(6		)	10,249
Purchased Gas Costs	—			517		—		—		—			517
Related Party Activity	6,015			—		1,258		502		(7,775		)	—
Freight Expense	—			—		49,293		—		—			49,293
Selling, General and Administrative Expense	—			9,924		28,628		447		—			38,999
Depreciation, Depletion and Amortization	3,919			48,803		102,102		523		—			155,347
Interest Expense	54,762			1,218		2,229		11		(100		)	58,120
Taxes Other Than Income	2,674			8,200		79,933		820		—			91,627
Total Costs	116,550			177,618		946,143		68,719		(837		)	1,308,193
Earnings (Loss) Before Income Taxes	53,473			12,401		215,141		6,260		(168,698		)	118,577
Income Tax Expense (Benefit)	(43,723		)	4,947		57,789		2,368		—			21,381
Net Income (Loss)	$	97,196		$	7,454	$	157,352	$	3,892	$	(168,698	)	$	97,196

28

Balance Sheet at March 31, 2012 (unaudited):

	Parent Issuer		CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Assets:
Current Assets:
Cash and Cash Equivalents	$	119,562	$	166,205		$	957		$	589	$	—		$	287,313
Accounts and Notes Receivable:
Trade	—		41,694			423			421,141		—			463,258
Notes Receivable	2,233		311,754			527			—		—			314,514
Other	2,670		109,101			10,440			4,720		—			126,931
Inventories	—		10,508			231,359			43,130		—			284,997
Deferred Income Taxes	190,377		(61,473		)	—			—		—			128,904
Prepaid Expenses	20,409		186,888			51,900			1,621		—			260,818
Total Current Assets	335,251		764,677			295,606			471,201		—			1,866,735
Property, Plant and Equipment:
Property, Plant and Equipment	204,057		5,577,282			8,551,640			24,267		—			14,357,246
Less-Accumulated Depreciation, Depletion and Amortization	113,848		825,783			3,958,974			17,204		—			4,915,809
Property, Plant and Equipment-Net	90,209		4,751,499			4,592,666			7,063		—			9,441,437
Other Assets:
Deferred Income Taxes	935,069		(467,316		)	—			—		—			467,753
Restricted Cash	22,158		—			—			—		—			22,158
Investment in Affiliates	9,464,098		108,858			720,339			—		(10,093,074		)	200,221
Notes Receivable	4,038		296,344			—			—		—			300,382
Other	123,720		127,733			35,475			9,997		—			296,925
Total Other Assets	10,549,083		65,619			755,814			9,997		(10,093,074		)	1,287,439
Total Assets	$	10,974,543	$	5,581,795		$	5,644,086		$	488,261	$	(10,093,074	)	$	12,595,611
Liabilities and Stockholders’ Equity:
Current Liabilities:
Accounts Payable	$	133,860	$	185,616		$	140,393		$	12,052	$	—		$	471,921
Accounts Payable (Recoverable)—Related Parties	3,026,857		15,655			(3,368,808		)	326,296		—			—
Current Portion Long-Term Debt	824		5,848			13,506			701		—			20,879
Accrued Income Taxes	49,826		487			—			—		—			50,313
Other Accrued Liabilities	645,803		62,128			136,219			12,708		—			856,858
Total Current Liabilities	3,857,170		269,734			(3,078,690		)	351,757		—			1,399,971
Long-Term Debt:	3,001,170		49,813			124,566			1,169					3,176,718
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	—		—			2,976,181			—		—			2,976,181
Pneumoconiosis Benefits	—		—			174,559			—		—			174,559
Mine Closing	—		—			409,778			—		—			409,778
Gas Well Closing	—		63,004			62,553			—		—			125,557
Workers’ Compensation	—		—			150,113			264		—			150,377
Salary Retirement	242,727		—			—			—		—			242,727
Reclamation	—		—			36,148			—		—			36,148
Other	99,364		20,727			9,392			—		—			129,483
Total Deferred Credits and Other Liabilities	342,091		83,731			3,818,724			264		—			4,244,810
Total Stockholders’ Equity	3,774,112		5,178,517			4,779,486			135,071		(10,093,074		)	3,774,112
Total Liabilities and Stockholders’ Equity	$	10,974,543	$	5,581,795		$	5,644,086		$	488,261	$	(10,093,074	)	$	12,595,611

29

Income Statement for the three months ended March 31, 2011 (unaudited):

	Parent Issuer			CNX Gas Guarantor		Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Sales—Outside	$	—		$	177,202	$	1,155,350		$	54,096	$	(1,170	)	$	1,385,478
Sales—Gas Royalty Interests	—			18,835		—			—		—			18,835
Sales—Purchased Gas	—			980		—			—		—			980
Freight—Outside	—			—		36,868			—		—			36,868
Other Income (including equity earnings)	246,864			1,680		11,421			9,241		(245,990		)	23,216
Total Revenue and Other Income	246,864			198,697		1,203,639			63,337		(247,160		)	1,465,377
Cost of Goods Sold and Other Operating Charges	28,976			87,612		628,960			53,987		14,174			813,709
Gas Royalty Interests’ Costs	—			16,821		—			—		(14		)	16,807
Purchased Gas Costs	—			676		—			—		—			676
Related Party Activity	(3,240		)	—		(1,741		)	466		4,515			—
Freight Expense	—			—		36,679			—		—			36,679
Selling, General and Administrative Expense	—			9,356		30,557			283		—			40,196
Depreciation, Depletion and Amortization	2,361			49,664		96,408			629		—			149,062
Interest Expense	61,142			2,680		2,742			13		(95		)	66,482
Taxes Other Than Income	1,503			7,807		80,514			865		—			90,689
Total Costs	90,742			174,616		874,119			56,243		18,580			1,214,300
Earnings (Loss) Before Income Taxes	156,122			24,081		329,520			7,094		(265,740		)	251,077
Income Tax Expense (Benefit)	(36,027		)	9,435		82,837			2,683		—			58,928
Net Income (Loss)	$	192,149		$	14,646	$	246,683		$	4,411	$	(265,740	)	$	192,149

30

Balance Sheet at December 31, 2011:

	Parent Issuer		CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Assets:
Current Assets:
Cash and Cash Equivalents	$	37,342	$	336,727		$	1,269		$	398	$	—		$	375,736
Accounts and Notes Receivable:
Trade	—		63,299			(5,081		)	404,594		—			462,812
Notes Receivable	2,669		311,754			527			—		—			314,950
Other	2,913		91,582			7,458			3,755		—			105,708
Inventories	—		8,600			206,096			43,639		—			258,335
Deferred Income Taxes	191,689		(50,606		)	—			—		—			141,083
Prepaid Expenses	28,470		159,900			49,224			1,759		—			239,353
Total Current Assets	263,083		921,256			259,493			454,145		—			1,897,977
Property, Plant and Equipment:
Property, Plant and Equipment	198,004		5,488,094			8,376,831			24,390		—			14,087,319
Less-Accumulated Depreciation, Depletion and Amortization	109,924		778,716			3,855,323			16,940		—			4,760,903
Property, Plant and Equipment-Net	88,080		4,709,378			4,521,508			7,450		—			9,326,416
Other Assets:
Deferred Income Taxes	963,332		(455,608		)	—			—		—			507,724
Restricted Cash	22,148		—			—			—		—			22,148
Investment in Affiliates	9,126,453		96,914			760,548			—		(9,801,879		)	182,036
Notes Receivable	4,148		296,344			—			—		—			300,492
Other	116,624		110,128			52,009			10,146		—			288,907
Total Other Assets	10,232,705		47,778			812,557			10,146		(9,801,879		)	1,301,307
Total Assets	$	10,583,868	$	5,678,412		$	5,593,558		$	471,741	$	(9,801,879	)	$	12,525,700
Liabilities and Stockholders’ Equity:
Current Liabilities:
Accounts Payable	$	140,823	$	206,072		$	164,521		$	10,587	$	—		$	522,003
Accounts Payable (Recoverable)-Related Parties	2,900,546		9,431			(3,228,229		)	318,252		—			—
Current Portion of Long-Term Debt	805		5,587			13,543			756		—			20,691
Accrued Income Taxes	68,819		6,814			—			—		—			75,633
Other Accrued Liabilities	493,450		58,401			206,649			11,570		—			770,070
Total Current Liabilities	3,604,443		286,305			(2,843,516		)	341,165		—			1,388,397
Long-Term Debt:	3,001,092		50,326			124,674			1,331		—			3,177,423
Deferred Credits and Other Liabilities:
Postretirement Benefits Other Than Pensions	—		—			3,059,671			—		—			3,059,671
Pneumoconiosis Benefits	—		—			173,553			—		—			173,553
Mine Closing	—		—			406,712			—		—			406,712
Gas Well Closing	—		61,954			62,097			—		—			124,051
Workers’ Compensation	—		—			150,786			248		—			151,034
Salary Retirement	269,069		—			—			—		—			269,069
Reclamation	—		—			39,969			—		—			39,969
Other	98,379		16,899			9,658			—		—			124,936
Total Deferred Credits and Other Liabilities	367,448		78,853			3,902,446			248		—			4,348,995
Total Stockholders’ Equity	3,610,885		5,262,928			4,409,954			128,997		(9,801,879		)	3,610,885
Total Liabilities and Stockholders’ Equity	$	10,583,868	$	5,678,412		$	5,593,558		$	471,741	$	(9,801,879	)	$	12,525,700

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Cash Flow for the Three Months Ended March 31, 2012 (unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination		Consolidated
Net Cash Provided by Operating Activities	$	123,513		$	54,417		$	51,118		$	438		$	—	$	229,486
Cash Flows from Investing Activities:
Capital Expenditures	$	(13,562	)	$	(98,455	)	$	(194,429	)	$	—		$	—	$	(306,446	)
Investment in Equity Affiliates	—			(13,500		)	(250		)	—			—		(13,750		)
Distributions from Equity Affiliates	—			3,500			—			—			—		3,500
Other Investing Activities	—			4,360			24,249			2			—		28,611
Net Cash Used in Investing Activities	$	(13,562	)	$	(104,095	)	$	(170,430	)	$	2		$	—	$	(288,085	)
Cash Flows from Financing Activities:
Dividends Received (Paid)	$	91,613		$	(120,000	)				$	—		$	—	$	(28,387	)
Other Financing Activities	657			(844		)	(1,000		)	(250		)	—		(1,437		)
Net Cash Provided by (Used in) Financing Activities	$	92,270		$	(120,844	)	$	(1,000	)	$	(250	)	$	—	$	(29,824	)

Cash Flow for the Three Months Ended March 31, 2011 (unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination		Consolidated
Net Cash Provided by Operating Activities	$	238,347		$	97,033		$	98,935		$	929		$	—	$	435,244
Cash Flows from Investing Activities:
Capital Expenditures	$	(3,613	)	$	(150,638	)	$	(100,527	)	$	—		$	—	$	(254,778	)
Distributions from Equity Affiliates	—			—			1,470			—			—		1,470
Other Investing Activities	10			40			245			5			—		300
Net Cash Used in Investing Activities	$	(3,603	)	$	(150,598	)	$	(98,812	)	$	5		$	—	$	(253,008	)
Cash Flows from Financing Activities:
Dividends Paid	$	(22,625	)	$	—		$	—		$	—		$	—	$	(22,625	)
(Payments on) Proceeds from Short-Term Borrowings	(155,000		)	41,500			—			—			—		(113,500		)
Payments on Securitization Facility	(200,000		)	—			—			—			—		(200,000		)
Proceeds from Long-Term Notes	250,000			—			—			—			—		250,000
Debt Issuance and Financing Fees	(4,517		)				—			—			—		(4,517		)
Other Financing Activities	6,781			(2,759		)	(516		)	(199		)	—		3,307
Net Cash Provided by (Used in) Financing Activities	$	(125,361	)	$	38,741		$	(516	)	$	(199	)	$	—	$	(87,335	)

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Statement of Comprehensive Income for the Three Months Ended March 31, 2012 (Unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Net Income	$	97,196		$	7,454		$	157,352		$	3,892	$	(168,698	)	$	97,196
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments
Change in Prior Service Cost (Net of tax: ($30,295))	50,276			—			50,276			—		(50,276		)	50,276
Amortization of Prior Service Cost (Net of tax:$4,552)	(7,554		)	—			(7,300		)	—		7,300			(7,554		)
Amortization of Net Loss (Net of tax:($10,154))	16,851			—			9,199			—		(9,199		)	16,851
Net Increase in the Value of Cash Flow Hedge (Net of Tax: ($49,008))	76,076			76,076			—			—		(76,076		)	76,076
Reclassification of Cash Flow Hedges from OCI to Earnings (Net of tax:$31,380)	(47,941		)	(47,941		)	—			—		47,941			(47,941		)
Other Comprehensive Income (Loss):	87,708			28,135			52,175			—		(80,310		)	87,708
Comprehensive Income	$	184,904		$	35,589		$	209,527		$	3,892	$	(249,008	)	$	184,904

Statement of Comprehensive Income for the Three Months Ended March 31, 2011 (Unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Net Income	$	192,149		$	14,646		$	246,683		$	4,411	$	(265,740	)	$	192,149
Other Comprehensive Income (Loss):
Treasury Rate Lock (Net of tax:$12)	(20		)	—			—			—		—			(20		)
Actuarially Determined Long-Term Liability Adjustments
Amortization of Prior Service Cost (Net of tax:$4,583)	(7,365		)	—			(7,262		)	—		7,262			(7,365		)
Amortization of Net Loss (Net of tax:($9,766))	15,692			—			10,055			—		(10,055		)	15,692
Net Increase in the Value of Cash Flow Hedge (Net of Tax: ($2,814))	4,371			4,371			—			—		(4,371		)	4,371
Reclassification of Cash Flow Hedges from OCI to Earnings (Net of tax:$12,615)	(18,840		)	(18,840		)	—			—		18,840			(18,840		)
Other Comprehensive Income (Loss):	(6,162		)	(14,469		)	2,793			—		11,676			(6,162		)
Comprehensive Income	$	185,987		$	177		$	249,476		$	4,411	$	(254,064	)	$	185,987

NOTE 16—RELATED PARTY TRANSACTIONS:

CONE Gathering LLC Related Party Transactions

During the three months ended March 31, 2012, 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 $3,462, which were included in Cost of Goods Sold on the Consolidated Statements of Income.

As of March 31, 2012 and December 31, 2011, CONSOL Energy and CNX Gas had a net receivable of $29,872 and $8,966, respectively, which were comprised of the following items:

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	March 31,			December 31,
	2012			2011			Location on Balance Sheet
CONE Gathering Capital Reimbursement	$	29,754		$	8,042		Accounts Receivable–Other
Reimbursement for CONE Expenses	205			2,009			Accounts Receivable–Other
Reimbursement for Services Provided to CONE	663			414			Accounts Receivable–Other
CONE Gathering Fee Payable	(750		)	(1,499		)	Accounts Payable
Net Receivable due from CONE	$	29,872		$	8,966

34

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

General

The domestic coal and natural gas industries faced challenges during the first quarter of 2012 amid a warm winter that reduced electricity and seasonal gas demand. The confluence of diminished demand and abundant natural gas supply contributed to lower coal and natural gas prices and increased inventories. Although international thermal coal prices have declined slightly and metallurgical coal prices have declined off recent highs, we believe that longer-term demand fundamentals remain sound.

Warmer temperatures coupled with lower electricity demand reduced domestic thermal coal consumption during the first quarter. Lower natural gas prices made gas-fired generation more competitive, reducing the demand for coal-fired generation. Preliminary estimates are that coal-fired generation supplied 39% of the U.S electric power sector during the first quarter versus 46% in 2011. As a result, utility stockpiles were up an estimated 25% across the nation versus the first quarter of 2011. Stockpiles grew more significantly in CONSOL Energy's traditional Mid-Atlantic and Southeast markets.

Long-term domestic outlook for coal declined slightly during the first quarter as new U.S. Environmental Protection Agency (EPA) power plant rules are likely to limit future demand. Utilities have begun to retire older, less cost effective units rather than invest in emission controls to bring these units into compliance. Despite the challenges facing domestic thermal coal demand, international demand and pricing have more favorable outlooks. In Europe, the effects of decreased nuclear production, the reduction in renewable subsidies and the phase-out of subsidized European mining has the potential to increase coal demand.

Metallurgical coal supply and demand was closer into balance than last year, thereby reducing settlement prices below 2011 levels. However, there are recent indications that Australian metallurgical coal producers are again struggling with weather induced operational disruptions and new labor issues. The affected mining regions represent a large percentage of global supply and we believe this may impact global pricing as was the case last year.

CONSOL Energy's coal sales outlook is as follows:

	2Q 2012		2012		2013		2014
Estimated Coal Sales (millions of tons)	14.2 - 14.9		58.9 - 60.9		59.4 - 61.4		63.5 - 65.5
Est. Low-Vol Met Sales	0.7 - 0.9		4.1 - 4.2		4.5 - 4.7		4.3 - 4.5
Tonnage: Firm	0.4		2.2		0.2		—
Avg. Price: Sold (Firm)	$	185.02	$	174.13	$	107.01	$	—
Price: Estimated (For open tonnage)	N/A		N/A		N/A		N/A
Est. High-Vol Met Sales	1.2 -1.3		4.5 - 4.7		5.0 - 5.1		5.6 - 5.8
Tonnage: Firm	0.8		2.4		0.3		0.3
Avg. Price: Sold (Firm)	$	73.32	$	72.66	$	71.69	$	75.53
Price: Estimated (For open tonnage)	N/A		N/A		N/A		N/A
Est. Thermal Sales	12.1 - 12.7		50.0 - 51.7		49.3 - 51.0		53.0 - 54.6
Tonnage: Firm	12.4		50.0		22.8		15.6
Avg. Price: Sold (Firm)	$	61.63	$	62.32	$	63.16	$	64.63
Price: Estimated (For open tonnage)	N/A		N/A		N/A		N/A

Note: N/A means not available or not forecast. CONSOL has chosen not to forecast prices for open tonnage due to ongoing customer

negotiations. In the thermal sales category, the open tonnage includes 4.7 million collared tons in 2013, with a ceiling of $59.78 per ton

and a floor of $51.63 per ton. For 2014, the open tonnage in the thermal sales category includes 7.0 million tons, with a ceiling of

$60.13 per ton and a floor of $46.76 per ton. Total estimated coal sales for 2012, 2013, and 2014 include 0.3, 0.6, and 0.6 million tons,

respectively, from Amonate. The Amonate tons are not included in the category breakdowns. None of the Amonate tons has yet been

sold.

Consol Energy expects to re-start the longwall at Blacksville, which was idled in March, on May 1. The Company has largely concluded negotiations with the thermal coal customers concerning deferred shipments, enabling it to resume longwall production. Also, as the result of negotiations with low volatile metallurgical overseas customers, Buchanan Mine is expected to restart the longwall, which was idled in March, on May 1.

35

Domestic natural gas production has significantly increased supply due to increased production of gas from shales coupled with an abnormally warm winter season. Supply volumes are up about 9% versus the same period last year. Although the low price environment has created more opportunity for domestic gas-fired electric generation, overall electric demand is down. Longer-term, the abundant domestic gas supply is expected to encourage manufacturing and chemical growth in the U.S. Moreover, recent EPA rulings have created greater incentives for the use of natural gas in the electric generation market.

Low natural gas prices in the first quarter 2012 have accelerated the transition of production from predominantly dry areas towards liquids-rich and oil producing plays. The number of rigs targeting dry-gas has dropped year over year while rigs targeting oil have risen. The Marcellus region has not declined as much as other regions, mainly due to its proximity to consuming Northeast U.S. markets and relatively favorable economics. Exiting the winter withdrawal season, gas storage was 900 Bcf above the same period last year. This will continue to have a dampening effect on gas prices as the market works through record-high storage levels accumulated during the warm winter and production growth begins to moderate.

CONSOL Energy continues to explore for oil and liquids in the Ohio Utica Shale. CONSOL Energy and its joint venture partner plan to drill 22 (gross) wells in 2012. Similarly, in the Marcellus Shale, CONSOL Energy and its joint venture partner are planning to drill 39 (gross) in the liquids-rich area of the play. Many of the remaining 60 (gross) Marcellus Shale wells are being drilled on 100%-net revenue interest acreage, which enables the joint venture to earn an economic return at current gas prices. CONSOL Energy expects its net gas production to be between 157 - 159 Bcf for the year. Second quarter gas production is expected to be approximately 37-38 Bcf.

The slow pace of the global economic recovery continued to temper demand expectations. In the U.S., lingering high unemployment, higher gasoline prices and regulatory uncertainty influenced energy demand while the continued European debt situation, tensions in the Middle East and slowing Chinese growth fueled concerns about the strength of the global recovery.

Despite the current challenges, longer-term fundamental drivers remain sound. With the large amount of coal-fired generation under construction around the world, particularly in developing nations, CONSOL Energy expects the international thermal market to remain strong. Likewise, a continued increase in blast furnace activity in the U.S. and abroad suggests improving overseas demand for metallurgical and cross-over coals to fuel infrastructure development. Domestically, we believe that natural gas demand is expected to rise to take advantage of the low price environment. The fundamental drivers of CONSOL Energy's business remain solid as the Company continues to meet the world's appetite for low-cost, reliable and abundant sources of energy in industrialized and developing markets.

The following developments impacting CONSOL Energy occurred in the three months ended March 31, 2012:

• CONSOL Energy announced certain changes to the salaried other post-retirement benefit plan that current retirees and current active employees will receive as of January 1, 2014. The change provides a fixed annual retiree medical contribution into a Health Reimbursement Account for eligible employees. The money in the account can be used to help pay for a commercial medical plan, Medicare Part B and Part D premiums and other qualified expenses. Employees who work or worked in corporate or operational support positions at retirement and who are age 50 or older at December 31, 2013 will receive the revised benefit in lieu of the current retiree medical and prescription drug coverage. Employees who work or worked in corporate or operations support positions who are under age 50 at December 31, 2013 will receive no retiree medical or prescription drug benefit. CONSOL Energy remeasured the salaried other postretirement plan as of March 31, 2012 to recognize these changes. The remeasurement reflects the change in benefit and the change in discount rate from 4.51% at December 31, 2011 to 4.57% at March 31, 2012. The remeasurement resulted in a reduction of approximately $80.6 million of Other Post-Retirement Benefits (OPEB) liability with a corresponding offset to Other Comprehensive Income, net of applicable deferred taxes. The change did not result in any reductions to OPEB expense in the three months ended March 31, 2012. OPEB expense is expected to be $9,425 lower than the $148,419 that was expected to be recognized over the remaining nine months of 2012. The change was made to align CONSOL Energy's corporate and operational support compensation package more closely with our peer group.

• Pennsylvania enacted Act 13 of 2012, which provides for the comprehensive regulation of Marcellus Shale development in Pennsylvania. Among other things, Act 13 requires an impact fee be paid annually on all nonconventional gas wells drilled in the state. The annual fee is based on annual average sales price and is modified annually for a 15-year period for each well. The impact fee also required the first year fee be paid on all applicable wells drilled before January 1, 2012 with subsequent annual fees to apply each year thereafter. CONSOL Energy's retroactive impact fee related to wells drilled prior to January 1, 2012 was approximately $4 million.

• West Virginia has an alternative bond system (ABS) for coal mine reclamation which consists of (i) individual site bonds posted by the permittee that are less than the full estimated reclamation cost plus (ii) a bond pool (Special

36

Reclamation Fund) funded by a per ton fee on coal mined in the State which is used to supplement the site specific bonds if needed in the event of bond forfeiture. The Special Reclamation Fund is currently underfunded. As the result of a decision by the U.S District Court in West Virginia in a citizens' suit concerning the adequacy of the Special Reclamation Fund, effective July 1, 2012, the rate per ton fee on coal mined in the state of West Virginia will be increased from $0.144 cents per ton to $0.279 per ton. CONSOL Energy expects to produce approximately 18 million tons of coal in West Virginia during the second half of 2012.

• In April 2012, CONSOL Energy entered into an agreement for the sale of its non-core Elk Creek reserves in southern West Virginia. The transaction will be reflected in April 2012 and will result in cash proceeds of approximately $25 million and a gain on sale of assets of approximately $10 million.

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

• Challenges in the overall environment in which we operate create increased risks that we must continuously monitor and manage. These risks include (i) increased prices for commodities such as diesel fuel, synthetic rubber and steel that we use in our operations, (ii) increased scrutiny of existing safety regulations and the development of new safety regulations and (iii) additional environmental restrictions such as air emission regulations.

• 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. For example, we entered into a consent decree with the EPA and the West Virginia Department of Environmental Protection pursuant to which we agreed to construct an advanced technology mine water treatment plant and related facilities to reduce high levels of total dissolved solids in water discharges from certain of our mines in Northern West Virginia, at a total estimated cost of approximately $200 million. The new facility must be placed into service no later than May 2013.

• 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. Another example is the Cross-State Air Pollution Rule (CSAPR) that was finalized by the EPA on July 6, 2011, although the effective date of the rule has been stayed by a court.  CSAPR replaces the Clean Air Interstate Rule and regulates the amount of SO2 and NOx that power plants in 23 eastern states can emit in order to meet clean air requirements in downwind states.  Another example is the Mercury and Air Toxic Standards issued by the EPA on December 16, 2011.  The 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.  Some older coal fired power plants may be retired or have operation time reduced rather than install additional expensive emission controls which could reduce the amount of coal consumed.  In April 2012, the EPA published its proposed new source emission standards for carbon dioxide for electric power plants.  The rule would apply to new power plants and to existing plants that make major modifications.  There is a 60 day comment period.  If the rule is adopted as proposed, the only new power plants that can meet the proposed emission limits would be coal fired plants with carbon dioxide capture and control and gas fired plants. On April 18, 2012, the EPA published new final rules for gas wells and related facilities.  These New Source Performance Standards 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.

• CONSOL Energy continues to explore potential sales of non-core assets.

37

Results of Operations

Three Months Ended March 31, 2012 Compared with Three Months Ended March 31, 2011

Net Income

CONSOL Energy reported net income of $97 million, or $0.42 per diluted share, for the three months ended March 31, 2012. Net income was $192 million, or $0.84 per diluted share, for the three months ended March 31, 2011.

The coal division includes thermal coal, high volatile metallurgical coal, low volatile metallurgical coal and other coal. The total coal division contributed $163 million of earnings before income tax for the three months ended March 31, 2012 compared to $299 million for the three months ended March 31, 2011. The coal division sold 15.1 million tons of coal produced from CONSOL Energy mines, excluding our portion of tons sold from equity affiliates, for the three months ended March 31, 2012 compared to 16.4 million tons for the three months ended March 31, 2011.

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

	For the Three Months Ended March 31,
	2012		2011		Variance			Percent Change
Average Sales Price per ton sold	$	69.06	$	68.20	$	0.86		1.3	%
Average Costs per ton sold	54.60		45.44		9.16			20.2	%
Margin	$	14.46	$	22.76	$	(8.30	)	(36.5	)%

The average sales price per ton sold was higher in the period-to-period comparison due to strength in our contracted domestic thermal sales pricing offsetting weakened pricing in the export high-volatile metallurgical coal market. Pricing for low volatile metallurgical coal was slightly increased in the period-to-period comparison. The decreased sales tonnage is due to decreased coal demand for both domestic electric generation and export metallurgical coal.

Average costs per ton sold increased in the period-to-period comparison due to increased variable costs and fixed costs being allocated over fewer sales tons. Labor and labor-related charges increased as a result of additional employees and the impact of the $2.00 per hour worked UMWA contract wage increases. Operating supplies and maintenance costs increased due to additional maintenance, timing of equipment overhaul costs and increased roof control costs. Subsidence costs increased due to the timing and nature of properties undermined and an increase in the length of streams that were impacted by longwall mining in the period-to-period comparison. Depreciation, depletion and amortization costs increased due to additional assets placed in service after the 2011 period. The March 2012 idling of longwalls at the Blacksville mine and the Buchanan mine resulted in an increase in unit costs of approximately $1.19 per ton as the fixed costs were allocated over fewer tons. These increases were partially offset by the improvement in Other Postretirement Benefits discussed in the long-term liabilities section below.

The total gas division includes coalbed methane (CBM), shallow oil and gas, Marcellus and other gas. The total gas division contributed $12 million of earnings before income tax for the three months ended March 31, 2012 compared to $24 million for the three months ended March 31, 2011. Total gas production was 37.7 billion cubic feet for the three months ended March 31, 2012 compared to 35.9 billion cubic feet for the three months ended March 31, 2011. Total gas production increased primarily due to the on-going drilling program, offset, in part, by a decrease of 2.4 billion net cubic feet of production related to the Antero divestiture and Noble joint venture.

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

	For the Three Months Ended March 31,
	2012		2011		Variance			Percent Change
Average Sales Price per thousand cubic feet sold	$	4.26	$	4.93	$	(0.67	)	(13.6	)%
Average Costs per thousand cubic feet sold	3.36		3.51		(0.15		)	(4.3	)%
Margin	$	0.90	$	1.42	$	(0.52	)	(36.6	)%

Total gas division outside sales revenue was $161 million for the three months ended March 31, 2012 compared to $177 million for the three months ended March 31, 2011. The decrease was primarily due to the 13.6% reduction in average sales

38

price, offset, in part, by the 5.0% increase in volumes sold. The decrease in average sales price is the result of lower general market prices for natural gas, offset, in part, by various gas swap transactions maturing 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 18.3 billion cubic feet of produced gas sales volumes for the three months ended March 31, 2012 at an average price of $5.44 per thousand cubic feet. These financial hedges represented 13.1 billion cubic feet of our produced gas sales volumes for the three months ended March 31, 2011 at an average price of $5.53 per thousand cubic feet.

Total gas division costs decreased for the three months ended March 31, 2012 compared to the three months ended March 31, 2011 primarily due to lower depreciation, depletion and amortization and lower direct administrative, selling and other costs. Lower depreciation, depletion and amortization rates were the result of increased volumes sold reducing the unit cost of straight line depreciation which remained consistent in the period-to-period comparison. Lower direct administrative, selling and other costs were also the result of the increase in volumes sold and actual dollars decreased due to reduced direct administrative labor and other costs. These improvements were offset, in part, by a slight increase in lifting costs in the period-to-period comparison due to increased repairs and maintenance 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.

In the quarter ended March 31, 2012, management decided that it would no longer consider general and administrative costs on a segment by segment basis as a factor in their decision making process. These decisions include allocation of capital and individual segment profit performance results. Management did conclude that general and administrative costs would continue to be considered in results at the divisional level (total coal and total gas). In order to present financial information in a manner consistent with internal management's evaluations, the prior periods general and administrative costs have been reclassified to reflect information consistent with the current year's presentation. The total divisional results have not changed. Individual segment results within the division have been recast to reflect costs excluding general and administrative. General and administrative costs are excluded from the coal and gas unit costs above. As in the prior periods, 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. The total general and administrative costs were made up of the following items:

	For the Three Months Ended March 31,
	2012		2011		Variance		Percent Change
Employee wages and related expenses	$	16	$	15	$	1	6.7	%
Consulting and professional services	8		8		—		—	%
Miscellaneous	11		9		2		22.2	%
Total Company General and Administrative Expenses	$	35	$	32	$	3	9.4	%

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

• Employee wages and related expenses increased $1 million in the period-to-period comparison due to annual wage increases and increased employee benefit costs.

• Consulting and professional services remained consistent in the period-to-period comparison.

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

Included in both coal and gas unit costs are total Company long-term liabilities, such as other postretirement benefits (OPEB), the salary retirement plan, workers' compensation and long-term disability. These long-term liabilities costs 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 calculated liabilities was $70 million for the three months ended March 31, 2012 compared to $76 million for the three months ended March 31, 2011. The decrease of $6 million for total CONSOL Energy expense was primarily due to a decrease in the discount rate assumptions used to calculate expense 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 three months ended March 31, 2012 compared to the three months ended March 31, 2011:

The coal segment contributed $163 million of earnings before income tax for the three months ended March 31, 2012 compared to $299 million for the three months ended March 31, 2011. Variances by the individual coal segments are discussed below.

	For the Three Months Ended											Difference to Three Months Ended
	March 31, 2012											March 31, 2011
	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	$	812	$	61	$	173	$	4		$	1,050	$	10		$	(17	)	$	(64	)	$	(3	)	$	(74	)
Purchased Coal	—		—		—		5			5		—			—			—			(1		)	(1		)
Total Outside Sales	812		61		173		9			1,055		10			(17		)	(64		)	(4		)	(75		)
Freight Revenue	—		—		—		49			49		—			—			—			12			12
Other Income	—		5		—		27			32		(2		)	2			—			13			13
Total Revenue and Other Income	812		66		173		85			1,136		8			(15		)	(64		)	21			(50		)
Costs and Expenses:
Total operating costs	530		38		72		41			681		75			8			(1		)	(7		)	75
Total provisions	46		3		8		10			67		(6		)	—			—			(1		)	(7		)
Total direct administrative & other costs	27		3		4		42			76		(1		)	1			—			1			1
Depreciation, depletion and amortization	80		6		10		4			100		5			1			1			(2		)	5
Total Costs and Expenses	683		50		94		97			924		73			10			—			(9		)	74
Freight Expense	—		—		—		49			49		—			—			—			12			12
Total Costs	683		50		94		146			973		73			10			—			3			86
Earnings (Loss) Before Income Taxes	$	129	$	16	$	79	$	(61	)	$	163	$	(65	)	$	(25	)	$	(64	)	$	18		$	(136	)

40

THERMAL COAL SEGMENT

The thermal coal segment contributed $129 million to total Company earnings before income tax for the three months ended March 31, 2012 compared to $194 million for the three months ended March 31, 2011. The thermal coal revenue and cost components on a per unit basis for these periods were as follows:

	For the Three Months Ended March 31,
	2012		2011		Variance			Percent Change
Produced Thermal Tons Sold (in millions)	13.1		13.9		(0.8		)	(5.8	)%
Average Sales Price Per Thermal Ton Sold	$	61.83	$	57.65	$	4.18		7.3	%
Average Operating Costs Per Thermal Ton Sold	40.36		32.71		7.65			23.4	%
Average Provision Costs Per Thermal Ton Sold	3.54		3.76		(0.22		)	(5.9	)%
Average Selling, Direct Administrative and Other Costs Per Thermal Ton Sold	2.02		1.98		0.04			2.0	%
Average Depreciation, Depletion and Amortization Costs Per Thermal Ton Sold	6.11		5.38		0.73			13.6	%
Total Average Costs Per Thermal Ton Sold	$	52.03	$	43.83	$	8.20		18.7	%
Margin Per thermal Ton Sold	$	9.80	$	13.82	$	(4.02	)	(29.1	)%

Thermal coal revenue was $812 million for the three months ended March 31, 2012 compared to $802 million for the three months ended March 31, 2011. The $10 million increase was attributable to the $4.18 per ton higher average sales price, offset, in part, by the 0.8 million ton reduction in thermal tons sold. The higher average thermal coal sales price in the 2012 period was the result of successful re-negotiation of several domestic thermal contracts whose pricing took effect on January 1, 2012. The sales ton decrease was primarily due to lower natural gas prices, warmer winter temperatures and a sluggish economy adversely impacting domestic electric generation demand for the three months ended March 31, 2012 compared to the three months ended March 31, 2011. Produced thermal coal inventory was 2.0 million tons at March 31, 2012 compared to 2.5 million tons at March 31, 2011.

Other income attributable to the thermal coal segment represents earnings from our equity affiliates that operate thermal coal mines. The equity in earnings of affiliates is insignificant to the total segment activity.

Operating costs are comprised of labor, supplies, maintenance, subsidence, taxes other than income 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. Operating costs related to the thermal coal segment were $530 million in the three months ended March 31, 2012 compared to $455 million in the three months ended March 31, 2011.

Changes in the average operating costs per ton for thermal coal sold were primarily related to the following items:

• Average operating costs per thermal ton sold increased due to fewer tons sold. Fixed costs are allocated over less tons, resulting in higher unit costs.

• Average operating costs per thermal ton sold also increased due to the idling of the Blacksville Mine longwall during the first quarter of 2012. The decrease in tonnage negatively impacted the average operating costs per thermal ton sold by approximately $0.58 per ton.

