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, 2013

OR

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

For the transition period from to

Commission file number: 001-14901

  __________________________________________________

CONSOL Energy Inc.

(Exact name of registrant as specified in its charter)

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

1000 CONSOL Energy Drive

Canonsburg, PA 15317-6506

(724) 485-4000

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

 __________________________________________________ 

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

Yes  x    No  o

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

Yes  x    No   o

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

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

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

Yes  o    No  x

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

Class	Shares outstanding as of April 22,2013
Common stock, $0.01 par value	228,629,068

TABLE OF CONTENTS
		Page
PART I FINANCIAL INFORMATION
ITEM 1.	Condensed Financial Statements
	Consolidated Statements of Income for the three months ended March 31, 2013 and 2012	3
	Consolidated Statements of Comprehensive Income for the three months ended March 31, 2013 and 2012	4
	Consolidated Balance Sheets at March 31, 2013 and December 31, 2012	5
	Consolidated Statement of Stockholders’ Equity for the three months ended March 31, 2013	7
	Consolidated Statements of Cash Flows for the three months ended March 31, 2013 and 2012	8
	Notes to Unaudited Consolidated Financial Statements	9
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	36
ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	64
ITEM 4.	Controls and Procedures	66
PART II OTHER INFORMATION
ITEM 1.	Legal Proceedings	67
ITEM 4.	Mine Safety Disclosures	67
ITEM 6.	Exhibits	67

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,
	2013			2012
Sales—Outside	$	1,226,165		$	1,311,471
Sales—Gas Royalty Interests	14,204			12,206
Sales—Purchased Gas	1,358			839
Freight—Outside	14,061			49,293
Other Income	33,852			52,961
Total Revenue and Other Income	1,289,640			1,426,770
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	932,963			904,137
Gas Royalty Interests Costs	11,806			10,249
Purchased Gas Costs	959			517
Freight Expense	14,061			49,293
Selling, General and Administrative Expenses	33,670			38,903
Depreciation, Depletion and Amortization	161,315			155,347
Interest Expense	53,378			58,120
Taxes Other Than Income	82,787			91,627
Total Costs	1,290,939			1,308,193
(Loss) Earnings Before Income Taxes	(1,299		)	118,577
Income Taxes	522			21,381
Net (Loss) Income	(1,821		)	97,196
Add: Net Loss Attributable to Noncontrolling Interest	257			—
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(1,564	)	$	97,196
Earnings Per Share:
Basic	$	(0.01	)	$	0.43
Dilutive	$	(0.01	)	$	0.42
Weighted Average Number of Common Shares Outstanding:
Basic	228,318,123			227,269,269
Dilutive	228,318,123			230,124,011
Dividends Paid Per Share	$	—		$	0.125

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,
	2013			2012
Net (Loss) Income	$	(1,821	)	$	97,196
Other Comprehensive Income:
Actuarially Determined Long-Term Liability Adjustments (Net of tax: ($28,250), ($35,897))	45,757			59,573
Net (Decrease) Increase in the Value of Cash Flow Hedge (Net of tax: $13,966, ($49,008))	(18,595		)	76,076
Reclassification of Cash Flow Hedges from OCI to Earnings (Net of tax: $11,984, $31,380)	(22,713		)	(47,941		)
Other Comprehensive Income	4,449			87,708
Comprehensive Income	2,628			184,904
Add: Comprehensive Loss Attributable to Noncontrolling Interest	257			—
Comprehensive Income Attributable to CONSOL Energy Inc. Shareholders	$	2,885		$	184,904

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, 2013		December 31, 2012
ASSETS
Current Assets:
Cash and Cash Equivalents	$	25,058	$	21,878
Accounts and Notes Receivable:
Trade	408,350		428,328
Notes Receivables	322,406		318,387
Other Receivables	153,697		131,131
Accounts Receivable - Securitized	30,119		37,846
Inventories	217,034		247,766
Deferred Income Taxes	160,750		148,104
Recoverable Income Taxes	6,602		—
Restricted Cash	—		48,294
Prepaid Expenses	115,156		157,360
Total Current Assets	1,439,172		1,539,094
Property, Plant and Equipment:
Property, Plant and Equipment	15,749,523		15,545,204
Less—Accumulated Depreciation, Depletion and Amortization	5,516,319		5,354,237
Total Property, Plant and Equipment—Net	10,233,204		10,190,967
Other Assets:
Deferred Income Taxes	425,079		444,585
Restricted Cash	20,383		20,379
Investment in Affiliates	248,127		222,830
Notes Receivable	25,995		25,977
Other	201,234		227,077
Total Other Assets	920,818		940,848
TOTAL ASSETS	$	12,593,194	$	12,670,909

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

5

CONSOL ENERGY INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Dollars in thousands, except per share data)

	(Unaudited)
	March 31, 2013			December 31, 2012
LIABILITIES AND EQUITY
Current Liabilities:
Accounts Payable	$	463,886		$	507,982
Current Portion of Long-Term Debt	13,353			13,485
Short-Term Notes Payable	—			25,073
Accrued Income Taxes	—			34,219
Borrowings Under Securitization Facility	30,119			37,846
Other Accrued Liabilities	839,294			768,494
Total Current Liabilities	1,346,652			1,387,099
Long-Term Debt:
Long-Term Debt	3,124,240			3,124,473
Capital Lease Obligations	48,299			50,113
Total Long-Term Debt	3,172,539			3,174,586
Deferred Credits and Other Liabilities:
Postretirement Benefits Other Than Pensions	2,825,925			2,832,401
Pneumoconiosis Benefits	175,952			174,781
Mine Closing	449,891			446,727
Gas Well Closing	150,973			148,928
Workers’ Compensation	154,573			155,648
Salary Retirement	172,306			218,004
Reclamation	43,833			47,965
Other	128,316			131,025
Total Deferred Credits and Other Liabilities	4,101,769			4,155,479
TOTAL LIABILITIES	8,620,960			8,717,164
Stockholders’ Equity:
Common Stock, $.01 Par Value; 500,000,000 Shares Authorized, 228,609,116 Issued and 228,574,361 Outstanding at March 31, 2013; 228,129,467 Issued and 228,094,712 Outstanding at December 31, 2012	2,289			2,284
Capital in Excess of Par Value	2,320,223			2,296,908
Preferred Stock, 15,000,000 shares authorized, None issued and outstanding	—			—
Retained Earnings	2,393,528			2,402,551
Accumulated Other Comprehensive Loss	(742,893		)	(747,342		)
Common Stock in Treasury, at Cost—34,755 Shares at March 31, 2013 and 34,755 Shares at December 31, 2012	(609		)	(609		)
Total CONSOL Energy Inc. Stockholders’ Equity	3,972,538			3,953,792
Noncontrolling Interest	(304		)	(47		)
TOTAL EQUITY	3,972,234			3,953,745
TOTAL LIABILITIES AND EQUITY	$	12,593,194		$	12,670,909

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

6

CONSOL ENERGY INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

(Dollars in thousands, except per share data)

	Common Stock		Capital in Excess of Par Value			Retained Earnings (Deficit)			Accumulated Other Comprehensive Income (Loss)			Common Stock in Treasury			Total CONSOL Energy Inc. Stockholders’ Equity			Non- Controlling Interest			Total Equity
December 31, 2012	$	2,284	$	2,296,908		$	2,402,551		$	(747,342	)	$	(609	)	$	3,953,792		$	(47	)	$	3,953,745
(Unaudited)
Net Loss	—		—			(1,564		)	—			—			(1,564		)	(257		)	(1,821		)
Other Comprehensive Income	—		—			—			4,449			—			4,449			—			4,449
Comprehensive Income (Loss)	—		—			(1,564		)	4,449			—			2,885			(257		)	2,628
Issuance of Common Stock	5		904			—			—			—			909			—			909
Treasury Stock Activity	—		—			(7,459		)	—			—			(7,459		)	—			(7,459		)
Tax Cost From Stock-Based Compensation	—		(3,658		)	—			—			—			(3,658		)	—			(3,658		)
Amortization of Stock-Based Compensation Awards	—		26,069			—			—			—			26,069			—			26,069
Balance at March 31, 2013	$	2,289	$	2,320,223		$	2,393,528		$	(742,893	)	$	(609	)	$	3,972,538		$	(304	)	$	3,972,234

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,
	2013			2012
Operating Activities:
Net (Loss) Income	$	(1,821	)	$	97,196
Adjustments to Reconcile Net Income to Net Cash Provided By Operating Activities:
Depreciation, Depletion and Amortization	161,315			155,347
Stock-Based Compensation	26,069			16,252
Gain on Sale of Assets	(2,176		)	(19,713		)
Amortization of Mineral Leases	503			1,886
Deferred Income Taxes	305			(2,265		)
Equity in Earnings of Affiliates	(4,797		)	(7,935		)
Changes in Operating Assets:
Accounts and Notes Receivable	27,137			(17,990		)
Inventories	30,732			(26,662		)
Prepaid Expenses	7,944			6,231
Changes in Other Assets	6,749			10,837
Changes in Operating Liabilities:
Accounts Payable	(26,474		)	(39,312		)
Other Operating Liabilities	19,940			62,233
Changes in Other Liabilities	16,652			(8,928		)
Other	6,202			2,309
Net Cash Provided by Operating Activities	268,280			229,486
Investing Activities:
Capital Expenditures	(405,972		)	(306,446		)
Change in Restricted Cash	48,294			—
Proceeds from Sales of Assets	138,636			28,611
Investments In Equity Affiliates	(12,500		)	(10,250		)
Net Cash Used in Investing Activities	(231,542		)	(288,085		)
Financing Activities:
Payments on Miscellaneous Borrowings	(27,601		)	(2,330		)
Payments on Securitization Facility	(7,727		)	—
Tax Benefit from Stock-Based Compensation	730			750
Dividends Paid	—			(28,387		)
Issuance of Common Stock	909			54
Issuance of Treasury Stock	—			109
Debt Issuance and Financing Fees	131			(20		)
Net Cash Used In Financing Activities	(33,558		)	(29,824		)
Net Increase (Decrease) in Cash and Cash Equivalents	3,180			(88,423		)
Cash and Cash Equivalents at Beginning of Period	21,878			375,736
Cash and Cash Equivalents at End of Period	$	25,058		$	287,313

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, 2013 are not necessarily indicative of the results that may be expected for future periods.

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

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

Basic earnings per share are computed by dividing net (loss) income attributable to shareholders by the weighted average shares outstanding during the reporting period. Dilutive earnings per share are computed similarly to basic earnings per share except that the weighted average shares outstanding are increased to include additional shares from the assumed exercise of stock options 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 stock units and performance share units were released, and that the proceeds from such activities were used to acquire shares of common stock at the average market price during the reporting period. CONSOL Energy Inc. (CONSOL Energy or the Company) includes the impact of pro forma deferred tax assets in determining potential windfalls and shortfalls for purposes of calculating assumed proceeds under the treasury stock method. The table below sets forth the share-based awards that have been excluded from the computation of the diluted earnings per share because their effect would be anti-dilutive:

	Three Months Ended March 31,
	2013	2012
Anti-Dilutive Options	5,011,771	1,574,922
Anti-Dilutive Restricted Stock Units	1,459,228	12,203
Anti-Dilutive Performance Share Units	700,040	—
Anti-Dilutive Performance Share Options	602,101	100,350
Anti-Dilutive CONSOL Share Units	891,921	—
	8,665,061	1,687,475

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

	Three Months Ended March 31,
	2013	2012
Options	84,994	11,716
Restricted Stock Units	478,509	458,018
Performance Share Units	159,228	229,730
	722,731	699,464

The weighted average exercise price per share of the options exercised during the three months ended March 31, 2013 and 2012 was $10.65 and $13.81, respectively.

9

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

	Three Months Ended March 31,
	2013			2012
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(1,564	)	$	97,196
Weighted average shares of common stock outstanding:
Basic	228,318,123			227,269,269
Effect of stock-based compensation awards	—			2,854,742
Dilutive	228,318,123			230,124,011
Earnings per share:
Basic	$	(0.01	)	$	0.43
Dilutive	$	(0.01	)	$	0.42

Changes in Accumulated Other Comprehensive Income / (Loss) by component, net of tax, were as follows:

	Gains and Losses on Cash Flow Hedges			Postretirement Benefits			Total
Balance at December 31, 2012	$	76,761		$	(824,103	)	$	(747,342	)
Other comprehensive income before reclassifications	(18,595		)	18,497			(98		)
Amounts reclassified from accumulated other comprehensive income	(22,713		)	27,260			4,547
New current period other comprehensive income	(41,308		)	45,757			4,449
Balance at March 31, 2013	$	35,453		$	(778,346	)	$	(742,893	)

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

	Three Months Ended March 31,
	2013			2012
Derivative Instruments (Note 12)
Natural gas price swaps	$	(34,697	)	$	(79,321	)
Tax benefit	11,984			31,380
Net of tax	$	(22,713	)	$	(47,941	)
Actuarially Determined Long-Term Liability Adjustments*(Note 3 and Note 4)
Amortization of prior service costs	$	(8,212	)	$	(12,106	)
Recognized net actuarial loss	25,188			27,005
Settlement loss	27,115			—
Total	44,091			14,899
Tax expense	(16,831		)	(5,602		)
Net of tax	$	27,260		$	9,297

*Excludes amounts related to the remeasurement of the Actuarially Determined Long-Term Liabilities for the three months ended March 31, 2013 and March 31, 2012.

10

NOTE 2—ACQUISITIONS AND DISPOSITIONS:

During the three months ended March 31, 2013, CNX Gas Company LLC (CNX Gas Company), a wholly owned subsidiary of CONSOL Energy, completed negotiations with the Allegheny County Airport Authority, which operates the Pittsburgh International Airport and the Allegheny County Airport, for the lease of the oil and gas rights on approximately 9.3 thousand acres.  A majority of these contiguous acres are in the liquids area of the Marcellus Shale play.  CNX Gas Company paid $46,315 as an up-front bonus payment at closing.  Approximately 7.6% of the bonus payment was placed into escrow while negotiations continue for a portion of the acres associated with the Allegheny County Airport and other acres that have potentially defective title.  CNX Gas Company must spud a well by February 21, 2015 and proceed with due diligence to complete the well or the lease terminates and CNX Gas Company foregoes the bonus. Our joint venture partner, Noble Energy, has indicated that it intends to acquire 50% of the acreage and accordingly, incur 50% of the associated costs.

In March 2013, CONSOL Energy completed a sale-leaseback of longwall shields for the Shoemaker Mine. Cash proceeds for the sale were $63,839. A loss of $279 was recognized due to transaction fees and is included in Other Income in the Consolidated Statement of Income. The lease has been accounted for as an operating lease. The lease term is five years.

In January 2013, CONSOL Energy completed a sale-leaseback of longwall shields for the Bailey Mine. Cash proceeds for the sale were $71,166. A loss of $358 was recognized due to transaction fees and is included in Other Income in the Consolidated Statement of Income. The lease has been accounted for as an operating lease. The lease term is five years.

On December 21, 2012, CONSOL Energy completed the disposition of its non-producing Ram River & Scurry Ram assets in Western Canada which consisted of 36 thousand acres of coal lands. In December 2012, cash proceeds of $51,869, of which $48,294 was restricted, were received related to this transaction. These proceeds were net of $637 in transaction fees. The restrictions on the cash were removed during the three months ended March 31, 2013 and are reflected as a Change in Restricted Cash in the Investing section of the Consolidated Statement of Cash Flows. Additionally, a note receivable was recognized in 2012 related to the two additional cash payments to be received in June 2013 and June 2014. Notes receivables of $25,500 and $24,500 were recorded in Accounts and Notes Receivables and Other Assets in the Consolidated Balance Sheet, respectively. The gain on the transaction was $89,943 and was included in Other Income in the Consolidated Statement of Income for the year ended December 31, 2012.

On February 9, 2012, CONSOL Energy completed the disposition of its Burning Star No. 4 property in Illinois, which consisted of 4.3 thousand acres of coal lands and surface rights, for proceeds of $13,023. The gain on the transaction was $11,261 and is included in Other Income in the Consolidated Statements of Income for the three month period ended March 31, 2012.

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,
	2013			2012			2013			2012
Service cost	$	5,706		$	5,153		$	4,849		$	5,200
Interest cost	8,843			9,378			29,619			35,527
Expected return on plan assets	(12,144		)	(11,627		)	—			—
Amortization of prior service cost (credits)	(408		)	(408		)	(7,804		)	(11,599		)
Recognized net actuarial loss	12,175			12,263			17,595			20,345
Settlement loss	27,115			—			—			—
Net periodic benefit cost	$	41,287		$	14,759		$	44,259		$	49,473

For the three months ended March 31, 2013, $18,560 was paid to the pension trust for pension benefits from operating cash flows. CONSOL Energy expects to contribute to the pension trust using prudent funding methods. Currently, depending on asset values and asset returns held in the trust, we expect to contribute $50,000 to the pension trust in 2013. Net periodic benefit costs are allocated to Costs of Goods Sold and Other Operating Charges and Selling, General and Administrative Expenses in the results of operations.

11

According to the Defined Benefit Plans Topic of the FASB Accounting Standards Codification, if the lump sum distributions made for the plan year, which for CONSOL Energy is January 1 to December 31, exceed the total of the projected service cost and interest cost for the plan year, settlement accounting is required. Lump sum payments exceeded this threshold during the first quarter of 2013. Accordingly, CONSOL Energy recognized expense of $27,115 for the quarter ended March 31, 2013 in Costs of Goods Sold and Other Operating Charges in the results of operations. The settlement charge represented a pro rata portion of the net unrecognized loss based on the percentage reduction in the projected benefit obligation due to the lump sum payments. The settlement charge noted above also resulted in a remeasurement of the pension plan at March 31, 2013. The remeasurement resulted in a change to the discount rate to 4.12% at March 31, 2013 from 4.00% at December 31, 2012. The remeasurement reduced the pension liability by $29,916. The settlement and the corresponding remeasurement of the pension plan resulted in an adjustment of $35,261 in other comprehensive income, net of $21,770 in deferred taxes. Currently, the settlement and remeasurement of the pension plan will result in a $6,760 reduction to pension expense compared to what was originally expected to be recognized for the remaining nine months of 2013. It is reasonably possible that CONSOL Energy will incur additional settlement charges in 2013, which would require the pension plan to be remeasured using updated assumptions.

CONSOL Energy does not expect to contribute to the other postemployment benefit plan in 2013. We intend to pay benefit claims as they become due. For the three months ended March 31, 2013, $41,922 of other postemployment benefits have been paid.

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,
	2013			2012			2013			2012
Service cost	$	2,135		$	1,928		$	3,533		$	3,634
Interest cost	1,808			1,991			1,655			1,778
Amortization of actuarial gain	(4,213		)	(4,934		)	(699		)	(986		)
State administrative fees and insurance bond premiums	—			—			1,659			1,910
Legal and administrative costs	—			—			591			648
Net periodic (benefit) cost	$	(270	)	$	(1,015	)	$	6,739		$	6,984

CONSOL Energy does not expect to contribute to the CWP plan in 2013. We intend to pay benefit claims as they become due. For the three months ended March 31, 2013, $2,698 of CWP benefit claims have been paid.

CONSOL Energy does not expect to contribute to the workers’ compensation plan in 2013. We intend to pay benefit claims as they become due. For the three months ended March 31, 2013, $8,640 of workers’ compensation benefits, state administrative fees and surety bond premiums have been paid.

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:

12

	For the Three Months Ended March 31,
	2013					2012
	Amount			Percent		Amount			Percent
Statutory U.S. federal income tax rate	$	(455	)	35.0	%	$	41,502		35.0	%
Impact of excess tax depletion	1,428			(109.9	)	(26,514		)	(22.4	)
Net effect of state income taxes	(179		)	13.7		3,510			3.0
Other	(272		)	21.0		2,883			2.4
Income Tax Expense / Effective Rate	$	522		(40.2	)%	$	21,381		18.0	%

The effective rates for the three months ended March 31, 2013 and 2012 were calculated using the annual effective rate projection on recurring earnings and include tax liabilities related to certain discrete transactions which are described below. The effective tax rate is sensitive to changes in annual profitability and percentage depletion.

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, 2013 and 2012 were $22,770 and $25,570, respectively. If these uncertain tax positions were recognized, approximately $2,071 and $3,891, respectively, would affect CONSOL Energy’s effective tax rate. There were no additions to the liability for unrecognized tax benefits during the three months ended March 31, 2013 and 2012.

CONSOL Energy recognizes interest accrued related to uncertain tax positions in its interest expense. As of March 31, 2013 and 2012, the Company reported an accrued interest liability relating to uncertain tax positions of $5,165 and $5,741, respectively. The accrued interest liability includes interest expense that is reflected in the Company’s Consolidated Statements of Income for the three months ended March 31, 2013 and 2012 of $335 and $368, respectively.

CONSOL Energy recognizes penalties related to uncertain tax positions in its income tax expense. As of March 31, 2013 and 2012, 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, 2013		December 31, 2012
Coal	$	51,954	$	78,825
Merchandise for resale	35,120		35,363
Supplies	129,960		133,578
Total Inventories	$	217,034	$	247,766

Inventories are stated at the lower of cost or market. The cost of coal inventories is determined by the first-in, first-out (FIFO) method. Coal inventory costs include labor, supplies, equipment costs, operating overhead, depreciation, depletion and amortization, and other related costs.

Merchandise for resale is valued using the last-in, first-out (LIFO) cost method. The excess of replacement cost of merchandise for resale inventories over carrying LIFO value was $19,726 and $19,700 at March 31, 2013 and December 31, 2012, 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, 2013, there were letters of credit outstanding against the facility of $159,281. CONSOL Energy management believes that these guarantees will expire without being funded, and therefore the commitments will not have a material adverse effect on the Company's financial condition. No amounts related to these financial guarantees and letters of credit are recorded as liabilities on the financial statements.

CNX Funding Corporation, a wholly owned, special purpose, bankruptcy-remote subsidiary, buys and sells eligible trade receivables generated by certain subsidiaries of CONSOL Energy. Under the receivables facility, CONSOL Energy and certain subsidiaries, irrevocably and without recourse, sell all of their eligible trade accounts receivable to CNX Funding Corporation, who in turn sells these receivables to financial institutions and their affiliates, while maintaining a subordinated interest in a portion of the pool of trade receivables. This retained interest, which is included in Accounts and Notes Receivable Trade in the Consolidated Balance Sheets, is recorded at fair value. Due to a short average collection cycle for such receivables, our collection experience history and the composition of the designated pool of trade accounts receivable that are part of this program, the fair value of our retained interest approximates the total amount of the designated pool of accounts receivable. CONSOL Energy will continue to service the sold trade receivables for the financial institutions for a fee based upon market rates for similar services.

In accordance with the Transfers and Servicing Topics of the Financial Accounting Standards Board (FASB) Accounting Standards Codification, CONSOL Energy records transactions under the securitization facility as secured borrowings on the Consolidated Balance Sheets. The pledge of collateral is reported as Accounts Receivable - Securitized and the borrowings are classified as debt in Borrowings under Securitization Facility.

The cost of funds under this facility is based upon commercial paper rates, plus a charge for administrative services paid to the financial institutions. Costs associated with the receivables facility totaled $472 and $419 for the three months ended March 31, 2013 and 2012, respectively. These costs have been recorded as financing fees which are included in Cost of Goods Sold and Other Operating Charges in the Consolidated Statements of Income. No servicing asset or liability has been recorded. The receivables facility expires in March 2017 with the underlying liquidity agreement renewing annually each March.

At March 31, 2013 and December 31, 2012, eligible accounts receivable totaled $199,800 and $200,000, respectively. There was subordinated retained interest of $10,400 at March 31, 2013. There was no subordinated retained interest at December 31, 2012. There were $30,119 borrowings under the Securitization Facility recorded on the Consolidated Balance Sheet as of March 31, 2013 and $37,846 at December 31, 2012. The accounts receivable securitization program decreased by $7,727 in the three months ended March 31, 2013 and there was no change in the three months ended March 31, 2012. The decrease is reflected in the Net Cash Used in Financing Activities in the Consolidated Statement of Cash Flows. In accordance with the facility agreement, the Company is able to receive proceeds based upon the eligible accounts receivable at the previous month end.

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NOTE 8—PROPERTY, PLANT AND EQUIPMENT:

	March 31, 2013		December 31, 2012
Coal and other plant and equipment	$	6,032,128	$	6,030,620
Intangible drilling cost	1,623,391		1,550,297
Proven gas properties	1,600,532		1,596,838
Coal properties and surface lands	1,351,271		1,346,151
Unproven gas properties	1,321,108		1,266,017
Gas gathering equipment	1,024,952		1,006,882
Airshafts	711,586		706,388
Mine development	561,288		537,939
Leased coal lands	529,741		529,758
Gas wells and related equipment	508,768		492,367
Coal advance mining royalties	394,438		391,501
Other gas assets	82,094		82,217
Gas advance royalties	8,226		8,229
Total Property Plant and Equipment	15,749,523		15,545,204
Less: Accumulated DD&A	5,516,319		5,354,237
Total Net PP&E	$	10,233,204	$	10,190,967

Industry Participation Agreements

CONSOL Energy has two significant industry participation agreements (referred to as "joint ventures" or "JVs") that provided drilling and completion carries for our retained interests.

On October 21, 2011, CNX Gas Company, a wholly owned subsidiary of CONSOL Energy, completed a sale to Hess Ohio Developments, LLC (Hess) of 50% of nearly 200 thousand net Utica Shale acres in Ohio. As part of the transaction, 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. Under the asset acquisition agreement, Hess had the right to perform due diligence on the title to the oil and gas interests which we conveyed to them and Hess's aggregate carried cost obligation under the joint venture agreements would be reduced by the value the parties allocated in the transaction to the acreage which subsequently proved to be defective. Based on title work performed by Hess as part of the title defect process, we believe that there are chain of title issues with respect to approximately 38 thousand of the joint venture acres (with a carry value of approximately $153,000), most of which likely cannot be cured. We are currently in discussions with Hess regarding an agreement to finally resolve the title defect process. If we are unable to reach an agreement, the title defects that Hess formally asserts will be resolved in arbitration in accordance with the asset acquisition agreement.

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. As part of the transaction, CNX Gas Company also received a commitment from Noble to pay one-third of the Company's working interest share of certain drilling and completion costs, up to approximately $2,100,000 with certain restrictions. These restrictions include the suspension of carry if average Henry Hub natural gas prices are below $4.00 per million British thermal units (MMBtu) for three consecutive months. The carry is currently suspended and will remain suspended until average natural gas prices are above $4.00/MMBtu for three consecutive months. Restrictions also include a $400,000 annual maximum on Noble's carried cost obligation. The aggregate amount of the drilling carry may also be adjusted downward under provisions of the joint venture agreements in certain events.

Under our joint venture agreement with Noble, Noble had the right to perform due diligence on the title to the oil and gas interests which we conveyed to them and to assert that title to the acreage is defective. CONSOL Energy can then review and respond to the asserted title defects, or cure them, and ultimately, if the claim is not resolved, either party can submit the defect to an arbitrator for resolution. If Noble establishes any title defects which are either not resolved in favor of CONSOL Energy or cured by us, then subject to certain deductibles, Noble's aggregate carried cost obligation under the joint venture agreement will be reduced by the value the parties previously allocated to the affected acreage in the transaction. If a significant

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percentage of the oil and gas interests we contributed have title defects which cannot be resolved or cured, the carried costs could be materially reduced and our aggregate share of the drilling and completion costs for wells in this joint venture could materially increase. Pursuant to the joint venture agreement, Noble Energy has submitted a final title defect notice to CONSOL Energy. Based on our review of this title defect notice, Noble has asserted title defects with respect to approximately 93 thousand gross deal acres, having a carry value of approximately $610,000, which we have not yet addressed. We are working closely with Noble to address these alleged defects and we believe that we will resolve or cure most of these defects favorably to CONSOL Energy. To date, we have conceded defects which have an aggregate value of approximately $37,000 in excess of the applicable deductible, and will attempt to cure as many of those defects as possible. The impact of these conceded defects on the Company's financial statements was $6,310 for the three months ended March 31, 2013.

The following table provides information about our industry participation agreements as of March 31, 2013:

Shale Play	Industry Participation Agreement Partner	Industry Participation Agreement Date	Drilling Carries Remaining*
Marcellus	Noble Energy, Inc.	September 30, 2011	$	2,052,790
Utica	Hess Ohio Developments, LLC	October 21, 2011	$	496,723

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

NOTE 9—SHORT-TERM NOTES PAYABLE:

CONSOL Energy's $1,500,000 Senior Secured Credit Agreement expires April 12, 2016. The facility is secured by substantially all of the assets of CONSOL Energy and certain of its subsidiaries. CONSOL Energy's credit facility allows for up to $1,500,000 of borrowings and letters of credit. CONSOL Energy can request an additional $250,000 increase in the aggregate borrowing limit amount. Fees and interest rate spreads are based on a ratio of financial covenant debt to twelve-month trailing earnings before interest, taxes, depreciation, depletion and amortization (Adjusted EBITDA), measured quarterly. The facility includes a minimum interest coverage ratio covenant of no less than 2.50 to 1.00, measured quarterly. The interest coverage ratio was 4.42 to 1.00 at March 31, 2013. 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 2.86 to 1.00 at March 31, 2013. The facility also includes a senior secured leverage ratio covenant of not more than 2.00 to 1.00, measured quarterly. The senior secured leverage ratio was 0.09 to 1.00 at March 31, 2013. Affirmative and negative covenants in the facility limit our ability to dispose of assets, make investments, purchase or redeem CONSOL Energy common stock, pay dividends, merge with another corporation and amend, modify or restate the senior unsecured notes. At March 31, 2013 and December 31, 2012, the $1,500,000 facility had no borrowings outstanding and $100,292 of letters of credit outstanding, leaving $1,399,708 of capacity available for borrowings and the issuance of letters of credit.

CNX Gas Corporation's (CNX Gas) $1,000,000 Senior Secured Credit Agreement expires April 12, 2016. The facility is secured by substantially all of the assets of CNX Gas and its subsidiaries. CNX Gas' credit facility allows for up to $1,000,000 for borrowings and letters of credit. CNX Gas can request an additional $250,000 increase in the aggregate borrowing limit amount. Fees and interest rate spreads are based on the percentage of facility utilization, measured quarterly. Covenants in the facility limit CNX Gas’ ability to dispose of assets, make investments, pay dividends and merge with another corporation. The credit facility allows investments in joint ventures for the development and operation of gas gathering systems and provides for $600,000 of loans, advances and dividends from CNX Gas to CONSOL Energy. Investments in CONE Gathering, LLC (CONE) are unrestricted. The facility includes a maximum leverage ratio covenant of not more than 3.50 to 1.00, measured quarterly. The leverage ratio was 0.56 to 1.00 at March 31, 2013. The facility also includes a minimum interest coverage ratio covenant of no less than 3.00 to 1.00, measured quarterly. This ratio was 42.09 to 1.00 at March 31, 2013. At March 31, 2013 and December 31, 2012, the $1,000,000 facility had no borrowings outstanding and $70,203 of letters of credit outstanding, leaving $929,797 of capacity available for borrowings and the issuance of letters of credit. The average interest rate for the three months ended March 31, 2013 was 1.89%. Accrued interest of $119 and $29 is included in Other Accrued Liabilities in the Consolidated Balance Sheet at March 31, 2013 and at December 31, 2012, respectively.

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NOTE 10—LONG-TERM DEBT:

	March 31, 2013		December 31, 2012
Debt:
Senior notes due April 2017 at 8.00%, issued at par value	$	1,500,000	$	1,500,000
Senior notes due April 2020 at 8.25%, issued at par value	1,250,000		1,250,000
Senior notes due March 2021 at 6.375%, issued at par value	250,000		250,000
MEDCO revenue bonds in series due September 2025 at 5.75%	102,865		102,865
Advance royalty commitments (7.43% weighted average interest rate for March 31, 2013 and December 31, 2012)	20,394		20,394
Other long-term notes maturing at various dates through 2031 (total value of $6,956 less unamortized discount of $1,411 at March 31, 2013)	5,545		5,758
	3,128,804		3,129,017
Less amounts due in one year *	4,564		4,544
Long-Term Debt	$	3,124,240	$	3,124,473

* Excludes current portion of Capital Lease Obligations of $8,789 and $8,941 at March 31, 2013 and December 31, 2012, respectively.

Accrued interest related to Long-Term Debt of $113,586 and $63,363 was included in Other Accrued Liabilities in the Consolidated Balance Sheets at March 31, 2013 and December 31, 2012, respectively.

NOTE 11—COMMITMENTS AND CONTINGENCIES:

CONSOL Energy and its subsidiaries are subject to various lawsuits and claims with respect to such matters as personal injury, wrongful death, damage to property, exposure to hazardous substances, governmental regulations including environmental remediation, employment and contract disputes and other claims and actions arising out of the normal course of business. We accrue the estimated loss for these lawsuits and claims when the loss is probable and can be estimated. Our current estimated accruals related to these pending claims, individually and in the aggregate, are immaterial to the financial position, results of operations or cash flows of CONSOL Energy. It is possible that the aggregate loss in the future with respect to these lawsuits and claims could ultimately be material to the financial position, results of operations or cash flows of CONSOL Energy; however, such amounts cannot be reasonably estimated. The amount claimed against CONSOL Energy is disclosed below when an amount is expressly stated in the lawsuit or claim, which is not often the case. The maximum aggregate amount claimed in those lawsuits and claims, regardless of probability, where a claim is expressly stated or can be estimated, exceeds the aggregate amounts accrued for all lawsuits and claims by approximately $845,000.

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

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

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Ward Transformer Superfund Site: CONSOL Energy was notified in November 2004 by the EPA that it is a potentially responsible party (PRP) under the Superfund program established by the Comprehensive Environmental Response, Compensation and Liability Act of 1980, as amended (CERCLA), with respect to the Ward Transformer site in Wake County, North Carolina. The EPA, CONSOL Energy and two other PRPs entered into an administrative Settlement Agreement and Order of Consent, requiring those PRPs to undertake and complete a PCB soil removal action, at and in the vicinity of the Ward Transformer property. In June 2008, while conducting the PCB soil excavation on the Ward property, it was determined that PCBs have migrated onto adjacent properties and in September 2008, the EPA notified CONSOL Energy and 60 other companies that they are PRPs for these additional areas. The current estimated cost of remedial action for the area CONSOL Energy was originally named a PRP, including payment of the EPA's past and future cost, is approximately $65,000. The current estimated cost of the most likely remediation plan for the additional areas discovered is approximately $11,000. CONSOL Energy recognized no expense in Cost of Goods Sold and Other charges in the three months ended March 31, 2013 and 2012, respectively. Also, CONSOL Energy has provided funding to an independent trust established for this remediation. No funding was made in the three months ended March 31, 2013 or 2012, respectively. As of March 31, 2013, CONSOL Energy and the other participating PRPs had asserted CERCLA cost recovery and contribution claims against approximately 225 nonparticipating PRPs to recover a share of the costs incurred and to be incurred to conduct the removal actions at the Ward Site. CONSOL Energy's portion of recoveries from settled claims is $4,393. Accordingly, the liability reflected in Other Accrued Liabilities was reduced by these settled claims. The remaining net liability at March 31, 2013 is $3,167.

Asbestos-Related Litigation: One of our subsidiaries, Fairmont Supply Company (Fairmont), which distributes industrial supplies, currently is named as a defendant in approximately 6,900 asbestos-related claims in state courts in Pennsylvania, Ohio, West Virginia, Maryland, Texas and Illinois. Because a very small percentage of products manufactured by third parties and supplied by Fairmont in the past may have contained asbestos and many of the pending claims are part of mass complaints filed by hundreds of plaintiffs against a hundred or more defendants, it has been difficult for Fairmont to determine how many of the cases actually involve valid claims or plaintiffs who were actually exposed to asbestos-containing products supplied by Fairmont. In addition, while Fairmont may be entitled to indemnity or contribution in certain jurisdictions from manufacturers of identified products, the availability of such indemnity or contribution is unclear at this time, and in recent years, some of the manufacturers named as defendants in these actions have sought protection from these claims under bankruptcy laws. Fairmont has no insurance coverage with respect to these asbestos cases. Based on over 15 years of experience with this litigation, we have established an accrual to cover our estimated liability for these cases. This accrual is immaterial to the overall financial position of CONSOL Energy and is included in Other Accrued Liabilities on the Consolidated Balance Sheet. Past payments by Fairmont with respect to asbestos cases have not been material.

Ryerson Dam Litigation: In 2008, the Pennsylvania Department of Conservation and Natural Resources (the Commonwealth) filed a six-count Complaint in the Court of Common Pleas of Allegheny County, Pennsylvania, claiming that the Company's underground longwall mining activities at its Bailey Mine caused cracks and seepage damage to the Ryerson Park Dam. The Commonwealth subsequently breached the dam, thereby eliminating the Ryerson Park Lake. The Commonwealth claimed that the Company is liable for dam reconstruction costs, lake restoration costs and natural resource damages totaling $58,000. In October 2008, the Common Pleas Court ruled that natural resource damages were not recoverable and referred the Commonwealth's claim to the Pennsylvania Department of Environmental Protection (DEP). 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. 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 challenge 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. See Note 18 - Subsequent Events for additional information.

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

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fees. The Award is against CONSOL of Kentucky only. The Panel is currently considering SCE&G's attorney fee claim of $1,873, which has been vigorously opposed by CONSOL Energy. We have established an accrual to cover our estimated liability for this case. This accrual is immaterial to the overall financial position of CONSOL Energy and is included in Other Accrued Liabilities on the Consolidated Balance Sheet.

Hale Litigation: A purported class action lawsuit was filed on September 23, 2010 in the U.S. District Court in Abingdon, Virginia styled Hale v. CNX Gas Company, et. al. The lawsuit alleges that the plaintiff class consists of forced-pooled unleased gas owners whose gas ownership is in conflict, the Virginia Supreme Court and General Assembly have decided that coalbed methane (CBM) belongs to the owner of the gas estate, the Virginia Gas and Oil Act of 1990 unconstitutionally provides only a 1/8 net proceeds royalty to CBM owners for gas produced under the forced-pooled orders, and CNX Gas Company relied upon control of only the coal estate in force pooling the CBM notwithstanding decisions by the Virginia Supreme Court. The lawsuit seeks a judicial declaration of ownership of the CBM and that the entire net proceeds of CBM production (that is, the 1/8 royalty and the 7/8 of net revenues since production began) be distributed to the class members. The lawsuit also alleges CNX Gas Company failed to either pay royalties due conflicting claimant, deemed lessors or paid them less than required because of the alleged practice of improper below market sales and/or taking alleged improper post-production deductions. The Magistrate Judge issued a Report and Recommendation in which she recommended that the District Judge decide that the deemed lease provision of the Gas and Oil Act is constitutional as is the 1/8 royalty. The Magistrate Judge recommended against the dismissal of certain other claims. The District Judge affirmed the Magistrate Judge's recommendations in their entirety. An amended complaint was filed, which added additional allegations that include gas hedging receipts should have been used as the basis for royalty payments, severance tax should not be allowed as a post-production deduction from royalties, and damages incurred because gas was produced prior to the entry of pooling orders. A motion to dismiss the Amended Complaint was filed and denied. The Magistrate Judge heard oral arguments on plaintiff's Motion for Class Certification on November 30, 2012 and has not yet issued a Report and Recommendation. Discovery is proceeding in this litigation. CONSOL Energy believes that the case has meritorious defenses and intends to defend it vigorously. We have established an accrual to cover our estimated liability for this case. This accrual is immaterial to the overall financial position of CONSOL Energy and is included in Other Accrued Liabilities on the Consolidated Balance Sheet.

Addison Litigation: A purported class action lawsuit was filed on April 28, 2010 in the United States District Court in Abingdon, Virginia styled Addison v. CNX Gas Company, et al.  The lawsuit alleges that the plaintiff class consists of gas lessors whose gas ownership is in conflict. The lawsuit alleges that the Virginia Supreme Court and General Assembly have decided that the plaintiff owns the gas and is entitled to royalties held in escrow by the Commonwealth of Virginia or CNX.  The lawsuit also alleges CNX Gas failed to either pay royalties due these conflicting claimant lessors or paid them less than required because of the alleged practice of improper below market sales and/or taking alleged improper post-production deductions. Plaintiff seeks a declaratory judgment regarding ownership, an accounting and compensatory and punitive damages for breach of contract; conversion; negligence (voluntary undertaking) for improperly asserting that conflicting ownership exists, negligence (breach of duties as an operator); breach of fiduciary duties; and unjust enrichment. The Magistrate Judge issued a Report and Recommendation recommending dismissing some claims and allowing others to proceed. The District Judge affirmed the Magistrate Judge's recommendations in their entirety. An Amended Complaint was filed which added an additional allegation that gas hedging receipts should have been used as the basis for royalty payments. A motion to dismiss those claims was filed and was denied. The Magistrate Judge heard oral arguments on plaintiff's Motion for Class Certification on November 30, 2012 and has not yet issued a Report and Recommendation. Discovery is proceeding in this litigation. CONSOL Energy believes that the case has meritorious defenses and intends to defend it vigorously. We have established an accrual to cover our estimated liability for this case. This accrual is immaterial to the overall financial position of CONSOL Energy and is included in Other Accrued Liabilities on the Consolidated Balance Sheet.

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

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

The following royalty and land right lawsuits and claims include those for which a loss is reasonably possible, but not probable, and accordingly, no accrual has been recognized. These claims are influenced by many factors which prevent the estimation of a range of potential loss. These factors include, but are not limited to, generalized allegations of unspecified damages (such as improper deductions), discovery having not commenced or not having been completed, unavailability of expert reports on damages and non-monetary issues are being tried. For example, in instances where a gas lease termination is sought, damages would depend on speculation as to if and when the gas production would otherwise have occurred, how many wells would have been drilled on the lease premises, what their production would be, what the cost of production would be, and what the price of gas would be during the production period. An estimate is calculated, if applicable, when sufficient information becomes available.

Ratliff: On March 22, 2012, the Company was served with four complaints filed on May 31, 2011 by four individuals against CCC, ICCC, CNX Gas Company, subsidiaries of CONSOL Energy, as well as CONSOL Energy itself in the Circuit Court of Russell County, Virginia. The complaints seek damages and injunctive relief in connection with the deposit of water from mining activities at CCC's Buchanan Mine into nearby void spaces at some of the mines of ICCC. The suits allege damage to coal and coalbed methane and seek recovery in tort, contract and assumpsit (quasi-contract). The cases were removed to federal court, motions to dismiss were filed by CCC, and then were voluntarily dismissed by the plaintiffs. On January 30, 2013, the four plaintiffs filed a single consolidated complaint in the United States District Court for the Western District of Virginia, alleging the same damage and theories of recovery for storage of water in the mine voids ostensibly underlying their property. The suit seeks damages ranging from $4,000 to $8,000 plus punitive damages. Service was effected by April 1, 2013 by waiver, and defendants' responsive pleadings are due May 31, 2013. CONSOL energy intends to vigorously defend the suit.

Hall Litigation: A purported class action lawsuit was filed on December 23, 2010 styled Hall v. CONSOL Gas Company in Allegheny County Pennsylvania Common Pleas Court.  The named plaintiff is Earl D. Hall.  The purported class plaintiffs are all Pennsylvania oil and gas lessors to Dominion Exploration and Production Company, whose leases were acquired by CONSOL Energy.  The complaint alleges more than 1,000 similarly situated lessors.  The lawsuit alleges that CONSOL Energy incorrectly calculated royalties by (i) calculating line loss on the basis of allocated volumes rather than on a well-by-well basis, (ii) possibly calculating the royalty on the basis of an incorrect price, (iii) possibly taking unreasonable deductions for post-production costs and costs that were not arms-length, (iv) not paying royalties on gas lost or used before the point of sale, and (v) not paying royalties on oil production. The complaint also alleges that royalty statements were false and misleading.  The complaint seeks damages, interest and an accounting on a well-by-well basis. CONSOL Energy believes that the case is without merit and intends to defend it vigorously. Consequently, we have not recognized any liability related to these actions.

    Kennedy Litigation: The Company is a party to a case filed on March 26, 2008 captioned Earl Kennedy (and others) v. CNX Gas Company and CONSOL Energy in the Court of Common Pleas of Greene County, Pennsylvania. The lawsuit alleges that CNX Gas Company and CONSOL Energy trespassed and converted gas and other minerals allegedly belonging to the plaintiffs in connection with wells drilled by CNX Gas Company. The complaint, as amended, seeks injunctive relief, including removing CNX Gas Company from the property, and compensatory damages of $20,000. The suit also sought to overturn existing law as to the ownership of coalbed methane in Pennsylvania, but that claim was dismissed by the court; the plaintiffs are seeking to appeal that dismissal. The suit also seeks a determination that the Pittsburgh 8 coal seam does not include the “roof/rider” coal. The court denied the plaintiff's summary judgment motion on that issue. The court held a bench trial on the “roof/rider” coal issue in November 2011 and ruled for CNX Gas Company and CONSOL Energy, holding that the “roof/rider” coal is included in the Pittsburgh 8 coal seam. The plaintiffs have indicated that they intend to appeal that decision. A trial on the issue of whether a drilling that deviates from the coal seam results in damage to the gas owner is now scheduled for October 21, 2013. CNX Gas Company and CONSOL Energy believe this lawsuit to be without merit and intend to vigorously defend it. Consequently, we have not recognized any liability related to these actions.

Rowland Litigation: Rowland Land Company filed a complaint in May 2011 against CONSOL Energy, CNX Gas Company, Dominion Resources, and EQT Production Company (EQT) in Raleigh County Circuit Court, West Virginia. Rowland is the lessor on a 33,000 acre oil and gas lease in southern West Virginia. EQT was the original lessee, but farmed out the development of the lease to Dominion Resources in exchange for an overriding royalty. Dominion Resources sold the indirect subsidiary that held the lease to a subsidiary of CONSOL Energy on April 30, 2010. Subsequent to that acquisition, the subsidiary that held the lease was merged into CNX Gas Company as part of an internal reorganization. Rowland alleges that (i) Dominion Resources' sale of the subsidiary to CONSOL Energy was a change in control that required its consent under the terms of the farmout agreement and lease, and/or (ii) the subsequent merger of the subsidiary into CNX Gas Company was an

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assignment that required its consent under the lease. Rowland has amended its complaint twice to include allegations that CONSOL Energy and Dominion Resources are liable for their subsidiaries' actions and that Rowland's title has been slandered. Motions to dismiss have been denied, discovery is proceeding but stayed pending mediation. Initial mediation efforts have been unsuccessful but are continuing. CONSOL Energy believes that the case is without merit and intends to defend it vigorously. Consequently, we have not recognized any liability related to these actions.

Majorsville Storage Field Declaratory Judgment: On March 3, 2011, an attorney sent a letter to CNX Gas Company regarding certain leases that CNX Gas Company obtained from Columbia Gas in Greene County, Pennsylvania involving the Majorsville Storage Field. The letter was written on behalf of three lessors alleging that the leases totaling 525 acres are invalid, and had expired by their terms. The plaintiffs' theory is that the rights of storage and production are severable under the leases. Ignoring the fact that the leases have been used for gas storage, they claim that since there has been no production or development of production, the right to produce gas expired at the end of the primary terms. On June 16, 2011, in the Court of Common Pleas of Greene County, Pennsylvania, the Company filed a declaratory judgment action, seeking to have a court confirm the validity of the leases. 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, 2013, CONSOL Energy has provided the following financial guarantees, unconditional purchase obligations and letters of credit to certain third parties, as described by major category in the following table. These amounts represent the maximum potential total of future payments that we could be required to make under these instruments. These amounts have not been reduced for potential recoveries under recourse or collateralization provisions. Generally, recoveries under reclamation bonds would be limited to the extent of the work performed at the time of the default. No amounts related to these financial guarantees and letters of credit are recorded as liabilities on the financial statements. CONSOL Energy management believes that these guarantees will expire without being funded, and therefore the commitments will not have a material adverse effect on financial condition.

	Amount of Commitment Expiration Per Period
	Total Amounts Committed		Less Than 1  Year		1-3 Years		3-5 Years		Beyond 5  Years
Letters of Credit:
Employee-Related	$	190,158	$	126,654	$	63,504	$	—	$	—
Environmental	56,293		34,346		21,947		—		—
Other	83,398		46,452		36,946		—		—
Total Letters of Credit	329,849		207,452		122,397		—		—
Surety Bonds:
Employee-Related	204,884		204,884		—		—		—
Environmental	533,974		524,072		9,902		—		—
Other	29,487		29,476		11		—		—
Total Surety Bonds	768,345		758,432		9,913		—		—
Total Commitments	$	1,098,194	$	965,884	$	132,310	$	—	$	—

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

CONSOL Energy and CNX Gas enter into long-term unconditional purchase obligations to procure major equipment purchases, natural gas firm transportation, gas drilling services and other operating goods and services. These purchase obligations are not recorded on the Consolidated Balance Sheet. As of March 31, 2013, the purchase obligations for each of the next five years and beyond were as follows:

Obligations Due	Amount
Less than 1 year	$	349,513
1 - 3 years	227,586
3 - 5 years	128,338
More than 5 years	414,276
Total Purchase Obligations	$	1,119,713

Costs related to these purchase obligations include:

	Three Months Ended
	March, 31
	2013		2012
Major equipment purchases	$	33,426	$	13,166
Firm transportation expense	28,525		15,045
Gas drilling obligations	28,863		29,576
Other	—		298
Total costs related to purchase obligations	$	90,814	$	58,085

NOTE 12—DERIVATIVE INSTRUMENTS:

CONSOL Energy enters into financial derivative instruments to manage our exposure to commodity price volatility. The fair value of CONSOL Energy's derivatives (natural gas price swaps) are based on intra-bank pricing models which utilize inputs that are either readily available in the public market, such as natural gas forward curves, or can be corroborated from active markets or broker quotes. These values are then compared to the values given by our counterparties for reasonableness. Changes in the fair value of the derivatives are recorded currently in earnings unless special hedge accounting criteria are met. For derivatives designated as fair value hedges, the changes in fair value of both the derivative instrument and the hedged item are recorded in earnings. For derivatives designated as cash flow hedges, the effective portions of changes in the fair value of the derivatives are reported in Other Comprehensive Income or Loss (OCI) on the Consolidated Balance Sheets and reclassified into Outside Sales on the Consolidated Statements of Income in the same period or periods which the forecasted transaction affects earnings. The ineffective portions of hedges are recognized in earnings in the current period. CONSOL Energy currently utilizes only cash flow hedges that are considered highly effective.

CONSOL Energy formally assesses both at inception of the hedge and on an ongoing basis whether each derivative is highly effective in offsetting changes in the fair values or the cash flows of the hedged item. If it is determined that a derivative is not highly effective as a hedge or if a derivative ceases to be a highly effective hedge, CONSOL Energy will discontinue hedge accounting prospectively.

CONSOL Energy is exposed to credit risk in the event of nonperformance by counterparties. The creditworthiness of counterparties is subject to continuing review. The Company has not experienced any issues of non-performance by derivative counterparties.

None of our counterparty master agreements currently requires CONSOL Energy to post collateral for any of its hedges. However, as stated in the counterparty master agreements, if CONSOL Energy's obligations with one of its

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counterparties cease to be secured on the same basis as similar obligations with the other lenders under the credit facility, CONSOL Energy would have to post collateral for hedges in a liabilities position in excess of defined thresholds.  

                Each of CONSOL Energy's counterparty master agreements allows, in the event of default, the ability to elect early termination of outstanding contracts. If early termination is elected, CONSOL Energy and the applicable counterparty would net settle all open hedge positions.

CONSOL Energy has entered into swap contracts for natural gas to manage the price risk associated with the forecasted natural gas revenues. The objective of these hedges is to reduce the variability of the cash flows associated with the forecasted revenues from the underlying commodity. As of March 31, 2013, the total notional amount of the Company’s outstanding natural gas swap contracts was 147.4 billion cubic feet. These swap contracts are forecasted to settle through December 31, 2015 and meet the criteria for cash flow hedge accounting. As these contracts settle, the cash received and/or paid will be shown on the Consolidated Statements of Cash Flows as Changes in Prepaid Expenses, Changes in Other Assets, Changes in Other Operating Liabilities and/or Changes in Other Liabilities. During the next twelve months, $20,494 of unrealized gain is expected to be reclassified from Other Comprehensive Income on the Consolidated Balance Sheets and into Outside Sales on the Consolidated Statements of Income, as a result of the gross settlements of cash flow hedges. No gains or losses have been reclassified into earnings as a result of the discontinuance of cash flow hedges.

The gross fair value at March 31, 2013 of CONSOL Energy's derivative instruments, which were all natural gas swaps and qualify as cash flow hedges, was an asset of $83,677 and a liability of $20,949. The total asset is comprised of $46,837 and $36,840 which were included in Prepaid Expense and Other Assets, respectively, on the Consolidated Balance Sheets. The total liability is comprised of $10,877 and $10,072 which were included in Other Accrued Liabilities and Other Liabilities, respectively, on the Consolidated Balance Sheets.

The gross fair value at December 31, 2012 of CONSOL Energy's derivative instruments, which were all natural gas swaps and qualify as cash flow hedges, was an asset of $135,969 and a liability of $7,024. The total asset is comprised of $80,057 and $55,912 which were included in Prepaid Expense and Other Assets, respectively, on the Consolidated Balance Sheets. The total liability is comprised of $970 and $6,054 which were included in Other Accrued Liabilities and Other Liabilities, respectively, on the Consolidated Balance Sheets.

The effect of derivative instruments in cash flow hedging relationships on the Consolidated Statements of Income and the Consolidated Statements of Stockholders' Equity were as follows:

	Three Months Ended March 31,
	2013			2012
Natural Gas Price Swaps
Beginning Balance – Accumulated OCI	$	76,761		$	151,780
Gain/(Loss) recognized in Accumulated OCI	$	(18,595	)	$	76,076
Less: Gain reclassified from Accumulated OCI into Outside Sales	$	22,713		$	47,941
Ending Balance – Accumulated OCI	$	35,453		$	179,915
Gain/(Loss) recognized in Outside Sales for ineffectiveness	$	1,041		$	(835	)

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

NOTE 13—FAIR VALUE OF FINANCIAL INSTRUMENTS:

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

	Fair Value Measurements at March 31, 2013						Fair Value Measurements at December 31, 2012
Description	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Gas Cash Flow Hedges	$	—	$	62,728	$	—	$	—	$	128,945	$	—

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The following methods and assumptions were used to estimate the fair value for which the fair value option was not elected:

Cash and cash equivalents: The carrying amount reported in the balance sheets for cash and cash equivalents approximates its fair value due to the short-term maturity of these instruments.

Restricted cash: The carrying amount reported in the balance sheets for restricted cash approximates its fair value due to the short-term maturity of these instruments.

Short-term notes payable: The carrying amount reported in the balance sheets for short-term notes payable approximates its fair value due to the short-term maturity of these instruments.

Borrowings under Securitization Facility: The carrying amount reported in the balance sheets for borrowings under the securitization facility approximates its fair value due to the short-term maturity of these instruments.

Long-term debt: The fair value of long-term debt is measured using unadjusted quoted market prices or estimated using discounted cash flow analyses. The discounted cash flow analyses are based on current market rates for instruments with similar cash flows.

The carrying amounts and fair values of financial instruments for which the fair value option was not elected are as follows:

	March 31, 2013						December 31, 2012
	Carrying Amount			Fair Value			Carrying Amount			Fair Value
Cash and Cash Equivalents	$	25,058		$	25,058		$	21,878		$	21,878
Restricted Cash	$	20,383		$	20,383		$	68,673		$	68,673
Short-Term Notes Payable	$	—		$	—		$	(25,073	)	$	(25,073	)
Borrowings Under Securitization Facility	$	(30,119	)	$	(30,119	)	$	(37,846	)	$	(37,846	)
Long-Term Debt	$	(3,128,804	)	$	(3,396,271	)	$	(3,129,017	)	$	(3,378,058	)

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NOTE 14—SEGMENT INFORMATION:

CONSOL Energy has two principal business divisions: Coal and Gas. The principal activities of the Coal division are mining, preparation and marketing of thermal coal, sold primarily to power generators, and metallurgical coal, sold to metal and coke producers. The Coal division includes four reportable segments. These reportable segments are Thermal, Low Volatile Metallurgical, High Volatile Metallurgical and Other Coal. Each of these reportable segments includes a number of operating segments (mines or type of coal sold). For the three months ended March 31, 2013, the Thermal aggregated segment includes the following mines: Bailey, Blacksville #2, Enlow Fork, Fola Complex, Loveridge, McElroy, Miller Creek Complex, Robinson Run and Shoemaker. For the three months ended March 31, 2013, the Low Volatile Metallurgical aggregated segment includes the Buchanan Mine and Amonate Complex. For the three months ended March 31, 2013, the High Volatile Metallurgical aggregated segment includes: Bailey, Blacksville #2, Enlow Fork, Fola Complex, Loveridge and Robinson Run coal sales. The Other Coal segment includes our purchased coal activities, idled mine activities, general and administrative activities as well as various other activities assigned to the Coal division but not allocated to each individual mine. The principal activity of the Gas division is to produce pipeline quality natural gas for sale primarily to gas wholesalers. The Gas division includes four reportable segments. These reportable segments are Coalbed Methane, Marcellus, Shallow Oil and Gas and Other Gas. The Other Gas segment includes our purchased gas activities, general and administrative activities as well as various other activities assigned to the Gas division but not allocated to each individual well type. CONSOL Energy’s All Other segment includes terminal services, river and dock services, industrial supply services, general and administrative activities and other business activities. Intersegment sales have been recorded at amounts approximating market. Operating profit for each segment is based on sales less identifiable operating and non-operating expenses. Assets are reflected at the division level only (coal, gas and other) and are not allocated between each individual segment. This presentation is consistent with the information regularly reviewed by the chief operating decision maker. The assets are not allocated to each individual segment due to the diverse asset base controlled by CONSOL Energy where each individual asset may service more than one segment within the division. An allocation of such asset base would not be meaningful or representative on a segment by segment basis.

Annually, the preparation of our gas reserve estimates are completed in accordance with CONSOL Energy's prescribed internal control procedures, which include verification of input data into a gas reserve forecasting and economic evaluation software, as well as multi-functional management review. The input data verification includes reviews of the price and cost assumptions used in the economic model to determine the reserves. Also, the production volumes are reconciled between the system used to calculate the reserves and other accounting/measurement systems. The technical employee responsible for overseeing the preparation of the reserve estimates is a petroleum engineer with over 10 years of experience in the oil and gas industry. Our 2012 gas reserve results, which are reported in the Supplemental Gas Data year ended December 31, 2012 Form 10-K, were audited by Netherland Sewell. The technical person primarily responsible for overseeing the audit of our reserves is a registered professional engineer in the state of Texas with over 14 years of experience in the oil and gas industry.

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Industry segment results for the three months ended March 31, 2013 are:

	Thermal		Low Volatile Metallurgical		High Volatile Metallurgical		Other Coal			Total Coal		Coalbed Methane		Marcellus Shale		Shallow Oil and Gas			Other Gas			Total Gas			All Other			Corporate, Adjustments & Eliminations			Consolidated
Sales—outside	$	761,272	$	146,828	$	58,622	$	5,663		$	972,385	$	83,640	$	48,411	$	32,436		$	3,355		$	167,842		$	85,938		$	—		$	1,226,165		(A)
Sales—purchased gas	—		—		—		—			—		—		—		—			1,358			1,358			—			—			1,358
Sales—gas royalty interests	—		—		—		—			—		—		—		—			14,204			14,204			—			—			14,204
Freight—outside	—		—		—		14,061			14,061		—		—		—			—			—			—			—			14,061
Intersegment transfers	—		—		—		—			—		—		—		—			836			836			35,477			(36,313		)	—
Total Sales and Freight	$	761,272	$	146,828	$	58,622	$	19,724		$	986,446	$	83,640	$	48,411	$	32,436		$	19,753		$	184,240		$	121,415		$	(36,313	)	$	1,255,788
Earnings (Loss) Before Income Taxes	$	128,432	$	54,717	$	13,352	$	(102,999	)	$	93,502	$	21,312	$	13,768	$	(4,161	)	$	(31,559	)	$	(640	)	$	(40,552	)	$	(53,609	)	$	(1,299	)	(B)
Segment assets										$	5,698,504											$	5,879,988		$	358,663		$	656,039		$	12,593,194		(C)
Depreciation, depletion and amortization										$	102,711											$	52,399		$	6,205		$	—		$	161,315
Capital expenditures										$	197,338											$	207,130		$	1,504		$	—		$	405,972

(A)    Included in the Coal segment are sales of $170,982 to First Energy and $183,121 to Xcoal Energy & Resources each comprising over 10% of sales.

(B)     Includes equity in earnings of unconsolidated affiliates of $817, $3,182 and $798 for Coal, Gas and All Other, respectively.

(C)    Includes investments in unconsolidated equity affiliates of $20,334, $167,058 and $60,735 for Coal, Gas and All Other, respectively.

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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	(D)
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	$	128,449	$	79,341	$	15,936	$	(61,256	)	$	162,470	$	36,390	$	3,251	$	(3,722	)	$	(23,419	)	$	12,500	$	4,083	$	(60,476	)	$	118,577	(E)
Segment assets										$	5,360,577											$	6,110,585	$	358,746	$	765,703		$	12,595,611	(F)
Depreciation, depletion and amortization										$	100,762											$	48,803	$	5,782	$	—		$	155,347
Capital expenditures										$	194,429											$	98,455	$	13,562	$	—		$	306,446

(D) 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.

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

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

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Reconciliation of Segment Information to Consolidated Amounts:

Earnings Before Income Taxes:

	For the Three Months Ended March 31,
	2013			2012
Segment Earnings Before Income Taxes for total reportable business segments	$	92,862		$	174,970
Segment (Loss) Earnings Before Income Taxes for all other businesses	(40,552		)	4,083
Interest expense, net and other non-operating activity (G)	(52,660		)	(60,042		)
Other Corporate Items (G)	(949		)	(434		)
(Loss) Earnings Before Income Taxes	$	(1,299	)	$	118,577

Total Assets:	March, 31
	2013		2012
Segment assets for total reportable business segments	$	11,578,492	$	11,471,162
Segment assets for all other businesses	358,663		358,746
Items excluded from segment assets:
Cash and other investments (G)	23,669		121,807
Recoverable income taxes	6,602		—
Deferred tax assets	585,829		596,657
Bond issuance costs	39,939		47,239
Total Consolidated Assets	$	12,593,194	$	12,595,611

_________________________ 

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

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NOTE 15—GUARANTOR SUBSIDIARIES FINANCIAL INFORMATION:

The payment obligations under the $1,500,000, 8.000% per annum senior notes due April 1, 2017, the $1,250,000, 8.250% per annum senior notes due April 1, 2020, and the $250,000, 6.375% per annum senior notes due March 1, 2021 issued by CONSOL Energy are jointly and severally, and also fully and unconditionally guaranteed by substantially all subsidiaries of CONSOL Energy. In accordance with positions established by the Securities and Exchange Commission (SEC), the following financial information sets forth separate financial information with respect to the parent, CNX Gas, a guarantor subsidiary, the remaining guarantor subsidiaries and the non-guarantor subsidiaries. The principal elimination entries include investments in subsidiaries and certain intercompany balances and transactions. CONSOL Energy, the parent, and a guarantor subsidiary manage several assets and liabilities of all other wholly owned subsidiaries. These include, for example, deferred tax assets, cash and other post-employment liabilities. These assets and liabilities are reflected as parent company or guarantor company amounts for purposes of this presentation.

Income Statement for the Three Months Ended March 31, 2013 (unaudited):

	Parent Issuer			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Sales—Outside	$	—		$	168,679		$	1,004,157		$	54,053	$	(724	)	$	1,226,165
Sales—Gas Royalty Interests	—			14,204			—			—		—			14,204
Sales—Purchased Gas	—			1,358			—			—		—			1,358
Freight—Outside	—			—			14,061			—		—			14,061
Other Income	77,976			13,224			15,255			5,373		(77,976		)	33,852
Total Revenue and Other Income	77,976			197,465			1,033,473			59,426		(78,700		)	1,289,640
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	75,990			114,352			681,705			53,726		7,190			932,963
Gas Royalty Interests Costs	—			11,817			—			—		(11		)	11,806
Purchased Gas Costs	—			959			—			—		—			959
Related Party Activity	(12,556		)	—			(7,778		)	404		19,930			—
Freight Expense	—			—			14,061			—		—			14,061
Selling, General and Administrative Expenses	—			10,112			23,247			311		—			33,670
Depreciation, Depletion and Amortization	3,195			52,399			105,237			484		—			161,315
Interest Expense	50,169			1,661			1,644			11		(107		)	53,378
Taxes Other Than Income	177			6,698			75,006			906		—			82,787
Total Costs	116,975			197,998			893,122			55,842		27,002			1,290,939
(Loss) Earnings Before Income Taxes	(38,999		)	(533		)	140,351			3,584		(105,702		)	(1,299		)
Income Taxes (Benefit) Expense	(37,435		)	(208		)	36,809			1,356		—			522
Net (Loss) Income	(1,564		)	(325		)	103,542			2,228		(105,702		)	(1,821		)
Add: Net Loss Attributable to Noncontrolling Interest	—			257			—			—		—			257
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(1,564	)	$	(68	)	$	103,542		$	2,228	$	(105,702	)	$	(1,564	)

29

Balance Sheet at March 31, 2013 (unaudited):

	Parent Issuer		CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Assets:
Current Assets:
Cash and Cash Equivalents	$	22,152	$	2,170		$	171		$	565	$	—		$	25,058
Accounts and Notes Receivable:
Trade	—		55,755			—			352,595		—			408,350
Notes Receivable	194		319,756			2,456			—		—			322,406
Other Receivables	5,081		112,802			32,024			3,790		—			153,697
Accounts Receivable—Securitized	—		—			—			30,119		—			30,119
Inventories	—		13,979			167,935			35,120		—			217,034
Deferred Income Taxes	169,920		(9,170		)	—			—		—			160,750
Recoverable Income Taxes	20,580		(13,978		)	—			—		—			6,602
Prepaid Expenses	20,814		52,271			40,544			1,527		—			115,156
Total Current Assets	238,741		533,585			243,130			423,716		—			1,439,172
Property, Plant and Equipment:
Property, Plant and Equipment	218,234		6,122,433			9,383,357			25,499		—			15,749,523
Less-Accumulated Depreciation, Depletion and Amortization	130,556		1,012,595			4,354,755			18,413		—			5,516,319
Total Property, Plant and Equipment-Net	87,678		5,109,838			5,028,602			7,086		—			10,233,204
Other Assets:
Deferred Income Taxes	855,493		(430,414		)	—			—		—			425,079
Restricted Cash	—		—			20,383			—		—			20,383
Investment in Affiliates	9,992,921		167,058			798,589			—		(10,710,441		)	248,127
Notes Receivable	212		—			25,783			—		—			25,995
Other	115,911		46,350			28,940			10,033		—			201,234
Total Other Assets	10,964,537		(217,006		)	873,695			10,033		(10,710,441		)	920,818
Total Assets	$	11,290,956	$	5,426,417		$	6,145,427		$	440,835	$	(10,710,441	)	$	12,593,194
Liabilities and Equity:
Current Liabilities:
Accounts Payable	$	195,092	$	173,468		$	85,104		$	10,222	$	—		$	463,886
Accounts Payable (Recoverable)—Related Parties	3,687,347		24,929			(3,969,054		)	227,778		29,000			—
Current Portion Long-Term Debt	1,568		5,939			5,084			762		—			13,353
Short-Term Notes Payable	—		29,000			—			—		(29,000		)	—
Borrowings Under Securitization Facility	—		—			—			30,119		—			30,119
Other Accrued Liabilities	161,155		68,331			599,867			9,941		—			839,294
Total Current Liabilities	4,045,162		301,667			(3,278,999		)	278,822		—			1,346,652
Long-Term Debt:	3,005,254		44,671			121,151			1,463		—			3,172,539
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	—		—			2,825,925			—		—			2,825,925
Pneumoconiosis Benefits	—		—			175,952			—		—			175,952
Mine Closing	—		—			449,891			—		—			449,891
Gas Well Closing	—		81,296			69,677			—		—			150,973
Workers’ Compensation	—		—			154,261			312		—			154,573
Salary Retirement	172,306		—			—			—		—			172,306
Reclamation	—		—			43,833			—		—			43,833
Other	95,696		26,151			6,469			—		—			128,316
Total Deferred Credits and Other Liabilities	268,002		107,447			3,726,008			312		—			4,101,769
Total CONSOL Energy Inc. Stockholders’ Equity	3,972,538		4,972,936			5,577,267			160,238		(10,710,441		)	3,972,538
Noncontrolling Interest	—		(304		)	—			—		—			(304		)
Total Liabilities and Equity	$	11,290,956	$	5,426,417		$	6,145,427		$	440,835	$	(10,710,441	)	$	12,593,194

30

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	167,985			16,305		29,703		5,957		(166,989		)	52,961
Total Revenue and Other Income	167,985			190,019		1,161,284		74,979		(167,497		)	1,426,770
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	49,180			98,644		682,853		66,416		7,044			904,137
Gas Royalty Interests Costs	—			10,255		—		—		(6		)	10,249
Purchased Gas Costs	—			517		—		—		—			517
Related Party Activity	7,013			—		1,258		502		(8,773		)	—
Freight Expense	—			—		49,293		—		—			49,293
Selling, General and Administrative Expenses	—			9,981		28,475		447		—			38,903
Depreciation, Depletion and Amortization	2,921			48,803		103,100		523		—			155,347
Interest Expense	54,762			1,218		2,229		11		(100		)	58,120
Taxes Other Than Income	636			8,200		81,971		820		—			91,627
Total Costs	114,512			177,618		949,179		68,719		(1,835		)	1,308,193
Earnings (Loss) Before Income Taxes	53,473			12,401		212,105		6,260		(165,662		)	118,577
Income Tax Expense (Benefit)	(43,723		)	4,947		57,789		2,368		—			21,381
Net Income (Loss)	$	97,196		$	7,454	$	154,316	$	3,892	$	(165,662	)	$	97,196

31

Balance Sheet at December 31, 2012:

	Parent Issuer		CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Assets:
Current Assets:
Cash and Cash Equivalents	$	17,491	$	3,352		$	175		$	860	$	—		$	21,878
Accounts and Notes Receivable:
Trade	—		58,126			—			370,202		—			428,328
Notes Receivable	154		315,730			2,503			—		—			318,387
Other Receivables	6,335		214,748			33,289			5,159		(128,400		)	131,131
Accounts Receivable—Securitized	—		—			—			37,846		—			37,846
Inventories	—		14,133			198,269			35,364		—			247,766
Deferred Income Taxes	174,176		(26,072		)	—			—		—			148,104
Restricted Cash	—		—			48,294			—		—			48,294
Prepaid Expenses	29,589		86,186			40,215			1,370		—			157,360
Total Current Assets	227,745		666,203			322,745			450,801		(128,400		)	1,539,094
Property, Plant and Equipment:
Property, Plant and Equipment	216,448		5,956,207			9,347,370			25,179		—			15,545,204
Less-Accumulated Depreciation, Depletion and Amortization	126,048		960,613			4,249,507			18,069		—			5,354,237
Total Property, Plant and Equipment-Net	90,400		4,995,594			5,097,863			7,110		—			10,190,967
Other Assets:
Deferred Income Taxes	884,310		(439,725		)	—			—		—			444,585
Restricted Cash	—		—			20,379			—		—			20,379
Investment in Affiliates	9,917,050		143,876			769,058			—		(10,607,154		)	222,830
Notes Receivable	239		—			25,738			—		—			25,977
Other	118,938		65,935			32,016			10,188		—			227,077
Total Other Assets	10,920,537		(229,914		)	847,191			10,188		(10,607,154		)	940,848
Total Assets	$	11,238,682	$	5,431,883		$	6,267,799		$	468,099	$	(10,735,554	)	$	12,670,909
Liabilities and Equity:
Current Liabilities:
Accounts Payable	$	177,734	$	166,182		$	154,936		$	9,130	$	—		$	507,982
Accounts Payable (Recoverable)-Related Parties	3,599,216		23,981			(3,749,584		)	254,787		(128,400		)	—
Current Portion of Long-Term Debt	1,554		5,953			5,222			756		—			13,485
Short-Term Notes Payable	25,073		—			—			—		—			25,073
Accrued Income Taxes	20,488		13,731			—			—		—			34,219
Borrowings Under Securitization Facility	—		—			—			37,846		—			37,846
Other Accrued Liabilities	135,407		57,074			566,485			9,528		—			768,494
Total Current Liabilities	3,959,472		266,921			(3,022,941		)	312,047		(128,400		)	1,387,099
Long-Term Debt:	3,005,515		46,081			121,523			1,467		—			3,174,586
Deferred Credits and Other Liabilities:
Postretirement Benefits Other Than Pensions	—		—			2,832,401			—		—			2,832,401
Pneumoconiosis Benefits	—		—			174,781			—		—			174,781
Mine Closing	—		—			446,727			—		—			446,727
Gas Well Closing	—		80,097			68,831			—		—			148,928
Workers’ Compensation	—		—			155,342			306		—			155,648
Salary Retirement	218,004		—			—			—		—			218,004
Reclamation	—		—			47,965			—		—			47,965
Other	101,899		24,518			4,608			—		—			131,025
Total Deferred Credits and Other Liabilities	319,903		104,615			3,730,655			306		—			4,155,479
Total CONSOL Energy Inc. Stockholders’ Equity	3,953,792		5,014,313			5,438,562			154,279		(10,607,154		)	3,953,792
Noncontrolling Interest	—		(47		)	—			—		—			(47		)
Total Liabilities and Equity	$	11,238,682	$	5,431,883		$	6,267,799		$	468,099	$	(10,735,554	)	$	12,670,909

32

Cash Flow for the Three Months Ended March 31, 2013 (unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination		Consolidated
Net Cash Provided by Operating Activities	$	59,082		$	190,004		$	11,589		$	7,605		$	—	$	268,280
Cash Flows from Investing Activities:
Capital Expenditures	$	(1,504	)	$	(207,129	)	$	(197,339	)	$	—		$	—	$	(405,972	)
Proceeds from Sales of Assets	(75		)	343			138,365			3			—		138,636
Investments in Equity Affiliates	—			(12,000		)	(500		)	—			—		(12,500		)
Change in Restricted Cash	—			—			48,294			—			—		48,294
Net Cash (Used in) Provided by Investing Activities	$	(1,579	)	$	(218,786	)	$	(11,180	)	$	3		$	—	$	(231,542	)
Cash Flows from Financing Activities:
Proceeds from (Payments on) Short-Term Borrowings	(29,000		)	29,000			—			—			—		—
Payments on Securitization Facility	—			—			—			(7,727		)	—		(7,727		)
Payments on Miscellaneous Borrowings	(25,612		)	—			(1,813		)	(176		)	—		(27,601		)
Other Financing Activities	1,770			(1,400		)	1,400						—		1,770
Net Cash (Used in) Provided by Financing Activities	$	(52,842	)	$	27,600		$	(413	)	$	(7,903	)	$	—	$	(33,558	)

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	)
Proceeds from Sales of Assets	—			4,359			24,250			2			—		28,611
Investments in Equity Affiliates	—			(9,999		)	(251		)	—			—		(10,250		)
Net Cash (Used in) Provided by Investing Activities	$	(13,562	)	$	(104,095	)	$	(170,430	)	$	2		$	—	$	(288,085	)
Cash Flows from Financing Activities:
Dividends Paid	$	91,613		$	(120,000	)	$	—		$	—		$	—	$	(28,387	)
Payments on Miscellaneous Borrowings	(236		)	—			(1,844		)	(250		)	—		(2,330		)
Other Financing Activities	893			(844		)	844			—			—		893
Net Cash (Used in) Provided by Financing Activities	$	92,270		$	(120,844	)	$	(1,000	)	$	(250	)	$	—	$	(29,824	)

33

Statement of Comprehensive Income for the Three Months Ended March 31, 2013 (Unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Net (Loss) Income	$	(1,564	)	$	(325	)	$	103,542	$	2,228	$	(105,702	)	$	(1,821	)
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	45,757			—			45,757		—		(45,757		)	45,757
Net (Decrease) Increase in the Value of Cash Flow Hedge	(18,595		)	(18,595		)	—		—		18,595			(18,595		)
Reclassification of Cash Flow Hedge from OCI to Earnings	(22,713		)	(22,713		)	—		—		22,713			(22,713		)
Other Comprehensive (Loss) Income:	4,449			(41,308		)	45,757		—		(4,449		)	4,449
Comprehensive Income (Loss)	2,885			(41,633		)	149,299		2,228		(110,151		)	2,628
Add: Comprehensive Loss Attributable to Noncontrolling Interest	—			257			—		—		—			257
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	2,885		$	(41,376	)	$	149,299	$	2,228	$	(110,151	)	$	2,885

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 (Loss)	$	97,196		$	7,454		$	154,316	$	3,892	$	(165,662	)	$	97,196
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	59,573			—			59,573		—		(59,573		)	59,573
Net Increase (Decrease) in the Value of Cash Flow Hedge	76,076			76,076			—		—		(76,076		)	76,076
Reclassification of Cash Flow Hedge from OCI to Earnings	(47,941		)	(47,941		)	—		—		47,941			(47,941		)
Other Comprehensive Income (Loss):	87,708			28,135			59,573		—		(87,708		)	87,708
Comprehensive Income (Loss)	$	184,904		$	35,589		$	213,889	$	3,892	$	(253,370	)	$	184,904

34

NOTE 16—RELATED PARTY TRANSACTIONS:

CONE Gathering LLC Related Party Transactions

During the three months ended March 31, 2013, CONE Gathering LLC (CONE), a 50% owned affiliate, provided CNX Gas Company LLC (CNX Gas Company) gathering services in the ordinary course of business. Gathering services received from CONE were $7,327 and $3,462 for the three months ended March 31, 2013 and 2012, respectively, which were included in Cost of Goods Sold on the Consolidated Statements of Income.