• Labor and related benefits average costs per ton sold increased. This was due to additional employees and the impact of the wage increases of $2.00 per hour worked related to the new collective bargaining agreement in the period-to-period comparison.

• Average operating supplies & maintenance cost per ton sold increased due to higher fuel costs, increased pumpable crib installations, increased equipment maintenance costs and the timing of major equipment overhaul costs in the period-to-period comparison.

• Production taxes average cost per ton sold increased due to the $4.18 per ton higher average sales price.

• Subsidence costs per ton sold increased due to more structures and higher costs related to these structures that were impacted by longwall mining in the period-to-period comparison. Subsidence costs have also increased due to an increase in the length of streams that were impacted by longwall mining in the period-to-period comparison.

Provision 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, long-term disability and accretion on mine closing and related liabilities. With the exception of accretion expense on mine closing and related liabilities, these liabilities are actuarially

41

calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. Accretion is calculated on a mine-by-mine basis. The average provision costs attributable to the thermal coal segment were $46 million for the three months ended March 31, 2012 compared to $52 million for the three months ended March 31, 2011. The decrease in the thermal coal provision expense was primarily attributable to a decrease in discount rates used to calculate the cost of the long-term liabilities. This improvement is offset, in part, by the reduction in sales volumes which negatively impacted unit costs.

Selling, direct administrative and other costs attributable to the thermal coal segment include selling, direct administrative costs and other allocated services which directly benefit the segment. Selling costs, excluding commission expense, are allocated to various segments based on a percentage of sales revenue attributable to each segment. Commission expense, which is a component of selling, is charged directly to the mine incurring the cost. Direct administrative and other allocated services costs are associated directly with the coal segment of the business and are allocated to various mines based on a combination of estimated time worked and production. Selling, direct administrative and other costs related to the thermal coal segment were $27 million for the three months ended March 31, 2012 compared to $28 million for the three months ended March 31, 2011. The decrease in total costs was a result of various items, none of which were individually material. The increased average unit costs were related the reduction in sales volumes. Costs were allocated over fewer tons, resulting in higher unit costs.

Depreciation, depletion and amortization for the thermal coal segment was $80 million for the three months ended March 31, 2012 compared to $75 million for the three months ended March 31, 2011. The increase was primarily due to additional equipment and infrastructure placed into service after the 2011 period that is depreciated on a straight-line basis. The increase was also due to higher units-of-production rates for thermal coal mines due to additional air shafts being placed into service after the 2011 period which had higher unit rates than historical shafts put into service. These higher expenses coupled with fewer tons sold resulted in a $0.73 increase in average depreciation, depletion and amortization costs per ton sold.

HIGH VOL METALLURGICAL COAL SEGMENT

The high volatile metallurgical coal segment contributed $16 million to total Company earnings before income tax for the three months ended March 31, 2012 compared to $41 million for the three months ended March 31, 2011. The high volatile metallurgical coal revenue and cost components on a per unit basis for these periods were as follows:

	For the Three Months Ended March 31,
	2012		2011		Variance			Percent Change
Produced High Vol Met Tons Sold (in millions)	1.0		1.0		—			—	%
Average Sales Price Per High Vol Met Ton Sold	$	62.18	$	75.25	$	(13.07	)	(17.4	%)
Average Operating Costs Per High Vol Met Ton Sold	39.44		28.47		10.97			38.5	%
Average Provision Costs Per High Vol Met Ton Sold	3.04		2.95		0.09			3.1	%
Average Selling, Direct Administrative and Other Costs Per High Vol Met Ton Sold	2.48		2.03		0.45			22.2	%
Average Depreciation, Depletion and Amortization Costs Per High Vol Met Ton Sold	6.01		5.15		0.86			16.7	%
Total Average Costs Per High Vol Met Ton Sold	$	50.97	$	38.60	$	12.37		32.0	%
Margin Per High Vol Met Ton Sold	$	11.21	$	36.65	$	(25.44	)	(69.4	%)

High volatile metallurgical coal revenue was $61 million for the three months ended March 31, 2012 compared to $78 million for the three months ended March 31, 2011. Average sales prices for high volatile metallurgical coal decreased compared to prior quarter due to weakening in global metallurgical coal demand. CONSOL Energy priced 0.8 million tons of high volatile metallurgical coal in the export market at an average sales price of $59.22 per ton for the three months ended March 31, 2012 compared to 1.0 million tons at an average price of $75.25 per ton for the three months ended March 31, 2011.

Other income attributed to the high volatile metallurgical coal segment represents earnings from our equity affiliates that operate high volatile metallurgical coal mines. The increase in equity in earnings of affiliates is insignificant to the total segment activity.

Operating costs related to the high volatile metallurgical coal segment were $38 million for the three months ended March 31, 2012 compared to $30 million for the three months ended March 31, 2011. Changes in average operating costs per ton for high volatile metallurgical coal sold were primarily related to the following items:

42

• Average operating costs per unit increased due to the mix of mines shipping high volatile metallurgical coal. The increased cost structure of high volatile metallurgical coal is due to more Central Appalachian mines shipping high vol tons. Central Appalachian mines shipping high volatile metallurgical tons have higher cost structures than the Northern Appalachian mines included in the prior period.

• Labor and related benefits increased due to higher employee counts and additional hours worked in the period-to- period comparison.

• Average operating supplies & maintenance costs per ton sold increased due to additional maintenance, equipment overhaul costs and increased fuel and blasting costs. Additional maintenance and equipment overhaul costs were related to additional equipment being serviced and major equipment overhauls in the current period. Additional fuel and blasting costs were due to increased surface tonnage moved in the period-to-period comparison.

• In-transit charges average cost per ton sold increased primarily due to the increased cost of moving coal from the mine to the preparation plant for processing. This increase is primarily related to the Central Appalachian mines which shipped high volatile metallurgical coal in the current period.

• Subsidence costs per ton sold increased due to more structures and higher costs related to these structures that were impacted by longwall mining in the period-to-period comparison. Subsidence costs also increased due to an increase in the length of streams that were impacted by longwall mining in the period-to-period comparison.

The provision expense attributable to the high volatile metallurgical coal segment was $3 million for the three months ended March 31, 2012 and 2011. The per unit increase was due to fewer tons sold in the period-to-period comparison.

Selling, direct administrative and other costs attributable to the high volatile coal segment include selling, direct administrative costs and other allocated services which directly benefit the segment. Selling costs, excluding commission expense, are allocated to various segments based on a percentage of sales revenue attributable to each segment. Commission expense, which is a component of selling, is charged directly to the mine incurring the cost. Direct administrative and other allocated services costs are costs associated directly with the coal segment of the business and are allocated to various mines based on a combination of estimated time worked and production. Selling, direct administrative and other costs related to the high volatile metallurgical coal segment were $3 million for the three months ended March 31, 2012 compared to $2 million for the three months ended March 31, 2011. The per unit increase was due to fewer tons sold in the period-to-period comparison.

Depreciation, depletion and amortization for the high volatile metallurgical coal segment was $6 million for the three months ended March 31, 2012 compared to $5 million for the three months ended March 31, 2011. The increase was primarily due to additional equipment and infrastructure placed into service after the 2011 period that is depreciated on a straight-line basis.

The high volatile metallurgical coal segment increased the margin on our coal production that would have otherwise been sold in the domestic steam coal market.

LOW VOL METALLURGICAL COAL SEGMENT

The low volatile metallurgical coal segment contributed $79 million to total Company earnings before income tax for the three months ended March 31, 2012 compared to $143 million for the three months ended March 31, 2011. The low volatile metallurgical coal revenue and cost components on a per ton basis for these periods are as follows:

	For the Three Months Ended March 31,
	2012		2011		Variance			Percent Change
Produced Low Vol Met Tons Sold (in millions)	1.0		1.4		(0.4		)	(28.6	)%
Average Sales Price Per Low Vol Met Ton Sold	$	167.87	$	165.71	$	2.16		1.3	%
Average Operating Costs Per Low Vol Met Ton Sold	$	69.68	$	51.21	$	18.47		36.1	%
Average Provision Costs Per Low Vol Met Ton Sold	$	7.62	$	5.94	$	1.68		28.3	%
Average Selling, Direct Administrative and Other Costs Per Low Vol Met Ton Sold	$	3.88	$	2.78	$	1.10		39.6	%
Average Depreciation, Depletion and Amortization Costs Per Low Vol Met Ton Sold	$	9.57	$	6.03	$	3.54		58.7	%
Total Average Costs Per Low Vol Met Ton Sold	$	90.75	$	65.96	$	24.79		37.6	%
Margin Per Low Vol Met Ton Sold	$	77.12	$	99.75	$	(22.63	)	(22.7	)%

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Low volatile metallurgical coal revenue was $173 million for the three months ended March 31, 2012 compared to $237 million for the three months ended March 31, 2011. The $64 million decrease was attributable to the 0.4 million ton decrease in sales tons, offset, in part, by a $2.16 per ton increase in average sales price. CONSOL Energy priced 0.8 million tons of low volatile metallurgical coal in the export market at an average sales price of $163.74 per ton for the three months ended March 31, 2012 compared to 1.2 million tons at an average price of $167.52 per ton for the three months ended March 31, 2011. Produced low volatile metallurgical coal inventory was 0.2 million tons at March 31, 2012 and 2011.

Operating costs are made up of labor, supplies, maintenance, subsidence, taxes other than income 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. Operating costs related to the low volatile metallurgical coal segment were $72 million for the three months ended March 31, 2012 compared to $73 million for the three months ended March 31, 2011. Changes in average operating costs per ton sold of low volatile metallurgical coal were primarily related to the following items:

• Average operating costs per low volatile ton sold primarily increased due to fewer tons sold. Fixed costs are allocated over less tons, resulting in higher unit costs.

• Average operating costs per low volatile ton sold also increased due to the idling of the Buchanan Mine longwall in March 2012. The decrease in tonnage negatively impacted the average operating costs per low volatile ton sold by approximately $16.46 per ton.

• Average labor and related benefits increased in the period-to-period comparison due to additional employees and increased wages.

• Average operating supplies and maintenance costs were impaired due to the decreased sales tonnage; however, total operating supplies and maintenance costs were improved due to the idling of longwall operations during the current period.

• Average gas well plugging and degasification costs were improved do to fewer degasification wells drilled in the current period.

The provision expense attributable to the low volatile metallurgical coal segment was $8 million for the three months ended March 31, 2012 and 2011. The per unit increase was due to fewer tons sold in the period-to-period comparison.

Selling, direct administrative and other costs attributable to the low volatile coal segment include selling, direct administrative costs and other allocated services which directly benefit the segment. Selling costs, excluding commission expense, are allocated to various segments based on a percentage of sales revenue attributable to each segment. Commission expense, which is a component of selling, is charged directly to the mine incurring the cost. Direct administrative and other allocated services costs are costs associated directly with the coal segment of the business and are allocated to various mines based on a combination of estimated time worked and production. Selling, direct administrative and other costs related to the low volatile metallurgical coal segment were $4 million for the three months ended March 31, 2012 and 2011. The per unit increase was due to fewer tons sold in the period-to-period comparison.

Depreciation, depletion and amortization for the low volatile metallurgical coal segment was $10 million for the three months ended March 31, 2012 compared to $9 million for the three months ended March 31, 2011. The increase was primarily due to additional equipment and infrastructure placed into service after the 2011 period that is depreciated on a straight-line basis. These increases were offset, in part, by lower total costs for units-of-production amortization due to the decreased tonnage. The decrease in sales tons increased average unit cost for depreciation, depletion and amortization due to fixed straight-line basis costs being allocated over fewer tons.

OTHER COAL SEGMENT

The other coal segment had a loss before income tax of $61 million for the three months ended March 31, 2012 compared to a loss before income tax of $79 million for the three months ended March 31, 2011. The other coal segment includes purchased coal activities, idle mine activities, coal general and administrative costs as well as various activities assigned to the coal division but not allocated to each individual mine.

Other coal segment produced coal sales include revenue from the sale of 0.1 million tons of coal which was recovered during the reclamation process at idled facilities for the three months ended March 31, 2012 compared to 0.2 million tons for the three months ended March 31, 2011. 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.

44

Purchased coal sales consist of revenues from processing third-party coal in our preparation plants for blending purposes to meet customer coal specifications, coal purchased from third parties and sold directly to our customers and revenues from processing third-party coal in our preparation plants. The revenues were $5 million for the three months ended March 31, 2012 compared to $6 million for the three months ended March 31, 2011. The decrease was due to various transactions that occurred throughout both periods, none of which were individually material.

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 in freight expense. Freight revenue was $49 million for the three months ended March 31, 2012 compared to $37 million for the three months ended March 31, 2011. The $12 million increase in freight expense is due to increased shipments on contracts for which CONSOL Energy contractually provides transportation services.

Miscellaneous other income was $27 million for the three months ended March 31, 2012 compared to $14 million for the three months ended March 31, 2011. The increase of $13 million primarily related to various miscellaneous sales of property and sales of coal and surface lands that resulted in $19 million of gain. This improvement was partially offset by various transactions that occurred throughout both periods, none of which were individually material.

Other coal segment total costs were $146 million for the three months ended March 31, 2012 compared to $143 million for the three months ended March 31, 2011. The increase of $3 million was due to the following items:

	For the Three Months Ended March 31,
	2012		2011		Variance
Freight Expense	$	49	$	37	$	12
Purchased Coal	12		13		(1		)
Closed and idle mines	21		26		(5		)
Other	64		67		(3		)
Total other coal segment costs	$	146	$	143	$	3

• Freight expense is based on weight of coal shipped, negotiated freight rates and method of transportation (i.e. rail, barge, truck, etc.) used for 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 in freight revenue. Freight expense increased $12 million primarily due to increased shipments on contracts for which CONSOL Energy contractually provides transportation services.

• Purchased coal costs decreased approximately $1 million in the period-to-period comparison primarily due to various transactions that occurred throughout both periods, none of which were individually material.

• Closed and idle mine costs decreased approximately $5 million for the three months ended March 31, 2012 compared to the three months ended March 31, 2011. Closed and idle mine costs decreased $3 million as the result of a decision to permanently abandon Mine 84. Closed and idle mine costs decreased $2 million 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.

• Other expenses related to the coal segment decreased $3 million in the period-to-period comparison due to various miscellaneous transactions, none of which were individually material.

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TOTAL GAS SEGMENT ANALYSIS for the three months ended March 31, 2012 compared to the three months ended March 31, 2011:

The gas segment contributed $12 million to the total Company earnings before income tax for the three months ended March 31, 2012 compared to $24 million for the three months ended March 31, 2011.

	For the Three Months Ended												Difference to Three Months Ended
	March 31, 2012												March 31, 2011
	CBM		Shallow Oil & Gas			Marcellus		Other Gas			Total Gas		CBM			Shallow Oil & Gas			Marcellus			Other Gas			Total Gas
Sales:
Produced	$	99	$	34		$	24	$	3		$	160	$	(15	)	$	(4	)	$	3		$	—		$	(16	)
Related Party	1		—			—		—			1		—			—			—			—			—
Total Outside Sales	100		34			24		3			161		(15		)	(4		)	3			—			(16		)
Gas Royalty Interest	—		—			—		12			12		—			—			—			(7		)	(7		)
Purchased Gas	—		—			—		1			1		—			—			—			—			—
Other Income	—		—			—		16			16		—			—			—			15			15
Total Revenue and Other Income	100		34			24		32			190		(15		)	(4		)	3			8			(8		)
Lifting	9		10			4		—			23		(1		)	1			2			—			2
Ad Valorem, Severance, and Other Taxes	3		3			1		—			7		—			—			1			—			1
Gathering	25		6			4		—			35		2			(1		)	1			—			2
Gas Direct Administrative, Selling & Other	5		4			3		1			13		—			(1		)	1			(3		)	(3		)
Depreciation, Depletion and Amortization	22		15			9		4			50		(2		)	(2		)	3			1			—
General & Administration	—		—			—		10			10		—			—			—			1			1
Gas Royalty Interest	—		—			—		10			10		—			—			—			(7		)	(7		)
Purchased Gas	—		—			—		1			1		—			—			—			—			—
Exploration and Other Costs	—		—			—		5			5		—			—			—			2			2
Other Corporate Expenses	—		—			—		23			23		—			—			—			8			8
Interest Expense	—		—			—		1			1		—			—			—			(2		)	(2		)
Total Cost	64		38			21		55			178		(1		)	(3		)	8			—			4
Earnings Before Income Tax	$	36	$	(4	)	$	3	$	(23	)	$	12	$	(14	)	$	(1	)	$	(5	)	$	8		$	(12	)

46

COALBED METHANE (CBM) GAS SEGMENT

The CBM segment contributed $36 million to the total Company earnings before income tax for the three months ended March 31, 2012 compared to $50 million for the three months ended March 31, 2011.

	For the Three Months Ended March 31,
	2012		2011		Variance			Percent Change
Produced gas CBM sales volumes (in billion cubic feet)	22.7		22.4		0.3			1.3	%
Average CBM sales price per thousand cubic feet sold	$	4.40	$	5.12	$	(0.72	)	(14.1	)%
Average CBM lifting costs per thousand cubic feet sold	$	0.41	$	0.43	$	(0.02	)	(4.7	)%
Average CBM ad valorem, severance, and other taxes per thousand cubic feet sold	$	0.12	$	0.14	$	(0.02	)	(14.3	)%
Average CBM gathering costs per thousand cubic feet sold	$	1.08	$	1.01	$	0.07		6.9	%
Average CBM direct administrative, selling & other costs per thousand cubic feet sold	$	0.23	$	0.22	$	0.01		4.5	%
Average CBM depreciation, depletion and amortization costs per thousand cubic feet sold	$	0.96	$	1.09	$	(0.13	)	(11.9	)%
Total Average CBM costs per thousand cubic feet sold	$	2.80	$	2.89	$	(0.09	)	(3.1	)%
Average Margin for CBM	$	1.60	$	2.23	$	(0.63	)	(28.3	)%

CBM sales revenues were $100 million for the three months ended March 31, 2012 compared to $115 million for the three months ended March 31, 2011. The $15 million decrease was primarily due to a 14.1% decrease in average sales price per thousand cubic feet sold, offset, in part, by a 1.3% increase in average volumes sold. The decrease in CBM average sales price is the result of lower general market prices for natural gas, offset, in part, by various gas swap transactions maturing 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 11.4 billion cubic feet of our produced CBM gas sales volumes for the three months ended March 31, 2012 at an average price of $5.63 per thousand cubic feet. In the three months ended March 31, 2011, these financial hedges represented 11.8 billion cubic feet at an average price of $5.62 per thousand cubic feet. CBM sales volumes increased 0.3 billion cubic feet primarily due to additional wells coming on-line from our on-going drilling program, offset, in part, by a decrease in volumes related to the Buchanan longwall being idled.

Total costs for the CBM segment were $64 million for the three months ended March 31, 2012 compared to $65 million for the three months ended March 31, 2011. Lower costs in the period-to-period comparison were primarily related to lower unit costs offset, in part, by increased volumes sold.

CBM lifting costs were $9 million in the three months ended March 31, 2012 compared to $10 million in the three months ended March 31, 2011. Lower average CBM lifting unit costs were related to a prior year contract buyout that eliminated idle rig fees that were incurred in the 2011 period, offset, in part, by increased well site maintenance due to slip repairs.

CBM ad valorem, severance and other taxes were $3 million in the three months ended March 31, 2012 and 2011. The improvement in unit costs was primarily due to increased volumes.

CBM gathering costs were $25 million for the three months ended March 31, 2012 compared to $23 million for the three months ended March 31, 2011. The $2 million increase was due to increased direct labor associated with gathering activities.

CBM direct administrative, selling & other costs for the CBM segment were $5 million for both the three months ended March 31, 2012 and 2011. 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.

47

Depreciation, depletion and amortization attributable to the CBM segment was $22 million for the three months ended March 31, 2012 compared to $24 million for the three months ended March 31, 2011. There was approximately $15 million, or $0.68 per unit-of-production, of depreciation, depletion and amortization related to CBM gas and related well equipment that was reflected on a unit-of-production method of depreciation for the three months ended March 31, 2012. The production portion of depreciation, depletion and amortization was $17 million, or $0.79 per unit-of-production for the three months ended March 31, 2011. The unit-of-production rates are generally calculated using the net book value of assets divided by either proved or proved developed reserves. There was approximately $7 million, or $0.28 average per unit cost of depreciation, depletion and amortization related to gathering and other equipment that is reflected on a straight line basis in the three months ended March 31, 2012. There was $7 million, or $0.30 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 March 31, 2011. The $1 million decrease was due to various items, none of which were individually material.

SHALLOW OIL AND GAS SEGMENT

The Shallow Oil and Gas segment had a loss before income tax of $4 million in the three months ended March 31, 2012 compared to a loss before income tax of $3 million in the three months ended March 31, 2011.

	For the Three Months Ended March 31,
	2012			2011			Variance			Percent Change
Produced gas Shallow oil and Gas sales volumes (in billion cubic feet)	7.6			8.2			(0.6		)	(7.3	)%
Average Shallow Oil and Gas sales price per thousand cubic feet sold	$	4.53		$	4.75		$	(0.22	)	(4.6	)%
Average Shallow Oil and Gas lifting costs per thousand cubic feet sold	$	1.32		$	1.16		$	0.16		13.8	%
Average Shallow Oil and Gas ad valorem, severance, and other taxes per thousand cubic feet sold	$	0.35		$	0.36		$	(0.01	)	(2.8	)%
Average Shallow Oil and Gas gathering costs per thousand cubic feet sold	$	0.78		$	0.85		$	(0.07	)	(8.2	)%
Average Shallow Oil and Gas direct administrative, selling & other costs per thousand cubic feet sold	$	0.59		$	0.63		$	(0.04	)	(6.3	)%
Average Shallow Oil and Gas depreciation, depletion and amortization costs per thousand cubic feet sold	$	1.98		$	2.08		$	(0.10	)	(4.8	)%
Total Average Shallow Oil and Gas costs per thousand cubic feet sold	$	5.02		$	5.08		$	(0.06	)	(1.2	)%
Average Margin for Shallow Oil and Gas	$	(0.49	)	$	(0.33	)	$	(0.16	)	48.5	%

Shallow Oil and Gas sales revenues were $34 million for the three months ended March 31, 2012 compared to $38 million for the three months ended March 31, 2011. The $4 million decrease was primarily due to the 7.3% decrease in volumes sold. Shallow Oil and Gas sales volumes decreased 0.6 billion cubic feet for the three months ended March 31, 2012 compared to the 2011 period primarily due to normal well declines without a corresponding increase in wells drilled. The focus of the gas division is to develop the Marcellus and Utica acreage. Average sales price decreased primarily due to lower general market prices of natural gas in the period-to-period comparison. This decrease was partially offset by the result of various gas swap transactions that matured in the three months ended March 31, 2012. These gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 4.1 billion cubic feet of our produced Shallow Oil and Gas gas sales volumes for the three months ended March 31, 2012 at an average price of $5.22 per thousand cubic feet. There were no Shallow Oil and Gas gas swap transactions that occurred in the three months ended March 31, 2011.

Total costs for the Shallow Oil and Gas segment were $38 million for the three months ended March 31, 2012 compared to $41 million for the three months ended March 31, 2011.

Shallow Oil and Gas lifting costs were $10 million for the three months ended March 31, 2012 compared to $9 million for the three months ended March 31, 2011. Lifting costs per unit increased due to increased equipment maintenance costs, increased water line costs, increased non-operated well costs and increased direct labor costs. Average lifting costs per unit were also negatively impacted by the decrease in sales volumes.

48

Shallow Oil and Gas ad valorem, severance and other taxes were $3 million for the three months ended March 31, 2012 and 2011. Costs were consistent in the period-to-period comparison.

Shallow Oil and Gas gathering costs were $6 million for the three months ended March 31, 2012 compared to $7 million for the three months ended March 31, 2011. Gathering costs decreased primarily due to lower transportation costs and pipeline maintenance.

Shallow Oil and Gas direct administrative, selling & other costs related to the Shallow Oil and Gas gas segment were $4 million for the three months ended March 31, 2012 compared to $5 million for the three months ended March 31, 2011. 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 $1 million decrease in the period-to-period comparison is due to Shallow Oil and Gas volumes representing a smaller proportion of total natural gas volumes.

Depreciation, depletion and amortization costs were $15 million for the three months ended March 31, 2012 compared to $17 million for the three months ended March 31, 2011. There was approximately $13 million, or $1.73 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 March 31, 2012. There was approximately $15 million, or $1.85 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 March 31, 2011. The rate is calculated by taking the net book value of the related assets divided by either proved or proved developed reserves, generally at the previous year end. There was approximately $2 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 three months ended March 31, 2012. There was $2 million, or $0.23 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 March 31, 2011.

MARCELLUS GAS SEGMENT

The Marcellus segment contributed $3 million to the total Company earnings before income tax for the three months ended March 31, 2012 compared to $8 million for the three months ended March 31, 2011.

	For the Three Months Ended March 31,
	2012		2011		Variance			Percent Change
Produced gas Marcellus sales volumes (in billion cubic feet)	6.7		4.8		1.9			39.6	%
Average Marcellus sales price per thousand cubic feet sold	$	3.54	$	4.35	$	(0.81	)	(18.6	)%
Average Marcellus lifting costs per thousand cubic feet sold	$	0.59	$	0.36	$	0.23		63.9	%
Average Marcellus ad valorem, severance, and other taxes per thousand cubic feet sold	$	0.13	$	0.06	$	0.07		116.7	%
Average Marcellus gathering costs per thousand cubic feet sold	$	0.59	$	0.58	$	0.01		1.7	%
Average Marcellus direct administrative, selling & other costs per thousand cubic feet sold	$	0.41	$	0.35	$	0.06		17.1	%
Average Marcellus depreciation, depletion and amortization costs per thousand cubic feet sold	$	1.34	$	1.25	$	0.09		7.2	%
Total Average Marcellus costs per thousand cubic feet sold	$	3.06	$	2.60	$	0.46		17.7	%
Average Margin for Marcellus	$	0.48	$	1.75	$	(1.27	)	(72.6	)%

The Marcellus segment sales revenues were $24 million for the three months ended March 31, 2012 compared to $21 million for the three months ended March 31, 2011. The decrease in Marcellus average sales price was the result of lower general market prices, offset, in part, by various gas swap transactions that matured in the three months ended March 31, 2012. These gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 2.8 billion cubic feet of our produced Marcellus gas sales volumes for the three months ended March 31, 2012 at an average price of $4.98 per thousand cubic feet. These financial hedges represented 1.3 billion cubic feet of our produced Marcellus gas sales volumes for the three months ended March 31, 2011 at an average price of $4.71 per thousand cubic feet. The increased sales volumes are primarily due to additional wells coming on-line from our on-going drilling program, offset, in part, by a decrease of 2.4 billion net cubic feet of production related to the Antero

49

divestiture and Noble joint venture. At March 31, 2012, there were 114 Marcellus Shale wells in production. At March 31, 2011, there were 60 Marcellus Shale wells in production.

Marcellus lifting costs were $4 million for the three months ended March 31, 2012 compared to $2 million for the three months ended March 31, 2011. Lifting costs per unit increased $0.23 per thousand cubic feet sold due to increased repairs and maintenance, increased environmental compliance and safety compliance, increased direct labor and increased well site maintenance. These increases were partially offset by the increased sales volumes.

Marcellus ad valorem, severance and other taxes were $1 million in the period ended March 31, 2012 compared to less than $1 million in the period ended March 31, 2011. The increase in the current period per unit cost is primarily due to new legislation passed in the state of Pennsylvania (Act 13 of 2012, House Bill 1950). This legislation permits Pennsylvania counties to impose annual fees on unconventional gas wells located within Pennsylvania.

Marcellus gathering costs were $4 million for the three months ended March 31, 2012 compared to $3 million for the three months ended March 31, 2011. Marcellus gathering average unit costs were consistent in the period-to-period comparison.

Marcellus direct administrative, selling & other costs related to the Marcellus gas segment were $3 million for the three months ended March 31, 2012 compared to $2 million for the three months ended March 31, 2011. Direct administrative, selling & other costs attributable to the total gas division are allocated to the individual gas segments based on a combination of production and employee counts. The $1 million increase in the period-to-period comparison is due to Marcellus volumes representing a larger proportion of total natural gas volumes.

Depreciation, depletion and amortization costs were $9 million for the three months ended March 31, 2012 compared to $6 million for the three months ended March 31, 2011. There was approximately $8 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 for the three months ended March 31, 2012. There was approximately $5 million, or $0.99 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 March 31, 2011. The rate is calculated by taking the net book value of the related assets divided by either proved or proved developed reserves, generally at the previous year end. There was $1 million, or $0.14 per thousand cubic feet, of depreciation, depletion and amortization related to gathering and other equipment that was reflected on a straight line basis in the three months ended March 31, 2012. There was $1 million, or $0.26 per thousand cubic feet, of depreciation, depletion and amortization related to gathering and other equipment that was reflected on a straight line basis in the three months ended March 31, 2011. The $0.12 decrease in unit is due to increased production volumes. Fixed costs are allocated over more volumes, resulting in lower unit costs.

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 gas general and administrative costs, 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. Revenue from this operation was approximately $3 million for the three months ended March 31, 2012 and 2011. Total costs related to these other sales were $5 million in the 2012 period and were $3 million in the 2011 period. The increase in costs is due to various items, none of which are individually material. A per unit analysis of the other operating costs in the Chattanooga shale is not meaningful due to the low volumes produced in the period-to-period analysis.

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 $10 million for the three month ended March 31, 2012 compared to $11 million for the three months ended March 31, 2011. Refer to the discussion of total general and administrative costs contained in the section "Net Income" of this quarterly report.

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 $12 million for the three months ended March 31, 2012 compared to $19 million for the three months ended March 31, 2011. 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.

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	For the Three Months Ended March 31,
	2012		2011		Variance			Percent Change
Gas Royalty Interest Sales Volumes (in billion cubic feet)	4.1		4.3		(0.2		)	(4.7	)%
Average Sales Price Per thousand cubic feet	$	2.96	$	4.38	$	(1.42	)	(32.4	)%

Purchased gas sales volumes represent volumes of gas we sold at market prices that were purchased from third-party producers. Purchased gas sales revenues were $1 million for each of the three months ended March 31, 2012 and 2011.

	For the Three Months Ended March 31,
	2012		2011		Variance			Percent Change
Purchased Gas Sales Volumes (in billion cubic feet)	0.3		0.2		0.1			50.0	%
Average Sales Price Per thousand cubic feet	$	3.01	$	4.50	$	(1.49	)	(33.1	)%

Other income was $16 million for the three months ended March 31, 2012 compared to $1 million for the three months ended March 31, 2011. The $15 million increase was due to $8 million of interest income in the current period due to notes receivable from Noble related to the September 2011 joint venture agreement, a $6 million increase in gain on sale of miscellaneous assets and a $1 million increase in equity in earnings of affiliates.

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 $10 million for the three months ended March 31, 2012 compared to $17 million for the three months ended March 31, 2011. 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 March 31,
	2012		2011		Variance			Percent Change
Gas Royalty Interest Sales Volumes (in billion cubic feet)	4.1		4.3		(0.2		)	(4.7	)%
Average Cost Per thousand cubic feet sold	$	2.49	$	3.91	$	(1.42	)	(36.3	)%

Purchased gas volumes represent volumes of gas purchased from third-party producers that we sell. Purchased gas volumes also reflect the impact of pipeline imbalances. The lower 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 both the three months ended March 31, 2012 and 2011.

	For the Three Months Ended March 31,
	2012		2011		Variance			Percent Change
Purchased Gas Volumes (in billion cubic feet)	0.3		0.2		0.1			50.0	%
Average Cost Per thousand cubic feet sold	$	1.62	$	2.27	$	(0.65	)	(28.6	)%

Exploration and other costs were $5 million for the three months ended March 31, 2012 compared to $3 million for the three months ended March 31, 2011. Costs included in the exploration and other cost line are detailed as follows:

	For the Three Months Ended March 31,
	2012		2011		Variance		Percent Change
Exploration	$	2	$	2	$	—	—	%
Dry Hole and Lease Expiration Costs	1		1		$	—	100.0	%
Other	2		—		$	2	100.0	%
Total Exploration and Other Costs	$	5	$	3	$	2	66.7	%

• Other costs were $2 million higher in the period-to-period comparison primarily due to environmental clean-up costs incurred during the three months ended March 31, 2012 at several well sites.

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Other corporate expenses were $23 million for the three months ended March 31, 2012 compared to $15 million for the three months ended March 31, 2011. The $8 million increase in the period-to-period comparison was made up of the following items:  

	For the Three Months Ended March 31,
	2012		2011		Variance		Percent Change
Short-term incentive compensation	$	7	$	5	$	2	40.0	%
Stock-based compensation	6		5		1		20.0	%
PA impact fees	4		—		4		100.0	%
Unutilized firm transportation	2		2		—		—	%
Bank fees	2		2		—		—	%
Other	2		1		1		100.0	%
Total Other Corporate Expenses	$	23	$	15	$	8	53.3	%

• 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 increased in the period-to-period comparison as the result of exceeding the targets in the 2012 period.

• Stock-based compensation was higher in the period-to-period comparison due to an increased allocation from CONSOL Energy as a result of an increase in total CONSOL Energy stock-based compensation expense.  The increase in CONSOL Energy stock-based compensation expense is due to additional awards granted in the period-to-period comparison.

• 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 lifting costs in the Marcellus gas segment.

• Unutilized firm transportation represents excess pipeline transportation capacity that the gas division obtained to enable gas production to flow on an uninterrupted basis as the gas operations continue to increase sales volumes.

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

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

Interest expense related to the other gas segment was $1 million for the three months ended March 31, 2012 compared to $3 million for the three months ended March 31, 2011. The $2 million decrease in interest expense in the period-to-period comparison is primarily due to lower average borrowings during the period on the CNX Gas Credit Facility.

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OTHER SEGMENT ANALYSIS for the three months ended March 31, 2012 compared to the three months ended March 31, 2011:

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 segments. The other segment had a loss before income tax of $56 million for the three months ended March 31, 2012 compared to a loss before income tax of $72 million for the three months ended March 31, 2011. The other segment also included total company income tax expense of $21 million for the three months ended March 31, 2012 compared to $59 million for the three months ended March 31, 2011.

	For the Three Months Ended March 31,
	2012			2011			Variance			Percent Change
Sales—Outside	$	97		$	79		$	18		22.8	%
Other Income	4			3			1			33.3	%
Total Revenue	101			82			19			23.2	%
Cost of Goods Sold and Other Charges	90			83			7			8.4	%
Depreciation, Depletion & Amortization	6			4			2			50.0	%
Taxes Other Than Income Tax	4			3			1			33.3	%
Interest Expense	57			64			(7		)	(10.9	)%
Total Costs	157			154			3			1.9	%
Loss Before Income Tax	(56		)	(72		)	16			22.2	%
Income Tax	21			59			(38		)	(64.4	)%
Net Loss	$	(77	)	$	(131	)	$	54		41.2	%

Industrial supplies:

Total revenue from industrial supplies was $69 million for the three months ended March 31, 2012 compared to $54 million for the three months ended March 31, 2011. The increase was primarily related to higher sales volumes.

Total costs related to industrial supply sales were $68 million for the three months ended March 31, 2012 compared to $58 million for the three months ended March 31, 2011. The increase of $10 million was primarily related to higher sales volumes.

Transportation operations:

Total revenue from transportation operations was $30 million for the three months ended March 31, 2012 compared to $27 million for the three months ended March 31, 2011. The increase of $3 million was primarily attributable to 1.1 million more tons transported in the period-to-period comparison.

Total costs related to the transportation operations were $21 million for the three months ended March 31, 2012 and for the three months ended March 31, 2011.

Miscellaneous other:

Additional other income of $2 million was recognized for the three months ended March 31, 2012 compared to $1 million for the three months ended March 31, 2011. The $1 million increase was due to various transactions that occurred throughout both periods, none of which were individually material.