As of March 31, 2013 and December 31, 2012, CONSOL Energy and CNX Gas Company had a net payable of $10,975 and $3,142, respectively, due CONE which was comprised of the following items:

	March 31,			December 31,
	2013			2012			Location on Balance Sheet
Reimbursement for CONE Expenses	$	(655	)	$	(1,336	)	Accounts Receivable–Other
Reimbursement for Services Provided to CONE	(288		)	(341		)	Accounts Receivable–Other
CONE Gathering Capital Reimbursement	—			(18		)	Accounts Receivable–Other
CONE Gathering Fee Payable	11,918			4,837			Accounts Payable
Net Payable due CONE	$	10,975		$	3,142

NOTE 17—RECENT ACCOUNTING PRONOUNCEMENTS:

In February 2013, the Financial Accounting Standards Board issued Update 2013-04 - Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date. The objective of the amendments in this update is to provide guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of this guidance is fixed at the reporting date, except for obligations addressed within existing guidance in U.S. generally accepted accounting principles (GAAP). The guidance in this update requires an entity to measure obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of this guidance is fixed at the reporting date, as the sum of the following: a.) The amount the reporting entity agreed to pay on the basis of its arrangement amount with its co-obligors, and b.) Any additional amount the reporting entity expects to pay on behalf of its co-obligors. The guidance in this update also requires an entity to disclose the nature and amount of the obligation as well as other information about those obligations. The amendments in this update are effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The amendments in this update should be applied retrospectively to all prior periods presented for those obligations resulting from joint and several liability arrangements within the update's scope that exist at the beginning of an entity's fiscal year of adoption. We believe adoption of this new guidance will not have a material impact on CONSOL Energy's financial statements.

NOTE 18—SUBSEQUENT EVENTS:

In April 2013, CONSOL Energy and the Commonwealth of Pennsylvania entered into a Settlement Agreement and Release settling all of the Commonwealth's claims regarding the Ryerson Park Dam and the Ryerson Park Lake, discussed further in Note 11 - Commitments and Contingencies. The Settlement provides in part for the payment to the Commonwealth of $36,000 for use to rebuild the dam and restore the lake. As part of the settlement, the Commonwealth will convey to the Company its oil and gas rights within the Park, subject to the Company's agreement to extract oil and gas from surface facilities located outside of the boundaries of the Park. The Settlement also provides in part for the conveyance by the Company to the Commonwealth of eight surface parcels containing approximately 506 acres of land adjoining the park after the parcels are no longer needed for the Company's operations and the conveyance by the Commonwealth to the Company certain coal and mining rights in an area of the Bailey Mine where a mining permit application is currently pending.

35

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

General

For most of the first quarter, warmer than normal temperatures kept downward pressure on thermal and natural gas prices. Domestic electric generation increased 3% during the first quarter versus the same period in 2012. Although global economic uncertainties persisted, disciplined production from coal, flat natural gas production growth, and favorable late winter weather helped reduce inventories and raise prices.

First quarter coal consumption was aided by below average temperatures in March.  As natural gas prices rose towards $4.00/MMbtu, electric generation continued to switch back to traditional coal-fired generators.  Early government estimates show that coal-fired generation produced 40% of U. S. power during the first quarter compared with 36% during the same period in 2012.  Comparatively, the percentage dropped from 40% in fourth quarter 2011 to 36% in first quarter of 2012.  The 2013 first quarter percentage is consistent with the percentage in fourth quarter 2012.  Utility stockpiles declined throughout the quarter versus 2012 periods.  A late winter cold snap, a rise in natural gas prices, and domestic coal production cuts contributed to continued stabilization of coal prices. 

In the longer term, the outlook for domestic thermal coal continues to face regulatory challenges.  With the upcoming 2015 deadline for the U.S. Environmental Protection Agency's Mercury and Air Toxics Standards (MATS) rule, utilities are retiring smaller and less efficient coal-fired units. 

Internationally, U.S. exports are expected to slightly decline in 2013 after a record year in 2012.  However, early government data suggests that first quarter exports are up slightly over the year ago period.  Longer-term fundamentals for U.S. thermal coal exports remain favorable as subsidized mining in Europe is phased out, nuclear growth plans are curtailed, and coal continues to maintain a cost advantage over other more expensive oil-linked fuels.

Also during the first quarter, metallurgical coal benchmark prices remained below the comparable 2012 period. The U.S. first quarter international benchmark price for premium metallurgical coal settled 3% lower than the U.S. fourth quarter settlement, before recovering 4% for the U.S. second quarter settlement. The low price environment is indicative of the continued oversupplied position of the global metallurgical coal market.

Global steel production has remained under pressure as a result of limited demand growth and steel mill overcapacity. The Amonate Complex has remained idled since September 2012 in response to weak market conditions and low price realization.

CONSOL Energy's coal sales outlook is as follows:

	Q2 2013		2013		2014		2015
Estimated Coal Sales (millions of tons)	13.25 - 13.75		55.5 - 57.5		62.6		63.9
Est. Low-Vol Met Sales	0.9 -1.0		4.0-4.2		5.3		5.3
Tonnage: Firm	0.6		2.3		N/A		N/A
Avg. Price: Sold (Firm)	$	108.58	$	107.17	N/A		N/A
Est. High-Vol Met Sales	0.5+		1.7+		4.8		6.4
Tonnage: Firm	0.3		1.2		0.2		0.2
Avg. Price: Sold (Firm)	$	62.97	$	65.74	$	75.53	$	74.74
Est. Thermal Sales	12.1+		49.8+		51.9		51.5
Tonnage: Firm	11.8		49.4		25.5		14.5
Avg. Price: Sold (Firm)	$	57.99	$	58.8	$	59.94	$	61.12

Note: While most of the data in the table are single point estimates, the inherent uncertainty of markets and mining operations means that investors should consider a reasonable range around these estimates. N/A means not available or not forecast. CONSOL has chosen not to forecast prices for open tonnage due to ongoing customer negotiations. In the thermal sales category, the open tonnage includes two items: sold, but unpriced tons and collared tons. Collared tons in 2014 are 7.0 million tons, with a ceiling of $55.90 per ton and a floor of $46.32 per ton. Collared tons in 2015 are 8.7 million tons, with a ceiling of $57.43 per ton and a floor of $44.86 per ton. Calendar years 2013, 2014 and 2015 include 0.1, 0.6, and 0.7 million tons, respectively, from Amonate. The Amonate tons are not included in the category breakdowns.

36

CONSOL Energy expects its net gas production to be between 170 - 180 Bcf for the year. Second quarter gas production, net to CONSOL Energy, is expected to be approximately 38 - 40 Bcf.

Several significant transactions occurred in the three months ended March 31, 2013. These transactions include the following:

• CNX Gas Company completed negotiations with the Allegheny County Airport Authority, which operates the Pittsburgh International Airport and the Allegheny County Airport, for the lease of the oil and gas rights on approximately 9.3 thousand acres.  A majority of these contiguous acres are in the liquids area of the Marcellus Shale play.  CNX Gas Company paid $46.3 million as an up-front bonus payment at closing.  Approximately 7.6% percent of the bonus payment was placed into escrow while negotiations continue for a portion of the acres associated with the Allegheny County Airport and other acres that have potentially defective title.  CNX Gas Company must spud a well by February 21, 2015 and proceed with due diligence to complete the well or the lease terminates and CNX Gas forgoes the bonus. Our joint venture partner, Noble Energy, has indicated that it intends to acquire 50% of the acreage and accordingly, incur 50% of the associated costs.

• Pension settlement accounting required the acceleration of previously unrecognized actuarial losses due to lump sum payments from the Company's salary retirement pension plan exceeding the annual projected service and interest costs of the plan. The pension settlement resulted in $27.1 million pre-tax expense adjustment. Many of the lump sum payments in the three months ended March 31, 2013 were paid to employees who elected to retire under the 2012 Voluntary Severance Incentive program. Also, pension settlement required the pension plan to be remeasured using updated assumptions at March 31, 2013. The updated assumptions include resetting the discount rate used in the actuarial calculation. See Note 3- Components of Pension and Other Postretirement Benefit (OPEB) Plans Net Periodic Benefit Costs, in the Notes to the Unaudited Consolidated Financial Statements included in this Form 10-Q for additional details of the updated assumptions.

• In the three months ended March 31, 2013, an agreement in principle was reached for resolution of the class actions brought by shareholders of CNX Gas challenging the tender offer by CONSOL Energy to acquire all the shares of CNX Gas common stock that CONSOL Energy did not already own for $38.25 per share in May 2010 in principle. The total settlement provides for a payment to the plaintiffs of $42.73 million, of which the company expects to pay $20.20 million. This settlement is subject to court approval and to the execution of final agreements with the parties. See Note 11 - Commitments and Contingencies, in the Notes to the Unaudited Consolidated Financial Statements included in this Form 10-Q for additional details.    

• On March 12, 2013, smoke was detected exiting the Orndoff shaft at CONSOL Energy's Blacksville No. 2 Mine near Wayne in Greene County, PA. All day shift underground employees were safely evacuated and no one sustained injuries. The location of the fire was identified and containment and extinguishment procedures were followed. The fire was successfully extinguished. It is unknown when mine operations will resume. This event resulted in pre-tax expense adjustment of $15.2 million in the quarter ended March 31, 2013.

• A review of certain titles in the company's Marcellus Shale acreage, continued throughout the three months ended March 31, 2013. As part of the title defect process the company is working through with its joint venture partner, Noble Energy, CONSOL Energy conceded title defects on acreage which had a book value to CONSOL Energy of $6.3 million.

CONSOL Energy continues to manage 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 increased scrutiny of existing safety regulations and the development of new safety regulations and additional environmental restrictions.

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

• Federal and state regulators have proposed regulations which, if adopted, would adversely impact our business.   These proposed regulations could require significant changes in the manner in which we operate and/or would increase the cost of our operations. For example, the Department of Interior, Office of Surface Mining Reclamation and Enforcement (OSM) is currently preparing an environmental impact statement relating to OSM's consideration of five alternatives for amending its coal mining stream protection rules.  All of the alternatives, except the no action alternative, could make it more costly to mine our coal and/or could eliminate the ability to mine some of our coal.  OSM has indicated that it will not issue a draft rule or a draft environmental impact statement until sometime in 2014. Other examples are the Mercury and Air Toxic Standards (MATS) (remanded by the court and reproposed by the EPA in November 2012) and the Utility Maximum Achievable Control Technology (Utility MACTS) rules issued by the

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EPA. These new regulations set mercury and air toxic standards for new and existing coal and oil fired electric utility steam generating units and include more stringent new source performance standards (NSPS) for particulate matter (PM), SO2 and NOx.  EPA reconsidered the UMACT rules and recently finalized revised new source performance standards for coal based power plants which raised some emission limits. The standards remain stringent and costly for compliance. On April 18, 2012, the EPA published new final New Source Performance Standards for gas wells and related facilities. These rules apply to wells that were hydraulically fractured after August 23, 2011 and require the implementation by January 1, 2015 of technologies that capture the gas that is currently vented or flared during completion (hydrofracturing) of a well.  Low pressure wells, including coalbed methane wells, are excluded from these new standards.

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

• CONSOL Energy surface coal mining operations in West Virginia are subject to several citizen suits and several citizen groups' Notices of Intent to Sue relating to alleged violations of water discharge permits from the coal mining operations. In each of these matters, CONSOL Energy investigates the complaints, if necessary develops and implements compliance plans, and defends the citizen suits as appropriate.

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

• Under our joint venture agreements with Noble Energy and Hess, each of them has the right to perform due diligence on the title to the oil and gas interests which we conveyed to them and to assert that title to the acreage is defective. If they establish any title defects which are not resolved in favor of CONSOL Energy or if the subject acreage is reassigned to us at our request, then subject to certain deductibles, Noble's and Hess's respective aggregate carried cost obligation under the joint venture agreements will be reduced by the value the parties previously allocated to the affected acreage in the transaction. If a significant percentage of the oil and gas interests we contributed have title defects, the carried costs could be materially reduced and our aggregate share of the drilling and completion costs for wells in these joint ventures could materially increase.  See Note 8 - Property, Plant and Equipment in the Notes to the Unaudited Consolidated Financial Statements included in this Form 10-Q for additional details.

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

• CONSOL Energy continues to explore potential sales of assets.

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Results of Operations

Three Months EndedMarch 31, 2013 Compared with Three Months EndedMarch 31, 2012

Net Income Attributable to CONSOL Energy Shareholders

CONSOL Energy reported a net loss attributable to CONSOL Energy shareholders of $2 million, or $0.01 per diluted share, for the three months ended March 31, 2013. Net income attributable to CONSOL Energy shareholders was $97 million, or $0.42 per diluted share, for the three months ended March 31, 2012.

The coal division includes thermal coal, high volatile metallurgical coal, low volatile metallurgical coal and other coal. The total coal division contributed $93 million of earnings before income tax for the three months ended March 31, 2013 compared to $163 million for the three months ended March 31, 2012. The total coal division sold 15.2 million tons of coal produced from CONSOL Energy mines for the three months ended March 31, 2013 and March 31, 2012.

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

	For the Three Months Ended March 31,
	2013		2012		Variance			Percent Change
Average Sales Price per ton sold	$	63.56	$	69.06	$	(5.50	)	(8.0	)%
Average Cost of Goods Sold per ton	50.69		54.60		(3.91		)	(7.2	)%
Margin per ton sold	$	12.87	$	14.46	$	(1.59	)	(11.0	)%

The lower average sales price per ton sold reflects a decrease in the global metallurgical coal markets. The coal division priced 2.8 million tons on the export market at an average sales price of $72.33 for the three months ended March 31, 2013 compared to 2.6 million tons at an average price of $92.52 per ton for the three months ended March 31, 2012. All other tons were sold on the domestic market.

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

• Direct operating costs improved primarily as the result of several cost saving initiatives at the Buchanan Mine, such as, slowing the pace of major maintenance projects, right sizing the workforce to fit the recently implemented five-day work schedule, and opening the Horne Mountain portal which allowed employees to enter the mine much closer to the longwall face.   

• The idle longwalls at the Blacksville Mine and the Buchanan Mine during March 2012 resulted in an decrease in unit costs of approximately $1.89 in the period-to-period comparison. The 2012 unit costs were higher as the 2012 fixed costs were allocated over fewer tons.

• Average direct service costs to operations were improved due to reduced subsidence expense related to the timing and nature of properties undermined in the period-to-period comparison.

• Average operating supplies and maintenance costs per ton sold decreased due to reduced equipment maintenance, timing of major equipment overhaul costs, reduced fuels and lubricants and use of pumpable cribs for roof support.

• The Fola Mining Complex was idled in August 2012 which resulted in lower direct operating costs per ton produced in the period-to-period comparison. The mine, which was idled for market reasons, was a higher cost mining operation which when removed reduced the overall average direct operating costs per ton produced by $0.55 per ton.

The total gas division includes CBM, Shallow Oil and Gas, Marcellus and other gas. The total gas division contributed $1 million of loss before income tax for the three months ended March 31, 2013 compared to $12 million of income before income tax for the three months ended March 31, 2012. Total gas production was 39.2 billion cubic feet for the three months ended March 31, 2013 compared to 37.7 billion cubic feet for the three months ended March 31, 2012. Total gas production increased primarily as a result of the Marcellus on-going drilling program.

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

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	For the Three Months Ended March 31,
	2013	2012	Variance		Percent Change
Average Sales Price per thousand cubic feet sold	4.30	4.26	0.04		0.9%
Average Costs per thousand cubic feet sold	3.53	3.37	0.16		4.7%
Margin per thousand cubic feet sold	0.77	0.89	(0.12	)	(13.5)%

Total gas division outside sales revenues were $168 million for the three months ended March 31, 2013 compared to $161 million for the three months ended March 31, 2012. The increase was primarily due to the 4.0% increase in volumes sold, along with 0.9% increase in average price per thousand cubic feet sold. The increase in average sales price is the result of the increase in general market prices and sales of natural gas liquids, partially offset by various gas swap transactions that occurred throughout both periods. The gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 16.7 billion cubic feet of our produced gas sales volumes for the three months ended March 31, 2013 at an average price of $4.79 per thousand cubic feet. These financial hedges represented 18.3 billion cubic feet of our produced gas sales volumes for the three months ended March 31, 2012 at an average price of $5.44 per thousand cubic feet.

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

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

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

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

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

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

	For the three months Ended March 31,
	2013		2012		Variance			Percent Change
Employee wages and related expenses	$	13	$	17	$	(4	)	(23.5	)%
Consulting and professional services	8		6		2			33.3	%
Advertising and promotion	2		2		—			—	%
Contributions	2		2		—			—	%
Miscellaneous	7		8		(1		)	(12.5	)%
Total Company General and Administrative Expenses	$	32	$	35	$	(3	)	(8.6	)%

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

• Employee wages and related expenses decreased $4 million primarily attributable to fewer employees as a result of the 2012 Voluntary Severance Incentive Plan and lower salary OPEB expenses in the period-to-period comparison. The lower OPEB expenses relate to changes in the discount rates and other assumptions, and a modification to the benefit plan for certain salaried employees.

• Consulting and professional services increased $2 million in the period-to-period comparison due to various legal proceedings and consulting projects, none of which are individually significant.

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

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

Total Company long-term liabilities, such as OPEB, the salary retirement plan, workers' compensation and long-term disability are actuarially calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. Total CONSOL Energy expense related to our actuarial liabilities was $90

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million for the three months ended March 31, 2013 compared to $69 million for the three months ended March 31, 2012. The increase of $21 million for total CONSOL Energy expense was primarily due to required pension settlement accounting of $27 million related to lump sum distributions made for the 2013 plan year exceeding the total of the service cost and interest cost for the 2013 plan year. The pension settlement was not allocated to individual operating segments and is therefore not included in unit costs presented for coal or gas. This was offset, in part, due to a modification to the benefit plan for salaried employees and a decrease in the discount rate assumptions used to calculate expense for benefit plans at the measurement date, which is December 31. See Note 3—Components of Pension and Other Postretirement Benefit Plans Net Periodic Benefit Costs and Note 4—Components of Coal Workers' Pneumoconiosis (CWP) and Workers' Compensation Net Periodic Benefit Costs in the Notes to the Unaudited Consolidated Financial Statements for additional detail of the total Company expense decrease.

TOTAL COAL SEGMENT ANALYSIS for the three months ended March 31, 2013 compared to the three months ended March 31, 2012:

The coal segment contributed $93 million of earnings before income tax in the three months ended March 31, 2013 compared to $163 million in the three months ended March 31, 2012. Variances by the individual coal segments are discussed below.

	For the Three Months Ended														Difference to Three Months Ended
	March 31, 2013														March 31, 2012
	Thermal Coal			High Vol Met Coal		Low Vol Met Coal			Other Coal			Total Coal			Thermal Coal			High Vol Met Coal			Low Vol Met Coal			Other Coal			Total Coal
Sales:
Produced Coal	$	761		$	59	$	147		$	—		$	967		$	(51	)	$	(2	)	$	(26	)	$	(4	)	$	(83	)
Purchased Coal	—			—		—			5			5			—			—			—			—			—
Total Outside Sales	761			59		147			5			972			(51		)	(2		)	(26		)	(4		)	(83		)
Freight Revenue	—			—		—			14			14			—			—			—			(35		)	(35		)
Other Income	—			—		—			14			14			—			—			—			(18		)	(18		)
Total Revenue and Other Income	761			59		147			33			1,000			(51		)	(2		)	(26		)	(57		)	(136		)
Costs and Expenses:
Beginning inventory costs	58			—		21			—			79			(32		)	—			5			—			(27		)
Total direct operating costs	391			31		48			45			515			(43		)	1			(12		)	14			(40		)
Total royalty/production taxes	53			—		7			—			60			(3		)	(3		)	(2		)	(1		)	(9		)
Total direct services to operations	57			6		6			60			129			(28		)	(2		)	—			3			(27		)
Total retirement and disability	45			3		7			4			59			(3		)	—			(1		)	—			(4		)
Depreciation, depletion and amortization	73			6		11			13			103			(7		)	—			1			9			3
Ending inventory costs	(44		)	—		(8		)	—			(52		)	66			—			7			—			73
Total Costs and Expenses	633			46		92			122			893			(50		)	(4		)	(2		)	25			(31		)
Freight Expense	—			—		—			14			14			—			—			—			(35		)	(35		)
Total Costs	633			46		92			136			907			(50		)	(4		)	(2		)	(10		)	(66		)
Earnings (Loss) Before Income Taxes	$	128		$	13	$	55		$	(103	)	$	93		$	(1	)	$	2		$	(24	)	$	(47	)	$	(70	)

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THERMAL COAL SEGMENT

The thermal coal segment contributed $128 million to total Company earnings before income tax for the three months ended March 31, 2013 and $129 million for the three months ended March 31, 2012. The thermal coal revenue and cost components on a per unit basis for these periods are as follows:

	For the Three Months Ended March 31,
	2013		2012		Variance			Percent Change
Company Produced Thermal Tons Sold (in millions)	12.9		13.1		(0.2		)	(1.5	)%
Average Sales Price Per Thermal Ton Sold	$	59.01	$	61.83	$	(2.82	)	(4.6	)%
Beginning Inventory Costs Per Thermal Ton	$	50.92	$	58.32	$	(7.40	)	(12.7	)%
Total Direct Operating Costs Per Thermal Ton Produced	$	31.02	$	31.89	$	(0.87	)	(2.7	)%
Total Royalty/Production Taxes Per Thermal Ton Produced	4.17		4.15		0.02			0.5	%
Total Direct Services to Operations Per Thermal Ton Produced	4.49		6.33		(1.84		)	(29.1	)%
Total Retirement and Disability Per Thermal Ton Produced	3.58		3.54		0.04			1.1	%
Total Depreciation, Depletion and Amortization Costs Per Thermal Ton Produced	5.74		5.90		(0.16		)	(2.7	)%
Total Production Costs Per Thermal Ton Produced	$	49.00	$	51.81	$	(2.81	)	(5.4	)%
Ending Inventory Costs Per Thermal Ton	$	50.57	$	55.60	$	(5.03	)	(9.0	)%
Total Costs Per Thermal Ton Sold	$	49.09	$	52.06	$	(2.97	)	(5.7	)%
Average Margin Per Thermal Ton Sold	$	9.92	$	9.77	$	0.15		1.5	%

Thermal coal revenue was $761 million for the three months ended March 31, 2013 compared to $812 million for the three months ended March 31, 2012. The $51 million decrease was attributable to a $2.82 per ton lower average sales price and 0.2 million reduction in tons sold. The lower average thermal coal sales price in the 2013 period was the result of the renewal of several domestic thermal contracts whose pricing was reduced effective January 1, 2013. Also, 1.0 million tons of thermal coal were priced on the export market at an average sales price of $58.91 per ton for the three months ended March 31, 2013 compared to 1.0 million tons at an average price of $62.01 per ton for the three months ended March 31, 2012.

Total cost of goods sold are comprised of changes in thermal coal inventory, both volumes and carrying values, and costs of tons produced in the period. Total cost of goods sold for thermal coal was $633 million for the three months ended March 31, 2013, or $51 million lower than the $684 million for the three months ended March 31, 2012. Total cost of goods sold for thermal coal was $49.09 per ton in the three months ended March 31, 2013 compared to $52.06 per ton in the three months ended March 31, 2012. The decrease in costs of goods sold per thermal ton was due to the items described below.

Direct Operating costs are comprised of labor, supplies, maintenance, power and preparation plant charges related to the extraction and sale of coal. These costs are reviewed regularly by management and are considered to be the direct responsibility of mine management. Direct Operating costs related to the thermal coal segment were $391 million in the three months ended March 31, 2013 compared to $434 million in the three months ended March 31, 2012. Direct operating costs were $31.02 per ton produced in the current period compared to $31.89 per ton produced in the prior period. Changes in the average direct operating costs per thermal ton produced were primarily related to the following items:

• The Blacksville No. 2 longwall idling in 2012 resulted in lower direct operating costs per ton produced in the period-to-period comparison. The mine continued to run the continuous miners and perform mine maintenance during the month of March 2012 when the longwall was idled for market reasons, which negatively impacted unit costs $0.73 per ton during the idle period when compared to the current period.

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

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Royalties and production taxes decreased $3 million to $53 million in the current period. Average cost per thermal ton produced increased $0.02 per ton to $4.17 per ton sold, due to lower production volumes, and lower average sales prices which is the basis for most production taxes.

Direct services to the operations are comprised of items which support groups manage on behalf of the coal operations. Costs included in direct services are comprised of subsidence costs, direct administrative and selling costs, permitting and compliance costs, mine closing and reclamation costs, and water treatment costs. The cost of these support services was $57 million in the current period compared to $85 million in the prior period. Direct services to the operations were $4.49 per ton in the current period compared to $6.33 per ton in the prior period. Changes in the average direct service to operations cost per thermal ton produced were primarily related to the following items:

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

• Permitting and compliance costs decreased due to reduction in stream monitoring expenses

Retirement and disability costs are comprised of the expenses related to the Company's long-term liabilities, such as other post-retirement benefits (OPEB), the salary retirement plan, workers' compensation, coal workers' pneumoconiosis (CWP) and long-term disability. These liabilities are actuarially calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. The average retirement and disability costs attributable to the thermal coal segment were $45 million for the three months ended March 31, 2013 compared to $48 million for the three months ended March 31, 2012. The decrease in the thermal coal retirement and disability costs was primarily attributable to a decrease in discount rates used to calculate the 2013 cost of the long-term liabilities and a modification of the salaried other post-retirement benefit plan that occurred March 31, 2012. These improvements were offset, in part, by the reduction in production volumes which negatively impacted unit costs.

Depreciation, depletion and amortization for the thermal coal segment was $73 million for the three months ended March 31, 2013 compared to $80 million for the three months ended March 31, 2012. Unit costs per thermal ton produced were lower in the three months ended March 31, 2013 compared to the three months ended March 31, 2012 due to idling of the Fola Mining Complex.

Changes in thermal coal inventory volumes and carrying value resulted in $14 million of cost of goods sold in the three months ended March 31, 2013 compared to $20 million reduction of cost of goods sold in the three months ended March 31, 2012. Thermal coal inventory was 0.9 million tons at March 31, 2013 compared to 2.0 million tons at March 31, 2012.

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HIGH VOL METALLURGICAL COAL SEGMENT

The high volatile metallurgical coal segment contributed $13 million to total Company earnings before income tax for the three months ended March 31, 2013 compared to $11 million for the three months ended March 31, 2012. The high volatile metallurgical coal revenue and cost components on a per unit basis for these periods are as follows:

	For the Three Months Ended March 31,
	2013			2012		Variance			Percent Change
Company Produced High Vol Met Tons Sold (in millions)	0.9			1.0		(0.1		)	(10.0	)%
Average Sales Price Per High Vol Met Ton Sold	$	66.72		$	62.18	$	4.54		7.3	%
Beginning Inventory Costs Per High Vol Met Ton	$	—		$	—	$	—		—	%
Total Direct Operating Costs Per High Vol Met Ton Produced	$	34.71		$	30.44	$	4.27		14.0	%
Total Royalty/Production Taxes Per High Vol Met Ton Produced	(0.05		)	3.36		(3.41		)	(101.5	)%
Total Direct Services to Operations Per High Vol Met Ton Produced	7.25			7.72		(0.47		)	(6.1	)%
Total Retirement and Disability Per High Vol Met Ton Produced	3.80			3.11		0.69			22.2	%
Total Depreciation, Depletion and Amortization Costs Per High Vol Met Ton Produced	6.25			6.01		0.24			4.0	%
Total Production Costs Per High Vol Met Ton Produced	$	51.96		$	50.64	$	1.32		2.6	%
Ending Inventory Costs Per High Vol Met Ton	$	—		$	—	$	—		—	%
Total Costs Per High Vol Met Ton Sold	$	51.96		$	50.64	$	1.32		2.6	%
Margin Per High Vol Met Ton Sold	$	14.76		$	11.54	$	3.22		27.9	%

High volatile metallurgical coal revenue was $59 million for the three months ended March 31, 2013 compared to $61 million for the three months ended March 31, 2012. Average sales prices for high volatile metallurgical coal increased $4.54 per ton in a period-to-period comparison. CONSOL Energy priced 0.7 million tons of high volatile metallurgical coal in the export market at an average sales price of $63.79 per ton for the three months ended March 31, 2013 compared to 0.8 million tons at an average price of $59.22 per ton for the three months ended March 31, 2012. The remaining tons sold in the period-to-period comparison were sold on the domestic market.

Total cost of goods sold are comprised of changes in high volatile metallurgical coal inventory, both volumes and carrying values, and costs of tons produced in the period. Total cost of goods sold for high volatile metallurgical coal was $46 million for the three months ended March 31, 2013, or $4 million lower than the $50 million for the three months ended March 31, 2012. Total cost of goods sold for high volatile metallurgical coal was $51.96 per ton in the three months ended March 31, 2013 compared to $50.64 per ton in the three months ended March 31, 2012. The increase in cost of goods sold per high volatile metallurgical ton was due to the items described below.

Direct Operating costs are comprised of labor, supplies, maintenance, power and preparation plant charges related to the extraction and sale of coal. These costs are reviewed regularly by management and are considered to be the direct responsibility of mine management. Direct Operating costs related to the high volatile metallurgical coal segment were $31 million in the three months ended March 31, 2013 compared to $30 million in the three months ended March 31, 2012. Direct operating costs were $34.71 per ton produced in the current period compared to $30.44 per ton produced in the prior period. The increase in the average direct operating costs per high volatile metallurgical ton produced were primarily related due to fewer tons produced. Fixed costs are allocated over less tons, resulting in higher unit costs.

Royalties and production taxes improved $3 million in the current period due to various items, none of which are individually significant.

Direct services to the operations are comprised of items which support groups manage on behalf of the coal operations. Costs included in direct services are comprised of subsidence costs, direct administrative and selling costs, permitting and compliance costs, mine closing and reclamation costs, and water treatment costs. The costs of these support services for high

44

volatile metallurgical coal were $6 million in the current period compared to $8 million in the prior period. Lower costs were attributable to lower subsidence costs due to the timing and nature of properties undermined. Direct services to the operations for high volatile metallurgical coal were $7.25 per ton in the current period compared to $7.72 per ton in the prior period. Changes in the average direct service to operations cost per ton for high volatile metallurgical coal produced were primarily related to lower subsidence expenses, offset, in part, by lower tons produced.

Retirement and disability costs are comprised of the expenses related to the Company's long-term liabilities, such as other post-retirement benefits (OPEB), the salary retirement plan, workers' compensation, coal workers' pneumoconiosis (CWP) and long-term disability. These liabilities are actuarially calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. The average retirement and disability costs attributable to the high volatile metallurgical coal segment were $3 million for the three months ended March 31, 2013 and for the three months ended March 31, 2012. The reduction in production volumes had a negative impact on the unit costs.

Depreciation, depletion and amortization for the high volatile metallurgical coal segment was $6 million for the three months ended March 31, 2013 and March 31, 2012. Unit costs per high volatile ton produced were higher in the three months ended March 31, 2013 compared to the three months ended March 31, 2012 due to additional equipment and infrastructure placed into service after the 2012 period that is depreciated on a straight-line basis, which is negatively impacted by lower production volumes.

There were no changes in volumes or carrying value of coal inventory in the three months ended March 31, 2013 and March 31, 2012. There was no high volatile metallurgical coal inventory at March 31, 2013 or March 31, 2012.

LOW VOL METALLURGICAL COAL SEGMENT

The low volatile metallurgical coal segment contributed $55 million to total Company earnings before income tax in the three months ended March 31, 2013 compared to $79 million in the three months ended March 31, 2012. 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,
	2013		2012		Variance			Percent Change
Company Produced Low Vol Met Tons Sold (in millions)	1.4		1.0		0.4			40.0	%
Average Sales Price Per Low Vol Met Ton Sold	$	102.69	$	167.87	$	(65.18	)	(38.8	)%
Beginning Inventory Costs Per Low Vol Met Ton	$	86.38	$	67.60	$	18.78		27.8	%
Total Direct Operating Costs Per Low Vol Met Ton Produced	$	37.83	$	58.76	$	(20.93	)	(35.6	)%
Total Royalty/Production Taxes Per Low Vol Met Ton Produced	5.62		9.23		(3.61		)	(39.1	)%
Total Direct Services to Operations Per Low Vol Met Ton Produced	4.80		6.32		(1.52		)	(24.1	)%
Total Retirement and Disability Per Low Vol Met Ton Produced	5.19		8.32		(3.13		)	(37.6	)%
Total Depreciation, Depletion and Amortization Costs Per Low Vol Met Ton Produced	8.29		9.81		(1.52		)	(15.5	)%
Total Production Costs Per Low Vol Met Ton Produced	$	61.73	$	92.44	$	(30.71	)	(33.2	)%
Ending Inventory Costs Per Low Vol Met Ton	$	85.60	$	72.97	$	12.63		17.3	%
Total Costs Per Low Vol Met Ton Sold	$	64.42	$	90.75	$	(26.33	)	(29.0	)%
Margin Per Low Vol Met Ton Sold	$	38.27	$	77.12	$	(38.85	)	(50.4	)%

Low volatile metallurgical coal revenue was $147 million for the three months ended March 31, 2013 compared to $173 million for the three months ended March 31, 2012. The $26 million decrease was attributable to a $65.18 per ton lower average sales price. Average sales prices for low volatile metallurgical coal decreased in the period-to-period comparison due to the weakening in global metallurgical coal demand. For the 2013 period, 1.1 million tons of low volatile metallurgical coal was priced on the export market at an average price of $89.72 per ton compared to 0.8 million tons at an average price of $163.74 per ton for the 2012 period. The remaining tons sold in the period-to-period comparison were sold on the domestic market.

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Total cost of goods sold are comprised of changes in low volatile metallurgical coal inventory, both volumes and carrying values, and costs of tons produced in the period. Total cost of goods sold for low volatile metallurgical coal was $92 million for the three months ended March 31, 2013, or $2 million lower than the $94 million for the three months ended March 31, 2012. Total cost of goods sold for low volatile metallurgical coal was $64.42 per ton in the three months ended March 31, 2013 compared to $90.75 per ton in the three months ended March 31, 2012. The decrease in cost of goods sold per low volatile metallurgical ton was due to the following items described below.

Direct Operating costs are comprised of labor, supplies, maintenance, power and preparation plant charges related to the extraction and sale of coal. These costs are reviewed regularly by management and are considered to be the direct responsibility of mine management. Direct Operating costs related to the low volatile metallurgical coal segment were $48 million in the three months ended March 31, 2013 compared to $60 million in the three months ended March 31, 2012. Direct operating costs improved primarily as the result of several cost saving initiatives at the Buchanan Mine, such as, slowing the pace of major maintenance projects, right sizing the workforce to fit the recently implemented five-day work schedule, and opening the Horne Mountain portal which allowed employees to enter the mine much closer to the longwall face. Direct operating costs were $37.83 per ton produced in the current period compared to $58.76 per ton produced in the prior period. Low volatile metallurgical coal production was 1.3 million tons in the three months ended March 31, 2013 compared to 1.0 million tons in the three months ended March 31, 2012.

Royalties and production taxes improved $2 million to $7 million in the current period compared to $9 million in the prior period. Unit costs also improved $3.61 per low volatile metallurgical ton produced to $5.62 per ton in the current period compared to $9.23 per ton in the prior period. Average cost per low volatile metallurgical ton produced decreased due to lower royalties and lower production taxes. These decreases were related to lower average sales prices.

Direct services to the operations are comprised of items which support groups manage on behalf of the coal operations. Costs included in direct services are comprised of subsidence costs, direct administrative and selling costs, permitting and compliance costs, mine closing and reclamation costs, and water treatment costs. The costs of these support services for low volatile metallurgical coal were $6 million in the current and prior periods. Direct services to the operations for low volatile metallurgical coal were $4.80 per ton in the current period compared to $6.32 per ton in the prior period. Changes in the average direct service to operations cost per ton for low volatile metallurgical coal produced were primarily related to higher tons of coal produced in the period-to-period comparison.

Retirement and disability costs are comprised of the expenses related to the Company's long-term liabilities, such as other post-retirement benefits (OPEB), the salary retirement plan, workers' compensation, coal workers' pneumoconiosis (CWP) and long-term disability. These liabilities are actuarially calculated for the Company as a whole. The expenses are then allocated to operational units based on active employee counts or active salary dollars. The average retirement and disability costs attributable to the low volatile metallurgical coal segment were $7 million for the three months ended March 31, 2013 compared to $8 million for the three months ended March 31, 2012. The decrease in the low volatile metallurgical coal retirement and disability costs was primarily attributable to a decrease in discount rates used to calculate the cost of the long-term liabilities and a modification of the salaried other post-retirement benefit plan that occurred on March 31, 2012. This coupled with the increase in volumes resulted in an improvement on the unit costs of $3.13 in the period-to-period comparison.

Depreciation, depletion and amortization for the low volatile metallurgical coal segment was $11 million for the three months ended March 31, 2013 compared to $10 million for the three months ended March 31, 2012. Unit costs per low volatile metallurgical tons produced were lower in the three months ended March 31, 2013 compared to the three months ended March 31, 2012 due to the cost of equipment and infrastructure depreciated on a straight-line basis being spread over higher volumes of produced coal during the current period.

Changes in low volatile metallurgical coal inventory volumes and carrying value resulted in an increase of $13 million to cost of goods sold in the three months ended March 31, 2013 and an increase of $1 million to cost of goods sold in the three months ended March 31, 2012. Produced low volatile metallurgical coal inventory was 0.1 million tons at March 31, 2013 compared to 0.2 million tons at March 31, 2012.

OTHER COAL SEGMENT

The other coal segment had a loss before income tax of $103 million for the three months ended March 31, 2013 compared to a loss before income tax of $56 million for the three months ended March 31, 2012. The other coal segment includes purchased coal activities, idle mine activities, as well as various activities assigned to the coal segment but not allocated to each individual mine.

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Other coal segment produced coal sales includes revenue from the sale of 0.1 million tons of coal which was recovered during the reclamation process at idled facilities for the three months ended March 31, 2012. No coal was recovered during the reclamation process at idled facilities for the three months ended March 31, 2013. The primary focus of the activity at these locations is reclaiming disturbed land in accordance with the mining permit requirements after final mining has occurred. The tons sold are incidental to total Company production or sales.

Purchased coal sales consist of revenues from processing third-party coal in our preparation plants for blending purposes to meet customer coal specifications and coal purchased from third parties and sold directly to our customers. The revenues were $5 million for the three months ended March 31, 2013 and March 31, 2012.

Freight revenue is the amount billed to customers for transportation costs incurred. This revenue is based on weight of coal shipped, negotiated freight rates and method of transportation (i.e. rail, barge, truck, etc.) used by the customers to which CONSOL Energy contractually provides transportation services. Freight revenue is offset by freight expense. Freight revenue was $14 million for the three months ended March 31, 2012 compared to $49 million for the three months ended March 31, 2012. The $35 million decrease in freight revenue was due to decreased shipments under contracts which CONSOL Energy contractually provides transportation services.

Miscellaneous other income was $14 million for the three months ended March 31, 2013 compared to $32 million for the three months ended March 31, 2012. The $18 million decrease is due to the following items:

• Gain on sale of assets attributable to the Other Coal segment were $2 million in the three months ended March 31, 2013 compared to $17 million in the three months ended March 31, 2012. The change was primarily related to 2012 sales of surface lands in Illinois and Pennsylvania that resulted in income of $16 million. See Note 2—Acquisitions and Dispositions in the Notes to the Unaudited Consolidated Financial Statements for additional detail of these sales. The remaining change was related to various transactions that occurred throughout both periods, none of which were individually material.

• Equity in earnings of affiliates decreased $4 million due to lower earnings from our equity affiliates.

• In the three months ended March 31, 2013, $3 million in business interruption insurance proceeds was received related to the 2012 Bailey Belt Conveyor accident. There is no assurance that additional proceeds from the incident will be received.

• The remaining $2 million decrease in other income is due to various items, none of which are individually significant.

Other coal segment total costs were $136 million for the three months ended March 31, 2013 compared to $146 million for the three months ended March 31, 2012. The decrease of $10 million was due to the following items:

	For the Three Months Ended March 31,
	2013		2012		Variance
Blacksville No. 2 Mine Fire	$	15	$	—	$	15
Stock-based compensation	17		10		7
Closed and idle mines	30		22		8
Freight expense	14		49		(35		)
Other	60		65		(5		)
Total Other Coal Segment Costs	$	136	$	146	$	(10	)

• On March 12, 2013, smoke was detected exiting the Orndoff shaft at CONSOL Energy's Blacksville No. 2 Mine near Wayne in Greene County, PA. All day shift underground employees were safely evacuated and no one sustained injuries. The location of the fire was identified and containment and extinguishment procedures were developed. The fire has since been extinguished as of March 24, 2013. It is unknown when mine operations will resume. The $15 million pre-tax expense impact reflects the expenses incurred to extinguish the fire. Insurance recovery is uncertain at this time and the impact of any potential recovery has not been reflected in the three months ended March 31, 2013.

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

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• Closed and idle mine costs increased approximately $8 million for the three months ended March 31, 2013 compared to the three months ended March 31, 2012.  The increase was the result of $6 million additional costs related to on-going idling costs incurred at the Fola Complex in the three months ended March 31, 2013 and $3 million in idling costs incurred at the Amonate Complex, which were idled in September 2012. Closed and idle mine costs decreased $1 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.

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

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

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TOTAL GAS SEGMENT ANALYSIS for the three months ended March 31, 2013 compared to the three months ended March 31, 2012:

The gas segment contributed a loss of $1 million to earnings before income tax in the three months ended March 31, 2013 compared to earnings of $12 million in the three months ended March 31, 2012.

	For the Three Months Ended													Difference to Three Months Ended
	March 31, 2013													March 31, 2012
	CBM		Shallow Oil and Gas			Marcellus		Other Gas			Total Gas			CBM			Shallow Oil and Gas			Marcellus		Other Gas			Total Gas
Sales:
Produced	$	83	$	32		$	49	$	3		$	167		$	(16	)	$	(2	)	$	25	$	—		$	7
Related Party	1		—			—		—			1			—			—			—		—			—
Total Outside Sales	84		32			49		3			168			(16		)	(2		)	25		—			7
Gas Royalty Interest	—		—			—		14			14			—			—			—		2			2
Purchased Gas	—		—			—		1			1			—			—			—		—			—
Other Income	—		—			—		14			14			—			—			—		(2		)	(2		)
Total Revenue and Other Income	84		32			49		32			197			(16		)	(2		)	25		—			7
Lifting	9		7			5		1			22			—			(3		)	1		1			(1		)
Ad Valorem, Severance, and Other Taxes	1		3			2		(1		)	5			(2		)	—			1		(1		)	(2		)
Gathering	28		10			9		1			48			3			4			5		1			13
Gas Direct Administrative, Selling & Other	2		2			6		1			11			(3		)	(2		)	3		—			(2		)
Depreciation, Depletion and Amortization	23		14			13		2			52			1			(1		)	4		(2		)	2
General & Administration	—		—			—		10			10			—			—			—		—			—
Gas Royalty Interest	—		—			—		12			12			—			—			—		2			2
Purchased Gas	—		—			—		1			1			—			—			—		—			—
Exploration and Other Costs	—		—			—		10			10			—			—			—		5			5
Other Corporate Expenses	—		—			—		25			25			—			—			—		2			2
Interest Expense	—		—			—		2			2			—			—			—		1			1
Total Cost	63		36			35		64			198			(1		)	(2		)	14		9			20
Earnings Before Income Tax	$	21	$	(4	)	$	14	$	(32	)	$	(1	)	$	(15	)	$	—		$	11	$	(9	)	$	(13	)

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COALBED METHANE (CBM) GAS SEGMENT

The CBM segment contributed $21 million to the total Company earnings before income tax for the three months ended March 31, 2013 compared to $36 million for the three months ended March 31, 2012.

	For the Three Months Ended March 31,
	2013		2012		Variance			Percent Change
Produced Gas CBM sales volumes (in billion cubic feet)	20.7		22.7		(2.0		)	(8.8	)%
Average CBM sales price per thousand cubic feet sold	$	4.08	$	4.40	$	(0.32	)	(7.3	)%
Average CBM lifting costs per thousand cubic feet sold	0.45		0.41		0.04			9.8	%
Average CBM ad valorem, severance, and other taxes per thousand cubic feet sold	0.06		0.12		(0.06		)	(50.0	)%
Average CBM gathering costs per thousand cubic feet sold	1.38		1.08		0.30			27.8	%
Average CBM direct administrative, selling & other costs per thousand cubic feet sold	0.08		0.23		(0.15		)	(65.2	)%
Average CBM depreciation, depletion and amortization costs per thousand cubic feet sold	1.08		0.96		0.12			12.5	%
Total Average CBM costs per thousand cubic feet sold	3.05		2.80		0.25			8.9	%
Average Margin for CBM	$	1.03	$	1.60	$	(0.57	)	(35.6	)%

CBM sales revenues were $84 million in the three months ended March 31, 2013 compared to $100 million for the three months ended March 31, 2012. The $16 million decrease was primarily due to an 8.8% decrease in average volumes sold and by a 7.3% decrease in average sales price per thousand cubic feet sold. The decrease in CBM average sales price was the result of higher average market prices offset by various gas swap transactions that matured in each period. The gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 9.1 billion cubic feet of our produced CBM gas sales volumes for the three months ended March 31, 2013 at an average price of $4.63 per thousand cubic feet. For the three months ended March 31, 2012, these financial hedges represented 11.4 billion cubic feet at an average price of $5.63 per thousand cubic feet. CBM sales volumes decreased 2 billion cubic feet for the three months ended March 31, 2013 compared to the 2012 period primarily due to normal well declines without a corresponding increase in wells drilled. Currently, the focus of the gas division is to develop its Marcellus and Utica acreage.

Total costs for the CBM segment were $63 million for the three months ended March 31, 2013 compared to $64 million for the three months ended March 31, 2012. Lower costs in the period-to-period comparison are primarily related to decreased gas production as discussed above. Costs per unit have increased due to the decrease in production.

CBM lifting costs were $9 million for the three months ended March 31, 2013 and 2012. The $0.04 per thousand cubic feet increase in average lifting costs during the current year is directly related to the decreased gas production as discussed above.

CBM ad valorem, severance and other taxes were $1 million for the three months ended March 31, 2013 compared to $3 million for the three months ended March 31, 2012. The $2 million decrease in total dollars was primarily due to a reassessment of our 2012 ad valorem taxes paid to Tazewell County, Virginia resulting in a current period refund and due to lower severance tax expense caused by lower average gas sales prices. Decreased ad valorem and severance costs resulted in a decrease in average unit costs, offset, in part, by an increase due to the reduction of volumes.

CBM gathering costs were $28 million for the three months ended March 31, 2013 compared to $25 million for the three months ended March 31, 2012. The $0.30 per thousand cubic feet increase in average CBM gathering unit costs are related to increased power usage, higher compressor maintenance, higher road maintenance expenses and lower volumes sold in the period-to-period comparison.

CBM direct administrative, selling & other costs for the CBM segment were $2 million for the three months ended March 31, 2013 compared to $5 million for the three months ended March 31, 2012. Direct administrative, selling & other costs attributable to the total gas segment are allocated to the individual gas segments based on a combination of production and employee counts. The decrease in direct administrative, selling & other costs was primarily due to reduced direct

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administrative labor and CBM volumes representing a smaller proportion of total natural gas volumes produced. Improvements in unit costs were offset, in part, by the reduction in volumes.

Depreciation, depletion and amortization attributable to the CBM segment was $23 million for the three months ended March 31, 2013 compared to $22 million for the three months ended March 31, 2012. There was approximately $16 million, or $0.75 per unit-of-production, of depreciation, depletion and amortization related to CBM gas and related well equipment that was reflected on a units-of-production method of depreciation in the three months ended March 31, 2013. The production portion of depreciation, depletion and amortization was $15 million, or $0.68 per unit-of-production in the three months ended March 31, 2012. There was approximately $7 million, or $0.33 average per unit cost of depreciation, depletion and amortization relating to gathering and other equipment reflected on a straight line basis for the three months ended March 31, 2013. The non-production related depreciation, depletion and amortization was $7 million, or $0.28 per thousand cubic feet for the three months ended March 31, 2012.

SHALLOW OIL AND GAS SEGMENT

The Shallow Oil and Gas segment had a loss before income tax of $4 million for both the three months ended March 31, 2013 and for the three months ended March 31, 2012.

	For the Three Months Ended March 31,
	2013			2012			Variance			Percent Change
Produced Gas Shallow Oil and Gas sales volumes (in billion cubic feet)	7.1			7.6			(0.5		)	(6.6	)%
Average Shallow Oil and Gas sales price per thousand cubic feet sold	$	4.57		$	4.53		$	0.04		0.9	%
Average Shallow Oil and Gas lifting costs per thousand cubic feet sold	1.00			1.32			(0.32		)	(24.2	)%
Average Shallow Oil and Gas ad valorem, severance, and other taxes per thousand cubic feet sold	0.38			0.35			0.03			8.6	%
Average Shallow Oil and Gas gathering costs per thousand cubic feet sold	1.42			0.78			0.64			82.1	%
Average Shallow Oil and Gas direct administrative, selling & other costs per thousand cubic feet sold	0.32			0.59			(0.27		)	(45.8	)%
Average Shallow Oil and Gas depreciation, depletion and amortization costs per thousand cubic feet sold	2.04			1.98			0.06			3.0	%
Total Average Shallow Oil and Gas costs per thousand cubic feet sold	5.16			5.02			0.14			2.8	%
Average Margin for Shallow Oil and Gas	$	(0.59	)	$	(0.49	)	$	(0.10	)	20.4	%

Shallow Oil and Gas sales revenues were $32 million for the three months ended March 31, 2013 compared to $34 million for the three months ended March 31, 2012. The $2 million decrease was primarily due to the 6.6% decrease in volumes sold, offset, in part, by a 0.9% increase in average sales price. The increase in shallow oil and gas average sales price is the result of higher average market prices and various gas swap transactions that matured in each period. These gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 3.3 billion cubic feet of our produced shallow oil and gas sales volumes for the three months ended March 31, 2013 at an average price of $5.28 per thousand cubic feet. For the three months ended March 31, 2012, these financial hedges represented 4.1 billion cubic feet at an average price of $5.22 per thousand cubic feet.

Total costs for the shallow oil and gas segment were $36 million for the three months ended March 31, 2013 compared to $38 million for the three months ended March 31, 2012. The decrease is primarily attributable to decreased contract services, repairs and maintenance, and salt water disposal costs, offset, in part, by an increase in firm transportation costs.

Shallow Oil and Gas lifting costs were $7 million for the three months ended March 31, 2013 compared to $10 million for the three months ended March 31, 2012. The $3 million decrease to total costs and $0.32 per thousand cubic feet decrease to average unit costs is due to lower road maintenance, lower salt water disposal costs and lower contract services in the current period, offset, in part, by lower sales volumes.

Shallow Oil and Gas ad valorem, severance and other taxes remained consistent at $3 million for the three months ended March 31, 2013 and 2012. The $0.03 per thousand cubic feet increase is primarily due to the decrease in production.

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Shallow Oil and Gas gathering costs were $10 million for the three months ended March 31, 2013 compared to $6 million for the three months ended March 31, 2012. Gathering costs increased $4 million primarily due to increased firm transportation costs and higher compressor repair and maintenance costs in the period-to-period comparison.

Shallow Oil and Gas direct administrative, selling & other costs were $2 million for the three months ended March 31, 2013 compared to $4 million for the three months ended March 31, 2012. Direct administrative, selling & other costs attributable to the total gas segment are allocated to the individual gas segments based on a combination of production and employee counts. The $2 million decrease in the period-to-period comparison is due to reduced direct administrative labor and Shallow Oil and Gas volumes representing a smaller proportion of total natural gas volumes produced. The decrease in costs were offset, in part, by lower sales volumes.

Depreciation, depletion and amortization costs were $14 million for the three months ended March 31, 2013 compared to $15 million for the three months ended March 31, 2012. There was approximately $12 million, or $1.79 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, 2013. 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 $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, 2013. There was $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.

MARCELLUS GAS SEGMENT

The Marcellus segment contributed $14 million to the total Company earnings before income tax for the three months ended March 31, 2013 compared to $3 million for the three months ended March 31, 2012.

	For the Three Months Ended March 31,
	2013		2012		Variance			Percent Change
Produced Gas Marcellus sales volumes (in billion cubic feet)	10.7		6.7		4.0			59.7	%
Average Marcellus sales price per thousand cubic feet sold	$	4.53	$	3.54	$	0.99		28.0	%
Average Marcellus lifting costs per thousand cubic feet sold	0.46		0.59		(0.13		)	(22.0	)%
Average Marcellus ad valorem, severance, and other taxes per thousand cubic feet sold	0.13		0.13		—			—	%
Average Marcellus gathering costs per thousand cubic feet sold	0.84		0.59		0.25			42.4	%
Average Marcellus direct administrative, selling & other costs per thousand cubic feet sold	0.57		0.41		0.16			39.0	%
Average Marcellus depreciation, depletion and amortization costs per thousand cubic feet sold	1.24		1.34		(0.10		)	(7.5	)%
Total Average Marcellus costs per thousand cubic feet sold	3.24		3.06		0.18			5.9	%
Average Margin for Marcellus	$	1.29	$	0.48	$	0.81		168.8	%

The Marcellus segment sales revenues were $49 million for the three months ended March 31, 2013 compared to $24 million for the three months ended March 31, 2012. The $25 million increase is primarily due to a 59.7% increase in volumes sold, and a 28% increase in average sales prices in the period-to-period comparison. The increase in Marcellus average sales price was the result of the improvement in general market prices and sales of natural gas liquids, offset by various gas swap transactions that matured in the three months ended March 31, 2013. These gas swap transactions qualify as financial cash flow hedges that exist parallel to the underlying physical transactions. These financial hedges represented approximately 4.3 billion cubic feet of our produced Marcellus gas sales volumes for the three months ended March 31, 2013 at an average price of $4.75 per thousand cubic feet. For the three months ended March 31, 2012, these financial hedges represented 2.8 billion cubic feet at an average price of $4.98 per thousand cubic feet. The increase in sales volumes is primarily due to additional wells coming on-line from our on-going drilling program.

Marcellus lifting costs were $5 million for the three months ended March 31, 2013 compared to $4 million for the three months ended March 31, 2012. The increase primarily relates to an increase in salt water disposal costs. The increase was

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offset, in part, by decreases in well servicing costs, road maintenance costs, well tending costs and various other costs, none of which were individually material. The decrease in unit costs was due to higher sales volumes.

Marcellus ad valorem, severance and other taxes were $2 million for the three months ended March 31, 2013 compared to $1 million for the three months ended March 31, 2012. The increase relates to the increase in volumes sold, as the per-unit cost remained consistent for the 2013 and 2012 periods.

Marcellus gathering costs were $9 million for the three months ended March 31, 2013 compared to $4 million for the three months ended March 31, 2012. Average gathering costs increased $0.25 per unit primarily due to increased firm transportation costs, and increased processing fees associated with natural gas liquids.

Marcellus direct administrative, selling & other costs were $6 million for the three months ended March 31, 2013 compared to $3 million for the three months ended March 31, 2012. Direct administrative, selling & other costs attributable to the total gas segment are allocated to the individual gas segments based on a combination of production and employee counts. The increase in direct administrative, selling & other costs was primarily due to Marcellus volumes representing a larger proportion of total natural gas volumes. The impact on average unit costs from the increase in direct administrative labor was offset by higher volumes sold.

Depreciation, depletion and amortization costs were $13 million for the three months ended March 31, 2013 compared to $9 million for the three months ended March 31, 2012. There was approximately $12 million, or $1.21 per unit-of-production, of depreciation, depletion and amortization related to Marcellus gas and related well equipment that was reflected on a units-of-production method of depreciation in the three months ended March 31, 2013. 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 $1 million, or $0.03 per thousand cubic feet, of depreciation, depletion and amortization related to gathering and other equipment that was reflected on a straight line basis for the three months ended March 31, 2013. There was $1 million, or $0.14 per thousand cubic feet, of depreciation, depletion and amortization related to gathering and other equipment reflected on a straight line basis for the three months ended March 31, 2012.

OTHER GAS SEGMENT

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

Other gas sales volumes are primarily related to production from the Chattanooga Shale in Tennessee and the Utica Shale in Ohio. Revenue from these operations were approximately $3 million for the three months ended March 31, 2013 and 2012. Total costs related to these other sales were $4 million for the three months ended March 31, 2013 and $5 million for the three months ended March 31, 2012. A per unit analysis of the other operating costs in Chattanooga Shale and Utica Shale is not meaningful due to the low volumes produced in the period-to-period analysis.

Royalty interest gas sales represent the revenues related to the portion of production belonging to royalty interest owners sold by the CONSOL Energy gas segment. Royalty interest gas sales revenue was $14 million for the three months ended March 31, 2013 compared to $12 million for the three months ended March 31, 2012. The changes in market prices, contractual differences among leases, and the mix of average and index prices used in calculating royalties contributed to the period-to-period increase.

	For the Three Months Ended March 31,
	2013		2012		Variance			Percent Change
Gas Royalty Interest Sales Volumes (in billion cubic feet)	3.5		4.1		(0.6		)	(14.6	)%
Average Sales Price Per thousand cubic feet	$	4.10	$	2.96	$	1.14		38.5	%

Purchased gas sales volumes represent volumes of gas sold at market prices that were purchased from third-party producers. Purchased gas sales revenues were $1 million for the three months ended March 31, 2013 and 2012.

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	For the Three Months Ended March 31,
	2013		2012		Variance		Percent Change
Purchased Gas Sales Volumes (in billion cubic feet)	0.4		0.3		0.1		33.3	%
Average Sales Price Per thousand cubic feet	$	3.45	$	3.01	$	0.44	14.6	%

Other income was $14 million for the three months ended March 31, 2013 compared to $16 million for the three months ended March 31, 2012. The $2 million change was primarily due to a $4 million decrease of interest income related to the notes receivable from the Noble joint venture transaction due to the timing of collections, offset by a $2 million increase in equity in earnings of affiliates related to CONE Gathering LLC (CONE).

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 months ended March 31, 2013 and 2012. Refer to the discussion of total company general and administrative costs contained in the section "Net Income Attributable to CONSOL Energy Shareholders"of this quarterly report for a detailed cost explanation.

Royalty interest gas costs represent the costs related to the portion of production belonging to royalty interest owners sold by the CONSOL Energy gas segment. Royalty interest gas costs were $12 million for the three months ended March 31, 2013 compared to $10 million for the three months ended March 31, 2012. The changes in market prices, contractual differences among leases, and the mix of average and index prices used in calculating royalties contributed to the period-to-period change.

	For the Three Months Ended March 31,
	2013		2012		Variance			Percent Change
Gas Royalty Interest Sales Volumes (in billion cubic feet)	3.5		4.1		(0.6		)	(14.6	)%
Average Cost Per thousand cubic feet sold	$	3.41	$	2.49	$	0.92		36.9	%

Purchased gas volumes represent volumes of gas purchased from third-party producers that we sell. The higher average cost per thousand cubic feet is due to overall price changes and contractual differences among customers in the period-to-period comparison. Purchased gas costs were $1 million for the three months ended March 31, 2013 and 2012.

	For the Three Months Ended March 31,
	2013		2012		Variance		Percent Change
Purchased Gas Volumes (in billion cubic feet)	0.4		0.3		0.1		33.3	%
Average Cost Per thousand cubic feet sold	$	2.44	$	1.62	$	0.82	50.6	%

Exploration and other costs were $10 million for the three months ended March 31, 2013 compared to $5 million for the three months ended March 31, 2012. The $5 million increase is due to the following items:

	For the Three Months Ended March 31,
	2013		2012		Variance			Percent Change
Marcellus Title Defects	$	6	$	—	$	6		—	%
Lease Expiration Costs	1		1		—			—	%
Exploration	3		4		(1		)	(25.0	)%
Total Exploration and Other Costs	$	10	$	5	$	5		100.0	%

• As part of the title defect process the company is working through with its joint venture partner, Noble Energy, CONSOL Energy conceded title defects on acreage which had a book value to CONSOL Energy of $6 million.

• Lease expiration costs remained consistent in the period-to-period comparison.

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

Other corporate expenses were $25 million for the three months ended March 31, 2013 compared to $23 million for the three months ended March 31, 2012. The $2 million increase in the period-to-period comparison was made up of the following items:

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	For the Three Months Ended March 31,
	2013		2012		Variance			Percent Change
Unutilized Firm Transportation	$	7	$	2	$	5		250.0	%
Stock-based compensation	9		6		3			50.0	%
Bank Fees	2		2		—			—	%
Short Term Incentive Compensation	5		7		(2		)	(28.6	)%
PA Impact Fees	—		4		(4		)	(100.0	)%
Other	2		2		—			100.0	%
Total Other Corporate Expenses	$	25	$	23	$	2		8.7	%

• Unutilized firm transportation costs represent pipeline transportation capacity the gas segment has obtained to enable gas production to flow uninterrupted as sales volumes increase. The $5 million increase is due to increased firm transportation capacity which has not been utilized by active operations.

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

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

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

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

• Other corporate related expense remained consistent in the period to period comparison.

Interest expense related to the gas segment was $2 million for the three months ended March 31, 2013 compared to $1 million for the three months ended March 31, 2012. Interest was incurred by the gas segment on the CNX Gas revolving credit facility, a capital lease and debt that was held by a variable interest entity. The $1 million increase was primarily due to higher levels of borrowings on the revolving credit facility throughout the period-to-period comparison.

OTHER SEGMENT ANALYSIS for the three months ended March 31, 2013 compared to the three months ended March 31, 2012:

The other segment includes activity from the sales of industrial supplies, the transportation operations and various other corporate activities that are not allocated to the coal or gas segment. The other segment had a loss before income tax of $93 million for the three months ended March 31, 2013 compared to a loss before income tax of $56 million for the three months ended March 31, 2012. The other segment also includes total Company income tax expense of $1 million for the three months ended March 31, 2013 compared to $21 million for the three months ended March 31, 2012.

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	For the Three Months Ended March 31,
	2013			2012			Variance			Percent Change
Sales—Outside	$	86		$	97		$	(11	)	(11.3	)%
Other Income	6			4			2			50.0	%
Total Revenue	92			101			(9		)	(8.9	)%
Cost of Goods Sold and Other Charges	125			90			35			38.9	%
Depreciation, Depletion & Amortization	6			6			—			—	%
Taxes Other Than Income Tax	3			4			(1		)	(25.0	)%
Interest Expense	51			57			(6		)	(10.5	)%
Total Costs	185			157			28			17.8	%
Loss Before Income Tax	(93		)	(56		)	(37		)	(66.1	)%
Income Tax	1			21			(20		)	(95.2	)%
Net Loss	$	(94	)	$	(77	)	$	(17	)	22.1	%

Industrial supplies:

Total revenue from industrial supplies was $54 million for the three months ended March 31, 2013 compared to $69 million for the three months ended March 31, 2012. The decrease was primarily related to lower sales volumes.

Total costs related to industrial supply sales were $53 million for the three months ended March 31, 2013 compared to $68 million for the three months ended March 31, 2012. The decrease of $15 million was primarily related to lower sales volumes and various changes in inventory costs, none of which were individually material.

Transportation operations:

Total revenue from transportation operations was $34 million for the three months ended March 31, 2013 compared to $30 million for the three months ended March 31, 2012. The increase of $4 million was primarily attributable to higher per ton thru-put rates at the CNX Marine Terminal.

Total costs related to the transportation operations were $25 million for the three months ended March 31, 2013 compared to $21 million for the three months ended March 31, 2012. The increase was due to various items in both periods, none of which were individually material.

Miscellaneous other:

Additional other income of $4 million was recognized for the three months ended March 31, 2013 compared to $2 million for the three months ended March 31, 2012. The $2 million increase was primarily due to an increase in interest income.

Other corporate costs in the other segment include interest expense, CNX Gas shareholder settlement, bank fees, and various other miscellaneous corporate charges. Total other costs were $107 million for the three months ended March 31, 2013 compared to $68 million for the three months ended March 31, 2012. Other corporate costs increased due to the following items:

	For the Three Months Ended March 31,
	2013		2012		Variance
CNX Gas shareholder settlement	$	20	$	—	$	20
Pension Settlement	27		—		27
Bank fees	3		4		(1		)
Interest Expense	51		57		(6		)
Other	6		7		(1		)
	$	107	$	68	$	39

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

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settlement provides for a payment to the plaintiffs of $42.73 million, of which the Company expects to pay $20.20 million. This settlement is subject to court approval and to the execution of final agreements with the parties.

• Pension Settlement adjustment is the result of accounting rules requiring acceleration of unrecognized actuarial losses when lump sum payments from a plan exceed the annual projected service and interest costs of the plan. In the three months ended March 31, 2013, lump sum pension payments exceeded the threshold which required settlement recognition. Many of these lump sums were paid to individuals who elected to retire under the 2012 Voluntary Severance Incentive Program.

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

• Interest expense decreased $6 million primarily due to an increase in capitalized interest due to higher capital expenditures for major construction projects in the current period.

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

Income Taxes:

The effective income tax rate was negative 40.2% for the three months ended March 31, 2013 compared to 18.0% for the three months ended March 31, 2012. The effective rates for the three months ended March 31, 2013 and 2012 were calculated using the annual effective rate projection on recurring earnings and include tax liabilities related to certain discrete transactions. The relationship between pre-tax earnings and percentage depletion impacts the effective tax rate. See Note 5—Income Taxes of the Notes to the Condensed Consolidated Financial Statements of this Form 10-Q for additional information. 

	For the Three Months Ended March 31,
	2013			2012			Variance			Percent Change
Total Company Earnings Before Income Tax	$	(1	)	$	119		$	(120	)	(100.8	)%
Income Tax Expense	$	1		$	21		$	(20	)	(95.2	)%
Effective Income Tax Rate	(40.2		)%	18.0		%	(58.2		)%

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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 of borrowings and letters of credit. CONSOL Energy can request an additional $250 million increase in the aggregate borrowing limit amount. Fees and interest rate spreads are based on a ratio of financial covenant debt to twelve-month trailing earnings before interest, taxes, depreciation, depletion and amortization (EBITDA), measured quarterly. The facility includes a minimum interest coverage ratio covenant of no less than 2.50 to 1.00, measured quarterly. The interest coverage ratio is calculated as the ratio of EBITDA to cash interest expense of CONSOL Energy and certain of its subsidiaries. The interest coverage ratio was 4.42 to 1.00 at March 31, 2013. 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 leverage ratio is calculated as the ratio of financial covenant debt to twelve-month trailing EBITDA for CONSOL Energy and certain subsidiaries. Financial covenant debt is comprised of the outstanding indebtedness and specific letters of credit, less cash on hand, for CONSOL Energy and certain of its subsidiaries. EBITDA, as used in the covenant calculation, excludes non-cash compensation expenses, non-recurring transaction expenses, uncommon gains and losses, gains and losses on discontinued operations and includes cash distributions received from affiliates plus pro-rata earnings from material acquisitions. The leverage ratio was 2.86 to 1.00 at March 31, 2013. The facility also includes a senior secured leverage ratio covenant of no more than 2.00 to 1.00, measured quarterly. The senior secured leverage ratio is calculated as the ratio of secured debt to EBITDA. Secured debt is defined as the outstanding borrowings and letters of credit on the revolving credit facility. The senior secured leverage ratio was 0.09 to 1.00 at March 31, 2013. Covenants in the facility limit our ability to dispose of assets, make investments, purchase or redeem CONSOL Energy common stock, pay dividends, merge with another company and amend, modify or restate, in any material way, the senior unsecured notes. At March 31, 2013, the facility had no outstanding borrowings and $100 million of letters of credit outstanding, leaving $1.4 billion of unused capacity. From time to time, CONSOL Energy is required to post financial assurances to satisfy contractual and other requirements generated in the normal course of business. Some of these assurances are posted to comply with federal, state or other government agencies statutes and regulations. We sometimes use letters of credit to satisfy these requirements and these letters of credit reduce our borrowing facility capacity.

CONSOL Energy also has an accounts receivable securitization facility. This facility allows the Company to receive, on a revolving basis, up to $200 million of short-term funding and letters of credit. The accounts receivable facility supports sales, on a continuous basis to financial institutions, of eligible trade accounts receivable. CONSOL Energy has agreed to continue servicing the sold receivables for the financial institutions for a fee based upon market rates for similar services. The cost of funds is based on commercial paper rates plus a charge for administrative services paid to financial institutions. At March 31, 2013, eligible accounts receivable totaled approximately $199.8 million. At March 31, 2013, the facility had $30 million of outstanding borrowings and $159 million of letters of credit outstanding.

CNX Gas' $1.0 billion Senior Secured Credit Agreement expires April 12, 2016. The facility is secured by substantially all of the assets of CNX Gas and its subsidiaries. CNX Gas' credit facility allows for up to $1.0 billion for borrowings and letters of credit. CNX Gas can request an additional $250 million increase in the aggregate borrowing limit amount. Fees and interest rate spreads are based on the percentage of facility utilization, measured quarterly. The facility includes a minimum interest coverage ratio covenant of no less than 3.00 to 1.00, measured quarterly. The interest coverage ratio is calculated as the ratio of EBITDA to cash interest expense for CNX Gas and its subsidiaries. The interest coverage ratio was 42.09 to 1.00 at March 31, 2013. The facility also includes a maximum leverage ratio covenant of no more than 3.50 to 1.00, measured quarterly. The leverage ratio is calculated as the ratio of financial covenant debt to twelve-month trailing EBITDA for CNX Gas and its subsidiaries. Financial covenant debt is comprised of the outstanding indebtedness and letters of credit, less cash on hand, for CNX Gas and its subsidiaries. EBITDA, as used in the covenant calculation, excludes non-cash compensation expenses, non-recurring transaction expenses, gains and losses on the sale of assets, uncommon gains and losses, gains and losses on discontinued operations and includes cash distributions received from affiliates plus pro-rata earnings from material acquisitions. The leverage ratio was 0.56 to 1.00 at March 31, 2013. Covenants in the facility limit CNX Gas' ability to dispose of assets, make investments, pay dividends and merge with another company. The credit facility allows unlimited investments in joint ventures for the development and operation of gas gathering systems and provides for $600 million of loans, advances and dividends from CNX Gas to CONSOL Energy. Investments in the CONE are unrestricted. At March 31, 2013, 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 regularly

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

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

In order to manage the market risk exposure of volatile natural gas prices in the future, CONSOL Energy enters into various physical gas supply transactions with both gas marketers and end users for terms varying in length. CONSOL Energy has also entered into various gas swap transactions that qualify as financial cash flow hedges, which exist parallel to the underlying physical transactions. The fair value of these contracts was a net asset of $63 million at March 31, 2013. The ineffective portion of these contracts was insignificant to earnings in the three months ended March 31, 2013. No issues related to our hedge agreements have been encountered to date.

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

Cash Flows (in millions)

	For the Three Months Ended March 31,
	2013			2012			Change
Cash flows from operating activities	$	268		$	229		$	39
Cash used in investing activities	$	(232	)	$	(288	)	$	56
Cash used in financing activities	$	(34	)	$	(30	)	$	(4	)

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

• Operating cash flow decreased $99 million in 2013 due to lower net income in the period-to-period comparison.

• Operating cash flows increased $138 million due several non-cash items, such as the pension settlement, the CNX Gas shareholder settlement which was not paid as of March 31, 2013, stock-based compensation accelerated charges, the Noble title defects and other non-cash transactions which were added back to the net loss attributable to CNX Shareholders. Other changes in operating assets, operating liabilities, other assets and other liabilities which occurred throughout both years also contributed to the increase in operating cash flows.

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

• Capital expenditures increased $100 million in the period-to-period comparison due to:

◦ Coal segment capital expenditures increased $3 million. The increase was comprised of $28 million in longwall shield projects, offset, in part, by a decrease of $11 million for the Northern West Virginia RO system and $10 million for Ohio Valley overland belt project. Mineral lease expenditures associated with our advance mining royalties and leased coal assets decreased $4 million in 2013;

◦ Gas segment capital expenditures increased $109 million. The increase was comprised of $42 million in increased drilling in the Marcellus and Utica plays, $48 million related to CONSOL's agreement to lease oil and gas rights from the Allegheny County Airport Authority and $19 million in various other individually insignificant projects;

◦ Other capital expenditures decreased $12 million due to various miscellaneous transactions that occurred throughout both periods, none of which were individually material.

• Proceeds from the sale of assets increased $110 million in the period-to-period comparison due to:

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

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

◦ $28 million received in the first quarter of 2012 related to the 2012 sales of several non-core assets including previously mined surface properties and rights-of-way; and

◦ $3 million increase due to various other transactions that occurred throughout both periods, none of which were individually material.

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

• Distributions from/investments in equity affiliates decreased $2 million due to various miscellaneous transactions that occurred throughout both periods, none of which were individually material.

• The release of $48 million of restricted cash associated with the Ram River & Scurry Canadian asset proceeds received during December 2012.

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

• In 2013, CONSOL Energy repaid $25 million of borrowings related to a miscellaneous short term note payable.

• In 2013, CONSOL Energy repaid $8 million of borrowing on its Securitization Facility.

• The accelerated declaration and payment of the regular quarterly dividend in the fourth quarter of 2012 resulted in no dividends paid in the first quarter of 2013. As compared to $28 million in dividends paid in the first quarter of 2012.

• $1 million in additional cash used due to various other transactions that occurred throughout both periods, none of which were individually material.

The following is a summary of our significant contractual obligations at March 31, 2013 (in thousands):

	Payments due by Year
	Less Than 1 Year		1-3 Years		3-5 Years		More Than 5 Years		Total
Borrowings Under Securitization Facility	$	30,119	$	—	$	—	$	—	$	30,119
Purchase Order Firm Commitments	267,454		72,599		—		—		340,053
Gas Firm Transportation	82,059		154,987		128,338		414,276		779,660
Long-Term Debt	4,564		8,441		1,505,508		1,610,291		3,128,804
Interest on Long-Term Debt	245,448		491,341		431,064		358,916		1,526,769
Capital (Finance) Lease Obligations	8,789		13,926		11,052		23,321		57,088
Interest on Capital (Finance) Lease Obligations	3,798		5,918		4,260		3,249		17,225
Operating Lease Obligations	112,150		208,401		147,008		154,566		622,125
Long-Term Liabilities—Employee Related (a)	224,511		441,888		438,519		2,308,925		3,413,843
Other Long-Term Liabilities (b)	345,345		131,848		85,746		485,891		1,048,830
Total Contractual Obligations (c)	$	1,324,237	$	1,529,349	$	2,751,495	$	5,359,435	$	10,964,516

 _________________________

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

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

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

Debt

At March 31, 2013, CONSOL Energy had total long-term debt and capital lease obligations of $3.186 billion outstanding, including the current portion of long-term debt of $13 million. This long-term debt consisted of:

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

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

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

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

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

• An aggregate principal amount of $6million on other various rate notes maturing through June 2031.

• An aggregate principal amount of $57million of capital leases with a weighted average interest rate of 6.37% per annum.

At March 31, 2013, CONSOL Energy also had no outstanding borrowings and had approximately $100 million of letters of credit outstanding under the $1.5 billion senior secured revolving credit facility.

At March 31, 2013, CONSOL Energy had $30 million in outstanding borrowings and had $159 million of letters of credit outstanding under the accounts receivable securitization facility.

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

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

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

The declaration and payment of dividends by CONSOL Energy is subject to the discretion of CONSOL Energy’s Board of Directors, and no assurance can be given that CONSOL Energy will pay dividends in the future. CONSOL Energy’s Board of Directors determines whether dividends will be paid quarterly. The determination to pay dividends will depend upon, among other things, general business conditions, CONSOL Energy’s financial results, contractual and legal restrictions regarding the payment of dividends by CONSOL Energy, planned investments by CONSOL Energy and such other factors as the Board of Directors deems relevant. Our credit facility limits our ability to pay dividends in excess of an annual rate of $0.40 per share when our leverage ratio exceeds 4.50 to 1.00 or our availability is less than or equal to $100 million. The leverage ratio was 2.86 to 1.00 and our availability was approximately $1.4 billion at March 31, 2013. The credit facility does not permit dividend payments in the event of default. The indentures to the 2017, 2020 and 2021 notes limit dividends to $0.40 per share annually unless several conditions are met. Conditions include no defaults, ability to incur additional debt and other payment limitations under the indentures. There were no defaults in the three months ended March 31, 2013.