Other corporate costs in the other segment include interest expense, bank fees and various other miscellaneous corporate charges. Total other costs were $68 million for the three months ended March 31, 2012 compared to $75 million for the three months ended March 31, 2011. Other corporate costs decreased due to the following items:

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	For the Three Months Ended March 31,
	2012		2011		Variance
Interest expense	$	57	$	64	$	(7	)
Bank fees	4		6		(2		)
Evaluation fees for non-core asset dispositions	1		1		—
Other	6		4		2
	$	68	$	75	$	(7	)

• Interest expense primarily decreased $4 million due to an increase in capitalized interest due to higher capital expenditures for major construction projects in the current period. Interest expense also decreased $2 million in the period-to-period comparison primarily due to the 2011 redemption of the 7.875% notes that were due in 2012, being replaced by the 2011 issuance of the 6.375% senior unsecured notes due March 2021. Additionally, a $1 million decrease in interest expense is due to lower borrowings on the revolving credit facilities.

• Bank fees decreased $2 million due to lower borrowings on the CNX Gas revolving credit facility in the period-to-period comparison.

• Evaluation fees for non-core asset dispositions remained consistent in the period-to-period comparison.

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

Income Taxes:

The effective income tax rate was 18.0% in the three months ended March 31, 2012 compared to 23.5% in the three months ended March 31, 2011. The relationship between pre-tax earnings and percentage depletion also 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 March 31,
	2012			2011			Variance			Percent Change
Total Company Earnings Before Income Tax	$	119		$	251		$	(132	)	(52.6	)%
Income Tax Expense	$	21		$	59		$	(38	)	(64.4	)%
Effective Income Tax Rate	18.0		%	23.5		%	(5.5		)%

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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. CONSOL Energy's credit facility allows for up to $1.5 billion for 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 minimum interest coverage ratio covenant is calculated as the ratio of EBITDA to cash interest expense of CONSOL Energy and certain of its subsidiaries. The interest coverage ratio was 5.84 to 1.00 at March 31, 2012. The facility includes a maximum leverage ratio covenant of no more than 4.75 to 1.00 through March 2013, and no more than 4.50 to 1.00 thereafter, measured quarterly. The maximum leverage ratio covenant 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 2.10 to 1.00 at March 31, 2012. 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 covenant 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 0.07 to 1.00 at March 31, 2012. 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 March 31, 2012, the facility had no outstanding borrowings and $101 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 March 31, 2012, eligible accounts receivable totaled approximately $200 million. At March 31, 2012, the facility had no outstanding borrowings and $161 million of letters of credit outstanding, leaving $39 million of unused capacity.

CNX Gas's $1.0 billion Senior Secured Credit Agreement expires April 12, 2016. 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 minimum interest coverage ratio covenant is calculated as the ratio of EBITDA to cash interest expense for CNX Gas and its subsidiaries. The interest coverage ratio was 35.79 to 1.00 at March 31, 2012. The facility also includes a maximum leverage ratio covenant of no more than 3.50 to 1.00, measured quarterly. The maximum leverage ratio covenant 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 0.00 to 1.00 at March 31, 2012. 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 $600,000 of loans, advances and dividends from CNX Gas to CONSOL Energy. Investments in the CONE Gathering Company are unrestricted. At March 31, 2012, the facility had no amounts drawn and $70 million of letters of credit outstanding, leaving $930 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 constantly

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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 $296 million at March 31, 2012. The ineffective portion of these contracts was insignificant to earnings in the three months ended March 31, 2012. 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 on terms which CONSOL Energy finds acceptable, or at all.

Cash Flows (in millions)

	For the Three Months Ended March 31,
	2012			2011			Change
Cash flows from operating activities	$	229		$	435		$	(206	)
Cash used in investing activities	$	(288	)	$	(253	)	$	(35	)
Cash used in financing activities	$	(30	)	$	(87	)	$	57

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

• Operating cash flow decreased $95 million in 2012 due to lower net income in the period-to-period comparison.

• Operating cash flows decreased due to various other changes in operating assets, operating liabilities, other assets and other liabilities which occurred throughout both years, none of which were individually material.

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

• During the 2012 period, $14 million was contributed to CONE Gathering LLC (CONE) in order to meet the operating and capital expenditure needs of the joint venture. The joint venture, of which CONSOL Energy owns 50%, was established on September 30, 2011 to develop and operate the gas gathering system in the Marcellus Shale play.

• Total capital expenditures increased $52 million to $306 million in the three months ended March 31, 2012 compared to $254 million in the three months ended March 31, 2011. Capital expenditures for the gas segment decreased $55 million primarily due to a decrease in Marcellus Shale drilling in the period-to-period comparison. Capital expenditures for coal and other activities increased $107 million in the period-to-period comparison. The ongoing development and expenditures of the BMX mine, which is scheduled to go on-line in 2014, increased $30 million in the period-to-period comparison. Capital expenditures for the Northern West Virginia RO system were $18 million for the 2012 period. The remaining increase was due to various projects throughout both periods, none of which were individually material.

• Proceeds from the sale of assets increased $28 million in the period-to-period comparison primarily due to the sale of several non-core assets including previously mined surface properties and rights-of-way.

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

• In 2011, proceeds of $250 million were received in connection with the issuance of $250 million of 6.375% senior unsecured notes due in March 2021.

• In 2011, CONSOL Energy repaid $200 million of borrowings under the accounts receivable securitization facility.

• In 2011, CONSOL Energy paid outstanding borrowings of $113 million under the revolving credit facilities. CONSOL Energy had no amounts outstanding on the revolving credit facilities for the three months ended March 31, 2012.

• Dividends of $28 million were paid in 2012 compared to $23 million in 2011. This is due to the increase of the quarterly dividend by 25%, or $0.10 per share, to $0.125 per share in the 2012 period.

The following is a summary of our significant contractual obligations at March 31, 2012 (in thousands):

	Payments due by Year
	Less Than 1 Year		1-3 Years		3-5 Years		More Than 5 Years		Total
Purchase Order Firm Commitments	$	465,999	$	62,067			$	—	$	528,066
Gas Firm Transportation	66,385		160,914		143,171		493,535		864,005
CONE Gathering Commitments	30,750		180,925		355,100		1,146,000		1,712,775
Long-Term Debt	11,759		6,279		5,287		3,110,668		3,133,993
Interest on Long-Term Debt	244,977		490,592		491,303		543,230		1,770,102
Capital (Finance) Lease Obligations	9,120		14,997		10,846		28,641		63,604
Interest on Capital (Finance) Lease Obligations	4,174		6,699		5,046		5,171		21,090
Operating Lease Obligations	91,951		157,647		99,546		152,095		501,239
Long-Term Liabilities—Employee Related (a)	224,974		464,339		479,746		2,384,033		3,553,092
Other Long-Term Liabilities (b)	369,123		121,316		65,938		445,723		1,002,100
Total Contractual Obligations (c)	$	1,519,212	$	1,665,775	$	1,655,983	$	8,309,096	$	13,150,066

 _________________________

(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 2012 contributions are expected to approximate $110 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.

Debt

At March 31, 2012, CONSOL Energy had total long-term debt of $3.198 billion outstanding, including the current portion of long-term debt of $21 million. This long-term debt consisted of:

• An aggregate principal amount of $1.5billion 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.

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• 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.

• $31million in advance royalty commitments with an average interest rate of 6.73% per annum.

• An aggregate principal amount of $64million of capital leases with a weighted average interest rate of 6.32% per annum.

At March 31, 2012, CONSOL Energy also had no outstanding borrowings and had approximately $101 million of letters of credit outstanding under the $1.5 billion senior secured revolving credit facility.

At March 31, 2012, CONSOL Energy had no outstanding borrowings and had $161 million of letters of credit outstanding under the accounts receivable securitization facility.

At March 31, 2012, CNX Gas, a wholly owned subsidiary, had no 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 $3.8 billion at March 31, 2012 and $3.6 billion at December 31, 2011. Total equity increased primarily due to net income, changes in the fair value of cash flow hedges, adjustments to actuarial liabilities, and the amortization of stock-based compensation awards. These increases were offset, in part, by the declaration of dividends and the issuance of treasury stock. 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
April 27, 2012	$	0.125	May 11, 2012	May 25, 2012
January 27, 2012	$	0.125	February 7, 2012	February 21, 2012

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 $0.50 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 2.10 to 1.00 and our availability was approximately $1.4 billion at March 31, 2012. 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 $0.50 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 three months ended March 31, 2012.

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 United Mine Workers’ of America (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 March 31, 2012. 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, 2011 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 March 31, 2012. 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.

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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;

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

• 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;

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

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

• costs associated with perfecting title for coal or gas rights on some of our properties;

• 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;

• our accruals for obligations for long-term employee benefits are based upon assumptions which, if inaccurate, could result in our being required to expend greater amounts than anticipated;

• due to our participation in an underfunded multi-employer pension plan, we have exposure under that plan that extends beyond what our obligation would be with respect to our employees and in the future we may have to make additional cash contributions to fund the pension plan or incur withdrawal liability;

• 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 and joint ventures that we recently have completed or entered into 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 proceedsincluding joint venture partners paying anticipated carry obligations;

• the terms of our existing joint ventures restrict our flexibility and actions taken by the other party in our gas joint ventures may impact our financial position;

• 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;

• other factors discussed in our 2011 Form 10-K under “Risk Factors,” as updated by any subsequent Form 10-Qs, which are 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 2011 Form 10-K.

A sensitivity analysis has been performed to determine the incremental effect on future earnings, related to open derivative instruments at March 31, 2012. A hypothetical 10 percent decrease in future natural gas prices would increase future earnings related to derivatives by $16.2 million. Similarly, a hypothetical 10 percent increase in future natural gas prices would decrease future earnings related to derivatives by $16.2 million.

CONSOL Energy’s interest expense is sensitive to changes in the general level of interest rates in the United States. At March 31, 2012, CONSOL Energy had $3,198 million aggregate principal amount of debt outstanding under fixed-rate instruments and no 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 during the three months ended March 31, 2012. CNX Gas did not have borrowings under its revolving credit facility for the three months ended March 31, 2012. A 100 basis-point increase in the average rate for CONSOL Energy's and/or CNX Gas' revolving credit facility would have had no affect on net income 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 April 17, 2012 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
2012 Fixed Price Volumes
Hedged Mcf	19,108,632		19,108,632		19,318,617		19,318,617		76,854,498
Weighted Average Hedge Price/Mcf	$	5.25	$	5.25	$	5.25	$	5.25	$	5.25
2013 Fixed Price Volumes
Hedged Mcf	12,513,747		12,652,788		12,791,830		12,791,830		50,750,195
Weighted Average Hedge Price/Mcf	$	5.06	$	5.06	$	5.06	$	5.06	$	5.06
2014 Fixed Price Volumes
Hedged Mcf	10,849,825		10,970,378		11,090,932		11,090,932		44,002,067
Weighted Average Hedge Price/Mcf	$	5.20	$	5.20	$	5.20	$	5.20	$	5.20
2015 Fixed Price Volumes
Hedged Mcf	2,783,505		2,814,433		2,845,361		2,845,361		11,288,660
Weighted Average Hedge Price/Mcf	$	4.03	$	4.03	$	4.03	$	4.03	$	4.03

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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 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 March 31, 2012 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 twentieth 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	CONSOL Energy Inc. Equity Incentive Plan, As Amended and Restated Effective May 1, 2012, incorporated by reference to Exhibit 10.1 to Form 8-K (file no. 001-14901) filed on March 21, 2012.
10.2	Long-Term Incentive Program (2012-2014).
10.3	Long-Term Incentive Program (2011-2013) (corrected for typographical error).
10.4	Form of Performance Share Unit Award Agreement.
10.5	Seventh Amendment to Amended and Restated Receivables Purchase Agreement, dated as of March 30, 2012, among CNX Funding Corporation, CONSOL Energy Inc., as the initial Servicer, the various Sub-Servicers listed on the signature pages thereto, the Conduit Purchasers listed on the signature pages thereto, the Purchaser Agents listed on the signature pages thereto, the LC Participants listed on the signature pages thereto and PNC Bank, National Association, as Administrator and as LC Bank.
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 March 31, 2011 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: April 30, 2012

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/    WILLIAM J. LYONS
	William J. Lyons
	Chief Financial Officer and Executive Vice President (Duly Authorized Officer and Principal Financial and Accounting Officer)

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EX-10.2

CONSOL ENERGY INC.

LONG-TERM INCENTIVE PROGRAM (2012 - 2014)

CONSOL ENERGY INC., a Delaware corporation (the "Company"), hereby establishes this CONSOL ENERGY INC. LONG-TERM INCENTIVE PROGRAM (2012 - 2014) (the "Program"), in accordance with the provisions of the CONSOL Energy Inc. Equity Incentive Plan, as amended (the "Plan"), and the terms provided herein.

WHEREAS, the Company maintains the Plan for the benefit of its key employees and that of its Affiliates and wishes to further align the interests of key employees with the interests of the stockholders by providing long-term incentive compensation; and

WHEREAS, the Program is intended to enhance the Company's ability to retain the employment of participants in the Program, and also to protect the Company's legitimate business interests, including its confidential information, customer relationships, and goodwill, through the use of restrictive covenants; and

WHEREAS, Section 8 of the Plan authorizes the Company to make performance-based awards.

NOW, THEREFORE, the Compensation Committee of the Board of Directors (the "Committee") of the Company hereby adopts the Program on the following terms and conditions:

1.Purpose. The purposes of the Program are to: (i) provide long-term incentive compensation to key employees to further align their interests with those of the Company's stockholders; and (ii) protect the Company's legitimate business interests, including its confidential information, customer relationships, and goodwill, through the use of restrictive covenants. In addition to the terms and conditions set forth herein, awards under the Program are subject to, and governed by, the terms and conditions set forth in the Plan, which are hereby incorporated by reference. Unless the context otherwise requires, capitalized terms used in this Program and not otherwise defined herein shall have the meanings set forth in the Plan. In the event of any conflict between the provisions of the Program and the Plan, the Committee shall have full authority and discretion to resolve such conflict and any such determination shall be final, conclusive and binding on the Participant and all interested parties.

2.Effective Date. The effective date of this Program is February 29, 2012. The Program will remain in effect until December 31, 2014, unless otherwise terminated sooner as provided herein.

3.Eligibility. The Chief Executive Officer of the Company (the "CEO") shall nominate the employees of the Company and its Affiliates (other than the CEO) who shall be eligible to participate in the Program. The Committee shall select from a group consisting of the CEO and the nominated employees those individuals who shall participate in the Program (each a "Participant" and collectively the "Participants"), subject to the Board's ratification of awards to the CEO. In the event that an employee is hired by the Company or an Affiliate during the Performance Period, upon nomination by the CEO and to the extent consistent with Section 162(m) of the Code, if applicable, the Committee shall determine whether such employee will become a Participant in the Program, subject to such terms, conditions and adjustments as the Committee determines to be necessary or desirable.

4.Performance Share Unit Awards.

4.1    The Committee shall determine the number of performance share units (the "Performance Share Units") to be awarded to each Participant. Each Performance Share Unit awarded under the Program shall represent a contingent right to receive one share of the Company's common stock as described more fully herein, to the extent such Performance Share Unit is earned and becomes payable pursuant to the terms of this Program. Notwithstanding, Performance Share Units as initially awarded have no independent economic value, but rather are mere units of measurement used for purposes of calculating the value of benefits, if any, to be paid under the Program.

4.2    Performance Share Units shall be increased and/or decreased in accordance with the terms of the Program as described more fully herein. Notwithstanding any provision of this Plan to the contrary, (i) the Committee, in its sole discretion, may reduce the amount of any Performance Share Units that would otherwise be earned by a Participant upon attainment of the Performance Condition (as defined below) if it concludes that such reduction is necessary or appropriate in accordance with the guidelines established by the Committee, and (ii) the Committee shall not use its discretionary authority to increase the number of Performance Share Units that would otherwise be earned upon attainment of the Performance Condition (as defined below) with respect to any award that is intended to be performance-based compensation under Section 162(m) of the Code.

5.Performance Condition of the Performance Share Units. The total number of Performance Share Units awarded a Participant will be earned (at a maximum award level of 250% of the target number of Performance Share Units awarded), subject to the Committee's exercise of its negative discretion to reduce the number of Performance Share Units earned, if any one or more of the performance goals are achieved for the following performance measures: (i) the Company's total stockholder return relative to the total stockholder return of each company in the peer group (as set forth on Attachment A); (ii) cumulative earnings before income, taxes, depreciation and amortization (EBITDA) of the Company; or (iii) cumulative net income of the Company, each as approved by (and in accordance with the procedures established by) the Committee on February 29, 2012 and on file with the Committee (each a "Performance Condition"), for the performance period of January 1, 2012 to December 31, 2014 (the "Performance Period"); provided, however, that except as otherwise specifically provided herein, the ability to earn Performance Share Units and to receive payment thereon under the Program is expressly contingent upon achievement of the performance goal for one or more Performance Condition and otherwise satisfying all other terms and conditions of the Program.

6.Issuance and Distribution.

6.1    After the end of the Performance Period, the Committee shall certify in writing prior to payment the extent to which the applicable Performance Condition and any other material terms of the Program have been achieved. For purposes of this provision, and for so long as the Code permits, the approved minutes of the Committee meeting in which the certification is made may be treated as written certification.

6.2    Subject to the terms and conditions of this Program, Performance Share Units earned by a Participant will be settled and paid in shares of the Company's common stock in

calendar year 2015 on a date determined in the Committee's discretion, but in no event later than March 15th of such year (the "Payment Date").

6.3    Notwithstanding any other provision of this Program, in the event of a Change in Control, the Performance Condition will be deemed to have been achieved (at a target award level of 100% of Performance Share Units awarded) and the value of such units will be settled on the closing date of the Change in Control transaction (the "CiC Payment Date"); provided, further, in the event of a Change in Control, Performance Share Units may, in the Committee's discretion, be settled in cash and/or securities or other property.

7.Dividends. Each Performance Share Unit will be cumulatively credited with dividends that are paid on the Company's common stock in the form of additional units. These additional units shall be deemed to have been purchased on the record date for the dividend using the closing stock price of the Company's common stock as reported in The Wall Street Journal and shall be subject to all the same conditions and restrictions as provided in this Program applicable to Performance Share Units.

8.Change in Participant's Status.

8.1    In the event a Participant Separates from Service (i) on or after the date the Participant has reached the age of 55 by reason of an "Early Retirement" or "Incapacity Retirement," (ii) by reason of a "Normal Retirement," (iii) on account of death or Disability (other than an Incapacity Retirement), or (iv) by reason of a reduction in force as specified and implemented by the Company, prior to the Payment Date or the CiC Payment Date, as applicable, the Participant shall be entitled to retain the Performance Share Units and receive payment therefore to the extent earned and payable pursuant to the provisions of this Program; provided, however, that in the case of a Separation from Service on account of Disability, the Participant shall only be entitled to retain a prorated portion of the Performance Share Units determined at the end of the Performance Period and based on the ratio of the number of complete months the Participant is employed or serves during the Performance Period to the total number of months in the Performance Period (or the number of remaining months in the Performance Period if the Participant is admitted after the start of the Performance Period). In the event a Participant Separates from Service for any other reason, including, but not limited to, by the Participant voluntarily, or by the Company with Cause or without Cause (other than in connection with a reduction in force as specified above), prior to the Payment Date or the CiC Payment Date, as applicable, the Performance Share Units awarded to the Participant shall be cancelled and forfeited, whether payable or not, without payment by the Company or any Affiliate. Any payments due a deceased Participant shall be paid to his estate as provided herein after the end of the Performance Period.

8.2    For purposes of the Program: the terms "Early Retirement," "Incapacity Retirement" and "Normal Retirement," shall have the meaning ascribed thereto under the CONSOL Energy Inc. Employee Retirement Plan, as amended, or any successor thereto applicable to the Participant; provided, however, for purposes of the Program a Participant shall not be considered to have Separated from Service on account of (i) "Early Retirement" unless the Participant shall also have completed at least one year of continuous service with the Company after the Effective Date of this Program, or (ii) "Normal Retirement" unless the Participant shall also have attained the age of sixty-two (62).

9.Responsibilities of the Committee. In addition to the authority granted to the Committee under the Plan, the Committee has responsibility for all aspects of the Program's administration, including but not limited to: ensuring that the Program is administered in accordance with the provisions of the Program and the Plan; approving Participants; authorizing Performance Share Unit awards to Participants; and adjusting Performance Share Units as authorized hereunder consistent with the terms of the Program. The ministerial responsibility of the Program (e.g., management of day-to-day matters) is a function that has been delegated to the Company's officers as permitted by the terms of the Plan and in compliance with applicable law and regulation. All decisions of the Committee under the Program shall be final, conclusive and binding on all interested parties. No member of the Committee shall be liable for any action or determination made in good faith on the Program or any Performance Share Units awarded thereunder.

10.Tax Consequences/Withholding.

10.1    It is intended that: (i) a Participant's Performance Share Units shall be considered to be subject to a substantial risk of forfeiture in accordance with those terms as defined in Section 409A and 3121(v)(2) of the Code; and (ii) a Participant shall have merely an unfunded, unsecured promise to be paid a benefit, and such unfunded promise shall not consist of a transfer of "property" within the meaning of Code Section 83.

10.2    A Participant shall timely remit to the Company all applicable federal, state and local income and employment taxes (including taxes of any foreign jurisdiction) which the Company is required to withhold at any time with respect to the Performance Share Units. Such payment shall be made to the Company in full, in cash or check, or as otherwise authorized under the terms of the Plan.

10.3    This Program is intended to be excepted from coverage under Section 409A of the Code and the regulations promulgated thereunder and shall be administered, interpreted and construed accordingly. Notwithstanding any provision of this Program to the contrary, if any benefit provided under this Program is subject to the provisions of Section 409A of the Code and the regulations issued thereunder (and not excepted therefrom), the provisions of the Program shall be administered, interpreted and construed in a manner necessary to comply with Section 409A (or disregarded to the extent such provision cannot be so administered, interpreted, or construed). Notwithstanding, Section 409A may impose upon the Participant certain taxes or other charges for which the Participant is and shall remain solely responsible, and nothing contained in this Program or the Plan shall be construed to obligate any member of the Committee or Board, the Company or any Affiliate (or its employees, officers or directors) for any such taxes or other charges.

10.4    Notwithstanding any provision of the Program to the contrary, if an award of Performance Share Units under this Program is intended to qualify as performance-based compensation under Section 162(m) of the Code and the regulations issued thereunder and a provision of this Program would prevent such award from so qualifying, such provision shall be administered, interpreted and construed to carry out such intention (or disregarded to the extent such provision cannot be so administered, interpreted or construed).

11.Non-Competition.

11.1    The Participants hereunder agree that this Section 11 is reasonable and

necessary in order to protect the legitimate business interests and goodwill of the Company, including the Company's trade secrets, valuable confidential business and professional information, substantial relationships with prospective and existing customers and clients, and specialized training provided to Participants and other employees of the Company. The Participants acknowledge and recognize the highly competitive nature of the business of the Company and its Affiliates and accordingly agree that during the term of each of their employment and for a period of two (2) years after the termination thereof:

(a)The Participants will not directly or indirectly engage in any business substantially similar to any line of business conducted by the Company or any of its Affiliates, including, but not limited to, where such engagement is as an officer, director, proprietor, employee, partner, investor (other than as a holder of less than 1% of the outstanding capital stock of a publicly traded corporation), consultant, advisor, agent or sales representative, in any geographic region in which the Company or any of its Affiliates conducted business;

(b)The Participants will not contact, solicit, perform services for, or accept business from any customer or prospective customer of the Company or any of its Affiliates;

(c)The Participants will not directly or indirectly induce any employee of the Company or any of its Affiliates to: (1) engage in any activity or conduct which is prohibited pursuant to subparagraph 11.1(a); or (2) terminate such employee's employment with the Company or any of its Affiliates. Moreover, the Participants will not directly or indirectly employ or offer employment (in connection with any business substantially similar to any line of business conducted by the Company or any of its Affiliates) to any person who was employed by the Company or any of its Affiliates unless such person shall have ceased to be employed by the Company or any of its Affiliates for a period of at least 12 months; and

(d)The Participants will not directly or indirectly assist others in engaging in any of the activities, which are prohibited under subparagraphs (a) - (c) above.

11.2    It is expressly understood and agreed that although the Participants and the Company consider the restrictions contained in this Section 11 to be reasonable, if a final judicial determination is made by a court of competent jurisdiction that the time or territory or any other restriction contained in this Program is an unenforceable restriction against any Participant, the provisions of this Program shall not be rendered void but shall be deemed amended to apply as to such maximum time and territory and to such maximum extent as such court may judicially determine or indicate to be enforceable against such Participant. Alternatively, if any court of competent jurisdiction finds that any restriction contained in this Program is unenforceable, and such restriction cannot be amended so as to make it enforceable, such finding shall not affect the enforceability of any of the other restrictions contained herein. The restrictive covenants set forth in this Section 11 shall be extended by any amount of time that a Participant is in breach of such covenants, such that the Company receives the full benefit of the time duration set forth above.

12.Confidential Information and Trade Secrets. The Participants and the Company agree that certain materials, including, but not limited to, information, data and other materials relating to customers, development programs, costs, marketing, trading, investment, sales activities, promotion, credit and financial data, manufacturing processes, financing methods, plans or the business and affairs of the Company and its Affiliates, constitute proprietary confidential information and trade secrets. Accordingly, the Participants will not at any time during or after a

Participant's employment with the Company (including any Affiliate) disclose or use for such Participant's own benefit or purposes or the benefit or purposes of any other person, firm, partnership, joint venture, association, corporation or other business organization, entity or enterprise other than the Company and any of its Affiliates, any proprietary confidential information or trade secrets, provided that the foregoing shall not apply to information which is not unique to the Company or any of its Affiliates or which is generally known to the industry or the public other than as a result of such Participant's breach of this covenant. The Participants agree that upon termination of employment with the Company (including any Affiliate) for any reason, the Participants will immediately return to the Company all memoranda, books, papers, plans, information, letters and other data, and all copies thereof or therefrom, which in any way relate to the business of the Company and its Affiliates, except that the Participants may retain personal notes, notebooks and diaries. The Participants further agree that the Participants will not retain or use for their own account at any time any trade names, trademark or other proprietary business designation used or owned in connection with the business of the Company or any of its Affiliates.

13.Remedies/Forfeiture.

13.1    The Participants acknowledge that a violation or attempted violation on a Participant's part of Sections 11 and 12 will cause irreparable damage to the Company and its Affiliates, and the Participants therefore agree that the Company and its Affiliates shall be entitled as a matter of right to an injunction, out of any court of competent jurisdiction, restraining any violation or further violation of such promises by the Participants or a Participant's employees, partners or agents. The Participants agree that such right to an injunction is cumulative and in addition to whatever other remedies the Company (including any Affiliate) may have under law or equity. Specifically, the Participants agree that such right to an injunction is cumulative and in addition to the Participants' obligations to make timely payment to the Company as set forth in Section 13.2 of this Program. The Participants further acknowledge and agree that a Participant's Performance Share Units shall be cancelled and forfeited without payment by the Company if such Participant breaches any of his or her obligations set forth in Sections 11 and 12 herein.

13.2    At any point after becoming aware of a breach of any obligation set forth in Sections 11 and 12 of this Program, the Company shall provide notice of such breach to a Participant. By agreeing to participate in this Program, the Participants agree that within ten (10) days after the date the Company provides such notice, a Participant shall pay to the Company in cash an amount equal to any and all distributions paid to or on behalf of such Participant under this Program within the six (6) months prior to the date of the earliest breach. The Participants agree that failure to make such timely payment to the Company constitutes an independent and material breach of the terms and conditions of this Program, for which the Company may seek recovery of the unpaid amount as liquidated damages, in addition to all other rights and remedies the Company may have resulting from a Participant's breach of the obligations set forth in Sections 11 and 12. The Participants agree that timely payment to the Company as set forth in this provision of the Program is reasonable and necessary because the compensatory damages that will result from breaches of Sections 11 and/or 12 cannot readily be ascertained. Further, the Participants agree that timely payment to the Company as set forth in this provision of the Program is not a penalty, and it does not preclude the Company from seeking all other remedies that may be available to the Company, including without limitation those set forth in this Section 13.

14.Assignment/Nonassignment.

14.1    The Company shall have the right to assign this Program, including without limitation Sections 11 and 12, and the Participants agree to remain obligated by all provisions of this Program that are assigned to any successor, assign or surviving entity. Any successor to the Company is an intended third party beneficiary of this Program.

14.2    The Performance Share Units shall not be sold, pledged, assigned, hypothecated, transferred or disposed of (a "Transfer") in any manner, other than by will or the laws of descent and distribution. Any attempt by a Participant to Transfer the Performance Share Units in violation of the terms of the Program shall render the Performance Share Units null and void, and result in the immediate forfeiture of such Performance Share Units, without payment by the Company.

15.Impact on Benefit Plans. Payments under the Program shall not be considered as earnings for purposes of the Company's and/or Affiliate's qualified retirement plans or any such retirement or benefit plan unless specifically provided for therein. Nothing herein shall prevent the Company or any Affiliate from maintaining additional compensation plans and arrangements for its employees.

16.Successors; Changes in Stock. The obligation of the Company under the Program shall be binding upon the successors and assigns of the Company. If a dividend or other distribution shall be declared upon the Company's common stock payable in shares of Company common stock, the Performance Share Units and the shares of Company common stock on which the Performance Condition is based shall be adjusted by adding thereto the number of shares of Company common stock which would have been distributable thereon if such shares and Performance Share Units had been actual Company shares and outstanding on the date fixed for determining the stockholders entitled to receive such stock dividend or distribution. In the event of any spin-off, split-off or split-up, dividend in property other than cash, recapitalization or other change in the capital structure of the Company, or any merger, consolidation, reorganization, partial or complete liquidation or other distribution of assets (other than a normal cash dividend), or any other corporate transaction or event having an effect similar to any of the foregoing, or extraordinary distribution to stockholders of the Company's common stock, the Performance Share Units, the shares of Company common stock relating to the Performance Share Units, and on which the Performance Conditions is based shall be appropriately adjusted to prevent dilution or enlargement of the rights of Participants which would otherwise result from any such transaction, provided such adjustment shall be consistent with Code Section 162(m) and Section 409A, as applicable.

In the case of a Change in Control, any obligation under the Program shall be handled in accordance with the terms of Section 6 hereof. In any case not constituting a Change in Control in which the Company's common stock is changed into or becomes exchangeable for a different number or kind of shares of stock or other securities of the Company or another corporation, or cash or other property, whether through reorganization, reclassification, recapitalization, stock split-up, combination of shares, merger or consolidation, then (i) the value of the Performance Share Units constituting an award shall be calculated based on the closing price of such common stock on the closing date of the transaction on the principal market on which such common stock is traded, (ii) there shall be substituted for each Performance Share Unit constituting an award, the number and kind of shares of stock or other securities (or cash or other property) into which each outstanding

share of the Company's common stock shall be so changed or for which each such share shall be exchangeable, and (iii) the share of Company common stock on which the Performance Condition is based shall be appropriately and equitably adjusted, provided any such adjustments shall be consistent with Code Section 162(m) and Section 409A, as applicable. In the case of any such adjustment, the Units shall remain subject to the terms of the Program.

17.Governing Law, Jurisdiction, and Venue.

17.1    This Program shall be governed by and construed in accordance with the laws of the State of Delaware, without giving effect to the principles of conflicts of law.

17.2    Participant hereby irrevocably submits to the personal and exclusive jurisdiction of the United States District Court for the Western District of Pennsylvania or the Court of Common Pleas of Allegheny County, Pennsylvania in any action or proceeding arising out of, or relating to, this Program (whether such action or proceeding arises under contract, tort, equity or otherwise). Participant hereby irrevocably waives any objection which Participant now or hereafter may have to the laying of venue or personal jurisdiction of any such action or proceeding brought in said courts.

17.3    Jurisdiction over, and venue of, any such action or proceeding shall be exclusively vested in the United States District Court for the Western District of Pennsylvania or the Court of Common Pleas of Allegheny County, Pennsylvania.

17.4    Provided that the Company commences any such action or proceeding in the courts identified in Section 17(3), Participant irrevocably waives Participant's right to object to or challenge the above selected forum on the basis of inconvenience or unfairness under 28 U.S.C. § 1404, 42 Pa. C.S. § 5322 or similar state or federal statutes. Participant agrees to reimburse the Company for all of the attorneys fees and costs it incurs to oppose Participant's efforts to challenge or object to litigation proceeding in the courts identified in Section 17(3) with respect to actions arising out of or relating to this Program (whether such actions arise under contract, tort, equity or otherwise).

18.Failure to Enforce Not a Waiver. The failure of the Company to enforce at any time any provision of this Program shall in no way be construed to be a waiver of such provision or of any other provision hereof.

19.Severability. In the event that any one or more of the provisions of this Program shall be held to be invalid, illegal or unenforceable, the validity, legality or enforceability of the remaining provisions shall not in any way be affected or impaired thereby.

20.Funding. The Program is not funded and all amounts payable hereunder, if any, shall be paid from the general assets of the Company or its Affiliate, as applicable. No provision contained in this Program or the Plan and no action taken pursuant to the provisions of this Program or the Plan shall create a trust of any kind or require the Company to maintain or set aside any specific funds to pay benefits hereunder. To the extent a Participant acquires a right to receive payments from the Company under the Program, such right shall be no greater than the right of any unsecured general creditor of the Company.

21.Headings. The descriptive headings of the Sections of this Program are inserted for convenience of reference only and shall not constitute a part of this Program.

22.Amendment or Termination of this Program. This Program may be modified, amended, suspended or terminated by the Committee at any time; provided, however, that no modification, amendment, suspension or termination of this Plan shall adversely affect the rights of a Participant under the Program without the consent of such Participant. Notwithstanding the foregoing or any provision of this Program to the contrary, the Company may, in its sole discretion and without the Participant's consent, modify or amend the terms of the Program or a Performance Share Unit award, or take any other action it deems necessary or advisable, to cause the Program to comply with Section 409A or Section 162(m) (or an exception thereto). Any modification, amendment, suspension or termination shall only be effective upon a writing issued by the Company, and a Participant shall not offer evidence of any purported oral modifications or amendments to vary or contradict the terms of this Program document.

IN WITNESS WHEREOF, the undersigned have executed this Program on the day and year indicated below. This Program may be executed in more than one counterpart, each of which is deemed to be an original and all of which taken together constitute one and the same agreement.

Dated:March 28, 2012/s/ J. Brett Harvey

J. Brett Harvey, Chairman, on behalf of the Board of Directors

Dated:March 28, 2012/s/ William Powell

William Powell, Chairman, on behalf of the Compensation Committee

ATTACHMENT A

Total Stockholder Return Peer Companies*

Alliance Resource Partners, L.P.	James River Coal Company
Alpha Natural Resources, Inc.	Newfield Exploration Company
Anadarko Petroleum Corporation	Nexen Inc.
Apache Corporation	Noble Energy Inc.
Arch Coal Inc.	Peabody Energy Corporation
Cabot Oil & Gas Corporation	Penn Virginia Corporation
Callon Petroleum Co/DE	Pioneer Natural Resources Company
Chesapeake Energy Corporation	Rio Tinto Group (GBR) -ADR
Cimarex Energy Co.	St. Mary Land & Explor Company
Comstock Resources Inc.	Stone Energy Corporation
Denbury Resources Inc.	Ultra Petroleum Corporation
Devon Energy Corporation	Westmoreland Coal Company
Encana Corporation
EOG Resources, Inc.

*In the event a Peer Group company ceases to exist during the performance period, such Peer Group company shall be excluded from the calculation of Total Stockholder Return; provided, however, that any Peer Group company that is liquidated and/or files for Chapter 11 reorganization would not be deemed excluded, but rather would automatically be deemed to be in "last place" for purposes of calculating Total Stockholder Return.

EX-10.3

CONSOL ENERGY INC.

LONG-TERM INCENTIVE PROGRAM (2011 - 2013)

CONSOL ENERGY INC., a Delaware corporation (the "Company"), hereby establishes this CONSOL ENERGY INC. LONG-TERM INCENTIVE PROGRAM (2011 - 2013) (the "Program"), in accordance with the provisions of the CONSOL Energy Inc. Equity Incentive Plan, as amended (the "Plan"), and the terms provided herein.

WHEREAS, the Company maintains the Plan for the benefit of its key employees and that of its Affiliates and wishes to further align the interests of key employees with the interests of the stockholders by providing long-term incentive compensation; and

WHEREAS, the Program is intended to enhance the Company's ability to retain the employment of participants in the Program, and also to protect the Company's legitimate business interests, including its confidential information, customer relationships, and goodwill, through the use of restrictive covenants; and

WHEREAS, Section 8 of the Plan authorizes the Company to make performance-based awards.

NOW, THEREFORE, the Compensation Committee of the Board of Directors (the "Committee") of the Company hereby adopts the Program on the following terms and conditions:

1.Purpose. The purposes of the Program are to: (i) provide long-term incentive compensation to key employees to further align their interests with those of the Company's stockholders; and (ii) protect the Company's legitimate business interests, including its confidential information, customer relationships, and goodwill, through the use of restrictive covenants. In addition to the terms and conditions set forth herein, awards under the Program are subject to, and governed by, the terms and conditions set forth in the Plan, which are hereby incorporated by reference. Unless the context otherwise requires, capitalized terms used in this Program and not otherwise defined herein shall have the meanings set forth in the Plan. In the event of any conflict between the provisions of the Program and the Plan, the Committee shall have full authority and discretion to resolve such conflict and any such determination shall be final, conclusive and binding on the Participant and all interested parties.

2.Effective Date. The effective date of this Program is February 23, 2011. The Program will remain in effect until the earlier of December 31, 2013, unless otherwise terminated sooner as provided herein.

3.Eligibility. The Chief Executive Officer of the Company (the "CEO") shall nominate the employees of the Company and its Affiliates (other than the CEO) who shall be eligible to participate in the Program. The Committee shall select from a group consisting of the CEO and the nominated employees those individuals who shall participate in the Program (each a "Participant" and collectively the "Participants"), subject to the Board's ratification of awards to the CEO. In the event that an employee is hired by the Company or an Affiliate during the Performance Period, upon nomination by the CEO and to the extent consistent with Section 162(m) of the Code, the Committee shall determine whether such employee will become a Participant in the Program, subject to such terms, conditions and adjustments as the Committee determines to be necessary or desirable.

4.Performance Share Unit Awards.

4.1The Committee shall determine the number of performance share units (the "Performance Share Units") to be awarded to each Participant. Each Performance Share Unit awarded under the Program shall represent a contingent right to receive one share of the Company's common stock as described more fully herein, to the extent such Performance Share Unit is earned and becomes payable pursuant to the terms of this Program. Notwithstanding, Performance Share Units as initially awarded have no independent economic value, but rather are mere units of measurement used for purpose of calculating the value of benefits, if any, to be paid under the Program.

4.2Performance Share Units shall be increased and/or decreased in accordance with the terms of the Program as described more fully herein. Notwithstanding any provision of this Plan to the contrary, (i) the Committee, in its sole discretion, may reduce the amount of any Performance Share Units that would otherwise be

earned by a Participant upon attainment of the Performance Condition (as defined below) if it concludes that such reduction is necessary or appropriate in accordance with the guidelines established by the Committee, and (ii) the Committee shall not use its discretionary authority to increase the number of Performance Share Units that would otherwise be earned upon attainment of the Performance Condition (as defined below) with respect to any award that is intended to be performance-based compensation under Section 162(m) of the Code.

5.Performance Condition of the Performance Share Units. The total number of Performance Share Units awarded a Participant will be earned (at a maximum award level of 250% of Performance Share Units awarded), subject to the Committee's exercise of its negative discretion to reduce the number of Performance Share Units earned, if any one or more of the performance goals are achieved for the following performance measures: (i) the Company's total stockholder return relative to the total stockholder return of each company in the peer group (as set forth on Attachment A); (ii) cumulative earnings before income, taxes, depreciation and amortization (EBITDA) of the Company; or (iii) cumulative net income of the Company, each as approved by (and in accordance with the procedures established by) the Committee on February 23, 2011 and on file with the Committee (each a "Performance Condition"), for the performance period of January 1, 2011 to December 31, 2013 (the "Performance Period"); provided, however, that except as otherwise specifically provided herein, the ability to earn Performance Share Units and to receive payment thereon under the Program is expressly contingent upon achievement of the performance goal for one or more Performance Condition and otherwise satisfying all other terms and conditions of the Program.

6.Issuance and Distribution.

6.1After the end of the Performance Period, the Committee shall certify in writing prior to payment the extent to which the applicable Performance Condition and any other material terms of the Program have been achieved. For purposes of this provision, and for so long as the Code permits, the approved minutes of the Committee meeting in which the certification is made may be treated as written certification.

6.2Subject to the terms and conditions of this Program, Performance Share Units earned by a Participant will be settled and paid in shares of the Company's common stock in calendar year 2014 on a date determined in the Committee's discretion, but in no event later than March 15th of such year (the "Payment Date").

6.3Notwithstanding any other provision of this Program, in the event of a Change in Control the Performance Condition will be deemed to have been achieved (at a target award level of 100% of Performance Share Units awarded) and the value of such units will be settled on the closing date of the Change in Control transaction (the "CiC Payment Date"); provided, further, in the event of a Change in Control, Performance Share Units may, in the Committee's discretion, be settled in cash and/or securities or other property.

7.Dividends. Each Performance Share Unit will be cumulatively credited with dividends that are paid on the Company's common stock in the form of additional units. These additional units shall be deemed to have been purchased on the record date for the dividend using the closing stock price of the Company's common stock as reported in The Wall Street Journal and shall be subject to all the same conditions and restrictions as provided in this Program applicable to Performance Share Units.

8.Change in Participant's Status.

8.1In the event a Participant Separates from Service (i) on or after the date the Participant has reached the age of 55 by reason of an "Early Retirement" or "Incapacity Retirement," (ii) by reason of a "Normal Retirement," (iii) on account of death or Disability (other than an Incapacity Retirement), or (iv) by reason of a reduction in force as specified and implemented by the Company, prior to the Payment Date or the CiC Payment Date, as applicable, the Participant shall be entitled to retain the Performance Share Units and receive payment therefore to the extent earned and payable pursuant to the provisions of this Program; provided, however, that in the case of a Separation from Service on account of Disability, the Participant shall only be entitled to retain a prorated portion of the Performance Share Units determined at the end of the Performance Period and based on the ratio of the number of complete months the Participant is employed or serves during the Performance Period to the total number of months in the Performance

Period (or the number of remaining months in the Performance Period if the Participant is admitted after the start of the Performance Period). In the event a Participant Separates from Service for any other reason, including, but not limited to, by the Participant voluntarily, or by the Company with Cause or without Cause (other than in connection with a reduction in force as specified above), prior to the Payment Date or the CiC Payment Date, as applicable, the Performance Share Units awarded to the Participant shall be cancelled and forfeited, whether payable or not, without payment by the Company or any Affiliate. Any payments due a deceased Participant shall be paid to his estate as provided herein after the end of the Performance Period.

8.2For purposes of the Program: the terms "Early Retirement," "Incapacity Retirement" and "Normal Retirement," shall have the meaning ascribed thereto under the CONSOL Energy Inc. Employee Retirement Plan, as amended, or any successor thereto applicable to the Participant; provided, however, for purposes of the Program a Participant shall not be considered to have Separated from Service on account of (i) "Early Retirement" unless the Participant shall also have completed at least one year of continuous service with the Company after the Effective Date of this Program, or (ii) "Normal Retirement" unless the Participant shall also have attained the age of sixty-two (62).

9.Responsibilities of the Committee. In addition to the authority granted to the Committee under the Plan, the Committee has responsibility for all aspects of the Program's administration, including but not limited to: ensuring that the Program is administered in accordance with the provisions of the Program and the Plan; approving Participants; authorizing Performance Share Unit awards to Participants; and adjusting Performance Share Units as authorized hereunder consistent with the terms of the Program. The ministerial responsibility of the Program (e.g., management of day-to-day matters) is a function that has been delegated to the Company's officers as permitted by the terms of the Plan and in compliance with applicable law and regulation. All decisions of the Committee under the Program shall be final, conclusive and binding on all interest parties. No member of the Committee shall be liable for any action or determination made in good faith on the Program or any Performance Share Units awarded thereunder.

10.Tax Consequences/Withholding.

10.1It is intended that: (i) a Participant's Performance Share Units shall be considered to be subject to a substantial risk of forfeiture in accordance with those terms as defined in Section 409A and 3121(v)(2) of the Code; and (ii) a Participant shall have merely an unfunded, unsecured promise to be paid a benefit, and such unfunded promise shall not consist of a transfer of "property" within the meaning of Code Section 83.

10.2A Participant shall timely remit to the Company all applicable federal, state and local income and employment taxes (including taxes of any foreign jurisdiction) which the Company is required to withhold at any time with respect to the Performance Share Units. Such payment shall be made to the Company in full, in cash or check, or as otherwise authorized under the terms of the Plan.

10.3This Program is intended to be excepted from coverage under Section 409A of the Code and the regulations promulgated thereunder and shall be administered, interpreted and construed accordingly. Notwithstanding any provision of this Program to the contrary, if any benefit provided under this Program is subject to the provisions of Section 409A of the Code and the regulations issued thereunder (and not excepted therefrom), the provisions of the Program shall be administered, interpreted and construed in a manner necessary to comply with Section 409A (or disregarded to the extent such provision cannot be so administered, interpreted, or construed). Notwithstanding, Section 409A may impose upon the Participant certain taxes or other charges for which the Participant is and shall remain solely responsible, and nothing contained in this Program or the Plan shall be construed to obligate any member of the Committee or Board, the Company or any Affiliate (or its employees, officers or directors) for any such taxes or other charges.

10.4Notwithstanding any provision of the Program to the contrary, if an award of Performance Share Units under this Program is intended to qualify as performance-based compensation under Section 162(m) of the Code and the regulations issued thereunder and a provision of this Program would prevent such award from so qualifying, such provision shall be administered, interpreted and construed to carry out such intention (or disregarded to the extent such provision cannot be so administered, interpreted or construed).

11.Non-Competition.

11.1The Participants hereunder agree that this Section 11 is reasonable and necessary in order to protect the legitimate business interests and goodwill of the Company, including the Company's trade secrets, valuable confidential business and professional information, substantial relationships with prospective and existing customers and clients, and specialized training provided to Participants and other employees of the Company. The Participants acknowledge and recognize the highly competitive nature of the business of the Company and its Affiliates and accordingly agree that during the term of each of their employment and for a period of two (2) years after the termination thereof:

(a)The Participants will not directly or indirectly engage in any business substantially similar to any line of business conducted by the Company or any of its Affiliates, including, but not limited to, where such engagement is as an officer, director, proprietor, employee, partner, investor (other than as a holder of less than 1% of the outstanding capital stock of a publicly traded corporation), consultant, advisor, agent or sales representative, in any geographic region in which the Company or any of its Affiliates conducted business;

(b)The Participants will not contact, solicit, perform services for, or accept business from any customer or prospective customer of the Company or any of its Affiliates;

(c)The Participants will not directly or indirectly induce any employee of the Company or any of its Affiliates to: (1) engage in any activity or conduct which is prohibited pursuant to subparagraph 11.1(a); or (2) terminate such employee's employment with the Company or any of its Affiliates. Moreover, the Participants will not directly or indirectly employ or offer employment (in connection with any business substantially similar to any line of business conducted by the Company or any of its Affiliates) to any person who was employed by the Company or any of its Affiliates unless such person shall have ceased to be employed by the Company or any of its Affiliates for a period of at least 12 months; and

(d)The Participants will not directly or indirectly assist others in engaging in any of the activities, which are prohibited under subparagraphs (a) - (c) above.

11.2It is expressly understood and agreed that although the Participants and the Company consider the restrictions contained in this Section 11 to be reasonable, if a final judicial determination is made by a court of competent jurisdiction that the time or territory or any other restriction contained in this Program is an unenforceable restriction against any Participant, the provisions of this Program shall not be rendered void but shall be deemed amended to apply as to such maximum time and territory and to such maximum extent as such court may judicially determine or indicate to be enforceable against such Participant. Alternatively, if any court of competent jurisdiction finds that any restriction contained in this Program is unenforceable, and such restriction cannot be amended so as to make it enforceable, such finding shall not affect the enforceability of any of the other restrictions contained herein. The restrictive covenants set forth in this Section 11 shall be extended by any amount of time that a Participant is in breach of such covenants, such that the Company receives the full benefit of the time duration set forth above.

12.Confidential Information and Trade Secrets. The Participants and the Company agree that certain materials, including, but not limited to, information, data and other materials relating to customers, development programs, costs, marketing, trading, investment, sales activities, promotion, credit and financial data, manufacturing processes, financing methods, plans or the business and affairs of the Company and its Affiliates, constitute proprietary confidential information and trade secrets. Accordingly, the Participants will not at any time during or after a Participant's employment with the Company (including any Affiliate) disclose or use for such Participant's own benefit or purposes or the benefit or purposes of any other person, firm, partnership, joint venture, association, corporation or other business organization, entity or enterprise other than the Company and any of its Affiliates, any proprietary confidential information or trade secrets, provided that the foregoing shall not apply to information which is not unique to the Company or any of its Affiliates or which is generally known to the industry or the public other than as a result of such Participant's breach of this covenant. The Participants agree that upon termination of employment with the Company

(including any Affiliate) for any reason, the Participants will immediately return to the Company all memoranda, books, papers, plans, information, letters and other data, and all copies thereof or therefrom, which in any way relate to the business of the Company and its Affiliates, except that the Participants may retain personal notes, notebooks and diaries. The Participants further agree that the Participants will not retain or use for their own account at any time any trade names, trademark or other proprietary business designation used or owned in connection with the business of the Company or any of its Affiliates.

13.Remedies/Forfeiture.

13.1The Participants acknowledge that a violation or attempted violation on a Participant's part of Sections 11 and 12 will cause irreparable damage to the Company and its Affiliates, and the Participants therefore agree that the Company and its Affiliates shall be entitled as a matter of right to an injunction, out of any court of competent jurisdiction, restraining any violation or further violation of such promises by the Participants or a Participant's employees, partners or agents. The Participants agree that such right to an injunction is cumulative and in addition to whatever other remedies the Company (including any Affiliate) may have under law or equity. Specifically, the Participants agree that such right to an injunction is cumulative and in addition to the Participants' obligations to make timely payment to the Company as set forth in Section 13.2 of this Program. The Participants further acknowledge and agree that a Participant's Performance Share Units shall be cancelled and forfeited without payment by the Company if such Participant breaches any of his or her obligations set forth in Sections 11 and 12 herein.

13.2At any point after becoming aware of a breach of any obligation set forth in Sections 11 and 12 of this Program, the Company shall provide notice of such breach to a Participant. By agreeing to participate in this Program, the Participants agree that within ten (10) days after the date the Company provides such notice, a Participant shall pay to the Company in cash an amount equal to any and all distributions paid to or on behalf of such Participant under of this Program within the six (6) months prior to the date of the earliest breach. The Participants agree that failure to make such timely payment to the Company constitutes an independent and material breach of the terms and conditions of this Program, for which the Company may seek recovery of the unpaid amount as liquidated damages, in addition to all other rights and remedies the Company may have resulting from a Participant's breach of the obligations set forth in Sections 11 and 12. The Participants agree that timely payment to the Company as set forth in this provision of the Program is reasonable and necessary because the compensatory damages that will result from breaches of Sections 11 and/or 12 cannot readily be ascertained. Further, the Participants agree that timely payment to the Company as set forth in this provision of the Program is not a penalty, and it does not preclude the Company from seeking all other remedies that may be available to the Company, including without limitation those set forth in this Section 13.

14.Assignment/Nonassignment.

14.1The Company shall have the right to assign this Program, including without limitation Sections 11 and 12, and the Participants agree to remain obligated by all provisions of this Program that are assigned to any successor, assign or surviving entity. Any successor to the Company is an intended third party beneficiary of this Program.

14.2The Performance Share Units shall not be sold, pledged, assigned, hypothecated, transferred or disposed of (a "Transfer") in any manner, other than by will or the laws of descent and distribution. Any attempt by a Participant to Transfer the Performance Share Units in violation of the terms of the Program shall render the Performance Share Units null and void, and result in the immediate forfeiture of such Performance Share Units, without payment by the Company.

15.Impact on Benefit Plans. Payments under the Program shall not be considered as earnings for purposes of the Company's and/or Affiliate's qualified retirement plans or any such retirement or benefit plan unless specifically provided for therein. Nothing herein shall prevent the Company or any Affiliate from maintaining additional compensation plans and arrangements for its employees.

16.Successors; Changes in Stock. The obligation of the Company under the Program shall be binding upon the successors and assigns of the Company. If a dividend or other distribution shall be declared upon the Company's common stock payable in shares of Company common stock, the Performance Share Units and the shares of Company common stock on which the Performance Condition is based shall be adjusted by adding thereto the number of shares of Company common stock which would have been distributable thereon if such shares and Performance Share Units had been actual Company shares and outstanding on the date fixed for determining the stockholders entitled to receive such stock dividend or distribution. In the event of any spin-off, split-off or split-up, dividend in property other than cash, recapitalization or other change in the capital structure of the Company, or any merger, consolidation, reorganization, partial or complete liquidation or other distribution of assets (other than a normal cash dividend), or any other corporate transaction or event having an effect similar to any of the foregoing, or extraordinary distribution to stockholders of the Company's common stock, the Performance Share Units and the shares of Company common stock on which the Performance Condition is based shall be appropriately adjusted to prevent dilution or enlargement of the rights of Participants which would otherwise result from any such transaction, provided such adjustment shall be consistent with Code Section 162(m) and Section 409A, as applicable.

In the case of a Change in Control, any obligation under the Program shall be handled in accordance with the terms of Sections 6 hereof. In any case not constituting a Change in Control in which the Company's common stock is changed into or becomes exchangeable for a different number or kind of shares of stock or other securities of the Company or another corporation, or cash or other property, whether through reorganization, reclassification, recapitalization, stock split-up, combination of shares, merger or consolidation, then (i) the value of the Performance Share Units constituting an award shall be calculated based on the closing price of such common stock on the closing date of the transaction on the principal market on which such common stock is traded, (ii) there shall be substituted for each Performance Share Unit constituting an award, the number and kind of shares of stock or other securities (or cash or other property) into which each outstanding share of the Company's common stock shall be so changed or for which each such share shall be exchangeable, and (iii) the share of Company common stock on which the Performance Condition is based shall be appropriately and equitably adjusted, provided any such adjustments shall be consistent with Code Section 162(m) and Section 409A, as applicable. In the case of any such adjustment, the Units shall remain subject to the terms of the Program.

17.Governing Law, Jurisdiction, and Venue.

17.1This Program shall be governed by and construed in accordance with the laws of the State of Delaware, without giving effect to the principles of conflicts of law.

17.2Participant hereby irrevocably submits to the personal and exclusive jurisdiction of the United States District Court for the Western District of Pennsylvania or the Court of Common Pleas of Allegheny County, Pennsylvania in any action or proceeding arising out of, or relating to, this Program (whether such action or proceeding arises under contract, tort, equity or otherwise). Participant hereby irrevocably waives any objection which Participant now or hereafter may have to the laying of venue or personal jurisdiction of any such action or proceeding brought in said courts.

17.3Jurisdiction over, and venue of, any such action or proceeding shall be exclusively vested in the United States District Court for the Western District of Pennsylvania or the Court of Common Pleas of Allegheny County, Pennsylvania.

17.4Provided that the Company commences any such action or proceeding in the courts identified in Section 17(3), Participant irrevocably waives Participant's right to object to or challenge the above selected forum on the basis of inconvenience or unfairness under 28 U.S.C. § 1404, 42 Pa. C.S. § 5322 or similar state or federal statutes. Participant agrees to reimburse the Company for all of the attorneys fees and costs it incurs to oppose Participant's efforts to challenge or object to litigation proceeding in the courts identified in Section 17(3) with respect to actions arising out of or relating to this Program (whether such actions arise under contract, tort, equity or otherwise).

18.Failure to Enforce Not a Waiver. The failure of the Company to enforce at any time any provision of

this Program shall in no way be construed to be a waiver of such provision or of any other provision hereof.

19.Severability. In the event that any one or more of the provisions of this Program shall be held to be invalid, illegal or unenforceable, the validity, legality or enforceability of the remaining provisions shall not in any way be affected or impaired thereby.

20.Funding. The Program is not funded and all amounts payable hereunder, if any, shall be paid from the general assets of the Company or its Affiliate, as applicable. No provision contained in this Program or the Plan and no action taken pursuant to the provisions of this Program or the Plan shall create a trust of any kind or require the Company to maintain or set aside any specific funds to pay benefits hereunder. To the extent a Participant acquires a right to receive payments from the Company under the Program, such right shall be no greater than the right of any unsecured general creditor of the Company.

21.Headings. The descriptive headings of the Sections of this Program are inserted for convenience of reference only and shall not constitute a part of this Program.

22.Amendment or Termination of this Program. This Program may be modified, amended, suspended or terminated by the Committee at any time; provided, however, that no modification, amendment, suspension or termination of this Plan shall adversely affect the rights of a Participant under the Program without the consent of such Participant. Notwithstanding the foregoing or any provision of this Program to the contrary, that the Company may, in its sole discretion and without the Participant's consent, modify or amend the terms of the Program or a Performance Share Unit award, or take any other action it deems necessary or advisable, to cause the Program to comply with Section 409A or Section 162(m) (or an exception thereto). Any modification, amendment, suspension or termination shall only be effective upon a writing issued by the Company, and a Participant shall not offer evidence of any purported oral modifications or amendments to vary or contradict the terms of this Program document.

IN WITNESS WHEREOF, the undersigned have executed this Program on the day and year indicated below. This Program may be executed in more than one counterpart, each of which is deemed to be an original and all of which taken together constitute one and the same agreement.

Dated:March 29, 2011/s/ J. Brett Harvey

J. Brett Harvey, Chairman, on behalf of the Board of Directors

Dated:February 25, 2011/s/ William Powell

William Powell, Chairman, on behalf of the Compensation Committee

ATTACHMENT A

Total Stockholder Return Peer Companies*

Alliance Resource Partners, L.P.	International Coal Group Inc.
Alpha Natural Resources, Inc.	James River Coal Company
Anadarko Petroleum Corporation	Massey Energy Company
Apache Corporation	Newfield Exploration Company
Arch Coal Inc.	Nexen Inc.
Cabot Oil & Gas Corporation	Noble Energy Inc.
Callon Petroleum Co/DE	Peabody Energy Corporation
Chesapeake Energy Corporation	Penn Virginia Corporation
Cimarex Energy Co.	Pioneer Natural Resources Company
Comstock Resources Inc.	Rio Tinto Group (GBR) - ADR
Denbury Resources Inc.	St. Mary Land & Explor Company
Devon Energy Corporation	Stone Energy Corporation
Encana Corporation	Ultra Petroleum Corporation
EOG Resources, Inc.	Westmoreland Coal Company

*In the event a Peer Group company ceases to exist during the performance period, such Peer Group company shall be excluded from the calculation of Total Shareholder Return; provided, however, that any Peer Group company that is liquidated and/or files for Chapter 11 reorganization would not be deemed excluded, but rather would automatically be deemed to be in "last place" for purposes of calculating Total Shareholder Return.

EX-10.4

CONSOL ENERGY INC.

EQUITY INCENTIVE PLAN

FORM OF PERFORMANCE SHARE UNIT AWARD AGREEMENT

This Performance Share Unit Award Agreement set forth below (this “Agreement”) is dated as of the grant date (the “Grant Date”) set forth on Exhibit A and is between CONSOL Energy Inc., a Delaware corporation (the “Company”), and the individual to whom the Compensation Committee of the Board of Directors (the “Committee”) of the Company has made this Performance Award and whose name is set forth on Exhibit A (the “Participant”).

The Company has established the CONSOL Energy Inc. Equity Incentive Plan, as amended (the “Plan”), to advance the interests of the Company and its stockholders by providing incentives to certain eligible persons who contribute significantly to the strategic and long-term performance objectives and growth of the Company. Unless the context otherwise requires, all capitalized terms not otherwise defined in this Agreement have the same meaning given such capitalized terms in the Plan.

Pursuant to the provisions of the Plan, the Committee has full power and authority to direct the execution and delivery of this Agreement in the name and on behalf of the Company, and has authorized the execution and delivery of this Agreement.

Agreement

1.Performance Share Unit Award. Subject to and pursuant to all terms and conditions stated in this Agreement and in the Plan, as of the Grant Date, the Company hereby makes a Performance Award to the Participant in the form of performance share units (the “Performance Share Units”) with the target number set forth on Exhibit A. Each Performance Share Unit awarded under this Agreement shall represent a contingent right to receive one share of the Company's common stock as described more fully herein, to the extent such Performance Share Unit is earned and becomes payable pursuant to the terms of this Agreement. Notwithstanding, Performance Share Units as initially awarded have no independent economic value, but rather are mere units of measurement used for purposes of calculating the value of benefits, if any, to be paid under this Agreement.

2.Performance Period. The “Performance Period” means the performance period as set forth on Exhibit A.

3.Performance Goals of the Performance Share Units. Subject to the provisions of this Agreement, the total number of Performance Share Units awarded Participant will be earned (at a maximum award level of 200% of the target number of Performance Share Units awarded), if the performance measures set forth on Exhibit A are satisfied (each, a “Performance Goal”); provided, however, that the Committee has sole discretion to determine whether the goals are met. As a condition to receiving this Award, Participant agrees that all determinations made by the Committee are final and conclusive. Notwithstanding any provision of the Plan or this Agreement to the contrary, (i) the Committee, in its sole discretion, may reduce the amount of any Performance Share Units that would otherwise be earned by the Participant upon attainment of the Performance Goals if it concludes that such reduction is necessary or appropriate in accordance with any negative discretion guidelines established by the Committee and set forth on Exhibit A, and (ii) the Committee shall not use its discretionary authority to increase the number of Performance Share Units that would otherwise be earned upon attainment of the Performance Goals.

4.Issuance and Distribution.

4.1After the end of the Performance Period, the Committee shall certify in writing prior to payment the extent to which the applicable Performance Goal and any other material terms of this Agreement have been achieved. For purposes of this provision, and for so long as the Code permits, the approved minutes of the Committee meeting in which the certification is made may be treated as written certification.

4.2Subject to the terms and conditions of this Agreement, Performance Share Units earned by the Participant will be settled and paid in shares of the Company's common stock in the first calendar year immediately following the end of the Performance Period on a date determined in the Committee's discretion, but in no event later than March 15th of such year (the “Payment Date”).

4.3Notwithstanding any other provision of this Agreement, in the event of a Change in Control, the Performance Goals will be deemed to have been achieved (at a target award level of 100% of Performance Share Units awarded) and the value of such units will be settled on the closing date of the Change in Control transaction (the “CiC Payment Date”); provided, further, in the event of a Change in Control, Performance Share Units may, in the Committee's discretion, be settled in cash and/or securities or other property.

5.Dividends. Each Performance Share Unit will be cumulatively credited with dividends that are paid on the Company's common stock in the form of additional units. These additional units shall be deemed to have been purchased on the record date for the dividend using the closing stock price of the Company's common stock as reported in The Wall Street Journal and shall be subject to all the same conditions and restrictions as provided in this Agreement applicable to Performance Share Units.

6.Change in Participant's Status.

6.1In the event the Participant Separates from Service (i) on or after the date the Participant has reached the age of 55 by reason of an “Early Retirement” or “Incapacity Retirement,” (ii) by reason of a “Normal Retirement,” (iii) on account of death or Disability (other than an Incapacity Retirement), or (iv) by reason of a reduction in force as specified and implemented by the Company, prior to the Payment Date or the CiC Payment Date, as applicable, the Participant shall be entitled to retain the Performance Share Units and receive payment therefore to the extent earned and payable pursuant to the provisions of this Agreement; provided, however, that in the case of a Separation from Service on account of Disability, the Participant shall only be entitled to retain a prorated portion of the Performance Share Units determined at the end of the Performance Period and based on the ratio of the number of complete months the Participant is employed or serves during the Performance Period to the total number of months in the Performance Period. In the event the Participant Separates from Service for any other reason, including, but not limited to, by the Participant voluntarily, or by the Company with Cause or without Cause (other than in connection with a reduction in force as specified above), prior to the Payment Date or the CiC Payment Date, as applicable, the Performance Share Units awarded to the Participant shall be cancelled and forfeited, whether payable or not, without payment by the Company or any Affiliate. Any payments due a deceased Participant shall be paid to his estate as provided herein after the end of the Performance Period.

6.2For purposes of the Agreement: the terms “Early Retirement,” “Incapacity Retirement” and “Normal Retirement,” shall have the meanings ascribed thereto under the CONSOL Energy Inc. Employee Retirement Plan, as amended, or any successor thereto applicable to the Participant; provided, however, for purposes of the Agreement the Participant shall not be considered to have Separated from Service on account of (i) “Early Retirement” unless the Participant shall also have completed at least one year of continuous service with the Company after the Grant Date of this Agreement, or (ii) “Normal Retirement” unless the Participant shall also have attained the age of sixty-two (62).

7.Tax Consequences/Withholding.

7.1It is intended that: (i) the Participant's Performance Share Units shall be considered to be subject to a substantial risk of forfeiture in accordance with those terms as defined in Section 409A and 3121(v)(2) of the Code; and (ii) the Participant shall have merely an unfunded, unsecured promise to be paid a benefit, and such unfunded promise shall not consist of a transfer of “property” within the meaning of Code Section 83.

7.2The Participant shall timely remit to the Company all applicable federal, state and local income and employment taxes (including taxes of any foreign jurisdiction) which the Company is required to withhold at any time with respect to the Performance Share Units. Such payment shall be made to the Company in

full, in cash or check, or as otherwise authorized under the terms of the Plan.

7.3This Agreement is intended to be excepted from coverage under Section 409A of the Code and the regulations promulgated thereunder and shall be administered, interpreted and construed accordingly. Notwithstanding any provision of this Agreement to the contrary, if any benefit provided under this Agreement is subject to the provisions of Section 409A of the Code and the regulations issued thereunder (and not excepted therefrom), the provisions of the Agreement shall be administered, interpreted and construed in a manner necessary to comply with Section 409A (or disregarded to the extent such provision cannot be so administered, interpreted, or construed). Notwithstanding, Section 409A may impose upon the Participant certain taxes or other charges for which the Participant is and shall remain solely responsible, and nothing contained in this Agreement or the Plan shall be construed to obligate any member of the Committee or Board, the Company or any Affiliate (or its employees, officers or directors) for any such taxes or other charges.

7.4Notwithstanding any provision of this Agreement to the contrary, if an award of Performance Share Units under this Agreement is intended to qualify as performance-based compensation under Section 162(m) of the Code and the regulations issued thereunder and a provision of this Agreement would prevent such award from so qualifying, such provision shall be administered, interpreted and construed to carry out such intention (or disregarded to the extent such provision cannot be so administered, interpreted or construed).

8.Non-Competition.

8.1The Participant hereby agrees that this Section 8 is reasonable and necessary in order to protect the legitimate business interests and goodwill of the Company, including the Company's trade secrets, valuable confidential business and professional information, substantial relationships with prospective and existing customers and clients, and specialized training provided to the Participant and other employees of the Company. The Participant acknowledges and recognizes the highly competitive nature of the business of the Company and its Affiliates and accordingly agrees that during the term of each of the Participant's employment and for a period of two (2) years after the termination thereof:

(a)The Participant will not directly or indirectly engage in any business substantially similar to any line of business conducted by the Company or any of its Affiliates, including, but not limited to, where such engagement is as an officer, director, proprietor, employee, partner, investor (other than as a holder of less than 1% of the outstanding capital stock of a publicly traded corporation), consultant, advisor, agent or sales representative, in any geographic region in which the Company or any of its Affiliates conducted business;

(b)The Participant will not contact, solicit, perform services for, or accept business from any customer or prospective customer of the Company or any of its Affiliates;

(c)The Participant will not directly or indirectly induce any employee of the Company or any of its Affiliates to: (1) engage in any activity or conduct which is prohibited pursuant to subparagraph 8.1(a); or (2) terminate such employee's employment with the Company or any of its Affiliates. Moreover, the Participant will not directly or indirectly employ or offer employment (in connection with any business substantially similar to any line of business conducted by the Company or any of its Affiliates) to any person who was employed by the Company or any of its Affiliates unless such person shall have ceased to be employed by the Company or any of its Affiliates for a period of at least 12 months; and

(d)The Participant will not directly or indirectly assist others in engaging in any of the activities, which are prohibited under subparagraphs (a) - (c) above.

8.2It is expressly understood and agreed that although the Participant and the Company consider the restrictions contained in this Section 8 to be reasonable, if a final judicial determination is made by a court of competent jurisdiction that the time or territory or any other restriction contained in this Agreement is an unenforceable restriction against the Participant, the provisions of this Agreement shall not be rendered void but

shall be deemed amended to apply as to such maximum time and territory and to such maximum extent as such court may judicially determine or indicate to be enforceable against such Participant. Alternatively, if any court of competent jurisdiction finds that any restriction contained in this Agreement is unenforceable, and such restriction cannot be amended so as to make it enforceable, such finding shall not affect the enforceability of any of the other restrictions contained herein. The restrictive covenants set forth in this Section 8 shall be extended by any amount of time that the Participant is in breach of such covenants, such that the Company receives the full benefit of the time duration set forth above.

9.Confidential Information and Trade Secrets. The Participant and the Company agree that certain materials, including, but not limited to, information, data and other materials relating to customers, development programs, costs, marketing, trading, investment, sales activities, promotion, credit and financial data, manufacturing processes, financing methods, plans or the business and affairs of the Company and its Affiliates, constitute proprietary confidential information and trade secrets. Accordingly, the Participant will not at any time during or after the Participant's employment with the Company (including any Affiliate) disclose or use for such Participant's own benefit or purposes or the benefit or purposes of any other person, firm, partnership, joint venture, association, corporation or other business organization, entity or enterprise other than the Company and any of its Affiliates, any proprietary confidential information or trade secrets, provided that the foregoing shall not apply to information which is not unique to the Company or any of its Affiliates or which is generally known to the industry or the public other than as a result of such Participant's breach of this covenant. The Participant agrees that upon termination of employment with the Company (including any Affiliate) for any reason, the Participant will immediately return to the Company all memoranda, books, papers, plans, information, letters and other data, and all copies thereof or therefrom, which in any way relate to the business of the Company and its Affiliates, except that the Participant may retain personal notes, notebooks and diaries. The Participant further agrees that the Participant will not retain or use for the Participant's own account at any time any trade names, trademark or other proprietary business designation used or owned in connection with the business of the Company or any of its Affiliates.

10.Remedies/Forfeiture.

10.1The Participant acknowledges that a violation or attempted violation on the Participant's part of Sections 8 and/or 9 will cause irreparable damage to the Company and its Affiliates, and the Participant therefore agrees that the Company and its Affiliates shall be entitled as a matter of right to an injunction, out of any court of competent jurisdiction, restraining any violation or further violation of such promises by the Participants or the Participant's employees, partners or agents. The Participant agrees that such right to an injunction is cumulative and in addition to whatever other remedies the Company (including any Affiliate) may have under law or equity. Specifically, the Participant agrees that such right to an injunction is cumulative and in addition to the Participants' obligations to make timely payment to the Company as set forth in Section 10.2 of this Agreement. The Participant further acknowledges and agrees that the Participant's Performance Share Units shall be cancelled and forfeited without payment by the Company if the Participant breaches any of his obligations set forth in Sections 8 and 9 herein.

10.2At any point after becoming aware of a breach of any obligation set forth in Sections 8 and 9 of this Agreement, the Company shall provide notice of such breach to the Participant. By agreeing to receive the Performance Share Units pursuant to this Agreement, the Participant agrees that within ten (10) days after the date the Company provides such notice, the Participant shall pay to the Company in cash an amount equal to any and all distributions paid to or on behalf of such Participant under this Agreement within the six (6) months prior to the date of the earliest breach. The Participant agrees that failure to make such timely payment to the Company constitutes an independent and material breach of the terms and conditions of this Agreement, for which the Company may seek recovery of the unpaid amount as liquidated damages, in addition to all other rights and remedies the Company may have resulting from the Participant's breach of the obligations set forth in Sections 8 and/or 9. The Participant agrees that timely payment to the Company as set forth in this provision of this Agreement is reasonable and necessary because the compensatory damages that will result from breaches of Sections 8 and/or 9 cannot readily be ascertained. Further, the Participant agrees that timely payment to the Company as set forth in this provision of this Agreement is not a penalty, and it does not preclude the Company

from seeking all other remedies that may be available to the Company, including without limitation those set forth in this Section 10.