Off-Balance Sheet Transactions

CONSOL Energy does not maintain off-balance sheet transactions, arrangements, obligations or other relationships with unconsolidated entities or others that are reasonably likely to have a material current or future effect on CONSOL Energy’s financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources which are not disclosed in the Notes to the Unaudited Consolidated Financial Statements. CONSOL Energy participates in various multi-employer benefit plans such as the UMWA 1974 Pension Plan, the UMWA Combined Benefit Fund and the UMWA 1993 Benefit Plan which generally accepted accounting principles recognize on a pay as you go basis. These benefit arrangements may result in additional liabilities that are not recognized on the balance sheet at March 31, 2013.

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The various multi-employer benefit plans are discussed in Note 17—Other Employee Benefit Plans in the Notes to the Audited Consolidated Financial Statements in Item 8 of the December 31, 2012 Form 10-K. CONSOL Energy also uses a combination of surety bonds, corporate guarantees and letters of credit to secure our financial obligations for employee-related, environmental, performance and various other items which are not reflected on the balance sheet at March 31, 2013. Management believes these items will expire without being funded. See Note 11—Commitments and Contingencies in the Notes to the Unaudited Consolidated Financial Statements included in Item 1 of this Form 10-Q for additional details of the various financial guarantees that have been issued by CONSOL Energy.

Recent Accounting Pronouncements

In February 2013, the Financial Accounting Standards Board issued Update 2013-04 - Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date. The objective of the amendments in this update is to provide guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of this guidance is fixed at the reporting date, except for obligations addressed within existing guidance in U.S. generally accepted accounting principles (GAAP). The guidance in this update requires an entity to measure obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of this guidance is fixed at the reporting date, as the sum of the following: a.) The amount the reporting entity agreed to pay on the basis of its arrangement amount with its co-obligors, and b.) Any additional amount the reporting entity expects to pay on behalf of its co-obligors. The guidance in this update also requires an entity to disclose the nature and amount of the obligation as well as other information about those obligations. The amendments in this update are effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The amendments in this update should be applied retrospectively to all prior periods presented for those obligations resulting from joint and several liability arrangements within the update's scope that exist at the beginning of an entity's fiscal year of adoption. We believe adoption of this new guidance will not have a material impact on CONSOL Energy's financial statements.

Forward-Looking Statements

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

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

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

• 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;

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

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

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

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

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

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

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

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

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

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

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

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

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

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

• the impacts of various asbestos litigation claims;

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

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

• exposure to multi-employer pension plan liabilities;

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

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

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

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

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

• risks associated with our debt;

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

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

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

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

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

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

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

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

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

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

A sensitivity analysis has been performed to determine the incremental effect on future earnings, related to open derivative instruments at March 31, 2013. A hypothetical 10 percent decrease in future natural gas prices would increase future earnings related to derivatives by $23.5 million. Similarly, a hypothetical 10 percent increase in future natural gas prices would decrease future earnings related to derivatives by $23.5 million.

CONSOL Energy’s primary exposure to market risk for changes in interest rates relates to our revolving credit facility, under which there were no borrowings outstanding at March 31, 2013. Also, CNX Gas had no borrowings under its revolving credit facility at March 31, 2013.

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 13, 2013 our hedged volumes for the periods indicated are as follows:

	For the Three Months Ended
	March 31,		June 30,		September 30,		December 31,		Total Year
2013 Fixed Price Volumes
Hedged Mcf	16,675,170		19,834,675		21,531,447		21,531,447		79,572,739
Weighted Average Hedge Price/Mcf	$	4.77	$	4.69	$	4.67	$	4.67	$	4.69
2014 Fixed Price Volumes
Hedged Mcf	15,007,908		15,174,663		15,341,417		15,341,417		60,865,406
Weighted Average Hedge Price/Mcf	$	4.96	$	4.96	$	4.96	$	4.96	$	4.96
2015 Fixed Price Volumes
Hedged Mcf	10,597,403		10,715,152		10,832,900		10,832,900		42,978,355
Weighted Average Hedge Price/Mcf	$	4.24	$	4.24	$	4.24	$	4.24	$	4.24
2016 Fixed Price Volumes
Hedged Mcf	866,667		866,667		876,190		876,190		3,485,714
Weighted Average Hedge Price/Mcf	$	4.45	$	4.45	$	4.45	$	4.45	$	4.45

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ITEM 4. CONTROLS AND PROCEDURES

Disclosure controls and procedures. CONSOL Energy, under the supervision and with the participation of its management, including CONSOL Energy’s principal executive officer and principal financial officer, evaluated the effectiveness of the Company’s “disclosure controls and procedures,” as such term is defined in Rule 13a-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), as of the end of the period covered by this Quarterly Report on Form 10-Q. Based on that evaluation, CONSOL Energy’s principal executive officer and principal financial officer have concluded that the Company’s disclosure controls and procedures are effective as of March 31, 2013 to ensure that information required to be disclosed by CONSOL Energy in reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms, and includes controls and procedures designed to ensure that information required to be disclosed by CONSOL Energy in such reports is accumulated and communicated to CONSOL Energy’s management, including CONSOL Energy’s principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

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

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PART II

OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

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

ITEM 4.     MINE SAFETY DISCLOSURES

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

ITEM 6. EXHIBITS

10.1	Amendment No. 2 to Credit Agreement, dated as of March 12, 2013, to the Amended and Restated Credit Agreement, dated as of April 12, 2011, as amended by Amendment No. 1, dated December 14, 2011, by and among CNX Gas Corporation, the lenders and agents party thereto and PNC Bank, National Association, as administrative agent.
10.2	Form of CONSOL Energy Inc. Stock Unit Award Agreement under the Equity Incentive Plan.
10.3	Retirement Letter, dated January 29, 2013, by and between CONSOL Energy Inc. and P. Jerome Richey.
10.4	Retirement and Consulting Agreement, dated February 28, 2013, by and between CONSOL Energy Inc. and William J. Lyons.
10.5	Retirement and Consulting Agreement, dated February 20, 2013, by and between CONSOL Energy Inc. and Robert F. Pusateri.
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, 2013 furnished in XBRL).

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

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SIGNATURES

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

Dated: May 7, 2013

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

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EX-10.1

AMENDMENT NO. 2 TOCREDIT AGREEMENT

AMENDMENT NO. 2, dated as of March 12, 2013 (this “Amendment”), to the Amended and Restated Credit Agreement, dated as of April 12, 2011 as amended by Amendment No. 1 dated December 14, 2011 (the “Credit Agreement”), by and among CNX Gas Corporation (the “Borrower”), the lenders and agents party thereto and PNC Bank, National Association, as administrative agent (the “Administrative Agent”). Capitalized terms used but not defined herein shall have the meanings given them in the Credit Agreement.

WITNESSETH

WHEREAS, the Borrower has requested the amendments to the Credit Agreement set forth herein.

NOW, THEREFORE, the parties hereto, in consideration of the mutual covenants and agreements herein contained and intending to be legally bound hereby, covenant and agree as follows:

1.Amendments.

(a)The following defined term shall be added to Section 1.1 of the Credit Agreement:

“Greenshale Obligations” shall mean the obligations of Greenshale Energy, LLC (a Joint Venture) and its wholly-owned Subsidiaries, under, or in connection with, the acquisition or performance of any Joint Operating or Development Agreement, or the bidding for, or performance of, any, permit, license or similar authorization or petroleum agreement relating to the exploration, drilling, development or production of Hydrocarbon Interests.

(b)Guaranties. Section 8.2.3 of the Agreement is hereby amended by adding the following before the period:

“ ; and

(g)    any Guaranty by any Loan Party in the form of a performance guaranty in respect of the Greenshale Obligations; provided that (i) the Guaranty shall be required in the ordinary course of business of Greenshale Energy, LLC and (ii) in no event shall any such Guaranty be secured by any Collateral”.

(c)Loans and Investments. Clause (d) of Section 8.2.4 is hereby amended by replacing the “$25,000,000” in clause (ii) with “$100,000,000”.

(d)Loans and Investments. Clause (i) of Section 8.2.4 is hereby amended and restated as follows:

“(i)    any Guaranty permitted by clause (a) or (g) of Section 8.2.3 [Guaranties];”.

2.Condition Precedent. This Amendment shall be effective upon completion of each of the following conditions to the satisfaction of the Administrative Agent:

(a)Execution and Delivery of Amendment. The Borrower shall have executed this Amendment, and the Administrative Agent shall have received consent from the Required Lenders to execute and shall have executed this Amendment.

(b)Fees. The Borrower shall have paid all reasonable legal fees and expenses of counsel to the Administrative Agent for the preparation and execution of this Amendment.

(c)Representations and Warranties. After giving effect to this Amendment, the representations and warranties in the Loan Documents are true and correct in all material respects (except where such representations and warranties expressly relate to an earlier date, in which case such representations and warranties shall have been true and correct in all material respects as of such earlier date).

(d)No Default. After giving effect to this Amendment, no Default or Event of Default has occurred and is continuing.

3.Full Force and Effect. Except as expressly modified by this Amendment, all of the terms, conditions, representations, warranties and covenants contained in the Loan Documents shall continue in full force and effect, including without limitation, all liens and security interests granted pursuant to the Loan Documents. This Amendment shall constitute a Loan Document for purposes of the Credit Agreement on and after the effectiveness of this Amendment and all references to the Credit Agreement in any Loan Document and all references in the Credit Agreement to “this Agreement,” “hereunder,” “hereof” or words of like import referring to the Credit Agreement, shall, unless expressly provided otherwise, shall mean and be a reference to the Credit Agreement, as amended by this Amendment.

4.Counterparts. This Amendment may be executed by different parties hereto in any number of separate counterparts, each of which, when so executed and delivered shall be an original and all such counterparts shall together constitute one and the same instrument.

5.Severability. If any term of this Amendment or any application thereof shall be held to be invalid, illegal or unenforceable, the validity of other terms of this Amendment or any other application of such term shall in no way be affected thereby.

6.Entire Agreement. This Amendment sets forth the entire agreement and understanding of the parties with respect to the amendments to the Credit Agreement contemplated hereby and supersedes all prior understandings and agreements, whether written or oral, between the parties hereto relating to such amendments. No representation, promise, inducement or statement of intention has been made by any party that is not embodied in this Amendment, and no party shall be bound by or liable for any alleged representation, promise, inducement or statement of intention not set forth herein.

7.Governing Law. This Agreement shall be deemed to be a contract under the Laws of the State of New York without regard to its conflict of laws principles.

[SIGNATURES APPEAR ON FOLLOWING PAGES]

IN WITNESS WHEREOF, the parties hereto, by their officers thereunto duly authorized, have executed this Amendment as of the day and year first above written.

CNX GAS CORPORATION

By: /s/ John M. Reilly    

Name:    John M. Reilly

Title:    Treasurer

PNC BANK, NATIONAL ASSOCIATION,as Administrative Agent

By: /s/ Richard C. Munsick    

Name:    Richard C. Munsick

Title:    Senior Vice President

BANK OF AMERICA, N.A., as a Lender

By: /s/ Adam H. Fey                Name:    Adam H. Fey
Title:    Director

Bank of Montreal, Chicago Branch, as a Lender

By: /s/ Yacouba Kane                Name:    Yacouba Kane
Title:    Vice President

For any institution requiring

a second signatory: By:    Name:    
Title:

The Bank of Nova Scotia, as a Lender

By: /s/ Thane Rattew                Name:    Thane Rattew
Title:    Managing Director

For any institution requiring

a second signatory: By:    Name:    
Title:

The Bank of Tokyo-Mitsubishi UFJ, Ltd., as a Lender

By: /s/ Andrew Oram                Name:    Andrew Oram
Title:    Managing Director

BOKF NA, dba BANK OF OKLAHOMA, as a Lender

By: /s/ Eric Griffin                Name:    Eric Griffin
Title:    Assistant Vice President

For any institution requiring

a second signatory: By:    Name:    
Title:

Branch Banking and Trust Company, as a Lender

By: /s/ James Giordano                Name:    James Giordano
Title:    Vice President

CAPITAL ONE, N.A., as a Lender

By: /s/ Nancy Mak                    Name:    Nancy Mak
Title:    Senior Vice President

CIBC Inc., as a Lender

By: /s/ Trudy Nelson                Name:    Trudy Nelson
Title:    Authorized Signatory

By:    /s/ Richard Antl                    Name:    Richard Antl
Title:    Authorized Signatory

COMERICA BANK, as a Lender

By: /s/ John S. Lesikar                Name:    John S. Lesikar
Title:    Vice President

For any institution requiring

a second signatory: By:    Name:    
Title:

BBVA Compass (“Compass Bank”), as a Lender

By: /s/ James Neblett                Name:    James Neblett
Title:    Vice President

COMMONWEALTH BANK OF AUSTRALIA, as a Lender

By: /s/ Ajay Lele                    Name:    Ajay Lele
Title:    Associate Vice President,

Natural Resources, Americas

For any institution requiring

a second signatory: By:    Name:    
Title:

CREDIT AGRICOLE CORPORATE AND INVESTMENT BANK, as a Lender

By: /s/ Blake Wright                Name:    Blake Wright
Title:    Managing Director

By:    /s/ Mike McIntyre                Name:    Mike McIntyre
Title:    Director

Fifth Third Bank, as a Lender

By: /s/ Martin H. McGinty                Name:    Martin H. McGinty
Title:    Vice President

For any institution requiring

a second signatory: By:    Name:    
Title:

First National Bank of Pennsylvania, as a Lender

By: /s/ Jonathan D. Kowalski            Name:    Jonathan D. Kowalski
Title:    Vice President

For any institution requiring

a second signatory: By:    Name:    
Title:

GOLDMAN SACHS BANK USA, as a Lender

By: /s/ Michelle Latzoni                Name:    Michelle Latzoni
Title:    Authorized Signatory

For any institution requiring

a second signatory: By:    Name:    
Title:

JPMorgan Chase Bank, N.A., as a Lender

By: /s/ Ryan Aman                    Name:    Ryan Aman
Title:    Authorized Officer

Natixis, as a Lender

By: /s/ Carlos Quinteros                Name:    Carlos Quinteros
Title:    Managing Director

By:    /s/ Timothy L. Polvado                Name:    Timothy L. Polvado
Title:    Managing Director

The Royal Bank of Scotland plc, as a Lender

By: /s/ David Slye                    Name:    David Slye
Title:    Authorised Signatory

TriState Capital Bank, as a Lender

By: /s/ Paul J. Oris                    Name:    Paul J. Oris
Title:    Senior Vice President

For any institution requiring

a second signatory: By:    Name:    
Title:

PNC Bank, N.A., as a Lender

By: /s/ Patrick J. Kerr                Name:    Patrick J. Kerr
Title:    Senior Vice President

For any institution requiring

a second signatory: By:    Name:    
Title:

Sovereign Bank, N.A., as a Lender

By: /s/ Robert D. Lanigan                Name:    Robert D. Lanigan
Title:    Senior Vice President

THE HUNTINGTON NATIONAL BANK, as a Lender

By: /s/ Joshua D. Elsea                Name:    Joshua D. Elsea
Title:    Vice President, Commercial Banking

TD Bank, N.A., as a Lender

By: /s/ Marla Willner                Name:    Marla Willner
Title:    Senior Vice President

For any institution requiring

a second signatory: By:    Name:    
Title:

UNION BANK, N.A., as a Lender

By: /s/ Bradley Kraus                Name:    Bradley Kraus
Title:    IBO

U.S. BANK NATIONAL ASSOCIATION, as a Lender

By: /s/ Daniel K. Hansen                Name:    Daniel K. Hansen
Title:    Vice President

Wells Fargo Bank, N.A., as a Lender

By: /s/ Suzanne Ridenhour                Name:    Suzanne Ridenhour
Title:    Director

For any institution requiring

a second signatory: By:    Name:    
Title:

CG&R Draft        US_ACTIVE-112049718.1-JSLAWLOR 04/22/2013 3:21 PM

EX-10.2

CONSOL ENERGY INC.

EQUITY INCENTIVE PLAN

CONSOL STOCK UNIT AWARD AGREEMENT

This CONSOL Stock 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.CONSOL Stock 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 grants a Performance Award to the Participant in the form of CONSOL stock units (the “Stock Units”) with the target number set forth on Exhibit A. Each Stock 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 Stock Unit is earned and becomes payable pursuant to the terms of this Agreement. Notwithstanding, Stock 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 Stock Units. Subject to the provisions of this Agreement, the total number of Stock Units awarded to Participant will be earned (at a maximum award level of 150% of the target number of Stock Units awarded), if the performance measures set by and on file with the Committee are satisfied (each, a “Performance Goal”); provided, however, that the Committee has sole discretion to determine whether the Performance Goals are met and the date of such determination shall be the vesting date of the Award (the “Vesting Date”) and provided, further, that the Award will only become payable, except as otherwise provided herein, if the Participant remains an employee of the Company and its subsidiaries through the Vesting Date. As a condition to receiving this Award, Participant agrees that all determinations made by the Committee are final and conclusive.

4.Issuance and Distribution.

4.1After the end of the Performance Period and prior to the commencement of the payment of Shares relating to the Award, the Committee shall certify in writing the extent to which the

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Performance Goals 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, Stock Units earned by the Participant will be settled and paid in Shares 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, subject to Participant’s satisfaction of all applicable income and employment withholding taxes (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 Stock 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, Stock Units may, in the Committee’s discretion,be settled in cash and/or securities or other property.

5.Dividends. Each Stock 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 Stock 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 is eligible for an “Incapacity Retirement” or has reached the age of 62 by reason of a “Normal Retirement,” (ii) on account of death or Disability (other than an Incapacity Retirement), or (iii) by reason of a reduction in force as specified and implemented by the Company, prior to any Payment Date or the CiC Payment Date, as applicable, the Participant shall be entitled to retain the Stock 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 Stock 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 any Payment Date or the CiC Payment Date, as applicable, the Stock 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, and except as provided above regarding age, 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 “Early Retirement” unless the Participant shall also have completed at least one year of continuous service with the Company after the Grant Date.    

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7.Tax Consequences/Withholding.

7.1It is intended that: (i) the Participant’s Stock Units shall be considered to be subject to a substantial risk of forfeiture in accordance with those terms as defined in Sections 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.

7.2Participant acknowledges that any income for federal, state or local income tax purposes, including payroll taxes, that the Participant is required to recognize on account of the vesting of the Stock Units and/or issuance of the Shares under this Award to Participant shall be subject to withholding of tax by the Company. In accordance with administrative procedures established by the Company, Participant may elect to satisfy Participant’s minimum statutory withholding tax obligations, if any, on account of the vesting of the Stock Units and/or issuance of Shares under this Award, in one or a combination of the following methods: in cash or by separate check made payable to the Company and/or by authorizing the Company to withhold from the Shares to be issued to the Participant a sufficient number of whole Shares distributable in connection with this Award equal to the applicable minimum statutory withholding tax obligation.

7.3This Agreement is intended to comply with, or 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 the Award of Stock 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

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nature of the business of the Company and its Affiliates and accordingly agrees that during the term of 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

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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 Participant or the Participant’s employees, partners or agents. The Participant agrees that such right to an injunction is cumulative, in addition to whatever other remedies the Company (including any Affiliate) may have under law or equity and to the Participant’s 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 Stock 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 Stock 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 Stock 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

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attempt by the Participant to Transfer the Stock Units in violation of the terms of this Agreement shall render the Stock Units null and void, and result in the immediate forfeiture of such Stock 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, the Stock Units and the Shares on which the Performance Goals are based shall be adjusted by adding thereto the number of Shares which would have been distributable thereon if such shares and Stock Units had been actual 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 Stock Units, the Shares relating to the Stock 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 Stock Units constituting the 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 Stock Unit constituting the Award, the number and kind of shares of stock or other securities (or cash or other property) into which each outstanding Share shall be so changed or for which each such Share shall be exchangeable, and (iii) the Share 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 Stock 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).

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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 Stock 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]

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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: ________ __, 2013                                             [Insert name]

CONSOL ENERGY INC.

Dated: ________ __, 2013                                            William Powell, on behalf of the
                     Compensation Committee

Exhibit A

Participant:    

Grant Date:    

Stock Units (Target):

Performance Period:        [3 Years]

EX-10.3

January 29, 2013

CONSOL Energy Inc.

CNX Center

1000 Consol Energy Drive

Canonsburg, PA 15317-6506

phone:	724-485-4018
fax:	724-485-4849
e-mail:	brettharvey@consolenergy.com
web:	www.consolenergy.com

J. BRETT HARVEY

Chairman of the Board
Chief Executive Officer

VIA HAND DELIVERY

Dear Mr. Richey:

As discussed, in connection with your retirement from CONSOL Energy Inc. (the “Company”), your employment with the Company will terminate effective as of March 1, 2013. In recognition of your service to the Company, the Company is offering you the following separation benefit:

• Separation payment. The Company is offering to pay you $772,000.00, minus applicable withholdings and deductions. This includes any amounts you would be eligible to receive under the CONSOL Energy Inc. Severance Pay Plan for Salaried Employees and/or under the Employment Letter. Your separation payment will be paid on the first regularly scheduled Company payday after this agreement becomes effective.

The above payment is expressly conditioned on your execution (without revocation) of this letter agreement. You are not otherwise entitled to receive this payment, unless you sign (and do not revoke) this agreement.

The Company advises you to consult with an attorney of your choice regarding this agreement, which includes an offer of consideration in exchange for a release of claims. You have 21 days from January 29, 2013 to review and consider its terms. Even after signing this agreement, you have 7 days after signing it to revoke it, if you change your mind.

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Regardless of whether you sign this agreement, to the extent you have unused vacation time for 2013 or accrued vacation time for 2014 as of your last day of work, you will be paid for such amounts in a lump sum (minus applicable withholdings and deductions) pursuant to the CONSOL Energy Inc. Vacation Policy. If you are covered under group medical, dental, or vision healthcare plans sponsored by the Company or its affiliates, you will receive information under separate cover regarding any rights you may have to continue such coverage under applicable law.

By signing and not revoking this agreement, you agree that the Offer Letter (the “Offer Letter”) between you and the Company dated February 11, 2005, is terminated and of no force and effect, and you release CONSOL Energy Inc., and all of its affiliated companies (collectively, the "CONSOL Companies") and all of their current and former directors, officers, agents, and employees, from any and all claims you have or might have against them as the result of events that occurred on or before the date this agreement is executed by you, except for the rights described in the next paragraph. Your released claims include, without limitation, all claims relating in any way to your employment with the CONSOL Companies; the termination of your employment; and any cause of action or claim you have or might have for an alleged violation of any express or implied contract, or federal or state law, including (without limitation) the Employee Retirement Income Security Act of 1974, Title VII of the Civil Rights Act of 1964, the Age Discrimination in Employment Act of 1967 (“ADEA”), the Americans with Disabilities Act, the Family and Medical Leave Act, Sarbanes Oxley, the WARN Act, the Pennsylvania Human Relations Act (“PHRA”), the Pennsylvania Wage Payment and Collection Law, and any other state, federal or local law, rule or regulation. Your released claims also include any claim you have or might have for payment under the CONSOL Energy Inc. Severance Pay Plan for Salaried Employees or the Offer Letter, other than the payment stated in this letter agreement. If any administrative agency or court assumes jurisdiction over any charge, complaint, proceeding or action involving claims released in this agreement, you agree that you will not accept, recover, or receive any monetary damages or other relief from or in connection with that charge, complaint, or proceeding.You agree that if a court of competent jurisdiction determines that you are to be awarded damages under the WARN Act or any other federal or state law, those damages would be offset by an amount equal to payment under this agreement minus $500.

You have certain rights that are not released by signing this agreement. The foregoing release does not affect the following: any rights or claims that may arise after the date this agreement is executed; your right to enforce the Company's obligations under this agreement; any rights you may have to vested Company pension or retirement benefits that you are entitled to on March 1, 2013; any rights you may otherwise have relative to nonqualified stock options, restricted stock units, and performance share units; your rights under any Indemnification Agreement with the Company or CNX Gas Corporation; your rights under the Company’s agreement with Ayco; your right to file a charge or complaint with any appropriate federal, state, or local agency, such as the United States Equal Employment Opportunity Commission; your right to participate in or cooperate with any such charge or complaint procedure; your right to challenge the validity of this agreement as applied to claims under the ADEA; and any right that cannot be waived as a matter of law. Any other claim you have or might have is, however, released by this agreement.

If you have any questions regarding the scope of your release, including those rights that are not released, the Company advises you to address that subject with your own attorney before signing this agreement.

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Further, you acknowledge that this is an amicable arrangement and will be portrayed as such in all public statements, whether written or oral, by executive management of the Company, and by you. As such, executive management of the Company will not disparage you, and you will not disparage them or the Company. Additionally, you will cooperate with the Company in any future matters relating to your past employment. You agree to be reasonably available to the CONSOL Companies for the purpose of responding to requests for information, to provide information, documents, declarations or statements, to meet with attorneys and other Company representatives, to prepare for and give testimony by deposition or otherwise, and to cooperate in the investigation, defense or prosecution of matters relating to any threatened, present, or future legal actions, investigations or administrative proceedings involving the CONSOL Companies. The Company will advance or reimburse your reasonable costs incurred as a result of these obligations.

If all of the above terms are agreeable to you, please sign the enclosed copy of this letter and return it to me for our files. Please direct any questions to Steve Johnson at (724) 485-4163. We appreciate your service to the Company, and wish you all the best in the future.

Sincerely,

/s/ J. Brett Harvey

J. Brett Harvey

I KNOWINGLY AND VOLUNTARILY AGREE TO THE ABOVE TERMS THIS 29^th DAY OF January, 2013, INTENDING TO BE LEGALLY BOUND.

/s/ P. Jerome Richey    

P. Jerome Richey

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EX-10.4

RETIREMENT AND CONSULTING
AGREEMENT

This Retirement and Consulting Agreement (“Agreement) is entered into by William Lyons (“Consultant”) and CONSOL Energy Inc. (the “Company”) as of the 28^th day of February, 2013.

Background.

Consultant is currently employed by the Company as its Executive Vice President and Chief Financial Officer; and

Consultant has elected to retire and is terminating his employment relationship with the Company effective as of February 28, 2013;

Following such retirement, Company has offered to retain Consultant to provide certain consulting services to the Company pursuant to an independent contractor consulting relationship, under the terms and conditions stated below.

Agreement.

NOW THEREFORE, in consideration of the mutual promises set forth below, the Company and Consultant, intending to be legally bound, hereby agree as follows:

1.    Retention as a Consultant. The parties agree that, effective as of February 28, 2013, Consultant’s employment with the Company will be terminated and thereafter Consultant shall be retained by the Company on an independent contractor basis to provide consulting services as needed until December 31, 2013 (“Consulting Period”). During the Consulting Period, Consultant will report directly to J. Brett Harvey, the Chairman and Chief Executive Officer of the Company.

2.    Consulting Services. Consultant agrees to make himself available on reasonable notice to provide such services as are within Consultant’s areas of expertise and of a type commensurate with Consultant’s former position with the Company as may from time to time be requested by Mr. Harvey or his designee. It is anticipated that Consultant will provide services at a level not to exceed 60 hours per month. Consultant is not obligated to report to Company for assignment unless specifically requested by Company. To the extent possible, the consulting services will be provided using telephone and home computer. Consultant agrees to meet any reasonable deadline applicable to any assignment. Consultant agrees to perform the services for each assignment personally, in accordance with all applicable laws and ordinary business custom.

3.    Fees for Consulting Services. The Company agrees to make monthly payments to Consultant in arrears in an amount equal to $47,478.33, which shall be payable on the first day of each month during the Consulting Period, starting on April 1, 2013. The Company will also provide Consultant with a complimentary parking pass for the underground garage at CNX Center during the Consulting Period. Consultant will not be provided with any additional

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compensation or benefits for the services referenced in paragraph 2, regardless of the frequency or duration of assignments made during the Consulting Period. In the event the Agreement is terminated by the Consultant, is terminated by the Company for Cause (as defined below), or the Consultant dies or is disabled to the point that he can no longer provide the consulting services referred to in Section 2, the Company shall only pay the monthly payment for services through the end of the month in which termination occurs. In the event that the Company terminates the Agreement other than for Cause, the Company shall pay the monthly payment applicable to the entire Term of the Agreement. For purposes of this Agreement, “Cause” means material breach of this Agreement or gross misconduct by the Consultant.

4.    Independent Contractor Status. During the Consulting Period, it is understood and agreed that all services which Consultant performs for the Company shall be as an independent contractor and not as an employee. Company shall have no right to control or direct the details, manner or means by which Consultant accomplishes his consulting services. Nothing herein shall be deemed to create an employer-employee relationship. Consultant understands and acknowledges that the Company will not withhold income taxes from the fees to be paid to Consultant, and it will not pay FICA, FUTA or unemployment taxes on Consultant’s behalf, nor will Consultant be eligible for workers' compensation and state and federal unemployment compensation benefits. Consultant is solely responsible for the payment of federal self-employment and all other federal, state and local taxes and agrees to indemnify, defend and hold harmless the Company from any liability attributable to his/her failure to make full and timely payment of any taxes.

5.    Benefits. Except as otherwise eligible under Company-provided retirement plans due to employment prior to the Consulting Period, Consultant shall not, as a provider of the consulting services under this Agreement, be eligible for any Company-paid benefits, including, but not limited to, pension, medical, disability, or other insurance, vacation, holiday or sick pay or any other compensation or consideration commonly known as fringe benefits.

6.    Expenses. Consultant shall be responsible for any and all expenses incurred in connection with services rendered under this Agreement, unless reimbursement is expressly agreed to in writing by Mr. Harvey or his designee before the expense is incurred, and Consultant provides the Company with such supporting documentation as may be requested.

7.    No Authority to Bind The Company. During the Consulting Period, Consultant agrees that he will not hold himself out as an employee or agent of the Company, and understands and agrees that he has no authority to bind, obligate or contract on behalf of the Company. Nor will the Company be liable for any acts of the Consultant during the Consulting Period that cause damages to any third party.

8.    Indemnification. Consultant agrees to indemnify, defend, and hold harmless the Company, its shareholders, directors and employees, from any and all liability (including costs of defense) upon claims asserted by third parties, including employees of the Company, arising out of Consultant’s performance of services under this Agreement. Consultant acknowledges that his/her actions or omissions may not be covered by the Company’s insurance policies and that it shall be the responsibility of Consultant to obtain any desired liability insurance protection.

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9.    Term. This Agreement shall terminate on December 31, 2013.

10.    Termination. The results of the Consultant’s services shall be subject to the Company’s review and approval. Notwithstanding Sections 1 and 9 of the Agreement, each party shall have the right to terminate this Agreement for any reason on 30 days prior written notice to the other party. The Company may terminate this Agreement immediately for Cause, and this Agreement shall terminate immediately if the Consultant dies or becomes disabled. Termination of this Agreement by any party shall not terminate Sections 12, 13, and 16.

11.    Services to Other Entities. The parties agree that Consultant may provide services to other entities for compensation during the Consulting Period, so long as such services do not create a conflict of interest and do not interfere with Consultant’s availability to provide services under this Agreement.

12.    Non-use/Non-disclosure of Confidential Information. Consultant acknowledges that he may be provided with confidential information about the Company or its customers in the course of performance under this Agreement. Consultant agrees that, during and after the Consulting Period, he will not disclose such information to any person who is not an employee of the Company having a business need to know such information and that he will not use such information for his own benefit. Confidential Information, as used herein, means information about the Company, its finances, costs, prices, marketing strategies or plans, opportunities, business plans, key employees, customers, or processes, that is not generally known outside of the Company, is considered and treated as confidential by the Company, and the disclosure of which would be detrimental to the Company or beneficial to a competitor. To the extent that Consultant is provided with, or has in his possession, documents (including electronically stored information) containing Confidential Information, he agrees to return such information to the Company and not to retain any reproductions or copies thereof within his custody or control.

13.    Release. By signing and not revoking this Agreement, Consultant releases CONSOL Energy Inc., CNX Gas Corporation, and all of their affiliated companies (collectively, the "CONSOL Companies") and all of their current and former directors, officers, agents, and employees, from any and all claims Consultant has or might have against them as the result of events that occurred on or before the date this Agreement is executed by Consultant, except for the rights described in the next paragraph. Consultant’s released claims include, without limitation, all claims relating in any way to employment with the CONSOL Companies; the termination of employment; and any cause of action Consultant has or might have for an alleged violation of any express or implied contract, or federal or state law, including (without limitation) the Employee Retirement Income Security Act of 1974, Title VII of the Civil Rights Act of 1964, the Age Discrimination in Employment Act of 1967, the Americans with Disabilities Act, the Family and Medical Leave Act, Sarbanes Oxley, the WARN Act, the Pennsylvania Wage Payment and Collection Law, and any other state, federal or local law, rule or regulation. Consultant’s released claims also include any claim Consultant has or might have for payments under the CONSOL Energy Inc. Severance Pay Plan for Salaried Employees, other than payments stated in this Agreement. If any administrative agency or court assumes jurisdiction over any charge, complaint, proceeding or action involving claims released in this Agreement,

- 3 -

Consultant agrees that not to accept, recover, or receive any monetary damages or other relief from or in connection with that charge, complaint, or proceeding. Consultant agrees that if a court of competent jurisdiction determines that Consultant is to be awarded damages under the WARN Act or any other federal or state law, those damages would be offset by an amount equal to payments under this Agreement minus $500.

Consultant does not release certain rights by signing this Agreement. The foregoing release does not affect the following: any rights or claims that may arise after the date this Agreement is executed; Consultant’s right to enforce the Company's obligations under this Agreement; any rights Consultant may have to vested Company pension or retirement benefits that Consultant is entitled to on February 28, 2013; any rights Consultant may otherwise have relative to nonqualified stock options, restricted stock units, and performance share units; Consultant’s rights under any indemnification agreement with the Company or CNX Gas Corporation; Consultant’s rights under the Company’s agreement with Ayco; Consultant’s right to file a charge or complaint with any appropriate federal, state, or local agency, such as the United States Equal Employment Opportunity Commission; Consultant’s right to participate in or cooperate with any such charge or complaint procedure; Consultant’s right to challenge the validity of this Agreement; and any right that cannot be waived as a matter of law. Any other claim Consultant has or might have is, however, released by this Agreement.

14.    Governing Law. This Agreement is governed by and shall be construed in accordance with the laws of the Commonwealth of Pennsylvania.

15.    Entire Agreement. This Agreement constitutes the entire agreement between the parties, supersedes all prior and contemporaneous agreements or understandings, oral or written, between the parties relating to the subject matter hereof, and may be modified only in writing signed by both parties; provided, however, that this Agreement shall not diminish or affect in any way the provisions of any agreements containing post-employment restrictions on competition, solicitation of employees and disclosure of confidential information.

16.     Non-Disparagement; Cooperation. Consultant and Company agree that this is an amicable arrangement and will be portrayed as such in all public statements, whether written or oral, by executive management of the Company, and by Consultant. As such, executive management of the Company will not disparage Consultant, and Consultant will not disparage them or the Company. Additionally, Consultant will cooperate with the Company in any future matters relating to past employment following the Consulting Period. Consultant agrees to be reasonably available to the Company for the purpose of responding to requests for information, to provide information, documents, declarations or statements, to meet with attorneys and other Company representatives, to prepare for and give testimony by deposition or otherwise, and to cooperate in the investigation, defense or prosecution of matters relating to any threatened, present, or future legal actions, investigations or administrative proceedings involving the Company. The Company will advance or reimburse Consultant’s reasonable costs incurred as a result of these obligations.

17.    Legal Review; Review and Revocation Period. The Company advises you to consult with an attorney of your choice regarding this Agreement, which includes an offer of

- 4 -

consideration in exchange for a release of claims. You have 21 days from January 30, 2013, to review and consider its terms. Even after signing this Agreement, you have 7 days after signing it to revoke it, if you change your mind.

[signature page follows]

- 5 -

IN WITNESS WHEREOF, the parties have hereunto set their hands on the date and year first written above.

CONSULTANT:

/s/ William Lyons                    

WILLIAM LYONS            

CONSOL ENERGY INC.

By: /s/ J. Brett Harvey

Name: J. Brett Harvey

Title: CEI & Chairman of the Board            

- 6 -

EX-10.5

RETIREMENT AND CONSULTING
AGREEMENT

This Retirement and Consulting Agreement (“Agreement) is entered into by Robert Pusateri (“Consultant”) and CONSOL Energy Inc. (the “Company”) as of the 20^th day of February, 2013.

Background.

Consultant is currently employed by the Company as its Executive Vice President – Energy Sales and Transportation Services; and

Consultant has elected to retire and is terminating his employment relationship with the Company effective as of February 28, 2013;

Following such retirement, Company has offered to retain Consultant to provide certain consulting services to the Company pursuant to an independent contractor consulting relationship, under the terms and conditions stated below.

Agreement.

NOW THEREFORE, in consideration of the mutual promises set forth below, the Company and Consultant, intending to be legally bound, hereby agree as follows:

1.    Retention as a Consultant. The parties agree that, effective as of February 28, 2013, Consultant’s employment with the Company will be terminated and thereafter Consultant shall be retained by the Company on an independent contractor basis to provide consulting services as needed until December 31, 2013 (“Consulting Period”). During the Consulting Period, Consultant will report directly to J. Brett Harvey, the Chairman and Chief Executive Officer of the Company.

2.    Consulting Services. Consultant agrees to make himself available on reasonable notice to provide such services as are within Consultant’s areas of expertise and of a type commensurate with Consultant’s former position with the Company as may from time to time be requested by Mr. Harvey or his designee. It is anticipated that Consultant will provide services at a level not to exceed 60 hours per month. Consultant is not obligated to report to Company for assignment unless specifically requested by Company. To the extent possible, the consulting services will be provided using telephone and home computer. Consultant agrees to meet any reasonable deadline applicable to any assignment. Consultant agrees to perform the services for each assignment personally, in accordance with all applicable laws and ordinary business custom.

3.    Fees for Consulting Services. The Company agrees to make monthly payments to Consultant in arrears in an amount equal to $40,395.00, which shall be payable on the first day of each month during the Consulting Period, starting on April 1, 2013. The Company will also provide Consultant with a complimentary parking pass for the underground garage at CNX Center during the Consulting Period. Consultant will not be provided with any additional

- 1 -

compensation or benefits for the services referenced in paragraph 2, regardless of the frequency or duration of assignments made during the Consulting Period. In the event the Agreement is terminated by the Consultant, is terminated by the Company for Cause (as defined below), or the Consultant dies or is disabled to the point that he can no longer provide the consulting services referred to in Section 2, the Company shall only pay the monthly payment for services through the end of the month in which termination occurs. In the event that the Company terminates the Agreement other than for Cause, the Company shall pay the monthly payment applicable to the entire Term of the Agreement. For purposes of this Agreement, “Cause” means material breach of this Agreement or gross misconduct by the Consultant.

4.    Independent Contractor Status. During the Consulting Period, it is understood and agreed that all services which Consultant performs for the Company shall be as an independent contractor and not as an employee. Company shall have no right to control or direct the details, manner or means by which Consultant accomplishes his consulting services. Nothing herein shall be deemed to create an employer-employee relationship. Consultant understands and acknowledges that the Company will not withhold income taxes from the fees to be paid to Consultant, and it will not pay FICA, FUTA or unemployment taxes on Consultant’s behalf, nor will Consultant be eligible for workers' compensation and state and federal unemployment compensation benefits. Consultant is solely responsible for the payment of federal self-employment and all other federal, state and local taxes and agrees to indemnify, defend and hold harmless the Company from any liability attributable to his/her failure to make full and timely payment of any taxes.

5.    Benefits. Except as otherwise eligible under Company-provided retirement plans due to employment prior to the Consulting Period, Consultant shall not, as a provider of the consulting services under this Agreement, be eligible for any Company-paid benefits, including, but not limited to, pension, medical, disability, or other insurance, vacation, holiday or sick pay or any other compensation or consideration commonly known as fringe benefits.

6.    Expenses. Consultant shall be responsible for any and all expenses incurred in connection with services rendered under this Agreement, unless reimbursement is expressly agreed to in writing by Mr. Harvey or his designee before the expense is incurred, and Consultant provides the Company with such supporting documentation as may be requested.

7.    No Authority to Bind The Company. During the Consulting Period, Consultant agrees that he will not hold himself out as an employee or agent of the Company, and understands and agrees that he has no authority to bind, obligate or contract on behalf of the Company. Nor will the Company be liable for any acts of the Consultant during the Consulting Period that cause damages to any third party.

8.    Indemnification. Consultant agrees to indemnify, defend, and hold harmless the Company, its shareholders, directors and employees, from any and all liability (including costs of defense) upon claims asserted by third parties, including employees of the Company, arising out of Consultant’s performance of services under this Agreement. Consultant acknowledges that his/her actions or omissions may not be covered by the Company’s insurance policies and that it shall be the responsibility of Consultant to obtain any desired liability insurance protection.

- 2 -

9.    Term. This Agreement shall terminate on December 31, 2013.

10.    Termination. The results of the Consultant’s services shall be subject to the Company’s review and approval. Notwithstanding Sections 1 and 9 of the Agreement, each party shall have the right to terminate this Agreement for any reason on 30 days prior written notice to the other party. The Company may terminate this Agreement immediately for Cause, and this Agreement shall terminate immediately if the Consultant dies or becomes disabled. Termination of this Agreement by any party shall not terminate Sections 12, 13, and 16.

11.    Services to Other Entities. The parties agree that Consultant may provide services to other entities for compensation during the Consulting Period, so long as such services do not create a conflict of interest and do not interfere with Consultant’s availability to provide services under this Agreement.

12.    Non-use/Non-disclosure of Confidential Information. Consultant acknowledges that he may be provided with confidential information about the Company or its customers in the course of performance under this Agreement. Consultant agrees that, during and after the Consulting Period, he will not disclose such information to any person who is not an employee of the Company having a business need to know such information and that he will not use such information for his own benefit. Confidential Information, as used herein, means information about the Company, its finances, costs, prices, marketing strategies or plans, opportunities, business plans, key employees, customers, or processes, that is not generally known outside of the Company, is considered and treated as confidential by the Company, and the disclosure of which would be detrimental to the Company or beneficial to a competitor. To the extent that Consultant is provided with, or has in his possession, documents (including electronically stored information) containing Confidential Information, he agrees to return such information to the Company and not to retain any reproductions or copies thereof within his custody or control.

13.    Release. By signing and not revoking this Agreement, Consultant releases CONSOL Energy Inc., CNX Gas Corporation, and all of their affiliated companies (collectively, the "CONSOL Companies") and all of their current and former directors, officers, agents, and employees, from any and all claims Consultant has or might have against them as the result of events that occurred on or before the date this Agreement is executed by Consultant, except for the rights described in the next paragraph. Consultant’s released claims include, without limitation, all claims relating in any way to employment with the CONSOL Companies; the termination of employment; and any cause of action Consultant has or might have for an alleged violation of any express or implied contract, or federal or state law, including (without limitation) the Employee Retirement Income Security Act of 1974, Title VII of the Civil Rights Act of 1964, the Age Discrimination in Employment Act of 1967, the Americans with Disabilities Act, the Family and Medical Leave Act, Sarbanes Oxley, the WARN Act, the Pennsylvania Wage Payment and Collection Law, and any other state, federal or local law, rule or regulation. Consultant’s released claims also include any claim Consultant has or might have for payments under the CONSOL Energy Inc. Severance Pay Plan for Salaried Employees, other than payments stated in this Agreement. If any administrative agency or court assumes jurisdiction over any charge, complaint, proceeding or action involving claims released in this Agreement,

- 3 -

Consultant agrees that not to accept, recover, or receive any monetary damages or other relief from or in connection with that charge, complaint, or proceeding. Consultant agrees that if a court of competent jurisdiction determines that Consultant is to be awarded damages under the WARN Act or any other federal or state law, those damages would be offset by an amount equal to payments under this Agreement minus $500.

Consultant does not release certain rights by signing this Agreement. The foregoing release does not affect the following: any rights or claims that may arise after the date this Agreement is executed; Consultant’s right to enforce the Company's obligations under this Agreement; any rights Consultant may have to vested Company pension or retirement benefits that Consultant is entitled to on February 28, 2013; any rights Consultant may otherwise have relative to nonqualified stock options, restricted stock units, and performance share units; Consultant’s rights under any indemnification agreement with the Company or CNX Gas Corporation; Consultant’s rights under the Company’s agreement with Ayco; Consultant’s right to file a charge or complaint with any appropriate federal, state, or local agency, such as the United States Equal Employment Opportunity Commission; Consultant’s right to participate in or cooperate with any such charge or complaint procedure; Consultant’s right to challenge the validity of this Agreement; and any right that cannot be waived as a matter of law. Any other claim Consultant has or might have is, however, released by this Agreement.

14.    Governing Law. This Agreement is governed by and shall be construed in accordance with the laws of the Commonwealth of Pennsylvania.

15.    Entire Agreement. This Agreement constitutes the entire agreement between the parties, supersedes all prior and contemporaneous agreements or understandings, oral or written, between the parties relating to the subject matter hereof, and may be modified only in writing signed by both parties; provided, however, that this Agreement shall not diminish or affect in any way the provisions of any agreements containing post-employment restrictions on competition, solicitation of employees and disclosure of confidential information.

16.     Non-Disparagement; Cooperation. Consultant and Company agree that this is an amicable arrangement and will be portrayed as such in all public statements, whether written or oral, by executive management of the Company, and by Consultant. As such, executive management of the Company will not disparage Consultant, and Consultant will not disparage them or the Company. Additionally, Consultant will cooperate with the Company in any future matters relating to past employment following the Consulting Period. Consultant agrees to be reasonably available to the Company for the purpose of responding to requests for information, to provide information, documents, declarations or statements, to meet with attorneys and other Company representatives, to prepare for and give testimony by deposition or otherwise, and to cooperate in the investigation, defense or prosecution of matters relating to any threatened, present, or future legal actions, investigations or administrative proceedings involving the Company. The Company will advance or reimburse Consultant’s reasonable costs incurred as a result of these obligations.

17.    Legal Review; Review and Revocation Period. The Company advises you to consult with an attorney of your choice regarding this Agreement, which includes an offer of

- 4 -

consideration in exchange for a release of claims. You have 21 days from January 30, 2013, to review and consider its terms. Even after signing this Agreement, you have 7 days after signing it to revoke it, if you change your mind.

[signature page follows]

- 5 -

IN WITNESS WHEREOF, the parties have hereunto set their hands on the date and year first written above.

CONSULTANT:

/s/ Robert Pusateri                    

ROBERT PUSATERI                

CONSOL ENERGY INC.

By: /s/ J.Brett Harvey

Name: J. Brett Harvey

Title: Chairman and CEO

- 6 -

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:	May 7, 2013
/s/ J. Brett Harvey
J. Brett Harvey
Chairman of the Board and Chief Executive Officer
(Principal Executive Officer)

EX-31.2

Exhibit 31.2

CERTIFICATIONS

I, David M. Khani, certify that:

1. I have reviewed this report on Form 10-Q of CONSOL Energy Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information;

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	May 7, 2013
/s/ David M. Khani
David M. Khani
Chief Financial Officer and Executive Vice President (Principal Financial Officer)

EX-32.1

Exhibit 32.1

CERTIFICATION

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002,

18 U.S.C. Section 1350

I, J. Brett Harvey, President and Chief Executive Officer (principal executive officer) of CONSOL Energy Inc. (the “Registrant”), certify that to my knowledge, based upon a review of the Quarterly Report on Form 10-Q for the period ended March 31, 2013, of the Registrant (the “Report”):

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Registrant.

Date:	May 7, 2013
/s/ J. Brett Harvey
J. Brett Harvey
Chairman of the Board and Chief Executive Officer

EX-32.2

Exhibit 32.2

CERTIFICATION

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002,

18 U.S.C. Section 1350

I, David M. Khani, Chief Financial Officer (principal financial officer) of CONSOL Energy Inc. (the “Registrant”), certify that to my knowledge, based upon a review of the Quarterly Report on Form 10-Q for the period ended March 31, 2013, of the Registrant (the “Report”):

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Registrant.

Date:	May 7, 2013
/s/ David M. Khani
David M. Khani
Chief Financial Officer and Executive Vice President

EX-95

Mine Safety and Health Administration Safety Data

We believe that CONSOL Energy is one of the safest mining companies in the world. The Company has in place health and safety programs that include extensive employee training, accident prevention, workplace inspection, emergency response, accident investigation, regulatory compliance and program auditing. The objectives of our health and safety programs are to eliminate workplace incidents, comply with all mining-related regulations and provide support for both regulators and the industry to improve mine safety.

The operation of our mines is subject to regulation by the federal Mine Safety and Health Administration (MSHA) under the Federal Mine Safety and Health Act of 1977 (Mine Act). MSHA inspects our mines on a regular basis and issues various citations, orders and violations when it believes a violation has occurred under the Mine Act. We present information below regarding certain mining safety and health violations, orders and citations, issued by MSHA and related assessments and legal actions and mine-related fatalities with respect to our coal mining operations. In evaluating this information, consideration should be given to factors such as: (i) the number of violations, orders and citations will vary depending on the size of the coal mine, (ii) the number of violations, orders and citations issued will vary from inspector to inspector and mine to mine, and (iii) violations, orders and citations can be contested and appealed, and in that process, are often reduced in severity and amount, and are sometimes dismissed.

The table below sets forth for the three months ended March 31, 2013 for each coal mine of CONSOL Energy and its subsidiaries, the total number of:  (i) violations of mandatory health or safety standards that could significantly and substantially contribute to the cause and effect of a coal or other mine safety or health hazard under section 104 of the Mine Act for which the operator received a citation from MSHA; (ii) orders issued under section 104(b) of the Mine Act; (iii) citations and orders for unwarrantable failure of the mine operator to comply with mandatory health or safety standards under section 104(d) of the Mine Act; (iv) flagrant violations under section 110(b)(2) of the Mine Act; (v) imminent danger orders issued under section 107(a) of the Mine Act; (vi) proposed assessments from MHSA (regardless of whether CONSOL Energy has challenged or appealed the assessment); (vii) mining-related fatalities; (viii) notices from MSHA of a pattern of violations of mandatory health or safety standards that are of such nature as could have significantly and substantially contributed to the cause and effect of coal or other mine health or safety hazards under section 104(e) of the Mine Act; (ix) notices from MSHA regarding the potential to have a pattern of violations as referenced in (viii) above; and (x) pending legal actions before the Federal Mine Safety and Health Review Commission (as of March 31, 2013) involving such coal or other mine, as well as the aggregate number of legal actions instituted and the aggregate number of legal actions resolved during the reporting period.

1

										Received
										Notice
									Received	of	Legal
								Total	Notice of	Potential	Actions
				Section			Total Dollar	Number	Pattern of	to have	Pending	Legal	Legal
		Section		104(d)			Value of	of	Violations	Pattern	as of	Actions	Actions
Mine or Operating		104	Section	Citations	Section	Section	MSHA	Mining	Under	Under	Last	Initiated	Resolved
Name/MSHA		S&S	104(b)	and	110(b)(2)	107(a)	Assessments	Related	Section	Section	Day of	During	During
Identification Number		Citations	Orders	Orders	Violations	Orders	Proposed	Fatalities	104(e)	104(e)	Period (1)	Period	Period
Active Operations
Alma No. 1 Mine	46-09277	1	—	—	—	—	1,000	—	No	No	—	—	—
Amonate Plant	46-05449	—	—	—	—	—	100	—	No	No	—	—	—
Bailey	36-07230	22	—	—	—	—	24,792	—	No	No	8	5	4
Blacksville 2	46-01968	46	—	1	—	—	91,628	—	No	No	26	5	5
Buchanan	44-04856	27	—	—	—	—	198,300	—	No	No	36	6	6
Central Repair Shop	46-03240	—	—	—	—	—	—	—	No	No	—	—	—
Enlow Fork	36-07416	13	—	2	—	—	21,560	—	No	No	8	5	9
Ireland Dock Loadout	46-01438	2	—	—	—	—	276	—	No	No	5	—	—
Keystone Cleaning Plant	36-08540	—	—	—	—	—	—	—	No	No	—	—	—
Loveridge	46-01433	78	—	9	—	1	126,408	1	No	No	26	1	2
McElroy	46-01437	56	—	—	—	1	85,479	—	No	No	27	2	2
Miller Creek PP #1	46-05890	5	—	—	—	—	324	—	No	No	—	—	2
Minway Surface	46-06089	—	—	—	—	—	—	—	No	No	—	—	—
Robinson Run	46-01318	26	—	—	—	—	289,893	—	No	No	32	7	1
Shoemaker	46-01436	32	—	—	—	—	309,625	—	No	No	26	8	4
Twin Branch Surface	46-09075	—	—	—	—	—	—	—	No	No	—	—	—
Wiley Creek (MT-13/500)	46-09185	—	—	—	—	—	243	—	No	No	2	1	—
Wiley Surface(MT34/Peg Fork)	46-09035	3	—	—	—	—	3,424	—	No	No	1	—	—
Inactive Operations
Big Branch #1Belt/Spruce Creek	46-09177	—	—	—	—	—	—	—	No	No	—	—	—
Big Fork	44-06859	—	—	—	—	—	—	—	No	No	—	—	—
Bronzite II (MT-41)	46-09307	—	—	—	—	—	1,111	—	No	No	1	—	1
Bronzite III (Jacobs)	46-05978	—	—	—	—	—	—	—	No	No	—	—	3
Elk Creek Prep Plant (Sold)	46-02444	—	—	—	—	—	—	—	No	No	—	—	—
Emery	42-00079	—	—	—	—	—	200	—	No	No	1	—	—
Fola Surface	46-08377	—	—	—	—	—	—	—	No	No	1	—	—
Ike Fork 5 Block	46-09420	—	—	—	—	—	648	—	No	No	2	—	—
Impoundment 14-N	36-08094	—	—	—	—	—	—	—	No	No	—	—	—

2

Jones Fork Prep Plant (Sold)	15-17021	—	—	—	—	—	—	—	No	No	—	—	—
Laurel Fork	46-09084	—	—	—	—	—	—	—	No	No	—	—	1
Lick Branch	46-08676	—	—	—	—	—	634	—	No	No	1	—	—
Little Eagle Mine #1	46-08560	—	—	—	—	—	—	—	No	No	—	—	—
Meigs #31 Mine	33-01172	—	—	—	—	—	—	—	No	No	—	—	—
Miles Branch	44-03932	—	—	—	—	—	—	—	No	No	—	—	—
Mine 84	36-00958	—	—	—	—	—	—	—	No	No	—	—	—
MT-34 UG	46-09424	—	—	—	—	—	9,175	—	No	No	—	—	—
Muskingum	33-00989	—	—	—	—	—	—	—	No	No	—	—	—
Peach Orchard Prep Plant	46-08376	—	—	—	—	—	—	—	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	—	—	—	—	—	300	—	No	No	—	—	1
Rock Lick	46-09171	—	—	—	—	—	—	—	No	No	2	—	6
Squire Jim #2	46-09211	—	—	—	—	—	—	—	No	No	—	—	—
Terry Eagle PP #1	46-02295	—	—	—	—	—	—	—	No	No	—	—	—
Wiley (MT-11)	46-09138	—	—	—	—	—	—	—	No	No	—	—	—
Wiley Area 80	15-18477	—	—	—	—	—	—	—	No	No	—	—	—
Winoc Prep Plant	46-08172	—	—	—	—	—	—	—	No	No	—	—	—
		310	—	12	—	2	1,164,120	1			205	40	47

3

(1) See table below for additional detail regarding Legal Actions Pending as of March 31, 2013.  With respect to Contests of Proposed Penalties, we have included the number of dockets (as opposed to citations) when counting the number of Legal Actions Pending as of March 31, 2013.

Mine or Operating Name/MSHA Identification Number		Contests of Citations, Orders (as of 3.31.13) (a)	Contests of Proposed Penalties (as of 3.31.13) (b)		Complaints for Compensation (as of 3.31.13) (c)	Complaints of Discharge, Discrimination or Interference (as of 3.31.13) (d)	Applications for Temporary Relief (as of 3.31.13) (e)	Appeals of Judges' Decisions or Order (as of 3.31.13) (f)
			Dockets	Citations
Active Operations
Alma No. 1 Mine	46-09277	—	—	—	—	—	—	—
Amonate Plant	46-05449	—	—	—	—	—	—	—
Bailey	36-07230	—	8	16	—	1	—	—
Blacksville 2	46-01968	—	26	287	—	—	—	—
Buchanan	44-04856	—	36	417	—	4	—	—
Central Repair Shop	46-03240	—	—	—	—	—	—	—
Enlow Fork	36-07416	—	8	32	—	—	—	—
Ireland Dock Loadout	46-01438	—	5	6	—	—	—	—
Keystone Cleaning Plant	36-08540	—	—	—	—	—	—	—
Loveridge	46-01433	—	26	179	—	—	—	—
McElroy	46-01437	—	27	576	—	—	—	—
Miller Creek PP #1	46-05890	—	—	—	—	—	—	—
Minway Surface	46-06089	—	—	—	—	—	—	—
Robinson Run	46-01318	—	32	248	—	—	—	1
Shoemaker	46-01436	—	26	273	—	1	—	—
Twin Branch Surface	46-09075	—	—	—	—	—	—	—
Wiley Creek (MT‑13/500)	46-09185	—	2	2	—	—	—	—
Wiley Surface(MT34/Peg Fork)	46-09035	—	1	2	—	—	—	—

4

Inactive Operations
Big Branch #1Belt/Spruce Creek	46-09177	—	—	—	—	—	—	—
Big Fork	44-06859	—	—	—	—	—	—	—
Bronzite II (MT‑41)	46-09307	—	1	1	—	—	—	—
Bronzite III (Jacobs)	46-05978	—	—	—	—	—	—	—
Elk Creek Prep Plant (Sold)	46-02444	—	—	—	—	—	—	—
Emery	42-00079	—	1	1	—	—	—	—
Fola Surface	46-08377	—	1	3	—	—	—	—
Ike Fork 5 Block	46-09420	—	2	2	—	—	—	—
Impoundment 14‑N	36-08094	—	—	—	—	—	—	—
Jones Fork Prep Plant(Sold)	15-17021	—	—	—	—	—	—	—
Laurel Fork	46-09084	—	—	—	—	—	—	—
Lick Branch	46-08676	—	1	3	—	—	—	—
Little Eagle Mine #1	46-08560	—	—	—	—	—	—	—
Meigs #31 Mine	33-01172	—	—	—	—	—	—	—
Miles Branch	44-03932	—	—	—	—	—	—	—
Mine 84	36-00958	—	—	—	—	—	—	—
MT-34 UG	46-09424	—	—	—	—	—	—	—
Muskingum	33-00989	—	—	—	—	—	—	—
Peach Orchard Prep Plant	46-08376	—	—	—	—	—	—	—
Powellton/Bridge Fork	46-08889	—	—	—	—	—	—	—
Reclamation #061	33-00962	—	—	—	—	—	—	—
Rend Lake	11-00601	—	—	—	—	—	—	—
Robena Prep	36-04175	—	—	—	—	—	—	—
Rock Lick	46-09171	—	2	18	—	—	—	—
Squire Jim #2	46-09211	—	—	—	—	—	—	—
Terry Eagle PP #1	46-02295	—	—	—	—	—	—	—
Wiley (MT‑11)	46-09138	—	—	—	—	—	—	—
Wiley Area 80	15-18477	—	—	—	—	—	—	—
Winoc Prep Plant	46-08172	—	—	—	—	—	—	—
		—	205	2,066	—	6	—	1

5

(a) Represents (if any) contests of citations and orders, which typically are filed prior to an operator's receipt of a proposed penalty assessment from MSHA or relate to orders for which penalties are not assessed (such as imminent danger orders under Section 107 of the Mine Act). This category includes: (i) contests of citations or orders issued under section 104 of the Mine Act, (ii) contests of imminent danger withdrawal orders under section 107 of the Mine Act, and (iii) Emergency response plan dispute proceedings (as required under the Mine Improvement and New Emergency Response Act of 2006, Pub. L. No. 109-236, 120 Stat. 493).

(b) Represents (if any) contests of proposed penalties, which are administrative proceedings before the Federal Mine Safety and Health Review Commission (“FMSHRC”) challenging a civil penalty that MSHA has proposed for the violation contained in a citation or order. This column includes four actions involving civil penalties against agents of the operator that have been contested.

(c) Represents (if any) complaints for compensation, which are cases under section 111 of the Mine Act that may be filed with the FMSHRC by miners idled by a closure order issued by MSHA who are entitled to compensation.

(d) Represents (if any) complaints of discharge, discrimination or interference under section 105 of the Mine Act, which cover: (i) discrimination proceedings involving a miner's allegation that he or she has suffered adverse employment action because he or she engaged in activity protected under the Mine Act, such as making a safety complaint, and (ii) temporary reinstatement proceedings involving cases in which a miner has filed a complaint with MSHA stating that he or she has suffered such discrimination and has lost his or her position. Complaints of Discharge, Discrimination, or Interference are also included in Contests of Proposed Penalties, Column B.

(e) Represents (if any) applications for temporary relief, which are applications under section 105(b)(2) of the Mine Act for temporary relief from any modification or termination of any order or from any order issued under section 104 of the Mine Act (other than citations issued under section 104(a) or (f) of the Mine Act).

(f) Represents (if any) appeals of judges' decisions or orders to the FMSHRC, including petitions for discretionary review and review by the FMSHRC on its own motion.

6

XML

Basis of Presentation Anti-Dilutive Options and Units Exluded from Earnings Per Share (Details)	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of diluted earnings per share	8,665,061	1,687,475
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	5,011,771	1,574,922
Restricted Stock Units (RSUs) [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of diluted earnings per share	1,459,228	12,203
Performance Share Units [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of diluted earnings per share	700,040	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	602,101	100,350

XML

Property, Plant and Equipment Joint Venture Activity (Details) (USD $)	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2013 Noble JV[Member] [Member]	Mar. 31, 2013 Hess [Member]	Mar. 31, 2013 Noble JV[Member] [Member] acre	Dec. 31, 2011 Noble JV[Member] [Member] acre	Sep. 30, 2011 Noble JV[Member] [Member]	Dec. 31, 2011 Hess [Member] acre
Drilling commitment carry						$ 2,100,000,000	$ 534,000,000
Maximum Annual Drilling Commitment Carry						400,000,000
Acres w/ Asserted Title Defects				93,000			38,000
Gas and Oil Acreage, Unproved, Net					628,000		200,000
Carry Value of Acres w/ Asserted Title Defects				610,000,000			153,000,000
drill carry remaining		2,052,790,000	496,723,000
Aggregate Value of Conceded Defects in Excess of the Applicable Deductible				37,000,000
Transaction Value of Asserted Title Defects	$ 6,310,000

XML

Income Taxes Income Tax Reconciliation (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Amount
Statutory U.S. Federal Income Tax Rate	$ (455)	$ 41,502
Income Tax Reconciliation, Nondeductible Expense, Depletion	1,428	(26,514)
Net Effect of State Income Taxes	(179)	3,510
Other	(272)	2,883
Income Tax Expense / Effective Rate	$ 522	$ 21,381
Percent
Statutory U.S. Federal Income Tax Rate	35.00%	35.00%
Excess Tax Depletion	(109.90%)	(22.40%)
Net Effect of State Income Taxes	13.70%	3.00%
Other	21.00%	2.40%
Income Tax Expense / Effective Rate	(40.20%)	18.00%

XML

Guarantor Subsidiaries, Condensed Statement of Cash Flows (Detail) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	$ 268,280	$ 229,486
Investing Activities:
Capital Expenditures	(405,972)	(306,446)
Other Investing Activities	138,636
Net Cash Used in Investing Activities	(231,542)	(288,085)
Proceeds from Sales of Assets	138,636	28,611
Financing Activities:
Dividends Paid	0	(28,387)
(Payments on) Proceeds from Short-Term Borrowings	0
Proceeds from Issuance of Common Stock	909	54
Other Financing Activities	1,770	893
Payments on Securitization Facility	7,727
Repayments of Other Debt	(27,601)	(2,330)
Net Cash (Used in) Provided by Financing Activities	(33,558)	(29,824)
Equity Method Investment, Dividends or Distributions	(12,500)	(10,250)
Increase (Decrease) in Restricted Cash	48,294	0
Parent Issuer
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	59,082	123,513
Investing Activities:
Capital Expenditures	(1,504)	(13,562)
Other Investing Activities	(75)
Net Cash Used in Investing Activities	(1,579)	(13,562)
Proceeds from Sales of Assets		0
Financing Activities:
Dividends Paid		91,613
(Payments on) Proceeds from Short-Term Borrowings	(29,000)
Other Financing Activities	1,770	893
Payments on Securitization Facility	0
Repayments of Other Debt	(25,612)	(236)
Net Cash (Used in) Provided by Financing Activities	(52,842)	92,270
Equity Method Investment, Dividends or Distributions	0	0
Increase (Decrease) in Restricted Cash	0
CNX Gas Guarantor
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	190,004	54,417
Investing Activities:
Capital Expenditures	(207,129)	(98,455)
Other Investing Activities	343
Net Cash Used in Investing Activities	(218,786)	(104,095)
Proceeds from Sales of Assets		4,359
Financing Activities:
Dividends Paid		(120,000)
(Payments on) Proceeds from Short-Term Borrowings	29,000
Other Financing Activities	(1,400)	(844)
Payments on Securitization Facility	0
Repayments of Other Debt	0	0
Net Cash (Used in) Provided by Financing Activities	27,600	(120,844)
Equity Method Investment, Dividends or Distributions	(12,000)	(9,999)
Increase (Decrease) in Restricted Cash	0
Other Guarantors Subsidiaries [Member]
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	11,589	51,118
Investing Activities:
Capital Expenditures	(197,339)	(194,429)
Other Investing Activities	138,365
Net Cash Used in Investing Activities	(11,180)	(170,430)
Proceeds from Sales of Assets		24,250
Financing Activities:
Dividends Paid		0
(Payments on) Proceeds from Short-Term Borrowings	0
Other Financing Activities	1,400	844
Payments on Securitization Facility	0
Repayments of Other Debt	(1,813)	(1,844)
Net Cash (Used in) Provided by Financing Activities	(413)	(1,000)
Equity Method Investment, Dividends or Distributions	(500)	(251)
Increase (Decrease) in Restricted Cash	48,294
Non-Guarantors
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	7,605	438
Investing Activities:
Capital Expenditures	0	0
Other Investing Activities	3
Net Cash Used in Investing Activities	3	2
Proceeds from Sales of Assets		2
Financing Activities:
Dividends Paid		0
(Payments on) Proceeds from Short-Term Borrowings	0
Other Financing Activities		0
Payments on Securitization Facility	7,727
Repayments of Other Debt	(176)	(250)
Net Cash (Used in) Provided by Financing Activities	(7,903)	(250)
Equity Method Investment, Dividends or Distributions	0	0
Increase (Decrease) in Restricted Cash	0
Consolidation, Eliminations [Member]
Schedule of Condensed Consolidating Statement of Cash Flows [Line Items]
Net Cash Provided by Operating Activities	0	0
Investing Activities:
Capital Expenditures	0	0
Other Investing Activities	0
Net Cash Used in Investing Activities	0	0
Proceeds from Sales of Assets		0
Financing Activities:
Dividends Paid		0
(Payments on) Proceeds from Short-Term Borrowings	0
Other Financing Activities	0	0
Payments on Securitization Facility	0
Repayments of Other Debt	0	0
Net Cash (Used in) Provided by Financing Activities	0	0
Equity Method Investment, Dividends or Distributions	0	0
Increase (Decrease) in Restricted Cash	$ 0

XML

Short-Term Notes Payable (Details) (USD $) In Thousands, unless otherwise specified			3 Months Ended
	Mar. 31, 2013	Dec. 31, 2010	Mar. 31, 2013 Senior Secured Credit Facility April122016 Member [Member]	Mar. 31, 2013 CNX Gas Senior Secured Credit Facility April122016 Member [Member]	Mar. 31, 2012 CNX Gas Senior Secured Credit Facility April122016 Member [Member]
Short-term Debt [Line Items]
Credit facility, face amount			$ 1,500,000	$ 1,000,000
Additional Capacity Available On Credit Lines At Request			250,000	250,000
Minimum interest coverage ratio			2.50	3.00
Interest coverage ratio			4.42	42.09
Maximum leverage ratio			4.75	3.50
Current maximum leverage ratio			2.86	0.56
Senior secured leverage ratio, maximum			2.00
Current secured leverage ratio			0.09
Letters of credit outstanding			100,292	70,203
Borrowings and issuance of letters of credit remaining capacity			1,399,708	929,797
Debt Instrument, Interest Rate During Period				1.89%
Interest Payable, Current	$ 113,586	$ 63,363		$ 119	$ 29

XML

Pension and OPEB - Periodic Cost (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Dec. 31, 2012
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	$ (8,212)	$ (12,106)
Amortization of actuarial gain	(25,188)	(27,005)
Other Comprehensive Income (Loss), Finalization of Pension and Non-Pension Postretirement Plan Valuation, Net of Tax	27,115
Net periodic (benefit) cost	44,091	14,899
Deferred Income Taxes	160,750		148,104
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	5,706	5,153
Interest cost	8,843	9,378
Expected return on plan assets	(12,144)	(11,627)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	(408)	(408)
Amortization of actuarial gain	12,175	12,263
Other Comprehensive Income (Loss), Finalization of Pension and Non-Pension Postretirement Plan Valuation, Net of Tax	27,115	0
Net periodic (benefit) cost	41,287	14,759
Pension Contributions	18,560
Total anticipated contributions to pension trust	50,000
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	4,849	5,200
Interest cost	29,619	35,527
Expected return on plan assets	0	0
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	(7,804)	(11,599)
Amortization of actuarial gain	17,595	20,345
Other Comprehensive Income (Loss), Finalization of Pension and Non-Pension Postretirement Plan Valuation, Net of Tax	0	0
Net periodic (benefit) cost	44,259	49,473
Defined Benefit Plan, Benefits Paid	41,922
Salary OPEB Amendment [Member] | Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Net periodic (benefit) cost	6,760
Defined Benefit Plan, Plan Amendments	29,916
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	35,261
Deferred Income Taxes	$ 21,770

XML

Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2013

Long-term Purchase Commitment [Table Text Block]

At March 31, 2013, CONSOL Energy has provided the following financial guarantees, unconditional purchase obligations and letters of credit to certain third parties, as described by major category in the following table. These amounts represent the maximum potential total of future payments that we could be required to make under these instruments. These amounts have not been reduced for potential recoveries under recourse or collateralization provisions. Generally, recoveries under reclamation bonds would be limited to the extent of the work performed at the time of the default. No amounts related to these financial guarantees and letters of credit are recorded as liabilities on the financial statements. CONSOL Energy management believes that these guarantees will expire without being funded, and therefore the commitments will not have a material adverse effect on financial condition.

	Amount of Commitment Expiration Per Period
	Total Amounts Committed		Less Than 1  Year		1-3 Years		3-5 Years		Beyond 5  Years
Letters of Credit:
Employee-Related	$	190,158	$	126,654	$	63,504	$	—	$	—
Environmental	56,293		34,346		21,947		—		—
Other	83,398		46,452		36,946		—		—
Total Letters of Credit	329,849		207,452		122,397		—		—
Surety Bonds:
Employee-Related	204,884		204,884		—		—		—
Environmental	533,974		524,072		9,902		—		—
Other	29,487		29,476		11		—		—
Total Surety Bonds	768,345		758,432		9,913		—		—
Total Commitments	$	1,098,194	$	965,884	$	132,310	$	—	$	—

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

Obligations Due	Amount
Less than 1 year	$	349,513
1 - 3 years	227,586
3 - 5 years	128,338
More than 5 years	414,276
Total Purchase Obligations	$	1,119,713

Supply Commitment [Table Text Block]

Costs related to these purchase obligations include:

	Three Months Ended
	March, 31
	2013		2012
Major equipment purchases	$	33,426	$	13,166
Firm transportation expense	28,525		15,045
Gas drilling obligations	28,863		29,576
Other	—		298
Total costs related to purchase obligations	$	90,814	$	58,085

XML

Subsequent Events Details (Details) (USD $) In Thousands, unless otherwise specified	0 Months Ended
	Apr. 12, 2013
Subsequent Event [Line Items]
Subsequent Event, Amount, Higher Range	$ 36,000

XML

Commitments and Contingencies Additional Information (Details) (USD $)				3 Months Ended				3 Months Ended	12 Months Ended	3 Months Ended			3 Months Ended
	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2013 Subsidiaries	Mar. 31, 2013 Commonwealth Park Property	Mar. 31, 2013 South Carolina Electric Gas Company [Member]	Mar. 31, 2012 South Carolina Electric Gas Company [Member] Counterclaim [Member]	Mar. 31, 2013 PCB Soil Removal Action	Mar. 31, 2013 American electric corp [Member]	Dec. 31, 2012 American electric corp [Member]	Dec. 31, 2007 Earl Kennedy	Mar. 31, 2013 Cnx Gas Stock Acquisition [Member]	Dec. 31, 2012 Cnx Gas Stock Acquisition [Member]	Mar. 31, 2013 Ratliff [Member]
Commitments and Contingencies Disclosure [Line Items]
Loss Contingency, Range of Possible Loss, Portion Not Accrued	$ 845,000,000
Claims by plaintiff				The Commonwealth claimed that the Company is liable for dam reconstruction costs, lake restoration costs and natural resource damages totaling $58,000.	36000					The complaint, as amended, seeks injunctive relief, including removing CNX Gas Company from the property, and compensatory damages of $20,000.			$4,000 to $8,000
The current estimated cost of remedial action for the area CONSOL Energy was originally named a PRP, including payment of the EPA's past and future cost, is approximately				30,000,000			65,000,000	5,400,000			20,200
Litigation Settlement, Gross									250
Counterclaim by the company						9400		408
Sale of Stock, Price Per Share												$ 38.25
Loss Contingency, Settlement Agreement, Court											42730
Loss Contingency, Estimate of Possible Loss				20,000,000			11,000,000
Loss Contingency, Range of Possible Loss, Minimum				9,000,000				2,000,000
CONSOL Energy's portion of probable recoveries from settled claims							4,393,000
Remaining liability in PCB soil removal action	839,294,000	768,494,000					3,167,000
Loss Contingency, Damages Sought, Value								$ 384,000
Commitments and Contingent, number of asbestos claims			6,900

XML

Guarantor Subsidiaries Financial Information Gurantor Subsidiaries Statement of Comprehensive Income (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Condensed Financial Statements, Captions [Line Items]
Net (Loss) Income	$ (1,821)	$ 97,196
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	45,757	59,573
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))	(18,595)	76,076
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $31,380, $12,615)	(22,713)	(47,941)
Other Comprehensive Income (Loss), Net of Tax	4,449	87,708
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,628	184,904
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	(257)	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,885	184,904
Parent Issuer
Condensed Financial Statements, Captions [Line Items]
Net (Loss) Income	(1,564)
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	45,757	59,573
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))	(18,595)	76,076
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $31,380, $12,615)	(22,713)	(47,941)
Other Comprehensive Income (Loss), Net of Tax	4,449	87,708
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,885
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,885	184,904
CNX Gas Guarantor
Condensed Financial Statements, Captions [Line Items]
Net (Loss) Income	(325)
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	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))	(18,595)	76,076
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $31,380, $12,615)	(22,713)	(47,941)
Other Comprehensive Income (Loss), Net of Tax	(41,308)	28,135
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(41,633)
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	(257)
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(41,376)	35,589
Other Guarantors Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net (Loss) Income	103,542
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	45,757	59,573
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	45,757	59,573
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	149,299
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	149,299	213,889
Non-Guarantors
Condensed Financial Statements, Captions [Line Items]
Net (Loss) Income	2,228
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	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, Including Portion Attributable to Noncontrolling Interest	2,228
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,228	3,892
Consolidation, Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Net (Loss) Income	(105,702)
Other Comprehensive Income (Loss), Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	(45,757)	(59,573)
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))	18,595	(76,076)
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $31,380, $12,615)	22,713	47,941
Other Comprehensive Income (Loss), Net of Tax	(4,449)	(87,708)
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(110,151)
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	$ (110,151)	$ (253,370)

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Subsequent Events (Notes)

0 Months Ended

Apr. 12, 2013

Subsequent Event [Line Items]

Subsequent Events [Text Block]

SUBSEQUENT EVENTS:

In April 2013, CONSOL Energy and the Commonwealth of Pennsylvania entered into a Settlement Agreement and Release settling all of the Commonwealth's claims regarding the Ryerson Park Dam and the Ryerson Park Lake, discussed further in Note 11 - Commitments and Contingencies. The Settlement provides in part for the payment to the Commonwealth of $36,000 for use to rebuild the dam and restore the lake. As part of the settlement, the Commonwealth will convey to the Company its oil and gas rights within the Park, subject to the Company's agreement to extract oil and gas from surface facilities located outside of the boundaries of the Park. The Settlement also provides in part for the conveyance by the Company to the Commonwealth of eight surface parcels containing approximately 506 acres of land adjoining the park after the parcels are no longer needed for the Company's operations and the conveyance by the Commonwealth to the Company certain coal and mining rights in an area of the Bailey Mine where a mining permit application is currently pending.