11.Assignment/Nonassignment.

11.1The Company shall have the right to assign this Agreement, including without limitation Sections 8 and/or 9, and the Participant agrees to remain obligated by all provisions of this Agreement that are assigned to any successor, assign or surviving entity. Any successor to the Company is an intended third party beneficiary of this Agreement.

11.2The Performance Share Units shall not be sold, pledged, assigned, hypothecated, transferred or disposed of (a “Transfer”) in any manner, other than by will or the laws of descent and distribution. Any attempt by the Participant to Transfer the Performance Share Units in violation of the terms of this Agreement shall render the Performance Share Units null and void, and result in the immediate forfeiture of such Performance Share Units, without payment by the Company.

12.Impact on Benefit Plans. Payments under this Agreement shall not be considered as earnings for purposes of the Company's and/or Affiliate's qualified retirement plans or any such retirement or benefit plan unless specifically provided for therein. Nothing herein shall prevent the Company or any Affiliate from maintaining additional compensation plans and arrangements for its employees.

13.Successors; Changes in Stock. The obligation of the Company under this Agreement shall be binding upon the successors and assigns of the Company. If a dividend or other distribution shall be declared upon the Company's common stock payable in shares of Company common stock, the Performance Share Units and the shares of Company common stock on which the Performance Goals are based shall be adjusted by adding thereto the number of shares of Company common stock which would have been distributable thereon if such shares and Performance Share Units had been actual Company shares and outstanding on the date fixed for determining the stockholders entitled to receive such stock dividend or distribution. In the event of any spin-off, split-off or split-up, dividend in property other than cash, recapitalization or other change in the capital structure of the Company, or any merger, consolidation, reorganization, partial or complete liquidation or other distribution of assets (other than a normal cash dividend), or any other corporate transaction or event having an effect similar to any of the foregoing, or extraordinary distribution to stockholders of the Company's common stock, the Performance Share Units, the shares of Company common stock relating to the Performance Share Units, and the Performance Goals shall be appropriately adjusted to prevent dilution or enlargement of the rights of Participants which would otherwise result from any such transaction, provided such adjustment shall be consistent with Code Section 162(m) and Section 409A, as applicable.

In the case of a Change in Control, any obligation under this Agreement shall be handled in accordance with the terms of Section 4 hereof. In any case not constituting a Change in Control in which the Company's common stock is changed into or becomes exchangeable for a different number or kind of shares of stock or other securities of the Company or another corporation, or cash or other property, whether through reorganization, reclassification, recapitalization, stock split-up, combination of shares, merger or consolidation, then (i) the value of the Performance Share Units constituting an award shall be calculated based on the closing price of such common stock on the closing date of the transaction on the principal market on which such common stock is traded, (ii) there shall be substituted for each Performance Share Unit constituting an award, the number and kind of shares of stock or other securities (or cash or other property) into which each outstanding share of the Company's common stock shall be so changed or for which each such share shall be exchangeable, and (iii) the share of Company common stock on which the Performance Goals are based shall be appropriately and equitably adjusted, provided any such adjustments shall be consistent with Code Section 162(m) and Section 409A, as applicable. In the case of any such adjustment, the Performance Share Units shall remain subject to the terms of the Agreement.

14.Governing Law, Jurisdiction, and Venue.

14.1This Agreement shall be governed by and construed in accordance with the laws of the State of Delaware, without giving effect to the principles of conflicts of law.

14.2The Participant hereby irrevocably submits to the personal and exclusive jurisdiction of the United States District Court for the Western District of Pennsylvania or the Court of Common Pleas of Allegheny County, Pennsylvania in any action or proceeding arising out of, or relating to, this Agreement (whether such action or proceeding arises under contract, tort, equity or otherwise). The Participant hereby irrevocably waives any objection which the Participant now or hereafter may have to the laying of venue or personal jurisdiction of any such action or proceeding brought in said courts.

14.3Jurisdiction over, and venue of, any such action or proceeding shall be exclusively vested in the United States District Court for the Western District of Pennsylvania or the Court of Common Pleas of Allegheny County, Pennsylvania.

14.4Provided that the Company commences any such action or proceeding in the courts identified in Section 14.3, the Participant irrevocably waives the Participant's right to object to or challenge the above selected forum on the basis of inconvenience or unfairness under 28 U.S.C. § 1404, 42 Pa. C.S. § 5322 or similar state or federal statutes. The Participant agrees to reimburse the Company for all of the attorneys fees and costs it incurs to oppose the Participant's efforts to challenge or object to litigation proceeding in the courts identified in Section 14.3 with respect to actions arising out of or relating to this Agreement (whether such actions arise under contract, tort, equity or otherwise).

15.Failure to Enforce Not a Waiver. The failure of the Company to enforce at any time any provision of this Agreement shall in no way be construed to be a waiver of such provision or of any other provision hereof.

16.Severability. In the event that any one or more of the provisions of this Agreement shall be held to be invalid, illegal or unenforceable, the validity, legality or enforceability of the remaining provisions shall not in any way be affected or impaired thereby.

17.Funding. This Agreement is not funded and all amounts payable hereunder, if any, shall be paid from the general assets of the Company or its Affiliate, as applicable. No provision contained in this Agreement or the Plan and no action taken pursuant to the provisions of this Agreement or the Plan shall create a trust of any kind or require the Company to maintain or set aside any specific funds to pay benefits hereunder. To the extent the Participant acquires a right to receive payments from the Company under this Agreement, such right shall be no greater than the right of any unsecured general creditor of the Company.

18.Headings. The descriptive headings of the Sections of this Agreement are inserted for convenience of reference only and shall not constitute a part of this Agreement.

19.Amendment or Termination of this Agreement. This Agreement may be modified, amended, suspended or terminated by the Committee at any time; provided, however, that no modification, amendment, suspension or termination of the Plan or this Agreement shall adversely affect the rights of the Participant under this Agreement without the consent of such Participant. Notwithstanding the foregoing or any provision of this Agreement to the contrary, the Company may, in its sole discretion and without the Participant's consent, modify or amend the terms of the Agreement or a Performance Share Unit award, or take any other action it deems necessary or advisable, to cause the Agreement to comply with Section 409A or Section 162(m) (or an exception thereto). Any modification, amendment, suspension or termination shall only be effective upon a writing issued by the Company, and the Participant shall not offer evidence of any purported oral modifications or amendments to vary or contradict the terms of this Agreement document.

[Remainder of this page intentionally left blank]

IN WITNESS WHEREOF, the undersigned have executed this Agreement on the day and year indicated

below. This Agreement may be executed in more than one counterpart, each of which is deemed to be an original and all of which taken together constitute one and the same agreement.

PARTICIPANT

Dated: March __, 20__

CONSOL ENERGY INC.

Dated: March __, 20__                

Exhibit A

Participant:

Grant Date:

Performance Share Units (Target):

Performance Period:

Performance Goals:

EX-10.5

SEVENTH AMENDMENT TO AMENDED AND RESTATED

RECEIVABLES PURCHASE AGREEMENT

THIS SEVENTH AMENDMENT TO AMENDED AND RESTATED RECEIVABLES PURCHASE AGREEMENT (this “Amendment”), dated as of March 30, 2012, is entered into among CNX FUNDING CORPORATION, (the “Seller”), CONSOL ENERGY INC. (“CONSOL Energy”), as the initial Servicer (in such capacity, the “Servicer”), the various Sub-Servicers listed on the signature pages hereto, the Conduit Purchasers listed on the signature pages hereto, the Purchaser Agents listed on the signature pages hereto, the LC Participants listed on the signature pages hereto and PNC BANK, NATIONAL ASSOCIATION, as Administrator (in such capacity, the “Administrator”) and as LC Bank (in such capacity, the “LC Bank”).

RECITALS

1.Reference is made to that certain Amended and Restated Receivables Purchase Agreement, dated as of April 30, 2007 (as amended, restated, supplemented or otherwise modified, the “Agreement”) by and among the Seller, the Servicer, the various Sub-Servicers, Conduit Purchasers, Purchaser Agents and LC Participants party thereto, the Administrator and the LC Bank; and

2.The parties hereto desire to amend the Agreement as hereinafter set forth.

NOW THEREFORE, for good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties agree as follows:

SECTION 1.Certain Defined Terms. Capitalized terms that are used but not defined herein shall have the meanings set forth in the Agreement.

SECTION 2.Amendment to the Agreement. The definition of “Facility Termination Date” set forth in Exhibit I to the Agreement is hereby amended by deleting the date “April 30, 2012” where it appears therein and replacing it with the date “March 30, 2017”.

SECTION 3.Representations and Warranties. Each of the Seller, CONSOL Energy, the Servicer and the Sub-Servicers hereby represents and warrants to the Administrator, the Purchaser Agents and the Purchasers as follows:

(a)Representations and Warranties. The representations and warranties made by it in the Transaction Documents are true and correct as of the date hereof (unless stated to relate solely to an earlier date, in which case such representations or warranties were true and correct as of such earlier date).

(b)Enforceability. The execution and delivery by such Person of this Amendment, and the performance of each of its obligations under this Amendment and the Agreement, as amended hereby, are within each of its corporate powers and have been duly authorized by all necessary corporate action on its part. This Amendment and the Agreement, as amended hereby, are such Person's valid and legally binding obligations, enforceable in accordance with its terms.

(c)No Default. Both before and immediately after giving effect to this Amendment and the transactions contemplated hereby, no Termination Event or Unmatured Termination Event exists or shall exist.

SECTION 4.Effect of Amendment. All provisions of the Agreement, as expressly amended and modified by this Amendment, shall remain in full force and effect. After this Amendment becomes effective, all references in the Agreement (or in any other Transaction Document) to “this Agreement”, “hereof”, “herein” or words of similar effect referring to the Agreement shall be deemed to be references to the Agreement as amended by this Amendment. This Amendment shall not be deemed, either expressly or impliedly, to waive, amend or supplement any provision of the Agreement other than as set forth herein.

SECTION 5.Effectiveness. This Amendment shall become effective as of the date hereof (the “Effective Date”) upon satisfaction of each of the following conditions precedent, each in form and substance satisfactory to the Administrator:

(a)receipt by the Administrator of duly executed counterparts of this Amendment; and

(b)receipt by the Administrator of duly executed counterparts of that Amended and Restated Fee Letter, dated as of the date hereof, by and among the Seller, the Servicer, Market Street Funding LLC, PNC Bank, National Association, as Administrator, Purchaser Agent and LC Bank, the Bank of Novia Scotia, as Purchaser Agent and LC Participant and Liberty Street Funding LLC.

SECTION 6.Counterparts. This Amendment may be executed in any number of counterparts and by different parties on separate counterparts, each of which when so executed shall be deemed to be an original and all of which when taken together shall constitute but one and the same instrument. Delivery of an executed counterpart of a signature page to this Amendment by facsimile or electronic transmission shall be effective as delivery of a manually executed counterpart hereof.

SECTION 7.Governing Law. This Amendment shall be governed by, and construed in accordance with, the internal laws of the State of New York.

SECTION 8.Section Headings. The various headings of this Amendment are included for convenience only and shall not affect the meaning or interpretation of this Amendment, the Agreement or any provision hereof or thereof.

[Signatures begin on next page]

IN WITNESS WHEREOF, the parties have executed this Amendment as of the date first written above.

CNX FUNDING CORPORATION,

as Seller

By: /s/ Christopher C. Jones

     Name: Christopher C. Jones

     Title: Vice President and Secretary

CONSOL ENERGY INC.,

as initial Servicer

By: /s/ John M. Reilly

     Name: John M. Reilly

     Title: Vice President and Treasurer

CNX MARINE TERMINALS INC.,

CONSOL ENERGY SALES COMPANY,

CONSOL OF KENTUCKY INC.,

CONSOL PENNSYLVANIA COAL COMPANY, LLC,

FOLA COAL COMPANY, L.L.C.,

LITTLE EAGLE COAL COMPANY, L.L.C.,

MON RIVER TOWING, INC., and

TERRY EAGLE COAL COMPANY, L.L.C.,

each as a Sub-Servicer

By: /s/ John M. Reilly                    

Name: John M. Reilly

Title: Treasurer

CONSOLIDATION COAL COMPANY,

EIGHTY-FOUR MINING COMPANY,

ISLAND CREEK COAL COMPANY,

KEYSTONE COAL MINING CORPORATION,

MCELROY COAL COMPANY, and

TWIN RIVERS TOWING COMPANY,

each as a Sub-Servicer

By: /s/ Daniel S. Cangilla                

Name: Daniel S. Cangilla

Title: Treasurer

MARKET STREET FUNDING LLC,

as a Conduit Purchaser

By: /s/ Doris J. Hearn                    

Name: Doris J. Hearn

Title: Vice President

PNC BANK, NATIONAL ASSOCIATION,

as Administrator and as Purchaser Agent for Market Street

By: /s/ William P. Falcon                

Name: William P. Falcon

Title: Vice President

PNC BANK, NATIONAL ASSOCIATION,

as the LC Bank and as an LC Participant

By: /s/ Richard C. Munsick                

Name: Richard C. Munsick

Title: Senior Vice President

LIBERTY STREET FUNDING LLC, as a Conduit Purchaser

By: /s/ Jill A. Russo                 

Name: Jill A. Russo

Title: Vice President

THE BANK OF NOVA SCOTIA, as Purchaser Agent for Liberty Street

By: /s/ Norman Last                    

Name: Norman Last

Title: Managing Director

THE BANK OF NOVA SCOTIA,

as an LC Participant

By: /s/ Norman Last                    

Name: Norman Last

Title: Managing Director

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:	April 30, 2012
/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, William J. Lyons, 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:	April 30, 2012
/s/ William J. Lyons
William J. Lyons
Chief Financial Officer and Executive Vice President (Principal Financial and Accounting 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 March 31, 2012, 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:	April 30, 2012
/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, William J. Lyons, 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 March 31, 2012, 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:	April 30, 2012
/s/ William J. Lyons
William J. Lyons
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 March 31, 2012 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 March 31, 2012) 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
Amonate	46-05449	2	—	—	—	—	—	—	No	No	—	—	—
Bailey	36-07230	9	—	—	—	—	19,555	—	No	No	8	1	4
Blacksville 2	46-01968	37	—	—	—	—	164,571	—	No	No	26	4	—
Bronzite II (MT-41)	46-09307	3	—	—	—	—	7,480	—	No	No	6	1	2
Bronzite III (Jacobs)	46-05978	9	—	—	—	—	7,399	—	No	No	4	—	—
Buchanan	44-04856	51	—	2	—	—	247,278	1	No	No	32	4	7
Central Repair Shop	46-03240	—	—	—	—	—	—	—	No	No	—	—	—
Enlow Fork	36-07416	8	—	—	—	1	19,094	—	No	No	10	2	2
Fola Surface	46-08377	3	—	—	—	—	3,040	—	No	No	3	—	1
Ike Fork 5 Block	46-08377	6	—	1	—	—	451	—	No	No	—	—	—
Ireland Dock Loadout	46-01438	—	—	—	—	—	—	—	No	No	6	—	—
Keystone Cleaning Plant	36-08540	1	—	—	—	—	—	—	No	No	—	—	—
Loveridge	46-01433	44	—	—	—	—	343,956	—	No	No	18	5	—
McElroy	46-01437	95	—	1	—	—	144,338	—	No	No	24	4	4
Miller Creek PP #1	46-05890	5	—	—	—	—	5,510	—	No	No	3	1	1
Minway Surface	46-06089	—	—	—	—	—	—	—	No	No	1	—	—
Peach Orchard Prep Plant	46-08376	—	—	—	—	—	—	—	No	No	—	—	—
Robinson Run	46-01318	53	—	—	—	—	318,418	—	No	No	25	3	3
Rock Lick	46-09171	6	—	—	—	—	28,511	—	No	No	13	3	3
Shoemaker	46-01436	52	—	5	—	—	141,712	—	No	No	26	6	1
Wiley Creek (MT-13/500)	46-09185	—	—	—	—	—	668	—	No	No	—	—	—
Wiley Surface(MT34/Peg Fork)	46-09035	—	—	—	—	—	1,802	—	No	No	—	—	—
Inactive Operations
Alma No. 1 Mine	46-09277	2	—	—	—	—	1,682	—	No	No	—	—	—
Big Branch #1Belt/Spruce Creek	46-09177	—	—	—	—	—	1,057	—	No	No	—	—	—
Big Fork	44-06859	—	—	—	—	—	—	—	No	No	—	—	—
Elk Creek Prep Plant	46-02444	—	—	—	—	—	—	—	No	No	—	—	—
Emery	42-00079	—	—	—	—	—	1,979	—	No	No	3	2	6

2

Impoundment 14-N	36-08094	—	—	—	—	—	—	—	No	No	—	—	—
Jones Fork E-3(Sold)	15-18589	—	—	—	—	—	—	—	No	No	—	—	1
Jones Fork Prep Plant(Sold)	15-17021	—	—	—	—	—	—	—	No	No	—	—	—
Laurel Fork	46-09084	1	—	—	—	—	3,844	—	No	No	—	—	—
Lick Branch	46-08676	—	—	—	—	—	—	—	No	No	3	—	—
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	—	—	—
Muskingum	33-00989	—	—	—	—	—	—	—	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	—	—	—
Squire Jim #2	46-09211	—	—	—	—	—	417	—	No	No	—	—	—
Terry Eagle PP #1	46-02295	—	—	—	—	—	—	—	No	No	—	—	—
Wiley (MT-11)	46-09138	—	—	—	—	—	—	—	No	No	—	—	—
Wiley Area 80	15-18477	—	—	—	—	—	—	—	No	No	—	—	—
Winoc Prep Plant	46-08172	—	—	—	—	—	—	—	No	No	—	—	—
		385	—	9	—	1	1,462,762	1			211	36	35

3

(1) See table below for additional detail regarding Legal Actions Pending as of March 31, 2012.  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 March 31, 2012.

Mine or Operating Name/MSHA Identification Number		Contests of Citations, Orders (as of 3.31.12) (a)	Contests of Proposed Penalties (as of 3.31.12) (b)		Complaints for Compensation (as of 3.31.12) (c)	Complaints of Discharge, Discrimination or Interference (as of 3.31.12) (d)	Applications for Temporary Relief (as of 3.31.12) (e)	Appeals of Judges' Decisions or Order (as of 3.31.12) (f)
			Dockets	Citations
Active Operations
Bailey	36-07230	—	8	26	—	3	—	—
Blacksville 2	46-01968	—	26	288	—	—	—	—
Bronzite II (MT‑41)	46-09307	—	6	12	—	—	—	—
Bronzite III (Jacobs)	46-05978	—	4	18	—	—	—	—
Buchanan	44-04856	—	32	628	—	2	—	—
Central Repair Shop	46-03240	—	—	—	—	—	—	—
Enlow Fork	36-07416	—	10	59	—	—	—	—
Fola Surface	46-08377	—	3	4	—	—	—	—
Ireland Dock Loadout	46-01438	—	6	10	—	—	—	—
Keystone Cleaning Plant	36-08540	—	—	—	—	—	—	—
Loveridge	46-01433	—	18	109	—	—	—	—
McElroy	46-01437	—	24	419	—	—	—	—
Miller Creek PP #1	46-05890	—	3	9	—	2	—	—
Minway Surface	46-06089	—	1	2	—	—	—	—
Peach Orchard Prep Plant	46-08376	—	—	—	—	—	—	—
Robinson Run	46-01318	—	25	267	—	1	—	1
Rock Lick	46-09171	—	13	51	—	—	—	—
Shoemaker	46-01436	—	26	275	—	—	—	—
Wiley Creek (MT‑13/500)	46-09185	—	—	—	—	—	—	—
Wiley Surface(MT34/Peg Fork)	46-09035	—	—	—	—	—	—	—

4

Inactive Operations
Alma No. 1 Mine	46-09277	—	—	—	—	—	—	—
Amonate	46-05449	—	—	—	—	—	—	—
Big Branch #1Belt/Spruce Creek	46-09177	—	—	—	—	—	—	—
Big Fork	44-06859	—	—	—	—	—	—	—
Elk Creek Prep Plant	46-02444	—	—	—	—	—	—	—
Emery	42-00079	—	3	3	—	—	—	—
Impoundment 14‑N	36-08094	—	—	—	—	—	—	—
Jones Fork E‑3(Sold)	15-18589	—	—	—	—	—	—	—
Jones Fork Prep Plant(Sold)	15-17021	—	—	—	—	—	—	—
Laurel Fork	46-09084	—	—	—	—	—	—	—
Lick Branch	46-08676	—	3	9	—	—	—	—
Little Eagle Mine #1	46-08560	—	—	—	—	—	—	—
Meigs #31 Mine	33-01172	—	—	—	—	—	—	—
Miles Branch	44-03932	—	—	—	—	—	—	—
Mine 84	36-00958	—	—	—	—	—	—	—
Muskingum	33-00989	—	—	—	—	—	—	—
Powellton/Bridge Fork	46-08889	—	—	—	—	—	—	—
Reclamation #061	33-00962	—	—	—	—	—	—	—
Rend Lake	11-00601	—	—	—	—	—	—	—
Robena Prep	36-04175	—	—	—	—	—	—	—
Terry Eagle PP #1	46-02295	—	—	—	—	—	—	—
Wiley (MT‑11)	46-09138	—	—	—	—	—	—	—
Wiley Area 80	15-18477	—	—	—	—	—	—	—
Winoc Prep Plant	46-08172	—	—	—	—	—	—	—
		—	211	2,189	—	8	—	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.

(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

XML

Basis of Presentation Share-based Compensation (Details) (USD $)	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures	699,464	562,289
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options Exercised	11,716	180,396
Weighted average exercise price of options exercised	13.81	20.51
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity awards other than options, vested	458,018	341,141
Performance Share Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity awards other than options, vested	229,730	40,752

XML

Maximum Potential Total of Future Payments Under Commitment Instruments (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	$ 1,617,159
Letters of Credit:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	332,068
Letters of Credit: | Employee-Related
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	194,566
Letters of Credit: | Environmental
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	56,994
Letters of Credit: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	80,508
Surety Bonds:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	680,482
Surety Bonds: | Employee-Related
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	204,895
Surety Bonds: | Environmental
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	447,858
Surety Bonds: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	27,729
Guarantees:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	604,609
Guarantees: | Gas
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	123,418
Guarantees: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	456,389
Guarantees: | Coal
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	24,802
Less Than 1 Year
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	1,025,856
Less Than 1 Year | Letters of Credit:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	209,433
Less Than 1 Year | Letters of Credit: | Employee-Related
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	130,826
Less Than 1 Year | Letters of Credit: | Environmental
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	35,046
Less Than 1 Year | Letters of Credit: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	43,561
Less Than 1 Year | Surety Bonds:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	643,723
Less Than 1 Year | Surety Bonds: | Employee-Related
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	179,515
Less Than 1 Year | Surety Bonds: | Environmental
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	436,545
Less Than 1 Year | Surety Bonds: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	27,663
Less Than 1 Year | Guarantees:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	172,700
Less Than 1 Year | Guarantees: | Gas
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	72,811
Less Than 1 Year | Guarantees: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	83,388
Less Than 1 Year | Guarantees: | Coal
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	16,501
1-3 Years
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	319,993
1-3 Years | Letters of Credit:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	122,635
1-3 Years | Letters of Credit: | Employee-Related
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	63,740
1-3 Years | Letters of Credit: | Environmental
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	21,948
1-3 Years | Letters of Credit: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	36,947
1-3 Years | Surety Bonds:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	36,758
1-3 Years | Surety Bonds: | Employee-Related
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	25,380
1-3 Years | Surety Bonds: | Environmental
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	11,313
1-3 Years | Surety Bonds: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	65
1-3 Years | Guarantees:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	160,600
1-3 Years | Guarantees: | Gas
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	19,985
1-3 Years | Guarantees: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	137,314
1-3 Years | Guarantees: | Coal
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	3,301
3-5 Years
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	88,975
3-5 Years | Letters of Credit:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
3-5 Years | Letters of Credit: | Employee-Related
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
3-5 Years | Letters of Credit: | Environmental
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
3-5 Years | Letters of Credit: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
3-5 Years | Surety Bonds:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
3-5 Years | Surety Bonds: | Employee-Related
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
3-5 Years | Surety Bonds: | Environmental
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
3-5 Years | Surety Bonds: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
3-5 Years | Guarantees:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	88,975
3-5 Years | Guarantees: | Gas
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
3-5 Years | Guarantees: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	87,975
3-5 Years | Guarantees: | Coal
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	1,000
Beyond 5 Years
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	182,335
Beyond 5 Years | Letters of Credit:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
Beyond 5 Years | Letters of Credit: | Employee-Related
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
Beyond 5 Years | Letters of Credit: | Environmental
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
Beyond 5 Years | Letters of Credit: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
Beyond 5 Years | Surety Bonds:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	1
Beyond 5 Years | Surety Bonds: | Employee-Related
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
Beyond 5 Years | Surety Bonds: | Environmental
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	0
Beyond 5 Years | Surety Bonds: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	1
Beyond 5 Years | Guarantees:
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	182,334
Beyond 5 Years | Guarantees: | Gas
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	30,622
Beyond 5 Years | Guarantees: | Other Commitments
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	147,712
Beyond 5 Years | Guarantees: | Coal
Loss Contingencies [Line Items]
Maximum potential total of future payments under commitments	$ 4,000

XML

Accounts Receivable Securitization (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011	Dec. 31, 2011
Current borrowing capacity of receivable facility	$ 200,000		$ 192,700
Letters of credit amount outstanding	160,779
Costs associated with the receivables facility	419	724
Expiration date of receivables facility	March 30, 2017
Eligible accounts receivable, a subordinated retained interest	$ 39,221		$ 192,700

XML

Related Party Transaction (Details) (CONE [Member], USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Dec. 31, 2011
Related Party Transaction [Line Items]
Due from Related Parties	$ 29,872	$ 8,966
Related Party Transaction, Expenses from Transactions with Related Party	3,462
CONE Capital Reimbursement [Member]
Related Party Transaction [Line Items]
Due from Related Parties	29,754	8,042
Reimbursement for CONE Expenses [Member]
Related Party Transaction [Line Items]
Due from Related Parties	205	2,009
Reimbursement for Services Provided to Cone [Member]
Related Party Transaction [Line Items]
Due from Related Parties	663	414
CONE Gathering Fees [Member]
Related Party Transaction [Line Items]
Due to Related Parties, Current	$ (750)	$ (1,499)

XML

Unrecorded Unconditional Purchase Obligation (Details) (Purchase Commitment [Member], USD $) In Thousands, unless otherwise specified	Mar. 31, 2012
Purchase Commitment [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Less than 1 year	$ 563,134
1 - 3 years	403,906
3 - 5 years	498,271
More than 5 years	1,639,535
Total Purchase Obligations	$ 3,104,846

XML

Income Taxes Tax Examinations (Details) (Internal Revenue Service (IRS) [Member], USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012
Internal Revenue Service (IRS) [Member]
Income Tax Examination [Line Items]
Tax Adjustments, Settlements, and Unusual Provisions	$ (983)

XML

Fair Value of Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2012

Notes to Financial Statements [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 March 31, 2012						Fair Value Measurements at December 31, 2011
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	$	—	$	296,203	$	—	$	—	$	251,277	$	—

Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Table Text Block]

	March 31, 2012						December 31, 2011
	Carrying Amount			Fair Value			Carrying Amount			Fair Value
Cash and cash equivalents	$	287,313		$	287,313		$	375,736		$	375,736
Restricted cash	$	22,158		$	22,158		$	22,148		$	22,148
Long-term debt	$	(3,133,993	)	$	(3,270,880	)	$	(3,133,993	)	$	(3,422,452	)

XML

Derivative Instruments (Details) (Cash Flow Hedging [Member], Price Swaps, Natural Gas, USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012 MMcf	Dec. 31, 2010
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Notional Amount of Outstanding Natural Gas Forward Contracts (in MMcf)	160,000,000,000
Unrealized Gain Expected to be Reclassified from Other Comprehensive Income and into Earnings During the Next Twelve Months	$ 110,024
Derivative Assets Designated as Hedging Instruments	297,708	251,277
Derivative Liabilities Designated as Hedging Instruments	1,505
Prepaid Expenses
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative Assets Designated as Hedging Instruments	181,072	153,376
Other Assets
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative Assets Designated as Hedging Instruments	$ 116,636	$ 97,901

XML

Pension and OPEB - Periodic Cost (Tables)

3 Months Ended

Mar. 31, 2012

COMPONENTS OF PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS NET PERIODIC BENEFIT COSTS: [Abstract]

Components of Net Periodic Costs

Components of net periodic costs for the three months ended March 31 are as follows:

	Pension Benefits						Other Postretirement Benefits
	Three Months Ended						Three Months Ended
	March 31,						March 31,
	2012			2011			2012			2011
Service cost	$	5,153		$	4,289		$	5,200		$	3,977
Interest cost	9,378			9,078			35,527			42,204
Expected return on plan assets	(11,627		)	(9,630		)	—			—
Amortization of prior service cost (credits)	(408		)	(167		)	(11,599		)	(11,599		)
Recognized net actuarial loss	12,263			9,146			20,345			22,364
Net periodic benefit cost	$	14,759		$	12,716		$	49,473		$	56,946

XML

Property, Plant and Equipment Joint Venture Activity (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012
Noble JV[Member] [Member]
Drilling commitment carry	$ 2,100,000
drilling carry billed	10,204
drill carry remaining	2,089,796
Hess [Member]
Drilling commitment carry	534,000
drilling carry billed	3,348
drill carry remaining	$ 530,652

XML

Pension and OPEB - Periodic Cost (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011	Dec. 31, 2011
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Pension Contributions	$ 29,746
Total anticipated contributions to pension trust	110,000
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	50,276	0
Deferred Tax Assets, Net, Current	128,904		141,083
Defined Benefit Plan, Benefits Paid	42,378
EERP REIMBURSEMENT		7,781
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	5,153	4,289
Interest cost	9,378	9,078
Expected return on plan assets	(11,627)	(9,630)
Amortization of prior service cost (credits)	(408)	(167)
Amortization of actuarial gain	12,263	9,146
Net periodic (benefit) cost	14,759	12,716
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	5,200	3,977
Interest cost	35,527	42,204
Expected return on plan assets	0	0
Amortization of prior service cost (credits)	(11,599)	(11,599)
Amortization of actuarial gain	20,345	22,364
Net periodic (benefit) cost	49,473	56,946
Salary OPEB Amendment [Member] | Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Net periodic (benefit) cost	9,425
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.57%		4.51%
Defined Benefit Plan, Plan Amendments	80,570
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	50,275
Deferred Tax Assets, Net, Current	$ 30,295

XML

Long Term Debt - Phantom Facts Level 4 (Details) (USD $)	Mar. 31, 2012	Dec. 31, 2010
Senior Notes 8 Percent Due April 2017 Par Value [Member]
Debt Instrument [Line Items]
Interest rate stated percentage	8.00%
Debt Instrument, Face Amount	$ 1,500,000,000
Senior Notes 8.25 Percent Due April 2020 Par Value Member [Member]
Debt Instrument [Line Items]
Interest rate stated percentage	8.25%
Debt Instrument, Face Amount	1,250,000,000
Senior Secured Notes Due March 2021 Par Value [Member]
Debt Instrument [Line Items]
Interest rate stated percentage	6.375%
Debt Instrument, Face Amount	250,000,000
Secured Notes Due March 2012 [Member]
Debt Instrument [Line Items]
Interest rate stated percentage	7.875%
Debt Instrument, Face Amount		250,000,000
Unamortized discount	$ 0	$ 242,000
Baltimore Port Facility Revenue Bonds In Series 5.75 Percent Due September 2025 [Member] [Member]
Debt Instrument [Line Items]
Interest rate stated percentage	5.75%
Advance royalty commitments [Member]
Debt Instrument [Line Items]
Interest rate stated percentage	6.73%	6.73%
Note Due Through December 2012 At 6.10% [Member] [Member]
Debt Instrument [Line Items]
Interest rate stated percentage	0.00%

XML

Long-Term Debt (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Debt Instrument [Line Items]
Debt	$ 3,133,993		$ 3,133,993
Less amounts due in one year	(11,759)		(11,759)
Long-Term Debt	3,122,234	3,122,234	3,122,234
Accrued interest	113,891		63,577
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	31,053		31,053
Other long-term notes maturing at various dates through 2031
Debt Instrument [Line Items]
Debt	$ 75		$ 75

XML

Guarantor Subsidiaries Balance Sheet (Detail) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011	Mar. 31, 2011	Dec. 31, 2010
Current Assets:
Cash and Cash Equivalents	$ 287,313	$ 375,736	$ 127,695	$ 32,794
Accounts and Notes Receivable:
Trade	463,258	462,812
Notes Receivable, Related Parties, Current	314,514	314,950
Other Receivables	126,931	105,708
Inventories	284,997	258,335
Deferred Income Taxes	128,904	141,083
Prepaid Expenses	260,818	239,353
Total Current Assets	1,866,735	1,897,977
Property, Plant and Equipment:
Property, Plant and Equipment	14,357,246	14,087,319
Less-Accumulated Depreciation, Depletion and Amortization	4,915,809	4,760,903
Total Property, Plant and Equipment-Net	9,441,437	9,326,416
Other Assets:
Deferred Income Taxes	467,753	507,724
Restricted Cash	22,158	22,148
Investments in Unconsolidated Equity Affiliates	200,221	182,036
Notes, Loans and Financing Receivable, Net	300,382	300,492
Other	296,925	288,907
Total Other Assets	1,287,439	1,301,307
Total Assets	12,595,611	12,525,700	12,223,741
Current Liabilities:
Accounts Payable	471,921	522,003
Accounts Payable (Recoverable)- Related Parties	0	0
Current Portion Long-Term Debt	20,879	20,691
Accrued Income Taxes, Current	50,313	75,633
Other Accrued Liabilities	856,858	770,070
Total Current Liabilities	1,399,971	1,388,397
Long-Term Debt:	3,176,718	3,177,423
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	2,976,181	3,059,671
Pneumoconiosis	174,559	173,553
Mine Closing	409,778	406,712
Gas Well Closing	125,557	124,051
Workers' Compensation	150,377	151,034
Salary Retirement	242,727	269,069
Reclamation	36,148	39,969
Other	129,483	124,936
Total Deferred Credits and Other Liabilities	4,244,810	4,348,995
Total CONSOL Energy Inc. Stockholders' Equity	3,774,112	3,610,885
TOTAL LIABILITIES AND EQUITY	12,595,611	12,525,700
Parent Issuer
Current Assets:
Cash and Cash Equivalents	119,562	37,342
Accounts and Notes Receivable:
Trade	0	0
Notes Receivable, Related Parties, Current	2,233	2,669
Other Receivables	2,670	2,913
Inventories	0	0
Deferred Income Taxes	190,377	191,689
Prepaid Expenses	20,409	28,470
Total Current Assets	335,251	263,083
Property, Plant and Equipment:
Property, Plant and Equipment	204,057	198,004
Less-Accumulated Depreciation, Depletion and Amortization	113,848	109,924
Total Property, Plant and Equipment-Net	90,209	88,080
Other Assets:
Deferred Income Taxes	935,069	963,332
Restricted Cash	22,158	22,148
Investments in Unconsolidated Equity Affiliates	9,464,098	9,126,453
Notes, Loans and Financing Receivable, Net	4,038	4,148
Other	123,720	116,624
Total Other Assets	10,549,083	10,232,705
Total Assets	10,974,543	10,583,868
Current Liabilities:
Accounts Payable	133,860	140,823
Accounts Payable (Recoverable)- Related Parties	3,026,857	2,900,546
Current Portion Long-Term Debt	824	805
Accrued Income Taxes, Current	49,826	68,819
Other Accrued Liabilities	645,803	493,450
Total Current Liabilities	3,857,170	3,604,443
Long-Term Debt:	3,001,170	3,001,092
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	242,727	269,069
Reclamation	0	0
Other	99,364	98,379
Total Deferred Credits and Other Liabilities	342,091	367,448
Total CONSOL Energy Inc. Stockholders' Equity	3,774,112	3,610,885
TOTAL LIABILITIES AND EQUITY	10,974,543	10,583,868
CNX Gas Guarantor
Current Assets:
Cash and Cash Equivalents	166,205	336,727
Accounts and Notes Receivable:
Trade	41,694	63,299
Notes Receivable, Related Parties, Current	311,754	311,754
Other Receivables	109,101	91,582
Inventories	10,508	8,600
Deferred Income Taxes	(61,473)	(50,606)
Prepaid Expenses	186,888	159,900
Total Current Assets	764,677	921,256
Property, Plant and Equipment:
Property, Plant and Equipment	5,577,282	5,488,094
Less-Accumulated Depreciation, Depletion and Amortization	825,783	778,716
Total Property, Plant and Equipment-Net	4,751,499	4,709,378
Other Assets:
Deferred Income Taxes	(467,316)	(455,608)
Restricted Cash	0	0
Investments in Unconsolidated Equity Affiliates	108,858	96,914
Notes, Loans and Financing Receivable, Net	296,344	296,344
Other	127,733	110,128
Total Other Assets	65,619	47,778
Total Assets	5,581,795	5,678,412
Current Liabilities:
Accounts Payable	185,616	206,072
Accounts Payable (Recoverable)- Related Parties	15,655	9,431
Current Portion Long-Term Debt	5,848	5,587
Accrued Income Taxes, Current	487	6,814
Other Accrued Liabilities	62,128	58,401
Total Current Liabilities	269,734	286,305
Long-Term Debt:	49,813	50,326
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	0	0
Pneumoconiosis	0	0
Mine Closing	0	0
Gas Well Closing	63,004	61,954
Workers' Compensation	0	0
Salary Retirement	0	0
Reclamation	0	0
Other	20,727	16,899
Total Deferred Credits and Other Liabilities	83,731	78,853
Total CONSOL Energy Inc. Stockholders' Equity	5,178,517	5,262,928
TOTAL LIABILITIES AND EQUITY	5,581,795	5,678,412
Other Subsidiary Guarantors
Current Assets:
Cash and Cash Equivalents	957	1,269
Accounts and Notes Receivable:
Trade	423	(5,081)
Notes Receivable, Related Parties, Current	527	527
Other Receivables	10,440	7,458
Inventories	231,359	206,096
Deferred Income Taxes	0	0
Prepaid Expenses	51,900	49,224
Total Current Assets	295,606	259,493
Property, Plant and Equipment:
Property, Plant and Equipment	8,551,640	8,376,831
Less-Accumulated Depreciation, Depletion and Amortization	3,958,974	3,855,323
Total Property, Plant and Equipment-Net	4,592,666	4,521,508
Other Assets:
Deferred Income Taxes	0	0
Restricted Cash	0	0
Investments in Unconsolidated Equity Affiliates	720,339	760,548
Notes, Loans and Financing Receivable, Net	0	0
Other	35,475	52,009
Total Other Assets	755,814	812,557
Total Assets	5,644,086	5,593,558
Current Liabilities:
Accounts Payable	140,393	164,521
Accounts Payable (Recoverable)- Related Parties	(3,368,808)	(3,228,229)
Current Portion Long-Term Debt	13,506	13,543
Accrued Income Taxes, Current	0	0
Other Accrued Liabilities	136,219	206,649
Total Current Liabilities	(3,078,690)	(2,843,516)
Long-Term Debt:	124,566	124,674
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	2,976,181	3,059,671
Pneumoconiosis	174,559	173,553
Mine Closing	409,778	406,712
Gas Well Closing	62,553	62,097
Workers' Compensation	150,113	150,786
Salary Retirement	0	0
Reclamation	36,148	39,969
Other	9,392	9,658
Total Deferred Credits and Other Liabilities	3,818,724	3,902,446
Total CONSOL Energy Inc. Stockholders' Equity	4,779,486	4,409,954
TOTAL LIABILITIES AND EQUITY	5,644,086	5,593,558
Non-Guarantors
Current Assets:
Cash and Cash Equivalents	589	398
Accounts and Notes Receivable:
Trade	421,141	404,594
Notes Receivable, Related Parties, Current	0	0
Other Receivables	4,720	3,755
Inventories	43,130	43,639
Deferred Income Taxes	0	0
Prepaid Expenses	1,621	1,759
Total Current Assets	471,201	454,145
Property, Plant and Equipment:
Property, Plant and Equipment	24,267	24,390
Less-Accumulated Depreciation, Depletion and Amortization	17,204	16,940
Total Property, Plant and Equipment-Net	7,063	7,450
Other Assets:
Deferred Income Taxes	0	0
Restricted Cash	0	0
Investments in Unconsolidated Equity Affiliates	0	0
Notes, Loans and Financing Receivable, Net	0	0
Other	9,997	10,146
Total Other Assets	9,997	10,146
Total Assets	488,261	471,741
Current Liabilities:
Accounts Payable	12,052	10,587
Accounts Payable (Recoverable)- Related Parties	326,296	318,252
Current Portion Long-Term Debt	701	756
Accrued Income Taxes, Current	0	0
Other Accrued Liabilities	12,708	11,570
Total Current Liabilities	351,757	341,165
Long-Term Debt:	1,169	1,331
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	264	248
Salary Retirement	0	0
Reclamation	0	0
Other	0	0
Total Deferred Credits and Other Liabilities	264	248
Total CONSOL Energy Inc. Stockholders' Equity	135,071	128,997
TOTAL LIABILITIES AND EQUITY	488,261	471,741
Elimination
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	0
Inventories	0	0
Deferred Income Taxes	0	0
Prepaid Expenses	0	0
Total Current Assets	0	0
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	0	0
Investments in Unconsolidated Equity Affiliates	(10,093,074)	(9,801,879)
Notes, Loans and Financing Receivable, Net	0	0
Other	0	0
Total Other Assets	(10,093,074)	(9,801,879)
Total Assets	(10,093,074)	(9,801,879)
Current Liabilities:
Accounts Payable	0	0
Accounts Payable (Recoverable)- Related Parties	0	0
Current Portion Long-Term Debt	0	0
Accrued Income Taxes, Current	0	0
Other Accrued Liabilities	0	0
Total Current Liabilities	0	0
Long-Term Debt:		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	(10,093,074)	(9,801,879)
TOTAL LIABILITIES AND EQUITY	$ (10,093,074)	$ (9,801,879)

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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	Mar. 31, 2012	Dec. 31, 2011	Mar. 31, 2011	Dec. 31, 2010
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]
Cash and Cash Equivalents	$ 287,313	$ 375,736	$ 127,695	$ 32,794
Long-term debt	(3,133,993)			(3,133,993)
Carrying Amount
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]
Cash and Cash Equivalents	287,313	375,736
Restricted cash	22,158	22,148
Long-term debt	(3,133,993)	(3,133,993)
Fair Value
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]
Cash and Cash Equivalents	287,313	375,736
Restricted cash	22,158	22,148
Long-term debt	$ (3,270,880)	$ (3,422,452)

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Inventory Components (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Schedule of Inventory [Line Items]
Coal	$ 125,308	$ 105,378
Merchandise for resale	43,130	43,639
Supplies	116,559	109,318
Total Inventories	284,997	258,335
Excess of replacement cost of merchandise for resl inventories over carrying LIFO value	$ 23,093	$ 22,406

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Acquisitions and Dispositions

3 Months Ended

Mar. 31, 2012

ACQUISITIONS AND DISPOSITIONS: [Abstract]

Acquisitions and Dispositions:

ACQUISITIONS AND DISPOSITIONS:

On February 9, 2012, CONSOL Energy completed the disposition of its Burning Star No. 4 property, 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.

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 its nearly 200 thousand net Utica Shale acres in Ohio. Cash proceeds related to this transaction were $54,254, which are 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 net gain on the transaction was $53,095 and was recognized in the three months ended December 31, 2011.

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 the three months ended December 31, 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. The net loss on the transaction was $64,142 and was recognized in the three months ended September 30, 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 will remain suspended until average natural gas prices are above $4.00/MMBtu for three consecutive months. Restrictions also include a $400,000 annual maximum on Noble's carried cost obligation.

The following unaudited pro forma combined financial statements are based on CONSOL Energy's historical consolidated financial statements and adjusted to give effect to the September 30, 2011 sale of a 50% interest in certain Marcellus Shale assets. The unaudited pro forma results for the period presented below are prepared as if the transaction occurred as of January 1, 2011 and do not include material, non-recurring charges.

	Three Months Ended
	March 31,
	2011
Total Revenue and Other Income	$	1,455,126
Earnings Before Income Taxes	$	247,418
Net Income	$	189,330
Basic Earnings Per Share	$	0.84
Dilutive Earnings Per Share	$	0.83

The pro forma results are not necessarily indicative of what actually would have occurred if the transaction had been completed as of January 1, 2011, nor are they necessarily indicative of future consolidated results.

On September 30 2011, CNX Gas Company and Noble formed CONE Gathering LLC (CONE), a joint venture established to develop and operate each company's gas gathering system needs in the Marcellus Shale play. CNX Gas Company's 50% ownership interest in CONE is accounted for under the equity method of accounting. CNX Gas contributed its existing Marcellus Shale gathering infrastructure which had a net book value of $119,740 and Noble contributed cash of approximately $67,545. CONE made a cash distribution to CNX Gas in the amount of $67,545. The cash proceeds were recognized as cash inflows of $59,870 and $7,675 in Distributions from Equity Affiliates and Proceeds from the Sale of Assets, respectively, in CONSOL Energy's 2011 third quarter results. The gain on the transaction was $7,161 and was recognized in the three months ended September 30, 2011.

On September 21, 2011 CONSOL Energy entered into an agreement with Antero Resources Appalachian Corp. (Antero), pursuant to which CONSOL Energy assigned to Antero overriding royalty interests (ORRI) of approximately 7% in approximately 116 thousand net acres of Marcellus Shale located in nine counties in southwestern Pennsylvania and north central West Virginia, in exchange for $193,000. The net gain on the transaction was $41,057 was recognized in the three months ended September 30, 2011.

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Segment Information Industry Segment Results (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011	Dec. 31, 2011
Segment Reporting Information [Line Items]
Sales-Outside	$ 1,311,471	$ 1,385,478
Sales-Purchased Gas	839	980
Sales-Gas Royalty Interests	12,206	18,835
Freight-Outside	49,293	36,868
Intersegment Transfers	0	0
Total Sales and Freight	1,373,809	1,442,161
Earnings Before Income Taxes	118,577	251,077
Total Assets	12,595,611	12,223,741	12,525,700
Depreciation, Depletion and Amortization	155,347	149,062
Capital Expenditures	306,446	254,778
Equity in Earnings of Unconsolidated Affiliates	7,935	5,481
Investments in Unconsolidated Equity Affiliates	200,221		182,036
Total Reportable Business Segments
Segment Reporting Information [Line Items]
Earnings Before Income Taxes	174,970	322,868
Total Assets	11,471,162	11,059,077
Coal
Segment Reporting Information [Line Items]
Sales-Outside	1,054,316	1,130,444
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	49,293	36,868
Intersegment Transfers	0	0
Total Sales and Freight	1,103,609	1,167,312
Earnings Before Income Taxes	162,470	298,692
Total Assets	5,360,577	5,092,682
Depreciation, Depletion and Amortization	100,762	95,081
Capital Expenditures	194,429	100,530
Equity in Earnings of Unconsolidated Affiliates	4,807	4,462
Investments in Unconsolidated Equity Affiliates	39,373	24,455
Gas
Segment Reporting Information [Line Items]
Sales-Outside	160,203	176,209
Sales-Purchased Gas	839	980
Sales-Gas Royalty Interests	12,206	18,835
Freight-Outside	0	0
Intersegment Transfers	466	993
Total Sales and Freight	173,714	197,017
Earnings Before Income Taxes	12,500	24,176
Total Assets	6,110,585	5,966,395
Depreciation, Depletion and Amortization	48,803	49,664
Capital Expenditures	98,455	150,638
Equity in Earnings of Unconsolidated Affiliates	1,944	484
Investments in Unconsolidated Equity Affiliates	108,858	24,053
All Other Segments [Member]
Segment Reporting Information [Line Items]
Sales-Outside	96,952	78,825
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Intersegment Transfers	37,209	53,396
Total Sales and Freight	134,161	132,221
Earnings Before Income Taxes	4,083	(1,849)
Total Assets	358,746	341,613
Depreciation, Depletion and Amortization	5,782	4,317
Capital Expenditures	13,562	3,610
Corporate Elimination [Member]
Segment Reporting Information [Line Items]
Sales-Outside	0	0
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Intersegment Transfers	(37,675)	(54,389)
Total Sales and Freight	(37,675)	(54,389)
Earnings Before Income Taxes	(60,476)	(69,942)
Total Assets	765,703	823,051
Depreciation, Depletion and Amortization	0	0
Capital Expenditures	0	0
All Other
Segment Reporting Information [Line Items]
Equity in Earnings of Unconsolidated Affiliates	1,184	535
Investments in Unconsolidated Equity Affiliates	51,990	49,012
Steam | Coal
Segment Reporting Information [Line Items]
Sales-Outside	812,053	801,952
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Intersegment Transfers	0	0
Total Sales and Freight	812,053	801,952
Earnings Before Income Taxes	128,855	194,044
Low Volatile Metallurgical | Coal
Segment Reporting Information [Line Items]
Sales-Outside	172,740	236,895
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Intersegment Transfers	0	0
Total Sales and Freight	172,740	236,895
Earnings Before Income Taxes	79,361	142,594
High Volatile Metallurgical | Coal
Segment Reporting Information [Line Items]
Sales-Outside	60,568	78,233
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Intersegment Transfers	0	0
Total Sales and Freight	60,568	78,233
Earnings Before Income Taxes	15,611	40,893
Other Coal | Coal
Segment Reporting Information [Line Items]
Sales-Outside	8,955	13,364
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	49,293	36,868
Intersegment Transfers	0	0
Total Sales and Freight	58,248	50,232
Earnings Before Income Taxes	(61,357)	(78,839)
Coalbed Methane | Gas
Segment Reporting Information [Line Items]
Sales-Outside	99,535	113,774
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Intersegment Transfers	0	0
Total Sales and Freight	99,535	113,774
Earnings Before Income Taxes	36,390	50,003
Marcellus Shale | Gas
Segment Reporting Information [Line Items]
Sales-Outside	23,791	21,042
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Intersegment Transfers	0	0
Total Sales and Freight	23,791	21,042
Earnings Before Income Taxes	3,251	8,503
Conventional Gas | Gas
Segment Reporting Information [Line Items]
Sales-Outside	34,373	38,745
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Intersegment Transfers	0	0
Total Sales and Freight	34,373	38,745
Earnings Before Income Taxes	(3,722)	(2,750)
Other Gas | Gas
Segment Reporting Information [Line Items]
Sales-Outside	2,504	2,648
Sales-Purchased Gas	839	980
Sales-Gas Royalty Interests	12,206	18,835
Freight-Outside	0	0
Intersegment Transfers	466	993
Total Sales and Freight	16,015	23,456
Earnings Before Income Taxes	(23,419)	(31,580)
First Energy [Member] | Coal
Segment Reporting Information [Line Items]
Entity-Wide Revenue, Major Customer, Amount	144,155
XCoal Energy and Resources [Member] | Coal
Segment Reporting Information [Line Items]
Entity-Wide Revenue, Major Customer, Amount	$ 138,341

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CWP and Workers Comp - Net Periodic Costs (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Coal Workers Pneumoconiosis [Member]
Schedule of Net Periodic Benefit Costs and Assumptions for Defined Benefit Postretirement Plans [Line Items]
Service cost	$ 1,178	$ 1,155
Interest cost	1,991	2,333
Amortization of actuarial gain	(4,934)	(5,478)
State administrative fees and insurance bond premiums	0	0
Legal and administrative costs	750	750
Net periodic (benefit) cost	(1,015)	(1,240)
Payments for Coal Workers Pnenumoconiosis	2,850
Workers Compensation [Member]
Schedule of Net Periodic Benefit Costs and Assumptions for Defined Benefit Postretirement Plans [Line Items]
Service cost	3,634	4,468
Interest cost	1,778	2,060
Amortization of actuarial gain	(986)	(977)
State administrative fees and insurance bond premiums	1,910	1,222
Legal and administrative costs	648	718
Net periodic (benefit) cost	6,984	7,491
Payments for workers compensation benefits, state administrative fees and surety bond premiums	$ 9,050

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Property, Plant and Equipment (Tables)

3 Months Ended

Mar. 31, 2012

Notes to Financial Statements [Abstract]

Property, Plant and Equipment

	March 31, 2012		December 31, 2011
Coal & Other Plant and Equipment	$	5,301,715	$	5,160,759
Proven Gas Properties	1,542,838		1,542,837
Coal Properties and Surface Lands	1,352,159		1,340,757
Intangible Drilling Cost	1,344,207		1,277,678
Unproven Gas Properties	1,269,083		1,258,027
Gas Gathering Equipment	970,552		963,494
Airshafts	666,334		659,736
Leased Coal Lands	541,577		540,817
Mine Development	474,859		457,179
Gas Wells and Related Equipment	410,245		408,814
Coal Advance Mining Royalties	396,682		393,340
Other Gas Assets	80,459		79,816
Gas Advance Royalties	6,536		4,065
Total Property Plant and Equipment	14,357,246		14,087,319
Less: Accumulated DD&A	4,915,809		4,760,903
Total Net PP&E	$	9,441,437	$	9,326,416

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Inventories (Tables)

3 Months Ended

Mar. 31, 2012

INVENTORIES: [Abstract]

Inventory components

	March 31, 2012		December 31, 2011
Coal	$	125,308	$	105,378
Merchandise for resale	43,130		43,639
Supplies	116,559		109,318
Total Inventories	$	284,997	$	258,335

XML

Costs Related to Purchase Obligations (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	$ 58,085	$ 46,392
Major equipment purchases
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	13,166	7,655
Firm transportation expense
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	15,045	12,818
Gas drilling obligations
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	29,576	25,818
Other Obligations
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	$ 298	$ 101

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Income Taxes Income Tax Reconciliation (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Amount
Statutory U.S. Federal Income Tax Rate	$ 41,502	$ 87,877
Income Tax Reconciliation, Nondeductible Expense, Depletion	(26,514)	(39,169)
Effect of Domestic Production Activities Deduction	0	(1,916)
Net Effect of State Income Taxes	3,510	8,818
Other	2,883	3,318
Income Tax Expense / Effective Rate	$ 21,381	$ 58,928
Percent
Statutory U.S. Federal Income Tax Rate	35.00%	35.00%
Excess Tax Depletion	(22.40%)	(15.60%)
Effect of Domestic Production Activities Deduction	0.00%	(0.80%)
Net Effect of State Income Taxes	3.00%	3.50%
Other	2.40%	1.40%
Income Tax Expense / Effective Rate	18.00%	23.50%

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Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2012

Notes to Financial Statements [Abstract]

Schedule of Long-term Debt

	March 31, 2012		December 31, 2011
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
Baltimore Port Facility revenue bonds in series due September 2025 at 5.75%	102,865		102,865
Advance royalty commitments (6.73% weighted average interest rate for March 31, 2012 and December 31, 2011, respectively)	31,053		31,053
Other long-term note maturing in 2031	75		75
	3,133,993		3,133,993
Less amounts due in one year	11,759		11,759
Long-Term Debt	$	3,122,234	$	3,122,234

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2012

Long-term Purchase Commitment [Table Text Block]

At March 31, 2012, 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	$	194,566	$	130,826	$	63,740	$	—	$	—
Environmental	56,994		35,046		21,948		—		—
Other	80,508		43,561		36,947		—		—
Total Letters of Credit	332,068		209,433		122,635		—		—
Surety Bonds:
Employee-Related	204,895		179,515		25,380		—		—
Environmental	447,858		436,545		11,313		—		—
Other	27,729		27,663		65		—		1
Total Surety Bonds	680,482		643,723		36,758		—		1
Guarantees:
Coal	24,802		16,501		3,301		1,000		4,000
Gas	123,418		72,811		19,985		—		30,622
Other	456,389		83,388		137,314		87,975		147,712
Total Guarantees	604,609		172,700		160,600		88,975		182,334
Total Commitments	$	1,617,159	$	1,025,856	$	319,993	$	88,975	$	182,335

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 March 31, 2012, the purchase obligations for each of the next five years and beyond were as follows:

Obligations Due	Amount
Less than 1 year	$	563,134
1 - 3 years	403,906
3 - 5 years	498,271
More than 5 years	1,639,535
Total Purchase Obligations	$	3,104,846

Supply Commitment [Table Text Block]

Costs related to these purchase obligations include:

	Three Months Ended
	March 31,
	2012		2011
Major equipment purchases	$	13,166	$	7,655
Firm transportation expense	15,045		12,818
Gas drilling obligations	29,576		25,818
Other	298		101
Total costs related to purchase obligations	$	58,085	$	46,392

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Basis of Presentation

3 Months Ended

Mar. 31, 2012

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 months ended March 31, 2012 are not necessarily indicative of the results that may be expected for future periods.

The balance sheet at December 31, 2011 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, 2011 included in CONSOL Energy Inc.'s Form 10-K.

Basic earnings per share are computed by dividing net income by the weighted average shares outstanding during the reporting period. Dilutive earnings per share are computed similarly to basic earnings per share except that the weighted average shares outstanding are increased to include additional shares from the assumed exercise of stock options and performance stock options and the assumed vesting of restricted and performance share units, if dilutive. The number of additional shares is calculated by assuming that outstanding stock options and performance share options were exercised, that outstanding restricted 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 March 31,
	2012	2011
Anti-Dilutive Options	1,574,922	1,157,937
Anti-Dilutive Restricted Stock Units	12,203	—
Anti-Dilutive Performance Share Options	100,350	—
	1,687,475	1,157,937

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

	Three Months Ended March 31,
	2012	2011
Options	11,716	180,396
Restricted Stock Units	458,018	341,141
Performance Share Units	229,730	40,752
	699,464	562,289

The weighted average exercise price per share of the options exercised during the three months ended March 31, 2012 and 2011 was $13.81 and $20.51, respectively.

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

	Three Months Ended March 31,
	2012		2011
Net income attributable to CONSOL Energy Inc. shareholders	$	97,196	$	192,149
Weighted average shares of common stock outstanding:
Basic	227,269,269		226,350,594
Effect of stock-based compensation awards	2,854,742		2,464,244
Dilutive	230,124,011		228,814,838
Earnings per share:
Basic	$	0.43	$	0.85
Dilutive	$	0.42	$	0.84

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Derivative Instruments (Tables)

3 Months Ended

Mar. 31, 2012

Notes to Financial Statements [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:

	Three Months Ended March 31,
	2012			2011
Natural Gas Price Swaps
Gain recognized in Accumulated OCI	$	76,076		$	4,371
Gain reclassified from Accumulated OCI into Outside Sales	$	47,941		$	18,840
Loss recognized in Outside Sales for ineffectiveness	$	(835	)	$	(108	)

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Basis of Presentation Earnings Per Share (Details) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Net Income	$ 97,196	$ 192,149
Weighted average shares of common stock outstanding:
Basic	227,269,269	226,350,594
Effect of stock-based compensation awards	2,854,742	2,464,244
Dilutive	230,124,011	228,814,838
Earnings per share:
Basic	$ 0.43	$ 0.85
Dilutive	$ 0.42	$ 0.84

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Commitments and Contingencies Additional Information (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified				3 Months Ended		3 Months Ended		12 Months Ended	3 Months Ended		3 Months Ended
	Mar. 31, 2012	Dec. 31, 2011	Mar. 31, 2012 Subsidiaries	Mar. 31, 2012 Commonwealth Park Property	Mar. 31, 2012 PCB Soil Removal Action	Mar. 31, 2012 American electric corp [Member]	Mar. 31, 2011 C. L. Ritter [Member]	Dec. 31, 2010 South Carolina Electric Gas Company	Mar. 31, 2012 South Carolina Electric Gas Company Counterclaim	Mar. 31, 2012 South Carolina Electric Gas Company worst case scenario [Member]	Mar. 31, 2012 CNX Gas Stock Acquisition	Dec. 31, 2007 Earl Kennedy	Mar. 31, 2012 Ratliff [Member]
Commitments and Contingencies Disclosure [Line Items]
Loss Contingency, Range of Possible Loss, Portion Not Accrued	$ 1,562,000
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.			$34,000 and $430,000	South Carolina Electric & Gas Company (SCE&G), a utility, has demanded arbitration, seeking $36,000 in damages against CONSOL of Kentucky and CONSOL Energy Sales Company, both wholly owned subsidiaries of CONSOL Energy.				The complaint, as amended, seeks injunctive relief, including removing CNX Gas Company from the property, and compensatory damages of $20,000.
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				30,000	65,000	5,400				29,000	221,000
Counterclaim by the company						408			CONSOL Energy counterclaimed against SCE&G for $9,400 for terminating coal shipments under the sales agreement which SCE&G had agreed could be made up in 2009.
Loss Contingency, Estimate of Possible Loss				20,000	11,000
Loss Contingency, Range of Possible Loss, Minimum				9,000		2,000				17,000
CONSOL Energy's portion of probable recoveries from settled claims					4,477
Remaining liability in PCB soil removal action	856,858	770,070			3,483
Loss Contingency, Damages Sought, Value						$ 384
Commitments and Contingent, number of asbestos claims			7,300
Allegations by plaintiff											All five 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.		$25,750 and $119,500
Price per share											$ 38.25

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Consolidated Statements of Income (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Sales-Outside	$ 1,311,471	$ 1,385,478
Sales-Gas Royalty Interests	12,206	18,835
Sales-Purchased Gas	839	980
Freight-Outside	49,293	36,868
Other Income	52,961	23,216
Total Revenue and Other Income	1,426,770	1,465,377
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	904,041	813,709
Gas Royalty Interests Costs	10,249	16,807
Related Party Activity	0	0
Purchased Gas Costs	517	676
Freight Expense	49,293	36,679
Selling, General and Administrative Expenses	38,999	40,196
Depreciation, Depletion and Amortization	155,347	149,062
Interest Expense	58,120	66,482
Taxes Other Than Income	91,627	90,689
Total Costs	1,308,193	1,214,300
Earnings Before Income Taxes	118,577	251,077
Income Taxes	21,381	58,928
Net Income	97,196	192,149
Earnings per share:
Basic	$ 0.43	$ 0.85
Dilutive	$ 0.42	$ 0.84
Weighted Average Number of Common Shares Outstanding:
Basic	227,269,269	226,350,594
Dilutive	230,124,011	228,814,838
Dividends Paid Per Share	$ 0.125	$ 0.100
Parent Issuer
Sales-Outside	0	0
Sales-Gas Royalty Interests	0	0
Sales-Purchased Gas	0	0
Freight-Outside	0	0
Other Income	170,023	246,864
Total Revenue and Other Income	170,023	246,864
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	49,180	28,976
Gas Royalty Interests Costs	0	0
Related Party Activity	6,015	(3,240)
Purchased Gas Costs	0	0
Freight Expense	0	0
Selling, General and Administrative Expenses	0	0
Depreciation, Depletion and Amortization	3,919	2,361
Interest Expense	54,762	61,142
Taxes Other Than Income	2,674	1,503
Total Costs	116,550	90,742
Earnings Before Income Taxes	53,473	156,122
Income Taxes	(43,723)	(36,027)
Net Income	97,196	192,149
Cnx Gas Guarantor [Member]
Sales-Outside	160,669	177,202
Sales-Gas Royalty Interests	12,206	18,835
Sales-Purchased Gas	839	980
Freight-Outside	0	0
Other Income	16,305	1,680
Total Revenue and Other Income	190,019	198,697
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	98,701	87,612
Gas Royalty Interests Costs	10,255	16,821
Related Party Activity	0	0
Purchased Gas Costs	517	676
Freight Expense	0	0
Selling, General and Administrative Expenses	9,924	9,356
Depreciation, Depletion and Amortization	48,803	49,664
Interest Expense	1,218	2,680
Taxes Other Than Income	8,200	7,807
Total Costs	177,618	174,616
Earnings Before Income Taxes	12,401	24,081
Income Taxes	4,947	9,435
Net Income	7,454	14,646
Other Guarantors Subsidiaries [Member]
Sales-Outside	1,082,288	1,155,350
Sales-Gas Royalty Interests	0	0
Sales-Purchased Gas	0	0
Freight-Outside	49,293	36,868
Other Income	29,703	11,421
Total Revenue and Other Income	1,161,284	1,203,639
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	682,700	628,960
Gas Royalty Interests Costs	0	0
Related Party Activity	1,258	(1,741)
Purchased Gas Costs	0	0
Freight Expense	49,293	36,679
Selling, General and Administrative Expenses	28,628	30,557
Depreciation, Depletion and Amortization	102,102	96,408
Interest Expense	2,229	2,742
Taxes Other Than Income	79,933	80,514
Total Costs	946,143	874,119
Earnings Before Income Taxes	215,141	329,520
Income Taxes	57,789	82,837
Net Income	157,352	246,683
Non-Guarantors
Sales-Outside	69,022	54,096
Sales-Gas Royalty Interests	0	0
Sales-Purchased Gas	0	0
Freight-Outside	0	0
Other Income	5,957	9,241
Total Revenue and Other Income	74,979	63,337
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	66,416	53,987
Gas Royalty Interests Costs	0	0
Related Party Activity	502	466
Purchased Gas Costs	0	0
Freight Expense	0	0
Selling, General and Administrative Expenses	447	283
Depreciation, Depletion and Amortization	523	629
Interest Expense	11	13
Taxes Other Than Income	820	865
Total Costs	68,719	56,243
Earnings Before Income Taxes	6,260	7,094
Income Taxes	2,368	2,683
Net Income	3,892	4,411
Consolidation, Eliminations [Member]
Sales-Outside	(508)	(1,170)
Sales-Gas Royalty Interests	0	0
Sales-Purchased Gas	0	0
Freight-Outside	0	0
Other Income	(169,027)	(245,990)
Total Revenue and Other Income	(169,535)	(247,160)
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	7,044	14,174
Gas Royalty Interests Costs	(6)	(14)
Related Party Activity	(7,775)	4,515
Purchased Gas Costs	0	0
Freight Expense	0	0
Selling, General and Administrative Expenses	0	0
Depreciation, Depletion and Amortization	0	0
Interest Expense	(100)	(95)
Taxes Other Than Income	0	0
Total Costs	(837)	18,580
Earnings Before Income Taxes	(168,698)	(265,740)
Income Taxes	0	0
Net Income	$ (168,698)	$ (265,740)

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Income Taxes Additional Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Deferred Tax Liability Not Recognized [Line Items]
Uncertain tax positions	$ 25,570	$ 65,510
Uncertain tax positions that, if recognized, would impact effective tax rate	3,891	16,802
Accrued interest liability relating to uncertain tax positions	5,741	11,895
Interest expense included in accrued interest liability	$ 368	$ 1,121

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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
Balance, Beginning of Period at Dec. 31, 2011		$ 2,273	$ 2,234,775	$ 2,184,737	$ (801,554)	$ (9,346)	$ 3,610,885
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss)	97,196	0	0	97,196	0	0	97,196
Treasury Rate Lock (Net of $12 Tax)	0
Gas Cash Flow Hedge (Net of $9,801 Tax)	76,076
Other Comprehensive Income (Loss), Net of Tax	87,708	0	0	0	87,708	0	87,708
Comprehensive Income (Loss)	184,904	0	0	97,196	87,708	0	184,904
Proceeds from Issuance of Common Stock	54	2	52	0	0	0	54
Issuance of Treasury Stock		0	0	(17,770)	0	8,737	(9,033)
Tax Benefit from Stock-Based Compensation		0	(563)	0	0	0	(563)
Amortization of Stock-Based Compensation Awards		0	16,252	0	0	0	16,252
Dividends ($0.125 per share)		0	0	(28,387)	0	0	28,387
Balance, End of Period at Mar. 31, 2012		$ 2,275	$ 2,250,516	$ 2,235,776	$ (713,846)	$ (609)	$ 3,774,112

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Other Comprehensive Loss (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Comprehensive Income [Roll Forward]
Accumulated Other Comprehensive Income (Loss), Net of Tax, Beginning Balance	$ (801,554)
Other Comprehensive Income (Loss), Net of Tax	87,708	(6,162)
Accumulated Other Comprehensive Income (Loss), Net of Tax, Ending Balance	$ (713,846)

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Guarantor Subsidiaries Financial Information (Tables)

3 Months Ended

12 Months Ended

Mar. 31, 2012

Mar. 31, 2011

Dec. 31, 2011

Guarantor Subsidiaries Financial Information [Abstract]

Guarantor FInancial Statements [Table Text Block] [Table Text Block]

Income Statement for the three months ended March 31, 2012 (unaudited):

	Parent Issuer			CNX Gas Guarantor		Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Sales—Outside	$	—		$	160,669	$	1,082,288	$	69,022	$	(508	)	$	1,311,471
Sales—Gas Royalty Interests	—			12,206		—		—		—			12,206
Sales—Purchased Gas	—			839		—		—		—			839
Freight—Outside	—			—		49,293		—		—			49,293
Other Income (including equity earnings)	170,023			16,305		29,703		5,957		(169,027		)	52,961
Total Revenue and Other Income	170,023			190,019		1,161,284		74,979		(169,535		)	1,426,770
Cost of Goods Sold and Other Operating Charges	49,180			98,701		682,700		66,416		7,044			904,041
Gas Royalty Interests’ Costs	—			10,255		—		—		(6		)	10,249
Purchased Gas Costs	—			517		—		—		—			517
Related Party Activity	6,015			—		1,258		502		(7,775		)	—
Freight Expense	—			—		49,293		—		—			49,293
Selling, General and Administrative Expense	—			9,924		28,628		447		—			38,999
Depreciation, Depletion and Amortization	3,919			48,803		102,102		523		—			155,347
Interest Expense	54,762			1,218		2,229		11		(100		)	58,120
Taxes Other Than Income	2,674			8,200		79,933		820		—			91,627
Total Costs	116,550			177,618		946,143		68,719		(837		)	1,308,193
Earnings (Loss) Before Income Taxes	53,473			12,401		215,141		6,260		(168,698		)	118,577
Income Tax Expense (Benefit)	(43,723		)	4,947		57,789		2,368		—			21,381
Net Income (Loss)	$	97,196		$	7,454	$	157,352	$	3,892	$	(168,698	)	$	97,196

Income Statement for the three months ended March 31, 2011 (unaudited):

	Parent Issuer			CNX Gas Guarantor		Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Sales—Outside	$	—		$	177,202	$	1,155,350		$	54,096	$	(1,170	)	$	1,385,478
Sales—Gas Royalty Interests	—			18,835		—			—		—			18,835
Sales—Purchased Gas	—			980		—			—		—			980
Freight—Outside	—			—		36,868			—		—			36,868
Other Income (including equity earnings)	246,864			1,680		11,421			9,241		(245,990		)	23,216
Total Revenue and Other Income	246,864			198,697		1,203,639			63,337		(247,160		)	1,465,377
Cost of Goods Sold and Other Operating Charges	28,976			87,612		628,960			53,987		14,174			813,709
Gas Royalty Interests’ Costs	—			16,821		—			—		(14		)	16,807
Purchased Gas Costs	—			676		—			—		—			676
Related Party Activity	(3,240		)	—		(1,741		)	466		4,515			—
Freight Expense	—			—		36,679			—		—			36,679
Selling, General and Administrative Expense	—			9,356		30,557			283		—			40,196
Depreciation, Depletion and Amortization	2,361			49,664		96,408			629		—			149,062
Interest Expense	61,142			2,680		2,742			13		(95		)	66,482
Taxes Other Than Income	1,503			7,807		80,514			865		—			90,689
Total Costs	90,742			174,616		874,119			56,243		18,580			1,214,300
Earnings (Loss) Before Income Taxes	156,122			24,081		329,520			7,094		(265,740		)	251,077
Income Tax Expense (Benefit)	(36,027		)	9,435		82,837			2,683		—			58,928
Net Income (Loss)	$	192,149		$	14,646	$	246,683		$	4,411	$	(265,740	)	$	192,149