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Income Taxes Tax Examinations (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Income Tax Examination [Line Items]
Income Tax Reconciliation, Nondeductible Expense, Depletion	$ 1,428	$ (26,514)
Internal Revenue Service (IRS) [Member]
Income Tax Examination [Line Items]
Tax Adjustments, Settlements, and Unusual Provisions	$ (983)

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Basis of Presentation Changes in Accumulated Other Comprehensive Income / (Loss) by component (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Dec. 31, 2012
Natural Gas Swaps	$ (34,697)	$ (79,321)
Accumulated Other Comprehensive Income (Loss), Net of Tax	(742,893)		(747,342)
Other Comprehensive Income (Loss), Net of Tax	4,449	87,708
Tax Benefit of Natural Gas Swaps	11,984	31,380
Natural Gas Swaps, Net of Tax	(22,713)	(47,941)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	(8,212)	(12,106)
Defined Benefit Plan, Amortization of Gains (Losses)	25,188	27,005
Other Comprehensive Income (Loss), Finalization of Pension and Non-Pension Postretirement Plan Valuation, Net of Tax	(27,115)
Defined Benefit Plan, Net Periodic Benefit Cost	44,091	14,899
Tax Expense on Actuarially Determined Long-Term Liabilities	16,831	5,602
Actuarially Determined Long-Term Liability Adjustments, Net of Tax	27,260	9,297
Accumulated Other Comprehensive Income (Loss)
Accumulated Other Comprehensive Income (Loss), Net of Tax	(742,893)		(747,342)
Other Comprehensive Income (Loss), Net of Tax	4,449
Amounts reclassified from accumulated other comprehensive income	4,547
Other comprehensive income before reclassifications	(98)
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax	35,453		76,761
Other Comprehensive Income (Loss), Net of Tax	(41,308)
Amounts reclassified from accumulated other comprehensive income	(22,713)
Other comprehensive income before reclassifications	(18,595)
Accumulated Defined Benefit Plans Adjustment [Member]
Accumulated Other Comprehensive Income (Loss), Net of Tax	(778,346)		(824,103)
Other Comprehensive Income (Loss), Net of Tax	45,757
Amounts reclassified from accumulated other comprehensive income	27,260
Other comprehensive income before reclassifications	18,497
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	(408)	(408)
Defined Benefit Plan, Amortization of Gains (Losses)	(12,175)	(12,263)
Other Comprehensive Income (Loss), Finalization of Pension and Non-Pension Postretirement Plan Valuation, Net of Tax	(27,115)	0
Defined Benefit Plan, Net Periodic Benefit Cost	$ 41,287	$ 14,759

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Guarantor Subsidiaries Financial Information (Tables)

3 Months Ended

12 Months Ended

Mar. 31, 2013

Mar. 31, 2012

Dec. 31, 2012

Guarantor Subsidiaries Financial Information [Abstract]

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

Income Statement for the Three Months Ended March 31, 2013 (unaudited):

	Parent Issuer			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Sales—Outside	$	—		$	168,679		$	1,004,157		$	54,053	$	(724	)	$	1,226,165
Sales—Gas Royalty Interests	—			14,204			—			—		—			14,204
Sales—Purchased Gas	—			1,358			—			—		—			1,358
Freight—Outside	—			—			14,061			—		—			14,061
Other Income	77,976			13,224			15,255			5,373		(77,976		)	33,852
Total Revenue and Other Income	77,976			197,465			1,033,473			59,426		(78,700		)	1,289,640
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	75,990			114,352			681,705			53,726		7,190			932,963
Gas Royalty Interests Costs	—			11,817			—			—		(11		)	11,806
Purchased Gas Costs	—			959			—			—		—			959
Related Party Activity	(12,556		)	—			(7,778		)	404		19,930			—
Freight Expense	—			—			14,061			—		—			14,061
Selling, General and Administrative Expenses	—			10,112			23,247			311		—			33,670
Depreciation, Depletion and Amortization	3,195			52,399			105,237			484		—			161,315
Interest Expense	50,169			1,661			1,644			11		(107		)	53,378
Taxes Other Than Income	177			6,698			75,006			906		—			82,787
Total Costs	116,975			197,998			893,122			55,842		27,002			1,290,939
(Loss) Earnings Before Income Taxes	(38,999		)	(533		)	140,351			3,584		(105,702		)	(1,299		)
Income Taxes (Benefit) Expense	(37,435		)	(208		)	36,809			1,356		—			522
Net (Loss) Income	(1,564		)	(325		)	103,542			2,228		(105,702		)	(1,821		)
Add: Net Loss Attributable to Noncontrolling Interest	—			257			—			—		—			257
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(1,564	)	$	(68	)	$	103,542		$	2,228	$	(105,702	)	$	(1,564	)

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	167,985			16,305		29,703		5,957		(166,989		)	52,961
Total Revenue and Other Income	167,985			190,019		1,161,284		74,979		(167,497		)	1,426,770
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	49,180			98,644		682,853		66,416		7,044			904,137
Gas Royalty Interests Costs	—			10,255		—		—		(6		)	10,249
Purchased Gas Costs	—			517		—		—		—			517
Related Party Activity	7,013			—		1,258		502		(8,773		)	—
Freight Expense	—			—		49,293		—		—			49,293
Selling, General and Administrative Expenses	—			9,981		28,475		447		—			38,903
Depreciation, Depletion and Amortization	2,921			48,803		103,100		523		—			155,347
Interest Expense	54,762			1,218		2,229		11		(100		)	58,120
Taxes Other Than Income	636			8,200		81,971		820		—			91,627
Total Costs	114,512			177,618		949,179		68,719		(1,835		)	1,308,193
Earnings (Loss) Before Income Taxes	53,473			12,401		212,105		6,260		(165,662		)	118,577
Income Tax Expense (Benefit)	(43,723		)	4,947		57,789		2,368		—			21,381
Net Income (Loss)	$	97,196		$	7,454	$	154,316	$	3,892	$	(165,662	)	$	97,196

Guarantor Balance Sheet [Table Text Block]

Balance Sheet at March 31, 2013 (unaudited):

	Parent Issuer		CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Assets:
Current Assets:
Cash and Cash Equivalents	$	22,152	$	2,170		$	171		$	565	$	—		$	25,058
Accounts and Notes Receivable:
Trade	—		55,755			—			352,595		—			408,350
Notes Receivable	194		319,756			2,456			—		—			322,406
Other Receivables	5,081		112,802			32,024			3,790		—			153,697
Accounts Receivable—Securitized	—		—			—			30,119		—			30,119
Inventories	—		13,979			167,935			35,120		—			217,034
Deferred Income Taxes	169,920		(9,170		)	—			—		—			160,750
Recoverable Income Taxes	20,580		(13,978		)	—			—		—			6,602
Prepaid Expenses	20,814		52,271			40,544			1,527		—			115,156
Total Current Assets	238,741		533,585			243,130			423,716		—			1,439,172
Property, Plant and Equipment:
Property, Plant and Equipment	218,234		6,122,433			9,383,357			25,499		—			15,749,523
Less-Accumulated Depreciation, Depletion and Amortization	130,556		1,012,595			4,354,755			18,413		—			5,516,319
Total Property, Plant and Equipment-Net	87,678		5,109,838			5,028,602			7,086		—			10,233,204
Other Assets:
Deferred Income Taxes	855,493		(430,414		)	—			—		—			425,079
Restricted Cash	—		—			20,383			—		—			20,383
Investment in Affiliates	9,992,921		167,058			798,589			—		(10,710,441		)	248,127
Notes Receivable	212		—			25,783			—		—			25,995
Other	115,911		46,350			28,940			10,033		—			201,234
Total Other Assets	10,964,537		(217,006		)	873,695			10,033		(10,710,441		)	920,818
Total Assets	$	11,290,956	$	5,426,417		$	6,145,427		$	440,835	$	(10,710,441	)	$	12,593,194
Liabilities and Equity:
Current Liabilities:
Accounts Payable	$	195,092	$	173,468		$	85,104		$	10,222	$	—		$	463,886
Accounts Payable (Recoverable)—Related Parties	3,687,347		24,929			(3,969,054		)	227,778		29,000			—
Current Portion Long-Term Debt	1,568		5,939			5,084			762		—			13,353
Short-Term Notes Payable	—		29,000			—			—		(29,000		)	—
Borrowings Under Securitization Facility	—		—			—			30,119		—			30,119
Other Accrued Liabilities	161,155		68,331			599,867			9,941		—			839,294
Total Current Liabilities	4,045,162		301,667			(3,278,999		)	278,822		—			1,346,652
Long-Term Debt:	3,005,254		44,671			121,151			1,463		—			3,172,539
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	—		—			2,825,925			—		—			2,825,925
Pneumoconiosis Benefits	—		—			175,952			—		—			175,952
Mine Closing	—		—			449,891			—		—			449,891
Gas Well Closing	—		81,296			69,677			—		—			150,973
Workers’ Compensation	—		—			154,261			312		—			154,573
Salary Retirement	172,306		—			—			—		—			172,306
Reclamation	—		—			43,833			—		—			43,833
Other	95,696		26,151			6,469			—		—			128,316
Total Deferred Credits and Other Liabilities	268,002		107,447			3,726,008			312		—			4,101,769
Total CONSOL Energy Inc. Stockholders’ Equity	3,972,538		4,972,936			5,577,267			160,238		(10,710,441		)	3,972,538
Noncontrolling Interest	—		(304		)	—			—		—			(304		)
Total Liabilities and Equity	$	11,290,956	$	5,426,417		$	6,145,427		$	440,835	$	(10,710,441	)	$	12,593,194

Balance Sheet at December 31, 2012:

	Parent Issuer		CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors		Elimination			Consolidated
Assets:
Current Assets:
Cash and Cash Equivalents	$	17,491	$	3,352		$	175		$	860	$	—		$	21,878
Accounts and Notes Receivable:
Trade	—		58,126			—			370,202		—			428,328
Notes Receivable	154		315,730			2,503			—		—			318,387
Other Receivables	6,335		214,748			33,289			5,159		(128,400		)	131,131
Accounts Receivable—Securitized	—		—			—			37,846		—			37,846
Inventories	—		14,133			198,269			35,364		—			247,766
Deferred Income Taxes	174,176		(26,072		)	—			—		—			148,104
Restricted Cash	—		—			48,294			—		—			48,294
Prepaid Expenses	29,589		86,186			40,215			1,370		—			157,360
Total Current Assets	227,745		666,203			322,745			450,801		(128,400		)	1,539,094
Property, Plant and Equipment:
Property, Plant and Equipment	216,448		5,956,207			9,347,370			25,179		—			15,545,204
Less-Accumulated Depreciation, Depletion and Amortization	126,048		960,613			4,249,507			18,069		—			5,354,237
Total Property, Plant and Equipment-Net	90,400		4,995,594			5,097,863			7,110		—			10,190,967
Other Assets:
Deferred Income Taxes	884,310		(439,725		)	—			—		—			444,585
Restricted Cash	—		—			20,379			—		—			20,379
Investment in Affiliates	9,917,050		143,876			769,058			—		(10,607,154		)	222,830
Notes Receivable	239		—			25,738			—		—			25,977
Other	118,938		65,935			32,016			10,188		—			227,077
Total Other Assets	10,920,537		(229,914		)	847,191			10,188		(10,607,154		)	940,848
Total Assets	$	11,238,682	$	5,431,883		$	6,267,799		$	468,099	$	(10,735,554	)	$	12,670,909
Liabilities and Equity:
Current Liabilities:
Accounts Payable	$	177,734	$	166,182		$	154,936		$	9,130	$	—		$	507,982
Accounts Payable (Recoverable)-Related Parties	3,599,216		23,981			(3,749,584		)	254,787		(128,400		)	—
Current Portion of Long-Term Debt	1,554		5,953			5,222			756		—			13,485
Short-Term Notes Payable	25,073		—			—			—		—			25,073
Accrued Income Taxes	20,488		13,731			—			—		—			34,219
Borrowings Under Securitization Facility	—		—			—			37,846		—			37,846
Other Accrued Liabilities	135,407		57,074			566,485			9,528		—			768,494
Total Current Liabilities	3,959,472		266,921			(3,022,941		)	312,047		(128,400		)	1,387,099
Long-Term Debt:	3,005,515		46,081			121,523			1,467		—			3,174,586
Deferred Credits and Other Liabilities:
Postretirement Benefits Other Than Pensions	—		—			2,832,401			—		—			2,832,401
Pneumoconiosis Benefits	—		—			174,781			—		—			174,781
Mine Closing	—		—			446,727			—		—			446,727
Gas Well Closing	—		80,097			68,831			—		—			148,928
Workers’ Compensation	—		—			155,342			306		—			155,648
Salary Retirement	218,004		—			—			—		—			218,004
Reclamation	—		—			47,965			—		—			47,965
Other	101,899		24,518			4,608			—		—			131,025
Total Deferred Credits and Other Liabilities	319,903		104,615			3,730,655			306		—			4,155,479
Total CONSOL Energy Inc. Stockholders’ Equity	3,953,792		5,014,313			5,438,562			154,279		(10,607,154		)	3,953,792
Noncontrolling Interest	—		(47		)	—			—		—			(47		)
Total Liabilities and Equity	$	11,238,682	$	5,431,883		$	6,267,799		$	468,099	$	(10,735,554	)	$	12,670,909

Guarantor Condensed Cash Flow [Table Text Block]

Cash Flow for the Three Months Ended March 31, 2013 (unaudited):

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors			Non- Guarantors			Elimination		Consolidated
Net Cash Provided by Operating Activities	$	59,082		$	190,004		$	11,589		$	7,605		$	—	$	268,280
Cash Flows from Investing Activities:
Capital Expenditures	$	(1,504	)	$	(207,129	)	$	(197,339	)	$	—		$	—	$	(405,972	)
Proceeds from Sales of Assets	(75		)	343			138,365			3			—		138,636
Investments in Equity Affiliates	—			(12,000		)	(500		)	—			—		(12,500		)
Change in Restricted Cash	—			—			48,294			—			—		48,294
Net Cash (Used in) Provided by Investing Activities	$	(1,579	)	$	(218,786	)	$	(11,180	)	$	3		$	—	$	(231,542	)
Cash Flows from Financing Activities:
Proceeds from (Payments on) Short-Term Borrowings	(29,000		)	29,000			—			—			—		—
Payments on Securitization Facility	—			—			—			(7,727		)	—		(7,727		)
Payments on Miscellaneous Borrowings	(25,612		)	—			(1,813		)	(176		)	—		(27,601		)
Other Financing Activities	1,770			(1,400		)	1,400						—		1,770
Net Cash (Used in) Provided by Financing Activities	$	(52,842	)	$	27,600		$	(413	)	$	(7,903	)	$	—	$	(33,558	)

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	)
Proceeds from Sales of Assets	—			4,359			24,250			2			—		28,611
Investments in Equity Affiliates	—			(9,999		)	(251		)	—			—		(10,250		)
Net Cash (Used in) Provided by Investing Activities	$	(13,562	)	$	(104,095	)	$	(170,430	)	$	2		$	—	$	(288,085	)
Cash Flows from Financing Activities:
Dividends Paid	$	91,613		$	(120,000	)	$	—		$	—		$	—	$	(28,387	)
Payments on Miscellaneous Borrowings	(236		)	—			(1,844		)	(250		)	—		(2,330		)
Other Financing Activities	893			(844		)	844			—			—		893
Net Cash (Used in) Provided by Financing Activities	$	92,270		$	(120,844	)	$	(1,000	)	$	(250	)	$	—	$	(29,824	)

Guarantor Condensed Comprehensive Income [Table Text Block]

	Parent			CNX Gas Guarantor			Other Subsidiary Guarantors		Non- Guarantors		Elimination			Consolidated
Net (Loss) Income	$	(1,564	)	$	(325	)	$	103,542	$	2,228	$	(105,702	)	$	(1,821	)
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	45,757			—			45,757		—		(45,757		)	45,757
Net (Decrease) Increase in the Value of Cash Flow Hedge	(18,595		)	(18,595		)	—		—		18,595			(18,595		)
Reclassification of Cash Flow Hedge from OCI to Earnings	(22,713		)	(22,713		)	—		—		22,713			(22,713		)
Other Comprehensive (Loss) Income:	4,449			(41,308		)	45,757		—		(4,449		)	4,449
Comprehensive Income (Loss)	2,885			(41,633		)	149,299		2,228		(110,151		)	2,628
Add: Comprehensive Loss Attributable to Noncontrolling Interest	—			257			—		—		—			257
Comprehensive Income (Loss) Attributable to CONSOL Energy Inc. Shareholders	$	2,885		$	(41,376	)	$	149,299	$	2,228	$	(110,151	)	$	2,885

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 (Loss)	$	97,196		$	7,454		$	154,316	$	3,892	$	(165,662	)	$	97,196
Other Comprehensive Income (Loss):
Actuarially Determined Long-Term Liability Adjustments	59,573			—			59,573		—		(59,573		)	59,573
Net Increase (Decrease) in the Value of Cash Flow Hedge	76,076			76,076			—		—		(76,076		)	76,076
Reclassification of Cash Flow Hedge from OCI to Earnings	(47,941		)	(47,941		)	—		—		47,941			(47,941		)
Other Comprehensive Income (Loss):	87,708			28,135			59,573		—		(87,708		)	87,708
Comprehensive Income (Loss)	$	184,904		$	35,589		$	213,889	$	3,892	$	(253,370	)	$	184,904

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Accounts Receivable Securitization (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Dec. 31, 2012
Accounts Receivable - Securitized	$ 30,119		$ 37,846
Increase (Decrease) in Accounts Receivable from Securitization	7,727
AR securitization facility [Member]
Line of Credit Facility, Maximum Borrowing Capacity	200,000
Current borrowing capacity of receivable facility	199,800		200,000
Letters of credit amount outstanding	159,281
Costs associated with the receivables facility	472	419
Expiration date of receivables facility	Mar. 30, 2017
Eligible accounts receivable, a subordinated retained interest	$ 10,400

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Guarantor Subsidiaries Financial Information Additional Information (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012	Dec. 31, 2011
Condensed Financial Statements, Captions [Line Items]
Cash and Cash Equivalents	$ 25,058	$ 21,878	$ 287,313	$ 375,736
Trade	408,350	428,328
Notes Receivable, Related Parties, Current	322,406	318,387
Other Receivables	153,697	131,131
Accounts Receivable - Securitized	30,119	37,846
Inventories	217,034	247,766
Deferred Income Taxes	160,750	148,104
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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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, 2013	Mar. 31, 2012	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax	$ 35,453,000	$ 179,915,000	$ 76,761,000	$ 151,780,000
Amount of Gain (Loss) Recognized in OCI on Derivative	(18,595,000)	76,076,000
Outside Sales
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified from Accumulated OCI into Income	22,713,000	47,941,000
Derivative Instruments, Gain (Loss) Recognized in Income, Net	$ 1,041,000	$ (835,000)

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CWP and Workers Comp - Net Periodic Costs (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Schedule of Net Periodic Benefit Costs and Assumptions for Defined Benefit Postretirement Plans [Line Items]
Amortization of actuarial gain	$ (25,188)	$ (27,005)
Net periodic (benefit) cost	44,091	14,899
Coal Workers Pneumoconiosis [Member]
Schedule of Net Periodic Benefit Costs and Assumptions for Defined Benefit Postretirement Plans [Line Items]
Service cost	2,135	1,928
Interest cost	1,808	1,991
Amortization of actuarial gain	(4,213)	(4,934)
State administrative fees and insurance bond premiums	0	0
Legal and administrative costs	0	0
Net periodic (benefit) cost	(270)	(1,015)
Payments for Coal Workers Pnenumoconiosis	2,698
Workers Compensation [Member]
Schedule of Net Periodic Benefit Costs and Assumptions for Defined Benefit Postretirement Plans [Line Items]
Service cost	3,533	3,634
Interest cost	1,655	1,778
Amortization of actuarial gain	(699)	(986)
State administrative fees and insurance bond premiums	1,659	1,910
Legal and administrative costs	591	648
Net periodic (benefit) cost	6,739	6,984
Payments for workers compensation benefits, state administrative fees and surety bond premiums	$ 8,640

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Basis of Presentation

3 Months Ended

Mar. 31, 2013

BASIS OF PRESENTATION: [Abstract]

Basis of Presentation

NOTE 1—BASIS OF PRESENTATION:

The accompanying Unaudited Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by generally accepted accounting principles for complete financial statements. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included. Operating results for the three months ended March 31, 2013 are not necessarily indicative of the results that may be expected for future periods.

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

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

Basic earnings per share are computed by dividing net (loss) income attributable to shareholders by the weighted average shares outstanding during the reporting period. Dilutive earnings per share are computed similarly to basic earnings per share except that the weighted average shares outstanding are increased to include additional shares from the assumed exercise of stock options 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 stock units and performance share units were released, and that the proceeds from such activities were used to acquire shares of common stock at the average market price during the reporting period. CONSOL Energy Inc. (CONSOL Energy or the Company) includes the impact of pro forma deferred tax assets in determining potential windfalls and shortfalls for purposes of calculating assumed proceeds under the treasury stock method. The table below sets forth the share-based awards that have been excluded from the computation of the diluted earnings per share because their effect would be anti-dilutive:

	Three Months Ended March 31,
	2013	2012
Anti-Dilutive Options	5,011,771	1,574,922
Anti-Dilutive Restricted Stock Units	1,459,228	12,203
Anti-Dilutive Performance Share Units	700,040	—
Anti-Dilutive Performance Share Options	602,101	100,350
Anti-Dilutive CONSOL Share Units	891,921	—
	8,665,061	1,687,475

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

	Three Months Ended March 31,
	2013	2012
Options	84,994	11,716
Restricted Stock Units	478,509	458,018
Performance Share Units	159,228	229,730
	722,731	699,464

The weighted average exercise price per share of the options exercised during the three months ended March 31, 2013 and 2012 was $10.65 and $13.81, respectively.

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

	Three Months Ended March 31,
	2013			2012
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(1,564	)	$	97,196
Weighted average shares of common stock outstanding:
Basic	228,318,123			227,269,269
Effect of stock-based compensation awards	—			2,854,742
Dilutive	228,318,123			230,124,011
Earnings per share:
Basic	$	(0.01	)	$	0.43
Dilutive	$	(0.01	)	$	0.42

Changes in Accumulated Other Comprehensive Income / (Loss) by component, net of tax, were as follows:

	Gains and Losses on Cash Flow Hedges			Postretirement Benefits			Total
Balance at December 31, 2012	$	76,761		$	(824,103	)	$	(747,342	)
Other comprehensive income before reclassifications	(18,595		)	18,497			(98		)
Amounts reclassified from accumulated other comprehensive income	(22,713		)	27,260			4,547
New current period other comprehensive income	(41,308		)	45,757			4,449
Balance at March 31, 2013	$	35,453		$	(778,346	)	$	(742,893	)

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

	Three Months Ended March 31,
	2013			2012
Derivative Instruments (Note 12)
Natural gas price swaps	$	(34,697	)	$	(79,321	)
Tax benefit	11,984			31,380
Net of tax	$	(22,713	)	$	(47,941	)
Actuarially Determined Long-Term Liability Adjustments*(Note 3 and Note 4)
Amortization of prior service costs	$	(8,212	)	$	(12,106	)
Recognized net actuarial loss	25,188			27,005
Settlement loss	27,115			—
Total	44,091			14,899
Tax expense	(16,831		)	(5,602		)
Net of tax	$	27,260		$	9,297

*Excludes amounts related to the remeasurement of the Actuarially Determined Long-Term Liabilities for the three months ended March 31, 2013 and March 31, 2012.

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Financial Instruments Measured at Fair Value on a Recurring Basis (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012
Quoted Prices in Active Markets for Identical Liabilities (Level 1)
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Gas Cash Flow hedges	$ 0	$ 0
Significant Other Observable Inputs (Level 2)
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Gas Cash Flow hedges	62,728	128,945
Significant Unobservable Inputs (Level 3)
Fair Value, Assets Measured on Recurring Basis, Financial Statement Captions [Line Items]
Gas Cash Flow hedges	$ 0	$ 0

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Basis of Presentation Reclassification of adjustments out of Accumulated Other Comprehensive Loss (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Natural Gas Swaps	$ (34,697)	$ (79,321)
Tax Benefit of Natural Gas Swaps	11,984	31,380
Natural Gas Swaps, Net of Tax	(22,713)	(47,941)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	(8,212)	(12,106)
Defined Benefit Plan, Amortization of Gains (Losses)	25,188	27,005
Other Comprehensive Income (Loss), Finalization of Pension and Non-Pension Postretirement Plan Valuation, Net of Tax	27,115
Defined Benefit Plan, Net Periodic Benefit Cost	44,091	14,899
Tax Expense on Actuarially Determined Long-Term Liabilities	16,831	5,602
Actuarially Determined Long-Term Liability Adjustments, Net of Tax	27,260	9,297
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	(408)	(408)
Defined Benefit Plan, Amortization of Gains (Losses)	(12,175)	(12,263)
Other Comprehensive Income (Loss), Finalization of Pension and Non-Pension Postretirement Plan Valuation, Net of Tax	27,115	0
Defined Benefit Plan, Net Periodic Benefit Cost	$ 41,287	$ 14,759

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Income Taxes (Tables)

3 Months Ended

Mar. 31, 2013

INCOME TAXES: [Abstract]

Components of Consolidated Income Taxes

	For the Three Months Ended March 31,
	2013					2012
	Amount			Percent		Amount			Percent
Statutory U.S. federal income tax rate	$	(455	)	35.0	%	$	41,502		35.0	%
Impact of excess tax depletion	1,428			(109.9	)	(26,514		)	(22.4	)
Net effect of state income taxes	(179		)	13.7		3,510			3.0
Other	(272		)	21.0		2,883			2.4
Income Tax Expense / Effective Rate	$	522		(40.2	)%	$	21,381		18.0	%

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CWP and Workers Comp - Net Periodic Costs (Tables)

3 Months Ended

Mar. 31, 2013

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,
	2013			2012			2013			2012
Service cost	$	2,135		$	1,928		$	3,533		$	3,634
Interest cost	1,808			1,991			1,655			1,778
Amortization of actuarial gain	(4,213		)	(4,934		)	(699		)	(986		)
State administrative fees and insurance bond premiums	—			—			1,659			1,910
Legal and administrative costs	—			—			591			648
Net periodic (benefit) cost	$	(270	)	$	(1,015	)	$	6,739		$	6,984

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Long-Term Debt (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012	Dec. 31, 2010
Debt Instrument [Line Items]
Capital Lease Obligations, Current	$ 8,789		$ 8,941
Debt	3,128,804	3,129,017
Less amounts due in one year	(4,564)	(4,544)
Long-Term Debt	3,124,240	3,124,473
Accrued interest	113,586			63,363
Senior Notes Due April 2017 at 8.00%
Debt Instrument [Line Items]
Debt	1,500,000	1,500,000
Senior notes due April 2020 at 8.25%
Debt Instrument [Line Items]
Debt	1,250,000	1,250,000
Senior notes due March 2021 at 6.375%
Debt Instrument [Line Items]
Debt	250,000	250,000
Baltimore Port Facility revenue bonds in series due September 2025 at 5.75%
Debt Instrument [Line Items]
Debt	102,865	102,865
Advance royalty commitments
Debt Instrument [Line Items]
Debt	20,394	20,394
Other long-term notes maturing at various dates through 2031
Debt Instrument [Line Items]
Debt	$ 5,545	$ 5,758

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Dispositions (Details) (USD $)			3 Months Ended	12 Months Ended		3 Months Ended
	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012 Burning Star Disposal [Member]	Dec. 31, 2012 Ram River [Member] acre	Dec. 31, 2012 Burning Start No.4 [Member] acre	Mar. 31, 2013 Shoemaker Longwall Shields [Member]	Mar. 31, 2013 Bailey Longwall Shields [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Sale Leaseback Transaction, Net Proceeds						$ 63,839,000	$ 71,166,000
Coal Lands and or Surface Rights				36,000	4,300.0
Proceeds from Sale of Property, Plant, and Equipment			13,023,000	51,869,000
Gain (Loss) on Sale of Property Plant Equipment			11,261,000	89,943,000		(279,000)	(358,000)
Note Receivable 1 year - PPE Sale				25,500,000
Note Receivable 2 year - PPE Sale				24,500,000
Restricted Cash and Cash Equivalents				48,294,000
Transaction and Financing Fees				637,000
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	$ 248,127,000	$ 222,830,000

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Inventories (Tables)

3 Months Ended

Mar. 31, 2013

INVENTORIES: [Abstract]

Inventory components

	March 31, 2013		December 31, 2012
Coal	$	51,954	$	78,825
Merchandise for resale	35,120		35,363
Supplies	129,960		133,578
Total Inventories	$	217,034	$	247,766

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Property, Plant and Equipment (Tables)

3 Months Ended

Mar. 31, 2013

Notes to Financial Statements [Abstract]

Collaborative Arrangement Disclosure [Text Block]

Shale Play	Industry Participation Agreement Partner	Industry Participation Agreement Date	Drilling Carries Remaining*
Marcellus	Noble Energy, Inc.	September 30, 2011	$	2,052,790
Utica	Hess Ohio Developments, LLC	October 21, 2011	$	496,723

Property, Plant and Equipment

	March 31, 2013		December 31, 2012
Coal and other plant and equipment	$	6,032,128	$	6,030,620
Intangible drilling cost	1,623,391		1,550,297
Proven gas properties	1,600,532		1,596,838
Coal properties and surface lands	1,351,271		1,346,151
Unproven gas properties	1,321,108		1,266,017
Gas gathering equipment	1,024,952		1,006,882
Airshafts	711,586		706,388
Mine development	561,288		537,939
Leased coal lands	529,741		529,758
Gas wells and related equipment	508,768		492,367
Coal advance mining royalties	394,438		391,501
Other gas assets	82,094		82,217
Gas advance royalties	8,226		8,229
Total Property Plant and Equipment	15,749,523		15,545,204
Less: Accumulated DD&A	5,516,319		5,354,237
Total Net PP&E	$	10,233,204	$	10,190,967

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Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Operating Activities:
Net Income	$ (1,821)	$ 97,196
Adjustments to Reconcile Net Income to Net Cash Provided By Operating Activities:
Depreciation, Depletion and Amortization	161,315	155,347
Stock-Based Compensation	26,069	16,252
(Gain) Loss on Sale of Assets	(2,176)	(19,713)
Amortization of Mineral Leases	503	1,886
Deferred Income Taxes	305	(2,265)
Equity in Earnings of Affiliates	(4,797)	(7,935)
Changes in Operating Assets:
Accounts and Notes Receivable	27,137	(17,990)
Inventories	30,732	(26,662)
Prepaid Expenses	7,944	6,231
Changes in Other Assets	6,749	10,837
Changes in Operating Liabilities:
Accounts Payable	(26,474)	(39,312)
Other Operating Liabilities	19,940	62,233
Changes in Other Liabilities	16,652	(8,928)
Other	6,202	2,309
Net Cash Provided by Operating Activities	268,280	229,486
Investing Activities:
Capital Expenditures	(405,972)	(306,446)
Increase (Decrease) in Restricted Cash	48,294	0
Proceeds from Sales of Assets	138,636	28,611
Net Investment in Equity Affiliates	(12,500)	(10,250)
Net Cash Used in Investing Activities	(231,542)	(288,085)
Financing Activities:
Payments on Miscellaneous Borrowings	(27,601)	(2,330)
Payments on Securitzation Facility	(7,727)	0
Tax Benefit from Stock-Based Compensation	730	750
Dividends Paid	0	(28,387)
Proceeds from Issuance of Common Stock	909	54
Issuance of Treasury Stock	0	109
Debt Issuance and Financing Fees	131	(20)
Net Cash (Used in) Provided by Financing Activities	(33,558)	(29,824)
Net Increase in Cash and Cash Equivalents	3,180	(88,423)
Cash and Cash Equivalents at Beginning of Period	21,878	375,736
Cash and Cash Equivalents at End of Period	$ 25,058	$ 287,313

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Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2013

Notes to Financial Statements [Abstract]

Schedule of Long-term Debt

	March 31, 2013		December 31, 2012
Debt:
Senior notes due April 2017 at 8.00%, issued at par value	$	1,500,000	$	1,500,000
Senior notes due April 2020 at 8.25%, issued at par value	1,250,000		1,250,000
Senior notes due March 2021 at 6.375%, issued at par value	250,000		250,000
MEDCO revenue bonds in series due September 2025 at 5.75%	102,865		102,865
Advance royalty commitments (7.43% weighted average interest rate for March 31, 2013 and December 31, 2012)	20,394		20,394
Other long-term notes maturing at various dates through 2031 (total value of $6,956 less unamortized discount of $1,411 at March 31, 2013)	5,545		5,758
	3,128,804		3,129,017
Less amounts due in one year *	4,564		4,544
Long-Term Debt	$	3,124,240	$	3,124,473

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Basis of Presentation Share-based Compensation (Details) (USD $)	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures	722,731	699,464
Performance Share Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity awards other than options, vested	159,228	229,730
Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Options Exercised	84,994	11,716
Share-based comp Options Granted Weighted average exercise price	10.65	13.81
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity awards other than options, vested	478,509	458,018

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Property, Plant and Equipment (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012
Property, Plant and Equipment [Line Items]
Coal and other plant and equipment	$ 6,032,128	$ 6,030,620
Drilling Cost	1,623,391	1,550,297
Proven gas properties	1,600,532	1,596,838
Coal properties and surface lands	1,351,271	1,346,151
Unproven gas properties	1,321,108	1,266,017
Gas gathering equipment	1,024,952	1,006,882
Airshafts	711,586	706,388
Mine development	561,288	537,939
Leased coal lands	529,741	529,758
Gas wells and related equipment	508,768	492,367
Coal advance mining royalties	394,438	391,501
Other gas assets	82,094	82,217
Gas advance royalties	8,226	8,229
Total property plant and equipment	15,749,523	15,545,204
Less Accumulated depreciation, depletion and amortization	5,516,319	5,354,237
Total Property, Plant and Equipment-Net	$ 10,233,204	$ 10,190,967

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Related Party Transaction (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Dec. 31, 2012
Related Party Transaction [Line Items]
Equity Method Investment, Ownership Percentage	50.00%
CONE [Member]
Related Party Transaction [Line Items]
Due from Related Parties	$ 10,975		$ 3,142
Related Party Transaction, Expenses from Transactions with Related Party	7,327	3,462
CONE [Member] | CONE Capital Reimbursement [Member]
Related Party Transaction [Line Items]
Due from Related Parties	0		(18)
CONE [Member] | Reimbursement for CONE Expenses [Member]
Related Party Transaction [Line Items]
Due from Related Parties	(655)		(1,336)
CONE [Member] | Reimbursement for Services Provided to Cone [Member]
Related Party Transaction [Line Items]
Due from Related Parties	(288)		(341)
CONE [Member] | CONE Gathering Fees [Member]
Related Party Transaction [Line Items]
Due to Related Parties, Current	$ 11,918		$ 4,837

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Consolidated Statements of Income (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Sales-Outside	$ 1,226,165	$ 1,311,471
Sales-Gas Royalty Interests	14,204	12,206
Sales-Purchased Gas	1,358	839
Freight-Outside	14,061	49,293
Other Income	33,852	52,961
Total Revenue and Other Income	1,289,640	1,426,770
Cost of Goods Sold and Other Operating Charges (exclusive of depreciation, depletion and amortization shown below)	932,963	904,137
Gas Royalty Interests Costs	11,806	10,249
Purchased Gas Costs	959	517
Freight Expense	14,061	49,293
Selling, General and Administrative Expenses	33,670	38,903
Depreciation, Depletion and Amortization	161,315	155,347
Interest Expense	53,378	58,120
Taxes Other Than Income	82,787	91,627
Total Costs	1,290,939	1,308,193
Earnings Before Income Taxes	(1,299)	118,577
Income Taxes	522	21,381
Net (Loss) Income	(1,821)	97,196
Net Income (Loss) Attributable to Noncontrolling Interest	257	0
Net Income	$ (1,564)	$ 97,196
Earnings per share:
Basic	$ (0.01)	$ 0.43
Dilutive	$ (0.01)	$ 0.42
Weighted Average Number of Common Shares Outstanding:
Basic	228,318,123	227,269,269
Dilutive	228,318,123	230,124,011
Dividends Paid Per Share	$ 0.000	$ 0.125

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Acquisitions and Dispositions Acquisitions (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013
Allegheny County Airport – Allegheny County Airport [Member]
Business Acquisition [Line Items]
Bonus Payment in Escrow	7.60%
Bonus Payment	$ 46,315
Allegheny County Airport – Pittsburgh International Airport [Member] [Member]
Business Acquisition [Line Items]
Gas and Oil Area, Undeveloped, Gross	9,263

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Consolidated Balance Sheets (Parentheticals) (USD $)	Mar. 31, 2013	Dec. 31, 2012
Common Stock [Member]
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Common Stock, Shares Authorized	500,000,000	500,000,000
Common Stock, Shares, Issued	228,609,116	228,129,467
Common Stock, Shares, Outstanding	228,574,361	228,094,712
Treasury Stock, Shares	34,755	34,755
Preferred Stock [Member]
Preferred Stock, Shares Authorized	15,000,000	15,000,000
Preferred Stock, Shares Issued	0	0
Preferred Stock, Shares Outstanding	0	0

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Costs Related to Purchase Obligations (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	$ 90,814	$ 58,085
Major equipment purchases
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	33,426	13,166
Firm transportation expense
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	28,525	15,045
Gas drilling obligations
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	28,863	29,576
Other Obligations
Schedule of Costs Related to Purchase Obligations [Line Items]
Total costs related to purchase obligations	$ 0	$ 298

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Fair Value of Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2013

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, 2013						Fair Value Measurements at December 31, 2012
Description	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Gas Cash Flow Hedges	$	—	$	62,728	$	—	$	—	$	128,945	$	—

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

	March 31, 2013						December 31, 2012
	Carrying Amount			Fair Value			Carrying Amount			Fair Value
Cash and Cash Equivalents	$	25,058		$	25,058		$	21,878		$	21,878
Restricted Cash	$	20,383		$	20,383		$	68,673		$	68,673
Short-Term Notes Payable	$	—		$	—		$	(25,073	)	$	(25,073	)
Borrowings Under Securitization Facility	$	(30,119	)	$	(30,119	)	$	(37,846	)	$	(37,846	)
Long-Term Debt	$	(3,128,804	)	$	(3,396,271	)	$	(3,129,017	)	$	(3,378,058	)