Guarantor Balance Sheet [Table Text Block]

Balance Sheet at March 31, 2012 (unaudited):

	Parent Issuer		CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Assets:
Current Assets:
Cash and Cash Equivalents	$	119,562	$	166,205		$	957		$	589	$	—		$	287,313
Accounts and Notes Receivable:
Trade	—		41,694			423			421,141		—			463,258
Notes Receivable	2,233		311,754			527			—		—			314,514
Other	2,670		109,101			10,440			4,720		—			126,931
Inventories	—		10,508			231,359			43,130		—			284,997
Deferred Income Taxes	190,377		(61,473		)	—			—		—			128,904
Prepaid Expenses	20,409		186,888			51,900			1,621		—			260,818
Total Current Assets	335,251		764,677			295,606			471,201		—			1,866,735
Property, Plant and Equipment:
Property, Plant and Equipment	204,057		5,577,282			8,551,640			24,267		—			14,357,246
Less-Accumulated Depreciation, Depletion and Amortization	113,848		825,783			3,958,974			17,204		—			4,915,809
Property, Plant and Equipment-Net	90,209		4,751,499			4,592,666			7,063		—			9,441,437
Other Assets:
Deferred Income Taxes	935,069		(467,316		)	—			—		—			467,753
Restricted Cash	22,158		—			—			—		—			22,158
Investment in Affiliates	9,464,098		108,858			720,339			—		(10,093,074		)	200,221
Notes Receivable	4,038		296,344			—			—		—			300,382
Other	123,720		127,733			35,475			9,997		—			296,925
Total Other Assets	10,549,083		65,619			755,814			9,997		(10,093,074		)	1,287,439
Total Assets	$	10,974,543	$	5,581,795		$	5,644,086		$	488,261	$	(10,093,074	)	$	12,595,611
Liabilities and Stockholders’ Equity:
Current Liabilities:
Accounts Payable	$	133,860	$	185,616		$	140,393		$	12,052	$	—		$	471,921
Accounts Payable (Recoverable)—Related Parties	3,026,857		15,655			(3,368,808		)	326,296		—			—
Current Portion Long-Term Debt	824		5,848			13,506			701		—			20,879
Accrued Income Taxes	49,826		487			—			—		—			50,313
Other Accrued Liabilities	645,803		62,128			136,219			12,708		—			856,858
Total Current Liabilities	3,857,170		269,734			(3,078,690		)	351,757		—			1,399,971
Long-Term Debt:	3,001,170		49,813			124,566			1,169					3,176,718
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	—		—			2,976,181			—		—			2,976,181
Pneumoconiosis Benefits	—		—			174,559			—		—			174,559
Mine Closing	—		—			409,778			—		—			409,778
Gas Well Closing	—		63,004			62,553			—		—			125,557
Workers’ Compensation	—		—			150,113			264		—			150,377
Salary Retirement	242,727		—			—			—		—			242,727
Reclamation	—		—			36,148			—		—			36,148
Other	99,364		20,727			9,392			—		—			129,483
Total Deferred Credits and Other Liabilities	342,091		83,731			3,818,724			264		—			4,244,810
Total Stockholders’ Equity	3,774,112		5,178,517			4,779,486			135,071		(10,093,074		)	3,774,112
Total Liabilities and Stockholders’ Equity	$	10,974,543	$	5,581,795		$	5,644,086		$	488,261	$	(10,093,074	)	$	12,595,611

Balance Sheet at December 31, 2011:

	Parent Issuer		CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Assets:
Current Assets:
Cash and Cash Equivalents	$	37,342	$	336,727		$	1,269		$	398	$	—		$	375,736
Accounts and Notes Receivable:
Trade	—		63,299			(5,081		)	404,594		—			462,812
Notes Receivable	2,669		311,754			527			—		—			314,950
Other	2,913		91,582			7,458			3,755		—			105,708
Inventories	—		8,600			206,096			43,639		—			258,335
Deferred Income Taxes	191,689		(50,606		)	—			—		—			141,083
Prepaid Expenses	28,470		159,900			49,224			1,759		—			239,353
Total Current Assets	263,083		921,256			259,493			454,145		—			1,897,977
Property, Plant and Equipment:
Property, Plant and Equipment	198,004		5,488,094			8,376,831			24,390		—			14,087,319
Less-Accumulated Depreciation, Depletion and Amortization	109,924		778,716			3,855,323			16,940		—			4,760,903
Property, Plant and Equipment-Net	88,080		4,709,378			4,521,508			7,450		—			9,326,416
Other Assets:
Deferred Income Taxes	963,332		(455,608		)	—			—		—			507,724
Restricted Cash	22,148		—			—			—		—			22,148
Investment in Affiliates	9,126,453		96,914			760,548			—		(9,801,879		)	182,036
Notes Receivable	4,148		296,344			—			—		—			300,492
Other	116,624		110,128			52,009			10,146		—			288,907
Total Other Assets	10,232,705		47,778			812,557			10,146		(9,801,879		)	1,301,307
Total Assets	$	10,583,868	$	5,678,412		$	5,593,558		$	471,741	$	(9,801,879	)	$	12,525,700
Liabilities and Stockholders’ Equity:
Current Liabilities:
Accounts Payable	$	140,823	$	206,072		$	164,521		$	10,587	$	—		$	522,003
Accounts Payable (Recoverable)-Related Parties	2,900,546		9,431			(3,228,229		)	318,252		—			—
Current Portion of Long-Term Debt	805		5,587			13,543			756		—			20,691
Accrued Income Taxes	68,819		6,814			—			—		—			75,633
Other Accrued Liabilities	493,450		58,401			206,649			11,570		—			770,070
Total Current Liabilities	3,604,443		286,305			(2,843,516		)	341,165		—			1,388,397
Long-Term Debt:	3,001,092		50,326			124,674			1,331		—			3,177,423
Deferred Credits and Other Liabilities:
Postretirement Benefits Other Than Pensions	—		—			3,059,671			—		—			3,059,671
Pneumoconiosis Benefits	—		—			173,553			—		—			173,553
Mine Closing	—		—			406,712			—		—			406,712
Gas Well Closing	—		61,954			62,097			—		—			124,051
Workers’ Compensation	—		—			150,786			248		—			151,034
Salary Retirement	269,069		—			—			—		—			269,069
Reclamation	—		—			39,969			—		—			39,969
Other	98,379		16,899			9,658			—		—			124,936
Total Deferred Credits and Other Liabilities	367,448		78,853			3,902,446			248		—			4,348,995
Total Stockholders’ Equity	3,610,885		5,262,928			4,409,954			128,997		(9,801,879		)	3,610,885
Total Liabilities and Stockholders’ Equity	$	10,583,868	$	5,678,412		$	5,593,558		$	471,741	$	(9,801,879	)	$	12,525,700

Guarantor Condensed Cash Flow [Table Text Block]

Cash Flow for the Three Months Ended March 31, 2012 (unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination		Consolidated
Net Cash Provided by Operating Activities	$	123,513		$	54,417		$	51,118		$	438		$	—	$	229,486
Cash Flows from Investing Activities:
Capital Expenditures	$	(13,562	)	$	(98,455	)	$	(194,429	)	$	—		$	—	$	(306,446	)
Investment in Equity Affiliates	—			(13,500		)	(250		)	—			—		(13,750		)
Distributions from Equity Affiliates	—			3,500			—			—			—		3,500
Other Investing Activities	—			4,360			24,249			2			—		28,611
Net Cash Used in Investing Activities	$	(13,562	)	$	(104,095	)	$	(170,430	)	$	2		$	—	$	(288,085	)
Cash Flows from Financing Activities:
Dividends Received (Paid)	$	91,613		$	(120,000	)				$	—		$	—	$	(28,387	)
Other Financing Activities	657			(844		)	(1,000		)	(250		)	—		(1,437		)
Net Cash Provided by (Used in) Financing Activities	$	92,270		$	(120,844	)	$	(1,000	)	$	(250	)	$	—	$	(29,824	)

Cash Flow for the Three Months Ended March 31, 2011 (unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination		Consolidated
Net Cash Provided by Operating Activities	$	238,347		$	97,033		$	98,935		$	929		$	—	$	435,244
Cash Flows from Investing Activities:
Capital Expenditures	$	(3,613	)	$	(150,638	)	$	(100,527	)	$	—		$	—	$	(254,778	)
Distributions from Equity Affiliates	—			—			1,470			—			—		1,470
Other Investing Activities	10			40			245			5			—		300
Net Cash Used in Investing Activities	$	(3,603	)	$	(150,598	)	$	(98,812	)	$	5		$	—	$	(253,008	)
Cash Flows from Financing Activities:
Dividends Paid	$	(22,625	)	$	—		$	—		$	—		$	—	$	(22,625	)
(Payments on) Proceeds from Short-Term Borrowings	(155,000		)	41,500			—			—			—		(113,500		)
Payments on Securitization Facility	(200,000		)	—			—			—			—		(200,000		)
Proceeds from Long-Term Notes	250,000			—			—			—			—		250,000
Debt Issuance and Financing Fees	(4,517		)				—			—			—		(4,517		)
Other Financing Activities	6,781			(2,759		)	(516		)	(199		)	—		3,307
Net Cash Provided by (Used in) Financing Activities	$	(125,361	)	$	38,741		$	(516	)	$	(199	)	$	—	$	(87,335	)

Guarantor Condensed Comprehensive Income [Table Text Block]

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Net Income	$	97,196		$	7,454		$	157,352		$	3,892	$	(168,698	)	$	97,196
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments
Change in Prior Service Cost (Net of tax: ($30,295))	50,276			—			50,276			—		(50,276		)	50,276
Amortization of Prior Service Cost (Net of tax:$4,552)	(7,554		)	—			(7,300		)	—		7,300			(7,554		)
Amortization of Net Loss (Net of tax:($10,154))	16,851			—			9,199			—		(9,199		)	16,851
Net Increase in the Value of Cash Flow Hedge (Net of Tax: ($49,008))	76,076			76,076			—			—		(76,076		)	76,076
Reclassification of Cash Flow Hedges from OCI to Earnings (Net of tax:$31,380)	(47,941		)	(47,941		)	—			—		47,941			(47,941		)
Other Comprehensive Income (Loss):	87,708			28,135			52,175			—		(80,310		)	87,708
Comprehensive Income	$	184,904		$	35,589		$	209,527		$	3,892	$	(249,008	)	$	184,904

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Net Income	$	192,149		$	14,646		$	246,683		$	4,411	$	(265,740	)	$	192,149
Other Comprehensive Income (Loss):
Treasury Rate Lock (Net of tax:$12)	(20		)	—			—			—		—			(20		)
Actuarially Determined Long-Term Liability Adjustments
Amortization of Prior Service Cost (Net of tax:$4,583)	(7,365		)	—			(7,262		)	—		7,262			(7,365		)
Amortization of Net Loss (Net of tax:($9,766))	15,692			—			10,055			—		(10,055		)	15,692
Net Increase in the Value of Cash Flow Hedge (Net of Tax: ($2,814))	4,371			4,371			—			—		(4,371		)	4,371
Reclassification of Cash Flow Hedges from OCI to Earnings (Net of tax:$12,615)	(18,840		)	(18,840		)	—			—		18,840			(18,840		)
Other Comprehensive Income (Loss):	(6,162		)	(14,469		)	2,793			—		11,676			(6,162		)
Comprehensive Income	$	185,987		$	177		$	249,476		$	4,411	$	(254,064	)	$	185,987

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Guarantor Subsidiaries Financial Information Additional Information (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012
Senior Notes Due April 2017 at 8.00%
Condensed Financial Statements, Captions [Line Items]
Debt Instrument, Face Amount	$ 1,500,000
Interest rate stated percentage	8.00%
Senior notes due April 2020 at 8.25%
Condensed Financial Statements, Captions [Line Items]
Debt Instrument, Face Amount	1,250,000
Interest rate stated percentage	8.25%
Senior notes due March 2021 at 6.375%
Condensed Financial Statements, Captions [Line Items]
Debt Instrument, Face Amount	$ 250,000
Interest rate stated percentage	6.375%

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Related Party Transaction

3 Months Ended

Mar. 31, 2012

Related Party Transaction [Line Items]

Related Party Transactions Disclosure [Text Block]

NOTE 16—RELATED PARTY TRANSACTIONS:

CONE Gathering LLC Related Party Transactions

During the three months ended March 31, 2012, 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 $3,462, which were included in Cost of Goods Sold on the Consolidated Statements of Income.

As of March 31, 2012 and December 31, 2011, CONSOL Energy and CNX Gas had a net receivable of $29,872 and $8,966, respectively, which were comprised of the following items:

	March 31,			December 31,
	2012			2011			Location on Balance Sheet
CONE Gathering Capital Reimbursement	$	29,754		$	8,042		Accounts Receivable–Other
Reimbursement for CONE Expenses	205			2,009			Accounts Receivable–Other
Reimbursement for Services Provided to CONE	663			414			Accounts Receivable–Other
CONE Gathering Fee Payable	(750		)	(1,499		)	Accounts Payable
Net Receivable due from CONE	$	29,872		$	8,966

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Related Party Transaction (Tables)

3 Months Ended

Mar. 31, 2012

NOTE 16- RELATED PARTY TRANSACTIONS [Abstract]

Related Party Receivables Payables [Table Text Block]

	March 31,			December 31,
	2012			2011			Location on Balance Sheet
CONE Gathering Capital Reimbursement	$	29,754		$	8,042		Accounts Receivable–Other
Reimbursement for CONE Expenses	205			2,009			Accounts Receivable–Other
Reimbursement for Services Provided to CONE	663			414			Accounts Receivable–Other
CONE Gathering Fee Payable	(750		)	(1,499		)	Accounts Payable
Net Receivable due from CONE	$	29,872		$	8,966

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Acquisitions and Dispositions (Tables)

3 Months Ended

Mar. 31, 2011

ACQUISITIONS AND DISPOSITIONS: [Abstract]

Business Acquisition, Pro Forma Information

The following unaudited pro forma combined financial statements are based on CONSOL Energy's historical consolidated financial statements and adjusted to give effect to the September 30, 2011 sale of a 50% interest in certain Marcellus Shale assets. The unaudited pro forma results for the period presented below are prepared as if the transaction occurred as of January 1, 2011 and do not include material, non-recurring charges.

	Three Months Ended
	March 31,
	2011
Total Revenue and Other Income	$	1,455,126
Earnings Before Income Taxes	$	247,418
Net Income	$	189,330
Basic Earnings Per Share	$	0.84
Dilutive Earnings Per Share	$	0.83

The pro forma results are not necessarily indicative of what actually would have occurred if the transaction had been completed as of January 1, 2011, nor are they necessarily indicative of future consolidated results.

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Guarantor Subsidiaries, Condensed Statement of Cash Flows (Detail) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	$ 229,486	$ 435,244
Investing Activities:
Capital Expenditures	(306,446)	(254,778)
Payments for Advance to Affiliate	(13,750)
Equity Method Investment, Dividends or Distributions	3,500	(1,470)
Net Investment in Equity Affiliates	(10,250)	1,470
Other Investing Activities	(28,611)	(300)
Net Cash Used in Investing Activities	(288,085)	(253,008)
Financing Activities:
Dividends Paid	(28,387)	(22,625)
(Payments on) Proceeds from Short-Term Borrowings	0	(113,500)
Proceeds from Accounts Receivable Securitization		(200,000)
Proceeds from Issuance of Long-Term Notes	0	250,000
Proceeds from Issuance of Common Stock	54	0
Other Financing Activities	(1,437)	3,307
Net Cash (Used in) Provided by Financing Activities	(29,824)	(87,335)
Parent Issuer
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	123,513	238,347
Investing Activities:
Capital Expenditures	(13,562)	(3,613)
Payments for Advance to Affiliate	0
Equity Method Investment, Dividends or Distributions	0	0
Other Investing Activities	0	10
Net Cash Used in Investing Activities	(13,562)	(3,603)
Financing Activities:
Dividends Paid	91,613	(22,625)
(Payments on) Proceeds from Short-Term Borrowings		(155,000)
Proceeds from Accounts Receivable Securitization		(200,000)
Proceeds from Issuance of Long-Term Notes		250,000
Debt Issuance and Financing Fees		(4,517)
Other Financing Activities	657	6,781
Net Cash (Used in) Provided by Financing Activities	92,270	(125,361)
CNX Gas Guarantor
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	54,417	97,033
Investing Activities:
Capital Expenditures	(98,455)	(150,638)
Payments for Advance to Affiliate	(13,500)
Equity Method Investment, Dividends or Distributions	(3,500)	0
Other Investing Activities	4,360	40
Net Cash Used in Investing Activities	(104,095)	(150,598)
Financing Activities:
Dividends Paid	(120,000)	0
(Payments on) Proceeds from Short-Term Borrowings		41,500
Proceeds from Accounts Receivable Securitization		0
Debt Issuance and Financing Fees
Other Financing Activities	(844)	(2,759)
Net Cash (Used in) Provided by Financing Activities	(120,844)	38,741
Other Subsidiary Guarantors
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	51,118	98,935
Investing Activities:
Capital Expenditures	(194,429)	(100,527)
Payments for Advance to Affiliate	(250)
Equity Method Investment, Dividends or Distributions	0	1,470
Other Investing Activities	24,249	245
Net Cash Used in Investing Activities	(170,430)	(98,812)
Financing Activities:
Dividends Paid		0
(Payments on) Proceeds from Short-Term Borrowings		0
Proceeds from Accounts Receivable Securitization		0
Proceeds from Issuance of Long-Term Notes		0
Debt Issuance and Financing Fees		0
Other Financing Activities	(1,000)	(516)
Net Cash (Used in) Provided by Financing Activities	(1,000)	(516)
Non-Guarantors
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	438	929
Investing Activities:
Capital Expenditures	0	0
Payments for Advance to Affiliate	0
Equity Method Investment, Dividends or Distributions	0	0
Other Investing Activities	2	5
Net Cash Used in Investing Activities	2	5
Financing Activities:
Dividends Paid	0	0
(Payments on) Proceeds from Short-Term Borrowings		0
Proceeds from Accounts Receivable Securitization		0
Proceeds from Issuance of Long-Term Notes		0
Debt Issuance and Financing Fees		0
Other Financing Activities	(250)	(199)
Net Cash (Used in) Provided by Financing Activities	(250)	(199)
Elimination
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	0	0
Investing Activities:
Capital Expenditures	0	0
Payments for Advance to Affiliate	0
Equity Method Investment, Dividends or Distributions	0	0
Other Investing Activities	0	0
Net Cash Used in Investing Activities	0	0
Financing Activities:
Dividends Paid	0	0
(Payments on) Proceeds from Short-Term Borrowings		0
Proceeds from Accounts Receivable Securitization		0
Proceeds from Issuance of Long-Term Notes		0
Debt Issuance and Financing Fees		0
Other Financing Activities	0	0
Net Cash (Used in) Provided by Financing Activities	$ 0	$ 0

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Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Operating Activities:
Net Income (Loss)	$ 97,196	$ 192,149
Adjustments to Reconcile Net Income to Net Cash Provided By Operating Activities:
Depreciation, Depletion and Amortization	155,347	149,062
Stock-Based Compensation	16,252	13,446
(Gain) Loss on Sale of Assets	(19,713)	(323)
Amortization of Mineral Leases	1,886	2,468
Deferred Income Taxes	(2,265)	23,099
Equity in Earnings of Affiliates	(7,935)	(5,481)
Changes in Operating Assets:
Accounts and Notes Receivable	(17,990)	(26,901)
Inventories	(26,662)	(29,435)
Prepaid Expenses	6,231	7,585
Changes in Other Assets	10,837	9,449
Changes in Operating Liabilities:
Accounts Payable	(39,312)	7,279
Other Operating Liabilities	62,233	75,863
Changes in Other Liabilities	(8,928)	13,521
Other	2,309	3,463
Net Cash Provided by Operating Activities	229,486	435,244
Investing Activities:
Capital Expenditures	(306,446)	(254,778)
Proceeds from Sales of Assets	28,611	300
Net Investment in Equity Affiliates	(10,250)	1,470
Net Cash Used in Investing Activities	(288,085)	(253,008)
Financing Activities:
(Payments on) Proceeds from Short-Term Borrowings	0	(113,500)
Payments on Miscellaneous Borrowings	(2,330)	(3,698)
Payments on Securitzation Facility	0	(200,000)
Proceeds from Issuance of Long-Term Notes	0	250,000
Tax Benefit from Stock-Based Compensation	750	3,306
Dividends Paid	(28,387)	(22,625)
Proceeds from Issuance of Common Stock	54	0
Issuance of Treasury Stock	109	3,699
Debt Issuance and Financing Fees	(20)	(4,517)
Net Cash (Used in) Provided by Financing Activities	(29,824)	(87,335)
Net Increase in Cash and Cash Equivalents	(88,423)	94,901
Cash and Cash Equivalents at Beginning of Period	375,736	32,794
Cash and Cash Equivalents at End of Period	$ 287,313	$ 127,695

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Parentheticals (USD $) In Thousands, except Share data, unless otherwise specified			3 Months Ended		3 Months Ended
	Mar. 31, 2012 Preferred Stock [Member]	Dec. 31, 2010 Preferred Stock [Member]	Mar. 31, 2012 Common Stock [Member]	Dec. 31, 2010 Common Stock [Member]	Mar. 31, 2012 Treasury Rate Lock [Member]	Mar. 31, 2012 Cash Flow Hedging [Member]	Mar. 31, 2012 Adjustment For Actuarially Determined Liabilities [Member]
Tax related to treasury rate lock					$ 0	$ 0	$ 0
Common Stock, Par Value			$ 0.01	$ 0.01
Common Stock, Shares Authorized			500,000,000	500,000,000
Common Stock, Issued			227,542,426	227,289,426
Common Stock, Shares, Outstanding			227,507,671	227,056,212
Preferred Stock, authorized	15,000,000	15,000,000
Preferred Stock, issued	0	0
Preferred Stock, outstanding	0	0
Common Stock in Treasury, Shares			34,755	233,214
Dividends Paid Per Share			$ 0.13

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Long-Term Debt

3 Months Ended

Mar. 31, 2012

Notes to Financial Statements [Abstract]

Long-term Debt

LONG-TERM DEBT:

	March 31, 2012		December 31, 2011
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
Baltimore Port Facility revenue bonds in series due September 2025 at 5.75%	102,865		102,865
Advance royalty commitments (6.73% weighted average interest rate for March 31, 2012 and December 31, 2011, respectively)	31,053		31,053
Other long-term note maturing in 2031	75		75
	3,133,993		3,133,993
Less amounts due in one year	11,759		11,759
Long-Term Debt	$	3,122,234	$	3,122,234

Accrued interest related to Long-Term Debt of $113,891 and $63,577 was included in Other Accrued Liabilities in the Consolidated Balance Sheets at March 31, 2012 and December 31, 2011, respectively.

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Document and Entity Information	3 Months Ended
	Mar. 31, 2012	Apr. 18, 2012
Document and Entity Information
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q1
Entity Registration Name	CONSOL Energy Inc
Entity Central Index Key	0001070412
Current Fiscal Year End	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock Shares Outstanding		227,545,200

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2012

Notes to Financial Statements [Abstract]

Commitments and Contingencies

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 amount 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 $1,562,000.

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. It is likely that the AOC will be executed in the second quarter of 2012. If the AOC is signed by April 30, 2012 the EPA will grant 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%. CONSOL Energy has established an initial accrual based on its percentage share of the costs at the high end of the range. 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 United States Environmental Protection Agency (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. 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. Also, in September 2008, the EPA notified CONSOL Energy and sixty other PRPs that there were additional areas of potential contamination allegedly related to the Ward Transformer Site. Current estimates of the cost or potential range of cost for this area are not yet available. CONSOL Energy recognized no expense in Cost of Goods Sold and Other charges in the three months ended March 31, 2012 and 2011, respectively. As of March 31, 2012, 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 $4,477. Accordingly, the liability reflected in Other Accrued Liabilities was reduced by these settled claims. The remaining net liability at March 31, 2012 is $3,483.

Asbestos-Related Litigation: One of our subsidiaries, Fairmont Supply Company (Fairmont), which distributes industrial supplies, currently is named as a defendant in approximately 7,300 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). On February 16, 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 has appealed the DEP's findings to the Pennsylvania Environmental Hearing Board (PEHB), which will consider the case de novo, meaning without regard to the DEP's decision, as to any finding of causation of damage and/or the amount of damages. Either party may appeal the decision of the PEHB to the Pennsylvania Commonwealth Court, and then, as may be allowed, to the Pennsylvania Supreme Court. A hearing on the merits of the case will not occur until sometime in the spring or summer of 2013. As to the underlying claim, CONSOL Energy believes it is not responsible for the damage to the dam and that numerous grounds exist upon which to attack the propriety of the claims. If CONSOL Energy is ultimately found to be liable for damages to the dam, we believe the range of loss would be between $9,000 and $30,000. There have been settlement discussions and we have established an accrual to cover our estimated settlement 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.

C. L. Ritter: On March 1, 2011, the Company was served with a complaint instituted by C. L. Ritter Lumber Company Incorporated against Consolidation Coal Company (CCC), Island Creek Coal Company, (ICCC), CNX Gas Company LLC, subsidiaries of CONSOL Energy Inc., as well as CONSOL Energy itself in the Circuit Court of Buchanan County, Virginia, seeking damages and injunctive relief in connection with the deposit of untreated water from mining activities at CCC's Buchanan Mine into nearby void spaces at one of the mines of ICCC. The suit alleges damages of between $34,000 and $430,000 for alleged damage to coal and coalbed methane, as well as breach of contract damages. We have removed the case to federal court and filed a motion to dismiss, largely predicated on the statute of limitations bar. The trial judge ruled that the issue of the applicability of the statute of limitations bar can only be addressed after discovery. There have been settlement discussions and we have established an accrual to cover our estimated settlement 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 U.S. District Court in Abingdon, Virginia styled Hale v. CNX Gas Company LLC et. al. The lawsuit alleges that the plaintiff class consists of oil and gas owners, that the Virginia Supreme Court has decided that coalbed methane (CBM) belongs to the owner of the oil and gas estate, that the Virginia Gas and Oil Act of 1990 unconstitutionally allows force pooling of CBM, that the Act unconstitutionally provides only a 1/8 royalty to CBM owners for gas produced under the force pooling orders, and that the Company only relied upon control of the coal estate in force pooling the CBM notwithstanding the Virginia Supreme Court decision holding that if only the coal estate is controlled, the CBM is not thereby controlled. 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 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, and that CNX Gas need not distribute the net proceeds to class members. The Magistrate Judge recommended against the dismissal of certain other claims, none of which are believed to have any significance. The District Judge affirmed the Magistrate Judge's Recommendations in their entirety. The plaintiffs and CNX Gas have agreed to stay this litigation. CONSOL Energy believes that the case is without merit 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 Federal court in Virginia styled Addison v. CNX Gas Company LLC. The case involves two primary claims: (i) the plaintiff and similarly situated CNX Gas lessors identified as conflicting claimants during the force pooling process before the Virginia Gas and Oil Board are the owners of the CBM and, accordingly, the owners of the escrowed royalty payments being held by the Commonwealth of Virginia; and (ii) 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. Plaintiffs seek a declaratory judgment regarding ownership and compensatory and punitive damages for breach of contract; conversion; negligence (voluntary undertaking), for force pooling coal owners after the Ratliff decision declared coal owners did not own the CBM; negligent breach of duties as an operator; breach of fiduciary duties; and unjust enrichment. We filed a Motion to Dismiss in this case, and the Magistrate Judge recommended dismissing some claims and allowing others to proceed. The District Judge affirmed the Magistrate Judge's Recommendations in their entirety. The plaintiffs and CNX Gas Company have agreed to stay this litigation. CONSOL Energy believes that the case is without merit 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.

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

South Carolina Gas & Electric Company Arbitration: South Carolina Electric & Gas Company (SCE&G), a utility, has demanded arbitration, seeking $36,000 in damages against CONSOL of Kentucky and CONSOL Energy Sales Company, both wholly owned subsidiaries of CONSOL Energy. SCE&G claims it suffered 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 which SCE&G had agreed could be made up in 2009.  A hearing on the claims is scheduled for April 30, 2012. The named CONSOL Energy defendants deny all liability and intend to vigorously defend the action filed against them. For that reason, we have not accrued a liability for this claim. If liability is ultimately imposed on the named CONSOL Energy defendants, we believe the range of loss would be between $17,000 and $29,000.

CNX Gas Shareholders Litigation: CONSOL Energy has been named as a defendant in five putative class actions brought by alleged shareholders of CNX Gas 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 three cases filed in the Delaware Chancery Court have been consolidated under the caption In Re CNX Gas Shareholders Litigation (C.A. No. 5377-VCL).  All five 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. The lawsuit will likely go to trial, possibly in 2013. CONSOL Energy believes that these actions are without merit and intends to defend them vigorously. For that reason, we have not accrued a liability for this claim; however, if liability is ultimately imposed, based on the expert reports that have been exchanged by the parties, we believe the range of loss could be up to $221,000.

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 which were instituted by four individuals against Consolidation Coal Company (CCC), Island Creek Coal Company, (ICCC), CNX Gas Company LLC, subsidiaries of CONSOL Energy, as well as CONSOL Energy itself in the Circuit Court of Russell County, Virginia, seeking damages and injunctive relief in connection with the deposit of untreated water from mining activities at CCC's Buchanan Mine into nearby void spaces at some of the mines of ICCC. The suits each allege damages of between $25,750 and $119,500 for alleged damage to coal and coalbed methane, as well as breach of contract and assumpsit damages. We have removed the cases to federal court and filed a motion to dismiss, largely predicated on the statute of limitations bar. Three similar lawsuits were filed recently, one in federal court and two in the Circuit Court of Buchanan County, Virginia, by other plaintiffs that collectively allege damages of between $100,000 and $622,000. One of the three suits which claimed damages of $22,000 was dismissed in federal court and has been appealed. Another which claimed damages of $312,000 was settled for an amount immaterial to the overall financial position of CONSOL Energy. The Company intends to file a motion to dismiss the remaining case. CCC believes that it had, and continues to have, the right to store water in these void areas. CCC and the other named CONSOL Energy defendants deny all liability and intend to vigorously defend the actions filed against them in connection with the removal and deposit of water from the Buchanan Mine. Consequently, we have not recognized any liability related to these actions.

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. 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 briefing will take place before a decision is rendered. 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, 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 they farmed out the development of the lease to Dominion, in exchange for an overriding royalty. Dominion 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's 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 (ii) the subsequent merger of the subsidiary into CNX Gas Company was an assignment that required its consent under the lease. Rowland alleges that the failure to obtain the required consent constitutes a breach of the lease and it seeks damages and a forfeiture of the lease. CONSOL Energy and CNX Gas Company have filed a motion to dismiss the complaint, arguing among other things, that Dominion's sale of the indirect subsidiary was not a change in control; that even if the sale constituted a change in control, the purchase agreement between Dominion and CONSOL Energy did not give effect to the transfer so the transfer never occurred; that the mergers did not require consent; and that Rowland did not provide timely notice of breach of the lease in accordance with its terms. Rowland is amending its complaint to include allegations that CONSOL Energy and Dominion Resources are liable for their subsidiaries' actions. We will file a motion to dismiss in response. 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. 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. 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. The trial court has dismissed this case. The dismissal is being appealed.

At March 31, 2012, 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	$	194,566	$	130,826	$	63,740	$	—	$	—
Environmental	56,994		35,046		21,948		—		—
Other	80,508		43,561		36,947		—		—
Total Letters of Credit	332,068		209,433		122,635		—		—
Surety Bonds:
Employee-Related	204,895		179,515		25,380		—		—
Environmental	447,858		436,545		11,313		—		—
Other	27,729		27,663		65		—		1
Total Surety Bonds	680,482		643,723		36,758		—		1
Guarantees:
Coal	24,802		16,501		3,301		1,000		4,000
Gas	123,418		72,811		19,985		—		30,622
Other	456,389		83,388		137,314		87,975		147,712
Total Guarantees	604,609		172,700		160,600		88,975		182,334
Total Commitments	$	1,617,159	$	1,025,856	$	319,993	$	88,975	$	182,335

Employee-related financial guarantees have primarily been provided to support the United Mine Workers’ of America’s 1992 Benefit Plan and various state 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 March 31, 2012, the purchase obligations for each of the next five years and beyond were as follows:

Obligations Due	Amount
Less than 1 year	$	563,134
1 - 3 years	403,906
3 - 5 years	498,271
More than 5 years	1,639,535
Total Purchase Obligations	$	3,104,846

Costs related to these purchase obligations include:

	Three Months Ended
	March 31,
	2012		2011
Major equipment purchases	$	13,166	$	7,655
Firm transportation expense	15,045		12,818
Gas drilling obligations	29,576		25,818
Other	298		101
Total costs related to purchase obligations	$	58,085	$	46,392

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Consolidated Statement of Comprehensive Income (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Net Income (Loss) Attributable to Parent [Abstract]
Net Income	$ 97,196	$ 192,149
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Treasury Rate Lock (Net of $12 Tax)	0	(20)
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 ($30,295))	50,276	0
Other Comprehensive Income (Loss), Amortization, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost Recognized in Net Periodic Pension Cost, Net of Tax: $4,552, $4,583	(7,554)	(7,365)
Defined Benefit Plan, Amortization of Net Loss (Net of Tax: ($10,154), ($9,766))	16,851	15,692
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Abstract]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, (Net of Tax: ($49,008), ($2,814))	76,076	4,371
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $31,380, $12,615)	(47,941)	(18,840)
Other Comprehensive Income (Loss), Net of Tax	87,708	(6,162)
Comprehensive Income (Loss)	$ 184,904	$ 185,987

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Income Taxes

3 Months Ended

Mar. 31, 2012

INCOME TAXES: [Abstract]

Income Taxes

INCOME TAXES:

The following is a reconciliation, stated in dollars and as a percentage of pretax income, of the U.S. statutory federal income tax rate to CONSOL Energy’s effective tax rate:

	For the Three Months Ended March 31,
	2012					2011
	Amount			Percent		Amount			Percent
Statutory U.S. federal income tax rate	$	41,502		35.0	%	$	87,877		35.0	%
Excess tax depletion	(26,514		)	(22.4	)	(39,169		)	(15.6	)
Effect of domestic production activities	—			—		(1,916		)	(0.8	)
Net effect of state income taxes	3,510			3.0		8,818			3.5
Other	2,883			2.4		3,318			1.4
Income Tax Expense / Effective Rate	$	21,381		18.0	%	$	58,928		23.5	%

The effective rates for the three months ended March 31, 2012 and 2011 were calculated using the annual effective rate projection on recurring earnings and include tax liabilities related to certain discrete transactions which are described below.

During the three months ended March 31, 2012, CONSOL Energy reached an agreement with the Internal Revenue Service Appeals Division on its Extraterritorial Income Exclusion refund claim for tax years 2004-2005. As a result of the agreement, the Company reflected $983 as a discrete reduction to income tax expense. The discrete transaction was reflected in the Other line of the rate reconciliation.

The total amounts of uncertain tax positions at March 31, 2012 and 2011 were $25,570 and $65,510, respectively. If these uncertain tax positions were recognized, approximately $3,891 and $16,802, respectively, would affect CONSOL Energy’s effective tax rate. There were no additions to the liability for unrecognized tax benefits during the three months ended March 31, 2012 and 2011.

CONSOL Energy recognizes interest accrued related to uncertain tax positions in its interest expense. As of March 31, 2012 and 2011, the Company reported an accrued interest liability relating to uncertain tax positions of $5,741 and $11,895, respectively. The accrued interest liability includes $368 of interest income and $1,121 of interest expense that is reflected in the Company’s Consolidated Statements of Income for the three months ended March 31, 2012 and 2011, respectively.

CONSOL Energy recognizes penalties accrued related to uncertain tax positions in its income tax expense. As of March 31, 2012 and 2011, CONSOL Energy had no accrued liability for tax penalties.

CONSOL Energy and its subsidiaries file federal income tax returns with the United States and returns within various states and Canadian jurisdictions. With few exceptions, the Company is no longer subject to United States federal, state, local, or non-U.S. income tax determinations by tax authorities for the years before 2008.

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CWP and Workers Comp - Net Periodic Costs

3 Months Ended

Mar. 31, 2012

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 months ended March 31 are as follows:

	CWP						Workers’ Compensation
	Three Months Ended						Three Months Ended
	March 31,						March 31,
	2012			2011			2012			2011
Service cost	$	1,178		$	1,155		$	3,634		$	4,468
Interest cost	1,991			2,333			1,778			2,060
Amortization of actuarial gain	(4,934		)	(5,478		)	(986		)	(977		)
State administrative fees and insurance bond premiums	—			—			1,910			1,222
Legal and administrative costs	750			750			648			718
Net periodic (benefit) cost	$	(1,015	)	$	(1,240	)	$	6,984		$	7,491

CONSOL Energy does not expect to contribute to the CWP plan in 2012. We intend to pay benefit claims as they become due. For the three months ended March 31, 2012, $2,850 of CWP benefit claims have been paid.

CONSOL Energy does not expect to contribute to the workers’ compensation plan in 2012. We intend to pay benefit claims as they become due. For the three months ended March 31, 2012, $9,050 of workers’ compensation benefits, state administrative fees and surety bond premiums have been paid.

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Basis of Presentation (Tables)

3 Months Ended

Mar. 31, 2012

BASIS OF PRESENTATION: [Abstract]

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share

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 March 31,
	2012	2011
Anti-Dilutive Options	1,574,922	1,157,937
Anti-Dilutive Restricted Stock Units	12,203	—
Anti-Dilutive Performance Share Options	100,350	—
	1,687,475	1,157,937

Schedule of Basic and Dilutive Earnings Per Share

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

	Three Months Ended March 31,
	2012		2011
Net income attributable to CONSOL Energy Inc. shareholders	$	97,196	$	192,149
Weighted average shares of common stock outstanding:
Basic	227,269,269		226,350,594
Effect of stock-based compensation awards	2,854,742		2,464,244
Dilutive	230,124,011		228,814,838
Earnings per share:
Basic	$	0.43	$	0.85
Dilutive	$	0.42	$	0.84

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 March 31,
	2012	2011
Options	11,716	180,396
Restricted Stock Units	458,018	341,141
Performance Share Units	229,730	40,752
	699,464	562,289

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Derivative Instruments

3 Months Ended

Mar. 31, 2012

Notes to Financial Statements [Abstract]

Derivative Instruments:

DERIVATIVE INSTRUMENTS:

CONSOL Energy enters into financial derivative instruments to manage our exposure to commodity price volatility. We measure each derivative instrument at fair value and record it on the balance sheet as either an asset or liability. 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 fair value of the derivative are reported in Other Comprehensive Income or Loss (OCI) and reclassified into earnings 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.

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 March 31, 2012, the total notional amount of the Company’s outstanding natural gas swap contracts was 160.0 billion cubic feet. These swap contracts are forecasted to settle through December 31, 2015 and meet the criteria for cash flow hedge accounting. During the next twelve months, $110,024 of unrealized gain is expected to be reclassified from Other Comprehensive Income and into earnings, as a result of the settlement of cash flow hedges. No gains or losses have been reclassified into earnings as a result of the discontinuance of cash flow hedges.

The fair value at March 31, 2012 of CONSOL Energy's derivative instruments, which were all natural gas swaps and qualify as cash flow hedges, was an asset of $297,708 and a liability of $1,505. The total asset is comprised of $181,072 and $116,636 which were included in Prepaid Expense and Other Assets, respectively, on the Consolidated Balance Sheets. The total liability is included in Other Liabilities on the Consolidated Balance Sheets.

The fair value at December 31, 2011 of CONSOL Energy's derivative instruments, which were all natural gas swaps and qualify as cash flow hedges, was an asset of $251,277. The total asset is comprised of $153,376 and $97,901 which were included in Prepaid Expense and Other Assets, 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:

	Three Months Ended March 31,
	2012			2011
Natural Gas Price Swaps
Gain recognized in Accumulated OCI	$	76,076		$	4,371
Gain reclassified from Accumulated OCI into Outside Sales	$	47,941		$	18,840
Loss recognized in Outside Sales for ineffectiveness	$	(835	)	$	(108	)

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Property, Plant and Equipment

3 Months Ended

Mar. 31, 2012

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

PROPERTY, PLANT AND EQUIPMENT:

	March 31, 2012		December 31, 2011
Coal & Other Plant and Equipment	$	5,301,715	$	5,160,759
Proven Gas Properties	1,542,838		1,542,837
Coal Properties and Surface Lands	1,352,159		1,340,757
Intangible Drilling Cost	1,344,207		1,277,678
Unproven Gas Properties	1,269,083		1,258,027
Gas Gathering Equipment	970,552		963,494
Airshafts	666,334		659,736
Leased Coal Lands	541,577		540,817
Mine Development	474,859		457,179
Gas Wells and Related Equipment	410,245		408,814
Coal Advance Mining Royalties	396,682		393,340
Other Gas Assets	80,459		79,816
Gas Advance Royalties	6,536		4,065
Total Property Plant and Equipment	14,357,246		14,087,319
Less: Accumulated DD&A	4,915,809		4,760,903
Total Net PP&E	$	9,441,437	$	9,326,416

Industry Participation Agreements

As of March 31, 2012, CONSOL Energy had entered into two significant industry participation agreements (referred to as "joint ventures" or "JVs") that provided drilling and completion carries for our retained interests. The following table provides information about our industry participation agreements as of March 31, 2012:

Shale Play	Industry Participation Agreement Partner	Industry Participation Agreement Date	Total Drilling Carries		Drilling Carries Billed to Partner		Drilling Carries Remaining
Marcellus	Noble Energy, Inc.	September 30, 2011	$	2,100,000	$	10,204	$	2,089,796
Utica	Hess Ohio Developments, LLC	October 21, 2011	$	534,000	$	3,348	$	530,652

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Financial Instruments Measured at Fair Value on a Recurring Basis (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
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	296,203	251,277
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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Inventories

3 Months Ended

Mar. 31, 2012

INVENTORIES: [Abstract]

Inventories

INVENTORIES:

Inventory components consist of the following:

	March 31, 2012		December 31, 2011
Coal	$	125,308	$	105,378
Merchandise for resale	43,130		43,639
Supplies	116,559		109,318
Total Inventories	$	284,997	$	258,335

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 $23,093 and $22,406 at March 31, 2012 and December 31, 2011, respectively.

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Accounts Receivable Securitization

3 Months Ended

Mar. 31, 2012

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 March 31, 2012, there were letters of credit outstanding against the facility of $160,779. 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. 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 $419 and $724 for the three months ended March 31, 2012 and 2011, respectively. These costs have been recorded as financing fees which are included in Cost of Goods Sold and Other Operating Charges in the Consolidated Statements of Income. No servicing asset or liability has been recorded. The receivables facility expires in March 2017 with the underlying liquidity agreement renewing annually each March.

At March 31, 2012 and December 31, 2011, eligible accounts receivable totaled $200,000 and $192,700, respectively. There was subordinated retained interest of $39,221 at March 31, 2012 and $192,700 at December 31, 2011. There were no borrowings under the Securitization Facility recorded on the Consolidated Balance Sheet as of March 31, 2012 and December 31, 2011. 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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Short-Term Notes Payable

3 Months Ended

Mar. 31, 2012

Notes to Financial Statements [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 (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 5.84 to 1.00 at March 31, 2012. The facility includes a maximum leverage ratio covenant of not more than 4.75 to 1.00, measured quarterly through March 31, 2013, and no more than 4.50 to 1.00 thereafter. The leverage ratio was 2.10 to 1.00 at March 31, 2012. 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 0.07 to 1.00 at March 31, 2012. 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 March 31, 2012, the $1,500,000 facility had no borrowings outstanding and $101,013 of letters of credit outstanding, leaving $1,398,987 of capacity available for borrowings and the issuance of letters of credit. The facility had no borrowings outstanding at December 31, 2011.

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 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 the CONE Gathering Company are unrestricted. The facility includes a maximum leverage ratio covenant of not more than 3.50 to 1.00, measured quarterly. The leverage ratio was 0.00 to 1.00 at March 31, 2012. The facility also includes a minimum interest coverage ratio covenant of no less than 3.00 to 1.00, measured quarterly. This ratio was 35.79 to 1.00 at March 31, 2012. At March 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 facility had no borrowings outstanding at

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Reconciliation of Segment Information, Total Assets (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011	Mar. 31, 2011
Assets:
Assets	$ 12,595,611	$ 12,525,700	$ 12,223,741
Total Reportable Business Segments
Assets:
Assets	11,471,162		11,059,077
Coal
Assets:
Assets	5,360,577		5,092,682
Gas
Assets:
Assets	6,110,585		5,966,395
All Other Segments [Member]
Assets:
Assets	358,746		341,613
Excludes Gas Segment [Member]
Items excluded from segment assets:
Cash and Other Investments	121,807		126,613
Corporate Elimination [Member]
Assets:
Assets	765,703		823,051
Items excluded from segment assets:
Recoverable Income Taxes	0		5,031
Deferred Tax Assets	596,657		636,636
Bond Issuance Costs	$ 47,239		$ 54,771

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Guarantor Subsidiaries Income Statement (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	$ 1,311,471	$ 1,385,478
Sales-Gas Royalty Interests	12,206	18,835
Sales-Purchased Gas	839	980
Freight-Outside	49,293	36,868
Other Income (including equity earnings)	52,961	23,216
Total Revenue and Other Income	1,426,770	1,465,377
Cost of Goods Sold and Other Operating Charges	904,041	813,709
Gas Royalty Interests Costs	10,249	16,807
Purchased Gas Costs	517	676
Related Party Activity	0	0
Freight Expense	49,293	36,679
Selling, General and Administrative Expenses	38,999	40,196
Depreciation, Depletion and Amortization	155,347	149,062
Interest Expense	58,120	66,482
Taxes Other Than Income	91,627	90,689
Total Costs	1,308,193	1,214,300
Earnings Before Income Taxes	118,577	251,077
Income Tax Expense (Benefit)	21,381	58,928
Net Income	97,196	192,149
Parent Issuer
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	0	0
Sales-Gas Royalty Interests	0	0
Sales-Purchased Gas	0	0
Freight-Outside	0	0
Other Income (including equity earnings)	170,023	246,864
Total Revenue and Other Income	170,023	246,864
Cost of Goods Sold and Other Operating Charges	49,180	28,976
Gas Royalty Interests Costs	0	0
Purchased Gas Costs	0	0
Related Party Activity	6,015	(3,240)
Freight Expense	0	0
Selling, General and Administrative Expenses	0	0
Depreciation, Depletion and Amortization	3,919	2,361
Interest Expense	54,762	61,142
Taxes Other Than Income	2,674	1,503
Total Costs	116,550	90,742
Earnings Before Income Taxes	53,473	156,122
Income Tax Expense (Benefit)	(43,723)	(36,027)
Net Income	97,196	192,149
CNX Gas Guarantor
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	160,669	177,202
Sales-Gas Royalty Interests	12,206	18,835
Sales-Purchased Gas	839	980
Freight-Outside	0	0
Other Income (including equity earnings)	16,305	1,680
Total Revenue and Other Income	190,019	198,697
Cost of Goods Sold and Other Operating Charges	98,701	87,612
Gas Royalty Interests Costs	10,255	16,821
Purchased Gas Costs	517	676
Related Party Activity	0	0
Freight Expense	0	0
Selling, General and Administrative Expenses	9,924	9,356
Depreciation, Depletion and Amortization	48,803	49,664
Interest Expense	1,218	2,680
Taxes Other Than Income	8,200	7,807
Total Costs	177,618	174,616
Earnings Before Income Taxes	12,401	24,081
Income Tax Expense (Benefit)	4,947	9,435
Net Income	7,454	14,646
Other Subsidiary Guarantors
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	1,082,288	1,155,350
Sales-Gas Royalty Interests	0	0
Sales-Purchased Gas	0	0
Freight-Outside	49,293	36,868
Other Income (including equity earnings)	29,703	11,421
Total Revenue and Other Income	1,161,284	1,203,639
Cost of Goods Sold and Other Operating Charges	682,700	628,960
Gas Royalty Interests Costs	0	0
Purchased Gas Costs	0	0
Related Party Activity	1,258	(1,741)
Freight Expense	49,293	36,679
Selling, General and Administrative Expenses	28,628	30,557
Depreciation, Depletion and Amortization	102,102	96,408
Interest Expense	2,229	2,742
Taxes Other Than Income	79,933	80,514
Total Costs	946,143	874,119
Earnings Before Income Taxes	215,141	329,520
Income Tax Expense (Benefit)	57,789	82,837
Net Income	157,352	246,683
Non-Guarantors
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	69,022	54,096
Sales-Gas Royalty Interests	0	0
Sales-Purchased Gas	0	0
Freight-Outside	0	0
Other Income (including equity earnings)	5,957	9,241
Total Revenue and Other Income	74,979	63,337
Cost of Goods Sold and Other Operating Charges	66,416	53,987
Gas Royalty Interests Costs	0	0
Purchased Gas Costs	0	0
Related Party Activity	502	466
Freight Expense	0	0
Selling, General and Administrative Expenses	447	283
Depreciation, Depletion and Amortization	523	629
Interest Expense	11	13
Taxes Other Than Income	820	865
Total Costs	68,719	56,243
Earnings Before Income Taxes	6,260	7,094
Income Tax Expense (Benefit)	2,368	2,683
Net Income	3,892	4,411
Elimination
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	(508)	(1,170)
Sales-Gas Royalty Interests	0	0
Sales-Purchased Gas	0	0
Freight-Outside	0	0
Other Income (including equity earnings)	(169,027)	(245,990)
Total Revenue and Other Income	(169,535)	(247,160)
Cost of Goods Sold and Other Operating Charges	7,044	14,174
Gas Royalty Interests Costs	(6)	(14)
Purchased Gas Costs	0	0
Related Party Activity	(7,775)	4,515
Freight Expense	0	0
Selling, General and Administrative Expenses	0	0
Depreciation, Depletion and Amortization	0	0
Interest Expense	(100)	(95)
Taxes Other Than Income	0	0
Total Costs	(837)	18,580
Earnings Before Income Taxes	(168,698)	(265,740)
Income Tax Expense (Benefit)	0	0
Net Income	$ (168,698)	$ (265,740)

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Reconciliation of Segment Information, Revenue and Other Income (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Earnings Before Income Taxes:
Earnings Before Income Taxes	$ 118,577	$ 251,077
Total Reportable Business Segments
Earnings Before Income Taxes:
Earnings Before Income Taxes	174,970	322,868
Coal
Earnings Before Income Taxes:
Earnings Before Income Taxes	162,470	298,692
Gas
Earnings Before Income Taxes:
Earnings Before Income Taxes	12,500	24,176
All Other Segments [Member]
Earnings Before Income Taxes:
Earnings Before Income Taxes	4,083	(1,849)
Excludes Gas Segment [Member]
Earnings Before Income Taxes:
Interest Income (Expense), Net and Other Non-operating Activity	(60,042)	(69,286)
Fees for Disposing Non-core Assets	(434)	(656)
Corporate Elimination [Member]
Earnings Before Income Taxes:
Earnings Before Income Taxes	$ (60,476)	$ (69,942)

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Segment Information (Tables)

3 Months Ended

Mar. 31, 2012

Mar. 31, 2011

Notes to Financial Statements [Abstract]

Industry segment results

Industry segment results for the three months ended March 31, 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	$	812,053	$	172,740	$	60,568	$	8,955		$	1,054,316	$	99,535	$	23,791	$	34,373		$	2,504		$	160,203	$	96,952	$	—		$	1,311,471	(A)
Sales—purchased gas	—		—		—		—			—		—		—		—			839			839		—		—			839
Sales—gas royalty interests	—		—		—		—			—		—		—		—			12,206			12,206		—		—			12,206
Freight—outside	—		—		—		49,293			49,293		—		—		—			—			—		—		—			49,293
Intersegment transfers	—		—		—		—			—		—		—		—			466			466		37,209		(37,675		)	—
Total Sales and Freight	$	812,053	$	172,740	$	60,568	$	58,248		$	1,103,609	$	99,535	$	23,791	$	34,373		$	16,015		$	173,714	$	134,161	$	(37,675	)	$	1,373,809
Earnings (Loss) Before Income Taxes	$	128,855	$	79,361	$	15,611	$	(61,357	)	$	162,470	$	36,390	$	3,251	$	(3,722	)	$	(23,419	)	$	12,500	$	4,083	$	(60,476	)	$	118,577	(B)
Segment assets										$	5,360,577											$	6,110,585	$	358,746	$	765,703		$	12,595,611	(C)
Depreciation, depletion and amortization										$	100,762											$	48,803	$	5,782	$	—		$	155,347
Capital expenditures										$	194,429											$	98,455	$	13,562	$	—		$	306,446

(A) Included in the Coal segment are sales of $144,155 to First Energy and $138,341 to Xcoal Energy & Resources each comprising over 10% of sales.

(B) Includes equity in earnings of unconsolidated affiliates of $4,807, $1,944 and $1,184 for Coal, Gas and All Other, respectively.

(C) Includes investments in unconsolidated equity affiliates of $39,373, $108,858 and $51,990 for Coal, Gas and All Other, respectively.

Industry segment results for the three months ended March 31, 2011 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	$	801,952	$	236,895	$	78,233	$	13,364		$	1,130,444	$	113,774	$	21,042	$	38,745		$	2,648		$	176,209	$	78,825		$	—		$	1,385,478
Sales—purchased gas	—		—		—		—			—		—		—		—			980			980		—			—			980
Sales—gas royalty interests	—		—		—		—			—		—		—		—			18,835			18,835		—			—			18,835
Freight—outside	—		—		—		36,868			36,868		—		—		—			—			—		—			—			36,868
Intersegment transfers	—		—		—		—			—		—		—		—			993			993		53,396			(54,389		)	—
Total Sales and Freight	$	801,952	$	236,895	$	78,233	$	50,232		$	1,167,312	$	113,774	$	21,042	$	38,745		$	23,456		$	197,017	$	132,221		$	(54,389	)	$	1,442,161
Earnings (Loss) Before Income Taxes	$	194,044	$	142,594	$	40,893	$	(78,839	)	$	298,692	$	50,003	$	8,503	$	(2,750	)	$	(31,580	)	$	24,176	$	(1,849	)	$	(69,942	)	$	251,077	(D)
Segment assets										$	5,092,682											$	5,966,395	$	341,613		$	823,051		$	12,223,741	(E)
Depreciation, depletion and amortization										$	95,081											$	49,664	$	4,317		$	—		$	149,062
Capital expenditures										$	100,530											$	150,638	$	3,610		$	—		$	254,778

Reconciliation of Revenue and Operating Income from Segments to Consolidated

Earnings Before Income Taxes:

	For the Three Months Ended March 31,
	2012			2011
Segment Earnings Before Income Taxes for total reportable business segments	$	174,970		$	322,868
Segment Earnings Before Income Taxes for all other businesses	4,083			(1,849		)
Interest income (expense), net and other non-operating activity (F)	(60,042		)	(69,286		)
Evaluation fees for non-core asset dispositions (F)	(434		)	(656		)
Earnings Before Income Taxes	$	118,577		$	251,077

Reconciliation of Assets and Liabilities from Segment to Consolidated

Total Assets:	March, 31
	2012		2011
Segment assets for total reportable business segments	$	11,471,162	$	11,059,077
Segment assets for all other businesses	358,746		341,613
Items excluded from segment assets:
Cash and other investments (F)	121,807		126,613
Recoverable income taxes	—		5,031
Deferred tax assets	596,657		636,636
Bond issuance costs	47,239		54,771
Total Consolidated Assets	$	12,595,611	$	12,223,741

_________________________ 

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

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Short-Term Notes Payable (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012
Short-term Debt [Line Items]
Letters of credit outstanding	$ 160,779
Senior Secured Credit Facility April122016 Member [Member]
Short-term Debt [Line Items]
Credit facility, face amount	1,500,000
Additional Capacity Available On Credit Lines At Request	250,000
Minimum interest coverage ratio	2.50
Interest coverage ratio	5.84
Maximum leverage ratio	4.75
Current maximum leverage ratio	2.10
Senior secured leverage ratio, maximum	2.00
Current secured leverage ratio	0.07
Letters of credit outstanding	101,013
Borrowings and issuance of letters of credit remaining capacity	1,398,987
CNX Gas Senior Secured Credit Facility April122016 Member [Member]
Short-term Debt [Line Items]
Credit facility, face amount	1,000,000
Additional Capacity Available On Credit Lines At Request	250,000
Minimum interest coverage ratio	3.00
Interest coverage ratio	35.79
Maximum leverage ratio	3.50
Current maximum leverage ratio	0.00
Letters of credit outstanding	70,203
Borrowings and issuance of letters of credit remaining capacity	$ 929,797

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Segment Information

3 Months Ended

Mar. 31, 2012

Notes to Financial Statements [Abstract]

Segment Information

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 steam 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 three months ended March 31, 2012, 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 three months ended March 31, 2012, the Low Volatile Metallurgical aggregated segment includes the Buchanan Mine and Amonate Complex. For the three months ended March 31, 2012, 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.

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CWP and Workers Comp - Net Periodic Costs (Tables)

3 Months Ended

Mar. 31, 2012

CWP And Workers Comp Net Periodic Costs [Abstract]

Components of Net Periodic Benefit Costs

Components of net periodic costs (benefits) for the three months ended March 31 are as follows:

	CWP						Workers’ Compensation
	Three Months Ended						Three Months Ended
	March 31,						March 31,
	2012			2011			2012			2011
Service cost	$	1,178		$	1,155		$	3,634		$	4,468
Interest cost	1,991			2,333			1,778			2,060
Amortization of actuarial gain	(4,934		)	(5,478		)	(986		)	(977		)
State administrative fees and insurance bond premiums	—			—			1,910			1,222
Legal and administrative costs	750			750			648			718
Net periodic (benefit) cost	$	(1,015	)	$	(1,240	)	$	6,984		$	7,491

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Property, Plant and Equipment (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Property, Plant and Equipment [Line Items]
Coal and other plant and equipment	$ 5,301,715	$ 5,160,759
Proven gas properties	1,542,838	1,542,837
Coal properties and surface lands	1,352,159	1,340,757
Drilling Cost	1,344,207	1,277,678
Unproven gas properties	1,269,083	1,258,027
Gas gathering equipment	970,552	963,494
Airshafts	666,334	659,736
Leased coal lands	541,577	540,817
Mine development	474,859	457,179
Gas wells and related equipment	410,245	408,814
Coal advance mining royalties	396,682	393,340
Other gas assets	80,459	79,816
Gas advance royalties	6,536	4,065
Total property plant and equipment	14,357,246	14,087,319
Less Accumulated depreciation, depletion and amortization	4,915,809	4,760,903
Total Property, Plant and Equipment-Net	$ 9,441,437	$ 9,326,416

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Dispositions (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified			3 Months Ended						3 Months Ended
	Mar. 31, 2012	Dec. 31, 2011	Mar. 31, 2012 Burning Star Disposal [Member] A	Sep. 30, 2011 Noble JV[Member] [Member] A	Mar. 31, 2011 Noble JV[Member] [Member]	Sep. 30, 2011 Antero [Member] A	Dec. 31, 2011 Hess [Member]	Oct. 21, 2011 Hess [Member] A	Sep. 30, 2011 CONE [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment									$ 119,740
acreage			4,300			116,000
Proceeds from Sale of Property, Plant, and Equipment			13,023			193,000	54,254		7,675
Business Acquisition, Cost of Acquired Entity, Transaction Costs								5,719
Gain (Loss) on Sale of Property Plant Equipment			11,261			41,057	53,095
Gas and Oil Acreage, Unproved, Net				628,000				200,000
Business Acquisition, Cost of Acquired Entity, Cash Paid				485,464
Note Receivable 1 year - joint venture proceed				311,754
Note receivable 2 year - joint venture proceeds				296,344
Business Acquisition, Purchase Price Allocation, Current Assets, Receivables				16,703
Business Acquisition, Purchase Price Allocation, Current Liabilities, Accounts Payable				980
Significant Acquisitions and Disposals, Gain (Loss) on Sale or Disposal, Pretax				64,142					7,161
Drilling commitment carry				2,100,000				534,000
Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds									67,545
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	200,221	182,036							59,870
Business Acquisition, Pro Forma Information [Abstract]
Business Acquisition, Pro Forma Revenue					1,455,126
Business Acquisition, Pro Forma Income (Loss) from Continuing Operations before Changes in Accounting and Extraordinary Items, Net of Tax					247,418
Business Acquisition, Pro Forma Net Income (Loss)					$ 189,330
Basic Earnings Per Share, Pro Forma					$ 0.84
Business Acquisition, Pro Forma Earnings Per Share, Diluted					$ 0.83

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Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Mar. 31, 2012	Dec. 31, 2011
Current Assets:
Cash and Cash Equivalents	$ 287,313	$ 375,736
Accounts and Notes Receivable:
Trade	463,258	462,812
Notes Receivable, Related Parties, Current	314,514	314,950
Other Receivables	126,931	105,708
Inventories	284,997	258,335
Deferred Income Taxes	128,904	141,083
Prepaid Expenses	260,818	239,353
Total Current Assets	1,866,735	1,897,977
Property, Plant and Equipment:
Property, Plant and Equipment	14,357,246	14,087,319
Less-Accumulated Depreciation, Depletion and Amortization	4,915,809	4,760,903
Total Property, Plant and Equipment-Net	9,441,437	9,326,416
Other Assets:
Deferred Income Taxes	467,753	507,724
Restricted Cash	22,158	22,148
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	200,221	182,036
Notes, Loans and Financing Receivable, Net, Noncurrent	300,382	300,492
Other	296,925	288,907
Total Other Assets	1,287,439	1,301,307
Total Assets	12,595,611	12,525,700
Current Liabilities:
Accounts Payable	471,921	522,003
Current Portion of Long-Term Debt	20,879	20,691
Accrued Income Taxes, Current	50,313	75,633
Other Accrued Liabilities	856,858	770,070
Total Current Liabilities	1,399,971	1,388,397
Long-Term Debt:
Long-Term Debt	3,122,234	3,122,234
Capital Lease Obligations	54,484	55,189
Total Long-Term Debt	3,176,718	3,177,423
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	2,976,181	3,059,671
Pneumoconiosis Benefits	174,559	173,553
Mine Closing	409,778	406,712
Gas Well Closing	125,557	124,051
Workers' Compensation	150,377	151,034
Salary Retirement	242,727	269,069
Reclamation	36,148	39,969
Other	129,483	124,936
Total Deferred Credits and Other Liabilities	4,244,810	4,348,995
TOTAL LIABILITIES	8,821,499	8,914,815
Stockholders' Equity:
Common Stock, $.01 Par Value; 500,000,000 Shares Authorized, 227,542,426 Issued and 227,507,671 Outstanding at March 31, 2012; 227,289,426 Issued and 227,056,212 Outstanding at December 31, 2011	2,275	2,273
Capital in Excess of Par Value	2,250,516	2,234,775
Preferred Stock, 15,000,000 shares authorized, None issued and outstanding	0	0
Retained Earnings	2,235,776	2,184,737
Accumulated Other Comprehensive Loss	(713,846)	(801,554)
Common Stock in Treasury, at Cost—34,755 Shares at March 31, 2012 and 233,214 Shares at December 31, 2011	(609)	(9,346)
Total CONSOL Energy Inc. Stockholders' Equity	3,774,112	3,610,885
TOTAL LIABILITIES AND EQUITY	$ 12,595,611	$ 12,525,700

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Pension and OPEB - Periodic Cost

3 Months Ended

Mar. 31, 2012

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 for the three months ended March 31 are as follows:

	Pension Benefits						Other Postretirement Benefits
	Three Months Ended						Three Months Ended
	March 31,						March 31,
	2012			2011			2012			2011
Service cost	$	5,153		$	4,289		$	5,200		$	3,977
Interest cost	9,378			9,078			35,527			42,204
Expected return on plan assets	(11,627		)	(9,630		)	—			—
Amortization of prior service cost (credits)	(408		)	(167		)	(11,599		)	(11,599		)
Recognized net actuarial loss	12,263			9,146			20,345			22,364
Net periodic benefit cost	$	14,759		$	12,716		$	49,473		$	56,946

For the three months ended March 31, 2012, $29,746 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 $110,000 to the pension trust in 2012.

On March 31, 2012, the salaried OPEB plan was remeasured to reflect an announced plan amendment that will reduce medical and prescription drug benefits as of January 1, 2014. The plan amendment calls for a fixed annual retiree medical contribution into a Health Reimbursement Account for eligible employees. The amount of contribution is dependent on several factors. The money in the account can be used to help pay for a commercial medical plan, Medicare Part B or Part D premiums, and other qualified expenses. Employees who work or worked in corporate or operational support positions at retirement and who are age 50 or above at December 31, 2013 will receive the revised benefit in lieu of the current retiree medical and prescription drug benefits. Employees who work or worked in corporate or operational support positions who are under age 50 at December 31, 2013 will receive no medical or prescription drug benefits. The remeasurement reflects the reduction in benefits and the change in discount rate to 4.57% at March 31, 2012 from 4.51% at December 31, 2011. The remeasurement resulted in an $80,570 reduction in the OPEB liability with a corresponding adjustment of $50,275 in other comprehensive income, net of $30,295 in deferred taxes. The change was made to align our corporate and operational support compensation package with our peer group. OPEB expense is expected to be $9,425 lower than the $148,419 that was expected to be recognized over the remaining nine months of 2012.

CONSOL Energy does not expect to contribute to the other postemployment benefit plan in 2012. We intend to pay benefit claims as they become due. For the three months ended March 31, 2012, $42,378 of other postemployment benefits have been paid.

For the three months ended March 31, 2011, CONSOL Energy received proceeds of $7,781 under the Patient Protection and Affordable Care Act (PPACA) related to reimbursement from the Federal government for retiree health spending. This amount is included as a reduction of benefit and other payments in the reconciliation of changes in benefit obligation. There is no guarantee that additional proceeds will be received under this program.

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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 $)	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in OCI on Derivative	$ 76,076	$ 4,371
Outside Sales
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from Accumulated OCI into Income	47,941	18,840
Amount of Gain (Loss) Recognized in Income on Derivative	$ (835)	$ (108)

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Guarantor Subsidiaries Financial Information Gurantor Subsidiaries Statement of Comprehensive Income (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Net Income (Loss) Attributable to Parent [Abstract]
Net Income	$ 97,196	$ 192,149
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Treasury Rate Lock (Net of $12 Tax)	0	(20)
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	50,276	0
Other Comprehensive Income (Loss), Amortization, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost Recognized in Net Periodic Pension Cost, Net of Tax	(7,554)	(7,365)
Defined Benefit Plan, Amortization of Net Loss	16,851	15,692
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, (Net of Tax: ($49,008), ($2,814))	76,076	4,371
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $31,380, $12,615)	(47,941)	(18,840)
Other Comprehensive Income (Loss), Net of Tax	87,708	(6,162)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	184,904	185,987
Parent Issuer
Net Income (Loss) Attributable to Parent [Abstract]
Net Income	97,196	192,149
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Treasury Rate Lock (Net of $12 Tax)		(20)
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	50,276
Other Comprehensive Income (Loss), Amortization, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost Recognized in Net Periodic Pension Cost, Net of Tax	(7,554)	(7,365)
Defined Benefit Plan, Amortization of Net Loss	16,851	15,692
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, (Net of Tax: ($49,008), ($2,814))	76,076	4,371
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $31,380, $12,615)	(47,941)	(18,840)
Other Comprehensive Income (Loss), Net of Tax	87,708	(6,162)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	184,904	185,987
CNX Gas Guarantor
Net Income (Loss) Attributable to Parent [Abstract]
Net Income	7,454	14,646
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Treasury Rate Lock (Net of $12 Tax)		0
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	0
Other Comprehensive Income (Loss), Amortization, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost Recognized in Net Periodic Pension Cost, Net of Tax	0	0
Defined Benefit Plan, Amortization of Net Loss	0	0
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, (Net of Tax: ($49,008), ($2,814))	76,076	4,371
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $31,380, $12,615)	(47,941)	(18,840)
Other Comprehensive Income (Loss), Net of Tax	28,135	(14,469)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	35,589	177
Other Guarantors Subsidiaries [Member]
Net Income (Loss) Attributable to Parent [Abstract]
Net Income	157,352	246,683
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Treasury Rate Lock (Net of $12 Tax)		0
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	50,276
Other Comprehensive Income (Loss), Amortization, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost Recognized in Net Periodic Pension Cost, Net of Tax	(7,300)	(7,262)
Defined Benefit Plan, Amortization of Net Loss	9,199	10,055
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, (Net of Tax: ($49,008), ($2,814))	0	0
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $31,380, $12,615)	0	0
Other Comprehensive Income (Loss), Net of Tax	52,175	2,793
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	209,527	249,476
Non-Guarantors
Net Income (Loss) Attributable to Parent [Abstract]
Net Income	3,892	4,411
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Treasury Rate Lock (Net of $12 Tax)		0
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	0
Other Comprehensive Income (Loss), Amortization, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost Recognized in Net Periodic Pension Cost, Net of Tax	0	0
Defined Benefit Plan, Amortization of Net Loss	0	0
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, (Net of Tax: ($49,008), ($2,814))	0	0
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $31,380, $12,615)	0	0
Other Comprehensive Income (Loss), Net of Tax	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	3,892	4,411
Consolidation, Eliminations [Member]
Net Income (Loss) Attributable to Parent [Abstract]
Net Income	(168,698)	(265,740)
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Treasury Rate Lock (Net of $12 Tax)		0
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	(50,276)
Other Comprehensive Income (Loss), Amortization, Pension and Other Postretirement Benefit Plans, Net Prior Service Cost Recognized in Net Periodic Pension Cost, Net of Tax	7,300	7,262
Defined Benefit Plan, Amortization of Net Loss	(9,199)	(10,055)
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, (Net of Tax: ($49,008), ($2,814))	(76,076)	(4,371)
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $31,380, $12,615)	47,941	18,840
Other Comprehensive Income (Loss), Net of Tax	(80,310)	11,676
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$ (249,008)	$ (254,064)

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Income Taxes (Tables)

3 Months Ended

Mar. 31, 2012

INCOME TAXES: [Abstract]

Components of Consolidated Income Taxes

	For the Three Months Ended March 31,
	2012					2011
	Amount			Percent		Amount			Percent
Statutory U.S. federal income tax rate	$	41,502		35.0	%	$	87,877		35.0	%
Excess tax depletion	(26,514		)	(22.4	)	(39,169		)	(15.6	)
Effect of domestic production activities	—			—		(1,916		)	(0.8	)
Net effect of state income taxes	3,510			3.0		8,818			3.5
Other	2,883			2.4		3,318			1.4
Income Tax Expense / Effective Rate	$	21,381		18.0	%	$	58,928		23.5	%

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Basis of Presentation Anti-Dilutive Options and Units Exluded from Earnings Per Share (Details)	3 Months Ended
	Mar. 31, 2012	Mar. 31, 2011
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of diluted earnings per share	1,687,475	1,157,937
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	1,574,922	1,157,937
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	12,203	0
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	100,350	0

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Fair Value of Financial Instruments

3 Months Ended

Mar. 31, 2012

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 March 31, 2012						Fair Value Measurements at December 31, 2011
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	$	—	$	296,203	$	—	$	—	$	251,277	$	—

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.

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:

	March 31, 2012						December 31, 2011
	Carrying Amount			Fair Value			Carrying Amount			Fair Value
Cash and cash equivalents	$	287,313		$	287,313		$	375,736		$	375,736
Restricted cash	$	22,158		$	22,158		$	22,148		$	22,148
Long-term debt	$	(3,133,993	)	$	(3,270,880	)	$	(3,133,993	)	$	(3,422,452	)