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Reconciliation of Segment Information, Revenue and Other Income (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Dec. 31, 2012
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	$ 1,226,165	$ 1,311,471
Earnings Before Income Taxes:
Earnings Before Income Taxes	(1,299)	118,577
Revenue from Purchased Oil and Gas	1,358	839
Sales-Gas Royalty Interests	14,204	12,206
Freight-Outside	14,061	49,293
Segment Reporting Information, Intersegment Revenue	0	0
Segment Reporting Information, Revenue for Reportable Segment	1,255,788	1,373,809
Total Assets	12,593,194	12,595,611	12,670,909
Depreciation, Depletion and Amortization	161,315	155,347
Capital Expenditures	405,972	306,446
Total Reportable Business Segments
Earnings Before Income Taxes:
Earnings Before Income Taxes	92,862	174,970
Total Assets	11,578,492	11,471,162
Coal
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	972,385	1,054,316
Earnings Before Income Taxes:
Earnings Before Income Taxes	93,502	162,470
Revenue from Purchased Oil and Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	14,061	49,293
Segment Reporting Information, Intersegment Revenue	0	0
Segment Reporting Information, Revenue for Reportable Segment	986,446	1,103,609
Total Assets	5,698,504	5,360,577
Depreciation, Depletion and Amortization	102,711	100,762
Capital Expenditures	197,338	194,429
Gas
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	167,842	160,203
Earnings Before Income Taxes:
Earnings Before Income Taxes	(640)	12,500
Revenue from Purchased Oil and Gas	1,358	839
Sales-Gas Royalty Interests	14,204	12,206
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	836	466
Segment Reporting Information, Revenue for Reportable Segment	184,240	173,714
Total Assets	5,879,988	6,110,585
Depreciation, Depletion and Amortization	52,399	48,803
Capital Expenditures	207,130	98,455
All Other Segments [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	85,938	96,952
Earnings Before Income Taxes:
Earnings Before Income Taxes	(40,552)	4,083
Revenue from Purchased Oil and Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	35,477	37,209
Segment Reporting Information, Revenue for Reportable Segment	121,415	134,161
Total Assets	358,663	358,746
Depreciation, Depletion and Amortization	6,205	5,782
Capital Expenditures	1,504	13,562
Excludes Gas Segment [Member]
Earnings Before Income Taxes:
Interest Income (Expense), Net and Other Non-operating Activity	(52,660)	(60,042)
Fees for Disposing Non-core Assets	949	434
Intersegment Elimination [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	0	0
Earnings Before Income Taxes:
Earnings Before Income Taxes	(53,609)	(60,476)
Revenue from Purchased Oil and Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	(36,313)	(37,675)
Segment Reporting Information, Revenue for Reportable Segment	(36,313)	(37,675)
Total Assets	656,039	765,703
Depreciation, Depletion and Amortization	0	0
Capital Expenditures	0	0
Steam [Member] | Coal
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	761,272	812,053
Earnings Before Income Taxes:
Earnings Before Income Taxes	128,432	128,449
Revenue from Purchased Oil and Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	0	0
Segment Reporting Information, Revenue for Reportable Segment	761,272	812,053
High Volatile Metallurgical [member] | Coal
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	58,622	60,568
Earnings Before Income Taxes:
Earnings Before Income Taxes	13,352	15,936
Revenue from Purchased Oil and Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	0	0
Segment Reporting Information, Revenue for Reportable Segment	58,622	60,568
Low Volatile Metallurgical [Member] | Coal
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	146,828	172,740
Earnings Before Income Taxes:
Earnings Before Income Taxes	54,717	79,341
Revenue from Purchased Oil and Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	0	0
Segment Reporting Information, Revenue for Reportable Segment	146,828	172,740
Other Coal [Member] | Coal
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	5,663	8,955
Earnings Before Income Taxes:
Earnings Before Income Taxes	(102,999)	(61,256)
Revenue from Purchased Oil and Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	14,061	49,293
Segment Reporting Information, Intersegment Revenue	0	0
Segment Reporting Information, Revenue for Reportable Segment	19,724	58,248
Coalbed Methane [Member] | Gas
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	83,640	99,535
Earnings Before Income Taxes:
Earnings Before Income Taxes	21,312	36,390
Revenue from Purchased Oil and Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	0	0
Segment Reporting Information, Revenue for Reportable Segment	83,640	99,535
Marcellus Shale [Member] | Gas
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	48,411	23,791
Earnings Before Income Taxes:
Earnings Before Income Taxes	13,768	3,251
Revenue from Purchased Oil and Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	0	0
Segment Reporting Information, Revenue for Reportable Segment	48,411	23,791
Conventional Gas [Member] | Gas
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	32,436	34,373
Earnings Before Income Taxes:
Earnings Before Income Taxes	(4,161)	(3,722)
Revenue from Purchased Oil and Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	0	0
Segment Reporting Information, Revenue for Reportable Segment	32,436	34,373
Other Gas | Gas
Segment Reporting, Revenue Reconciling Item [Line Items]
Sales-Outside	3,355	2,504
Earnings Before Income Taxes:
Earnings Before Income Taxes	(31,559)	(23,419)
Revenue from Purchased Oil and Gas	1,358	839
Sales-Gas Royalty Interests	14,204	12,206
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	836	466
Segment Reporting Information, Revenue for Reportable Segment	19,753	16,015
First Energy [Member] | Coal
Segment Reporting, Revenue Reconciling Item [Line Items]
Entity-Wide Revenue, Major Customer, Amount	$ 170,982	$ 144,155

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Segment Information

3 Months Ended

Mar. 31, 2013

Segment Reporting Information [Line Items]

Segment Reporting Disclosure [Text Block]

SEGMENT INFORMATION:

CONSOL Energy has two principal business divisions: Coal and Gas. The principal activities of the Coal division are mining, preparation and marketing of thermal coal, sold primarily to power generators, and metallurgical coal, sold to metal and coke producers. The Coal division includes four reportable segments. These reportable segments are Thermal, Low Volatile Metallurgical, High Volatile Metallurgical and Other Coal. Each of these reportable segments includes a number of operating segments (mines or type of coal sold). For the three months ended March 31, 2013, the Thermal aggregated segment includes the following mines: Bailey, Blacksville #2, Enlow Fork, Fola Complex, Loveridge, McElroy, Miller Creek Complex, Robinson Run and Shoemaker. For the three months ended March 31, 2013, the Low Volatile Metallurgical aggregated segment includes the Buchanan Mine and Amonate Complex. For the three months ended March 31, 2013, the High Volatile Metallurgical aggregated segment includes: Bailey, Blacksville #2, Enlow Fork, Fola Complex, Loveridge and Robinson Run coal sales. The Other Coal segment includes our purchased coal activities, idled mine activities, general and administrative activities as well as various other activities assigned to the Coal division but not allocated to each individual mine. The principal activity of the Gas division is to produce pipeline quality natural gas for sale primarily to gas wholesalers. The Gas division includes four reportable segments. These reportable segments are Coalbed Methane, Marcellus, Shallow Oil and Gas and Other Gas. The Other Gas segment includes our purchased gas activities, general and administrative activities as well as various other activities assigned to the Gas division but not allocated to each individual well type. CONSOL Energy’s All Other segment includes terminal services, river and dock services, industrial supply services, general and administrative activities and other business activities. Intersegment sales have been recorded at amounts approximating market. Operating profit for each segment is based on sales less identifiable operating and non-operating expenses. Assets are reflected at the division level only (coal, gas and other) and are not allocated between each individual segment. This presentation is consistent with the information regularly reviewed by the chief operating decision maker. The assets are not allocated to each individual segment due to the diverse asset base controlled by CONSOL Energy where each individual asset may service more than one segment within the division. An allocation of such asset base would not be meaningful or representative on a segment by segment basis.

Annually, the preparation of our gas reserve estimates are completed in accordance with CONSOL Energy's prescribed internal control procedures, which include verification of input data into a gas reserve forecasting and economic evaluation software, as well as multi-functional management review. The input data verification includes reviews of the price and cost assumptions used in the economic model to determine the reserves. Also, the production volumes are reconciled between the system used to calculate the reserves and other accounting/measurement systems. The technical employee responsible for overseeing the preparation of the reserve estimates is a petroleum engineer with over 10 years of experience in the oil and gas industry. Our 2012 gas reserve results, which are reported in the Supplemental Gas Data year ended December 31, 2012 Form 10-K, were audited by Netherland Sewell. The technical person primarily responsible for overseeing the audit of our reserves is a registered professional engineer in the state of Texas with over 14 years of experience in the oil and gas industry.

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Segment Information (Tables)

3 Months Ended

Mar. 31, 2013

Mar. 31, 2012

Notes to Financial Statements [Abstract]

Industry segment results

Industry segment results for the three months ended March 31, 2013 are:

	Thermal		Low Volatile Metallurgical		High Volatile Metallurgical		Other Coal			Total Coal		Coalbed Methane		Marcellus Shale		Shallow Oil and Gas			Other Gas			Total Gas			All Other			Corporate, Adjustments & Eliminations			Consolidated
Sales—outside	$	761,272	$	146,828	$	58,622	$	5,663		$	972,385	$	83,640	$	48,411	$	32,436		$	3,355		$	167,842		$	85,938		$	—		$	1,226,165		(A)
Sales—purchased gas	—		—		—		—			—		—		—		—			1,358			1,358			—			—			1,358
Sales—gas royalty interests	—		—		—		—			—		—		—		—			14,204			14,204			—			—			14,204
Freight—outside	—		—		—		14,061			14,061		—		—		—			—			—			—			—			14,061
Intersegment transfers	—		—		—		—			—		—		—		—			836			836			35,477			(36,313		)	—
Total Sales and Freight	$	761,272	$	146,828	$	58,622	$	19,724		$	986,446	$	83,640	$	48,411	$	32,436		$	19,753		$	184,240		$	121,415		$	(36,313	)	$	1,255,788
Earnings (Loss) Before Income Taxes	$	128,432	$	54,717	$	13,352	$	(102,999	)	$	93,502	$	21,312	$	13,768	$	(4,161	)	$	(31,559	)	$	(640	)	$	(40,552	)	$	(53,609	)	$	(1,299	)	(B)
Segment assets										$	5,698,504											$	5,879,988		$	358,663		$	656,039		$	12,593,194		(C)
Depreciation, depletion and amortization										$	102,711											$	52,399		$	6,205		$	—		$	161,315
Capital expenditures										$	197,338											$	207,130		$	1,504		$	—		$	405,972

(A)    Included in the Coal segment are sales of $170,982 to First Energy and $183,121 to Xcoal Energy & Resources each comprising over 10% of sales.

(B)     Includes equity in earnings of unconsolidated affiliates of $817, $3,182 and $798 for Coal, Gas and All Other, respectively.

(C)    Includes investments in unconsolidated equity affiliates of $20,334, $167,058 and $60,735 for Coal, Gas and All Other, respectively.

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	(D)
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	$	128,449	$	79,341	$	15,936	$	(61,256	)	$	162,470	$	36,390	$	3,251	$	(3,722	)	$	(23,419	)	$	12,500	$	4,083	$	(60,476	)	$	118,577	(E)
Segment assets										$	5,360,577											$	6,110,585	$	358,746	$	765,703		$	12,595,611	(F)
Depreciation, depletion and amortization										$	100,762											$	48,803	$	5,782	$	—		$	155,347
Capital expenditures										$	194,429											$	98,455	$	13,562	$	—		$	306,446

(D) 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.

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

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

Reconciliation of Revenue and Operating Income from Segments to Consolidated

Earnings Before Income Taxes:

	For the Three Months Ended March 31,
	2013			2012
Segment Earnings Before Income Taxes for total reportable business segments	$	92,862		$	174,970
Segment (Loss) Earnings Before Income Taxes for all other businesses	(40,552		)	4,083
Interest expense, net and other non-operating activity (G)	(52,660		)	(60,042		)
Other Corporate Items (G)	(949		)	(434		)
(Loss) Earnings Before Income Taxes	$	(1,299	)	$	118,577

Reconciliation of Assets and Liabilities from Segment to Consolidated

Total Assets:	March, 31
	2013		2012
Segment assets for total reportable business segments	$	11,578,492	$	11,471,162
Segment assets for all other businesses	358,663		358,746
Items excluded from segment assets:
Cash and other investments (G)	23,669		121,807
Recoverable income taxes	6,602		—
Deferred tax assets	585,829		596,657
Bond issuance costs	39,939		47,239
Total Consolidated Assets	$	12,593,194	$	12,595,611

_________________________ 

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

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Recent Accounting Pronouncements (Notes)

3 Months Ended

Mar. 31, 2013

New Accounting Pronouncements or Change in Accounting Principle [Line Items]

Description of New Accounting Pronouncements Not yet Adopted [Text Block]

RECENT ACCOUNTING PRONOUNCEMENTS:

In February 2013, the Financial Accounting Standards Board issued Update 2013-04 - Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date. The objective of the amendments in this update is to provide guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of this guidance is fixed at the reporting date, except for obligations addressed within existing guidance in U.S. generally accepted accounting principles (GAAP). The guidance in this update requires an entity to measure obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of this guidance is fixed at the reporting date, as the sum of the following: a.) The amount the reporting entity agreed to pay on the basis of its arrangement amount with its co-obligors, and b.) Any additional amount the reporting entity expects to pay on behalf of its co-obligors. The guidance in this update also requires an entity to disclose the nature and amount of the obligation as well as other information about those obligations. The amendments in this update are effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The amendments in this update should be applied retrospectively to all prior periods presented for those obligations resulting from joint and several liability arrangements within the update's scope that exist at the beginning of an entity's fiscal year of adoption. We believe adoption of this new guidance will not have a material impact on CONSOL Energy's financial statements.

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Guarantor Subsidiaries Income Statement (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	$ 1,226,165	$ 1,311,471
Sales-Gas Royalty Interests	14,204	12,206
Sales-Purchased Gas	1,358	839
Freight-Outside	14,061	49,293
Other Income (including equity earnings)	33,852	52,961
Total Revenue and Other Income	1,289,640	1,426,770
Cost of Goods Sold and Other Operating Charges	932,963	904,137
Gas Royalty Interests Costs	11,806	10,249
Purchased Gas Costs	959	517
Related Party Activity	0	0
Freight Expense	14,061	49,293
Selling, General and Administrative Expenses	33,670	38,903
Depreciation, Depletion and Amortization	161,315	155,347
Interest Expense	53,378	58,120
Taxes Other Than Income	82,787	91,627
Total Costs	1,290,939	1,308,193
Earnings Before Income Taxes	(1,299)	118,577
Income Tax Expense (Benefit)	522	21,381
Net (Loss) Income	(1,821)	97,196
Net Income (Loss) Attributable to Noncontrolling Interest	257	0
Net Income (Loss) Available to Common Stockholders, Basic	(1,564)
Net Income (Loss)	(1,564)	97,196
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)	77,976	167,985
Total Revenue and Other Income	77,976	167,985
Cost of Goods Sold and Other Operating Charges	75,990	49,180
Gas Royalty Interests Costs	0	0
Purchased Gas Costs	0	0
Related Party Activity	(12,556)	7,013
Freight Expense	0	0
Selling, General and Administrative Expenses	0	0
Depreciation, Depletion and Amortization	3,195	2,921
Interest Expense	50,169	54,762
Taxes Other Than Income	177	636
Total Costs	116,975	114,512
Earnings Before Income Taxes	(38,999)	53,473
Income Tax Expense (Benefit)	(37,435)	(43,723)
Net (Loss) Income	(1,564)
Net Income (Loss) Attributable to Noncontrolling Interest	0
Net Income (Loss) Available to Common Stockholders, Basic	(1,564)
Net Income (Loss)		97,196
CNX Gas Guarantor
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	168,679	160,669
Sales-Gas Royalty Interests	14,204	12,206
Sales-Purchased Gas	1,358	839
Freight-Outside	0	0
Other Income (including equity earnings)	13,224	16,305
Total Revenue and Other Income	197,465	190,019
Cost of Goods Sold and Other Operating Charges	114,352	98,644
Gas Royalty Interests Costs	11,817	10,255
Purchased Gas Costs	959	517
Related Party Activity	0	0
Freight Expense	0	0
Selling, General and Administrative Expenses	10,112	9,981
Depreciation, Depletion and Amortization	52,399	48,803
Interest Expense	1,661	1,218
Taxes Other Than Income	6,698	8,200
Total Costs	197,998	177,618
Earnings Before Income Taxes	(533)	12,401
Income Tax Expense (Benefit)	(208)	4,947
Net (Loss) Income	(325)
Net Income (Loss) Attributable to Noncontrolling Interest	257
Net Income (Loss) Available to Common Stockholders, Basic	(68)
Net Income (Loss)		7,454
Other Guarantors Subsidiaries [Member]
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	1,004,157	1,082,288
Sales-Gas Royalty Interests	0	0
Sales-Purchased Gas	0	0
Freight-Outside	14,061	49,293
Other Income (including equity earnings)	15,255	29,703
Total Revenue and Other Income	1,033,473	1,161,284
Cost of Goods Sold and Other Operating Charges	681,705	682,853
Gas Royalty Interests Costs	0	0
Purchased Gas Costs	0	0
Related Party Activity	(7,778)	1,258
Freight Expense	14,061	49,293
Selling, General and Administrative Expenses	23,247	28,475
Depreciation, Depletion and Amortization	105,237	103,100
Interest Expense	1,644	2,229
Taxes Other Than Income	75,006	81,971
Total Costs	893,122	949,179
Earnings Before Income Taxes	140,351	212,105
Income Tax Expense (Benefit)	36,809	57,789
Net (Loss) Income	103,542
Net Income (Loss) Attributable to Noncontrolling Interest	0
Net Income (Loss) Available to Common Stockholders, Basic	103,542
Net Income (Loss)		154,316
Non-Guarantors
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	54,053	69,022
Sales-Gas Royalty Interests	0	0
Sales-Purchased Gas	0	0
Freight-Outside	0	0
Other Income (including equity earnings)	5,373	5,957
Total Revenue and Other Income	59,426	74,979
Cost of Goods Sold and Other Operating Charges	53,726	66,416
Gas Royalty Interests Costs	0	0
Purchased Gas Costs	0	0
Related Party Activity	404	502
Freight Expense	0	0
Selling, General and Administrative Expenses	311	447
Depreciation, Depletion and Amortization	484	523
Interest Expense	11	11
Taxes Other Than Income	906	820
Total Costs	55,842	68,719
Earnings Before Income Taxes	3,584	6,260
Income Tax Expense (Benefit)	1,356	2,368
Net (Loss) Income	2,228
Net Income (Loss) Attributable to Noncontrolling Interest	0
Net Income (Loss) Available to Common Stockholders, Basic	2,228
Net Income (Loss)		3,892
Consolidation, Eliminations [Member]
Schedule of Condensed Consolidating Statement of Operations [Line Items]
Sales-Outside	(724)	(508)
Sales-Gas Royalty Interests	0	0
Sales-Purchased Gas	0	0
Freight-Outside	0	0
Other Income (including equity earnings)	(77,976)	(166,989)
Total Revenue and Other Income	(78,700)	(167,497)
Cost of Goods Sold and Other Operating Charges	7,190	7,044
Gas Royalty Interests Costs	(11)	(6)
Purchased Gas Costs	0	0
Related Party Activity	19,930	(8,773)
Freight Expense	0	0
Selling, General and Administrative Expenses	0	0
Depreciation, Depletion and Amortization	0	0
Interest Expense	(107)	(100)
Taxes Other Than Income	0	0
Total Costs	27,002	(1,835)
Earnings Before Income Taxes	(105,702)	(165,662)
Income Tax Expense (Benefit)	0	0
Net (Loss) Income	(105,702)
Net Income (Loss) Attributable to Noncontrolling Interest	0
Net Income (Loss) Available to Common Stockholders, Basic	(105,702)
Net Income (Loss)		$ (165,662)

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Consolidated Statements of Stockholders' Equity (USD $) In Thousands, except Per Share data, unless otherwise specified	Total	Common Stock [Member]	Capital in Excess of Par Value	Retained Earnings (Deficit)	Accumulated Other Comprehensive Income (Loss)	Common Stock in Treasury	Total CONSOL Energy Inc. Stockholders' Equity	Non-Controlling Interest
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest at Dec. 31, 2012	$ 3,953,745	$ 2,284	$ 2,296,908	$ 2,402,551	$ (747,342)	$ (609)	$ 3,953,792	$ (47)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	(1,821)	0	0	(1,564)	0	0	(1,564)	(257)
Other Comprehensive Income (Loss), Net of Tax	4,449	0	0	0	4,449	0	4,449	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,628	0	0	(1,564)	4,449	0	2,885	(257)
Proceeds from Issuance of Common Stock	909	5	904	0	0	0	909	0
Stock Issued During Period, Value, Treasury Stock Reissued	(7,459)	0	0	(7,459)	0	0	(7,459)	0
Adjustments to Additional Paid in Capital, Income Tax Benefit from Share-based Compensation	(3,658)	0	(3,658)	0	0	0	(3,658)	0
Adjustments to Additional Paid in Capital, Share-based Compensation, Requisite Service Period Recognition	26,069	0	26,069	0	0	0	26,069	0
Dividends Paid Per Share	$ 0.000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest at Mar. 31, 2013	$ 3,972,234	$ 2,289	$ 2,320,223	$ 2,393,528	$ (742,893)	$ (609)	$ 3,972,538	$ (304)

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Consolidated Statement of Comprehensive Income (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Secured Debt, Current	$ 30,119
Restricted Cash and Cash Equivalents, Noncurrent	20,383
Restricted Cash and Cash Equivalents, Current	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest [Abstract]
Net Income	(1,821)	97,196
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	45,757	59,573
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent [Abstract]
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Net of Tax	(18,595)	76,076
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Abstract]
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $29,683, $13,292, $97,760, $36,746)	22,713	47,941
Other Comprehensive Income (Loss), Net of Tax	4,449	87,708
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,628	184,904
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	257	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,885	184,904
Other Guarantors Subsidiaries [Member]
Secured Debt, Current	0
Restricted Cash and Cash Equivalents, Noncurrent	20,383
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest [Abstract]
Net Income	103,542
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	45,757	59,573
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Abstract]
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $29,683, $13,292, $97,760, $36,746)	0	0
Other Comprehensive Income (Loss), Net of Tax	45,757	59,573
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	149,299
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	149,299	213,889
Non-Guarantors
Secured Debt, Current	30,119
Restricted Cash and Cash Equivalents, Noncurrent	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest [Abstract]
Net Income	2,228
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	0	0
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Abstract]
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $29,683, $13,292, $97,760, $36,746)	0	0
Other Comprehensive Income (Loss), Net of Tax	0	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,228
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,228	3,892
Consolidation, Eliminations [Member]
Secured Debt, Current	0
Restricted Cash and Cash Equivalents, Noncurrent	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest [Abstract]
Net Income	(105,702)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	(45,757)	(59,573)
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Abstract]
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $29,683, $13,292, $97,760, $36,746)	(22,713)	(47,941)
Other Comprehensive Income (Loss), Net of Tax	(4,449)	(87,708)
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(110,151)
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(110,151)	(253,370)
Parent Issuer
Secured Debt, Current	0
Restricted Cash and Cash Equivalents, Noncurrent	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest [Abstract]
Net Income	(1,564)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	45,757	59,573
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Abstract]
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $29,683, $13,292, $97,760, $36,746)	22,713	47,941
Other Comprehensive Income (Loss), Net of Tax	4,449	87,708
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,885
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	2,885	184,904
CNX Gas Guarantor
Secured Debt, Current	0
Restricted Cash and Cash Equivalents, Noncurrent	0
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest [Abstract]
Net Income	(325)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax, Portion Attributable to Parent	0	0
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax [Abstract]
Cash Flow Hedge Gain (Loss) Reclassified to Earnings, (Net of tax: $29,683, $13,292, $97,760, $36,746)	22,713	47,941
Other Comprehensive Income (Loss), Net of Tax	(41,308)	28,135
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(41,633)
Comprehensive Income (Loss), Net of Tax, Attributable to Noncontrolling Interest	257
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	$ (41,376)	$ 35,589

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Short-Term Notes Payable

3 Months Ended

Mar. 31, 2013

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 (Adjusted EBITDA), measured quarterly. The facility includes a minimum interest coverage ratio covenant of no less than 2.50 to 1.00, measured quarterly. The interest coverage ratio was 4.42 to 1.00 at March 31, 2013. 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 2.86 to 1.00 at March 31, 2013. The facility also includes a senior secured leverage ratio covenant of not more than 2.00 to 1.00, measured quarterly. The senior secured leverage ratio was 0.09 to 1.00 at March 31, 2013. Affirmative and negative covenants in the facility limit our ability to dispose of assets, make investments, purchase or redeem CONSOL Energy common stock, pay dividends, merge with another corporation and amend, modify or restate the senior unsecured notes. At March 31, 2013 and December 31, 2012, the $1,500,000 facility had no borrowings outstanding and $100,292 of letters of credit outstanding, leaving $1,399,708 of capacity available for borrowings and the issuance of letters of credit.

CNX Gas Corporation's (CNX Gas) $1,000,000 Senior Secured Credit Agreement expires April 12, 2016. The facility is secured by substantially all of the assets of CNX Gas and its subsidiaries. CNX Gas' credit facility allows for up to $1,000,000 for borrowings and letters of credit. CNX Gas can request an additional $250,000 increase in the aggregate borrowing limit amount. Fees and interest rate spreads are based on the percentage of facility utilization, measured quarterly. Covenants in the facility limit CNX Gas’ ability to dispose of assets, make investments, pay dividends and merge with another corporation. The credit facility allows investments in joint ventures for the development and operation of gas gathering systems and provides for $600,000 of loans, advances and dividends from CNX Gas to CONSOL Energy. Investments in CONE Gathering, LLC (CONE) are unrestricted. The facility includes a maximum leverage ratio covenant of not more than 3.50 to 1.00, measured quarterly. The leverage ratio was 0.56 to 1.00 at March 31, 2013. The facility also includes a minimum interest coverage ratio covenant of no less than 3.00 to 1.00, measured quarterly. This ratio was 42.09 to 1.00 at March 31, 2013. At March 31, 2013 and December 31, 2012, the $1,000,000 facility had no borrowings outstanding and $70,203 of letters of credit outstanding, leaving $929,797 of capacity available for borrowings and the issuance of letters of credit. The average interest rate for the three months ended March 31, 2013 was 1.89%. Accrued interest of $119 and $29 is included in Other Accrued Liabilities in the Consolidated Balance Sheet at March 31, 2013 and at December 31, 2012, respectively.

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Document and Entity Information	3 Months Ended
	Mar. 31, 2013	Apr. 22, 2013
Document Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2013
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q1
Entity Registrant Name	CONSOL Energy Inc
Entity Central Index Key	0001070412
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		228,629,068

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Long-Term Debt

3 Months Ended

Mar. 31, 2013

Notes to Financial Statements [Abstract]

Long-term Debt

LONG-TERM DEBT:

	March 31, 2013		December 31, 2012
Debt:
Senior notes due April 2017 at 8.00%, issued at par value	$	1,500,000	$	1,500,000
Senior notes due April 2020 at 8.25%, issued at par value	1,250,000		1,250,000
Senior notes due March 2021 at 6.375%, issued at par value	250,000		250,000
MEDCO revenue bonds in series due September 2025 at 5.75%	102,865		102,865
Advance royalty commitments (7.43% weighted average interest rate for March 31, 2013 and December 31, 2012)	20,394		20,394
Other long-term notes maturing at various dates through 2031 (total value of $6,956 less unamortized discount of $1,411 at March 31, 2013)	5,545		5,758
	3,128,804		3,129,017
Less amounts due in one year *	4,564		4,544
Long-Term Debt	$	3,124,240	$	3,124,473

* Excludes current portion of Capital Lease Obligations of $8,789 and $8,941 at March 31, 2013 and December 31, 2012, respectively.

Accrued interest related to Long-Term Debt of $113,586 and $63,363 was included in Other Accrued Liabilities in the Consolidated Balance Sheets at March 31, 2013 and December 31, 2012, respectively.

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Consolidated Statement of Comprehensive Income (Parentheticals) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Other Comprehensive Income (Loss), Tax	$ 11,984	$ 31,380
Adjustment For Actuarially Determined Liabilities [Member]
Other Comprehensive Income (Loss), Tax	(28,250)	(35,897)
Cash Flow Hedging [Member]
Other Comprehensive Income (Loss), Tax	$ 13,966	$ (49,008)

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CWP and Workers Comp - Net Periodic Costs

3 Months Ended

Mar. 31, 2013

CWP And Workers Comp Net Periodic Cost [Abstract]

Coal Workers' Pneumoconiosis (CWP) and Workers' Compensation:

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

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

	CWP						Workers' Compensation
	Three Months Ended						Three Months Ended
	March 31,						March 31,
	2013			2012			2013			2012
Service cost	$	2,135		$	1,928		$	3,533		$	3,634
Interest cost	1,808			1,991			1,655			1,778
Amortization of actuarial gain	(4,213		)	(4,934		)	(699		)	(986		)
State administrative fees and insurance bond premiums	—			—			1,659			1,910
Legal and administrative costs	—			—			591			648
Net periodic (benefit) cost	$	(270	)	$	(1,015	)	$	6,739		$	6,984

CONSOL Energy does not expect to contribute to the CWP plan in 2013. We intend to pay benefit claims as they become due. For the three months ended March 31, 2013, $2,698 of CWP benefit claims have been paid.

CONSOL Energy does not expect to contribute to the workers’ compensation plan in 2013. We intend to pay benefit claims as they become due. For the three months ended March 31, 2013, $8,640 of workers’ compensation benefits, state administrative fees and surety bond premiums have been paid.

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Pension and OPEB - Periodic Cost

3 Months Ended

Mar. 31, 2013

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

Components of Pension and Other Postretirement Benefit Plans:

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

Components of net periodic costs 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,
	2013			2012			2013			2012
Service cost	$	5,706		$	5,153		$	4,849		$	5,200
Interest cost	8,843			9,378			29,619			35,527
Expected return on plan assets	(12,144		)	(11,627		)	—			—
Amortization of prior service cost (credits)	(408		)	(408		)	(7,804		)	(11,599		)
Recognized net actuarial loss	12,175			12,263			17,595			20,345
Settlement loss	27,115			—			—			—
Net periodic benefit cost	$	41,287		$	14,759		$	44,259		$	49,473

For the three months ended March 31, 2013, $18,560 was paid to the pension trust for pension benefits from operating cash flows. CONSOL Energy expects to contribute to the pension trust using prudent funding methods. Currently, depending on asset values and asset returns held in the trust, we expect to contribute $50,000 to the pension trust in 2013. Net periodic benefit costs are allocated to Costs of Goods Sold and Other Operating Charges and Selling, General and Administrative Expenses in the results of operations.

According to the Defined Benefit Plans Topic of the FASB Accounting Standards Codification, if the lump sum distributions made for the plan year, which for CONSOL Energy is January 1 to December 31, exceed the total of the projected service cost and interest cost for the plan year, settlement accounting is required. Lump sum payments exceeded this threshold during the first quarter of 2013. Accordingly, CONSOL Energy recognized expense of $27,115 for the quarter ended March 31, 2013 in Costs of Goods Sold and Other Operating Charges in the results of operations. The settlement charge represented a pro rata portion of the net unrecognized loss based on the percentage reduction in the projected benefit obligation due to the lump sum payments. The settlement charge noted above also resulted in a remeasurement of the pension plan at March 31, 2013. The remeasurement resulted in a change to the discount rate to 4.12% at March 31, 2013 from 4.00% at December 31, 2012. The remeasurement reduced the pension liability by $29,916. The settlement and the corresponding remeasurement of the pension plan resulted in an adjustment of $35,261 in other comprehensive income, net of $21,770 in deferred taxes. Currently, the settlement and remeasurement of the pension plan will result in a $6,760 reduction to pension expense compared to what was originally expected to be recognized for the remaining nine months of 2013. It is reasonably possible that CONSOL Energy will incur additional settlement charges in 2013, which would require the pension plan to be remeasured using updated assumptions.

CONSOL Energy does not expect to contribute to the other postemployment benefit plan in 2013. We intend to pay benefit claims as they become due. For the three months ended March 31, 2013, $41,922 of other postemployment benefits have been paid.

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Related Party Transaction

3 Months Ended

Mar. 31, 2013

Related Party Transaction [Line Items]

Related Party Transactions Disclosure [Text Block]

RELATED PARTY TRANSACTIONS:

CONE Gathering LLC Related Party Transactions

During the three months ended March 31, 2013, CONE Gathering LLC (CONE), a 50% owned affiliate, provided CNX Gas Company LLC (CNX Gas Company) gathering services in the ordinary course of business. Gathering services received from CONE were $7,327 and $3,462 for the three months ended March 31, 2013 and 2012, respectively, which were included in Cost of Goods Sold on the Consolidated Statements of Income.

As of March 31, 2013 and December 31, 2012, CONSOL Energy and CNX Gas Company had a net payable of $10,975 and $3,142, respectively, due CONE which was comprised of the following items:

	March 31,			December 31,
	2013			2012			Location on Balance Sheet
Reimbursement for CONE Expenses	$	(655	)	$	(1,336	)	Accounts Receivable–Other
Reimbursement for Services Provided to CONE	(288		)	(341		)	Accounts Receivable–Other
CONE Gathering Capital Reimbursement	—			(18		)	Accounts Receivable–Other
CONE Gathering Fee Payable	11,918			4,837			Accounts Payable
Net Payable due CONE	$	10,975		$	3,142

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2013

Notes to Financial Statements [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES:

CONSOL Energy and its subsidiaries are subject to various lawsuits and claims with respect to such matters as personal injury, wrongful death, damage to property, exposure to hazardous substances, governmental regulations including environmental remediation, employment and contract disputes and other claims and actions arising out of the normal course of business. We accrue the estimated loss for these lawsuits and claims when the loss is probable and can be estimated. Our current estimated accruals related to these pending claims, individually and in the aggregate, are immaterial to the financial position, results of operations or cash flows of CONSOL Energy. It is possible that the aggregate loss in the future with respect to these lawsuits and claims could ultimately be material to the financial position, results of operations or cash flows of CONSOL Energy; however, such amounts cannot be reasonably estimated. The amount claimed against CONSOL Energy is disclosed below when an amount is expressly stated in the lawsuit or claim, which is not often the case. The maximum aggregate amount claimed in those lawsuits and claims, regardless of probability, where a claim is expressly stated or can be estimated, exceeds the aggregate amounts accrued for all lawsuits and claims by approximately $845,000.

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

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

Ward Transformer Superfund Site: CONSOL Energy was notified in November 2004 by the EPA that it is a potentially responsible party (PRP) under the Superfund program established by the Comprehensive Environmental Response, Compensation and Liability Act of 1980, as amended (CERCLA), with respect to the Ward Transformer site in Wake County, North Carolina. The EPA, CONSOL Energy and two other PRPs entered into an administrative Settlement Agreement and Order of Consent, requiring those PRPs to undertake and complete a PCB soil removal action, at and in the vicinity of the Ward Transformer property. In June 2008, while conducting the PCB soil excavation on the Ward property, it was determined that PCBs have migrated onto adjacent properties and in September 2008, the EPA notified CONSOL Energy and 60 other companies that they are PRPs for these additional areas. The current estimated cost of remedial action for the area CONSOL Energy was originally named a PRP, including payment of the EPA's past and future cost, is approximately $65,000. The current estimated cost of the most likely remediation plan for the additional areas discovered is approximately $11,000. CONSOL Energy recognized no expense in Cost of Goods Sold and Other charges in the three months ended March 31, 2013 and 2012, respectively. Also, CONSOL Energy has provided funding to an independent trust established for this remediation. No funding was made in the three months ended March 31, 2013 or 2012, respectively. As of March 31, 2013, CONSOL Energy and the other participating PRPs had asserted CERCLA cost recovery and contribution claims against approximately 225 nonparticipating PRPs to recover a share of the costs incurred and to be incurred to conduct the removal actions at the Ward Site. CONSOL Energy's portion of recoveries from settled claims is $4,393. Accordingly, the liability reflected in Other Accrued Liabilities was reduced by these settled claims. The remaining net liability at March 31, 2013 is $3,167.

Asbestos-Related Litigation: One of our subsidiaries, Fairmont Supply Company (Fairmont), which distributes industrial supplies, currently is named as a defendant in approximately 6,900 asbestos-related claims in state courts in Pennsylvania, Ohio, West Virginia, Maryland, Texas and Illinois. Because a very small percentage of products manufactured by third parties and supplied by Fairmont in the past may have contained asbestos and many of the pending claims are part of mass complaints filed by hundreds of plaintiffs against a hundred or more defendants, it has been difficult for Fairmont to determine how many of the cases actually involve valid claims or plaintiffs who were actually exposed to asbestos-containing products supplied by Fairmont. In addition, while Fairmont may be entitled to indemnity or contribution in certain jurisdictions from manufacturers of identified products, the availability of such indemnity or contribution is unclear at this time, and in recent years, some of the manufacturers named as defendants in these actions have sought protection from these claims under bankruptcy laws. Fairmont has no insurance coverage with respect to these asbestos cases. Based on over 15 years of experience with this litigation, we have established an accrual to cover our estimated liability for these cases. This accrual is immaterial to the overall financial position of CONSOL Energy and is included in Other Accrued Liabilities on the Consolidated Balance Sheet. Past payments by Fairmont with respect to asbestos cases have not been material.

Ryerson Dam Litigation: In 2008, the Pennsylvania Department of Conservation and Natural Resources (the Commonwealth) filed a six-count Complaint in the Court of Common Pleas of Allegheny County, Pennsylvania, claiming that the Company's underground longwall mining activities at its Bailey Mine caused cracks and seepage damage to the Ryerson Park Dam. The Commonwealth subsequently breached the dam, thereby eliminating the Ryerson Park Lake. The Commonwealth claimed that the Company is liable for dam reconstruction costs, lake restoration costs and natural resource damages totaling $58,000. In October 2008, the Common Pleas Court ruled that natural resource damages were not recoverable and referred the Commonwealth's claim to the Pennsylvania Department of Environmental Protection (DEP). 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. 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 challenge 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. See Note 18 - Subsequent Events for additional information.

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

Hale Litigation: A purported class action lawsuit was filed on September 23, 2010 in the U.S. District Court in Abingdon, Virginia styled Hale v. CNX Gas Company, et. al. The lawsuit alleges that the plaintiff class consists of forced-pooled unleased gas owners whose gas ownership is in conflict, the Virginia Supreme Court and General Assembly have decided that coalbed methane (CBM) belongs to the owner of the gas estate, the Virginia Gas and Oil Act of 1990 unconstitutionally provides only a 1/8 net proceeds royalty to CBM owners for gas produced under the forced-pooled orders, and CNX Gas Company relied upon control of only the coal estate in force pooling the CBM notwithstanding decisions by the Virginia Supreme Court. The lawsuit seeks a judicial declaration of ownership of the CBM and that the entire net proceeds of CBM production (that is, the 1/8 royalty and the 7/8 of net revenues since production began) be distributed to the class members. The lawsuit also alleges CNX Gas Company failed to either pay royalties due conflicting claimant, deemed lessors or paid them less than required because of the alleged practice of improper below market sales and/or taking alleged improper post-production deductions. The Magistrate Judge issued a Report and Recommendation in which she recommended that the District Judge decide that the deemed lease provision of the Gas and Oil Act is constitutional as is the 1/8 royalty. The Magistrate Judge recommended against the dismissal of certain other claims. The District Judge affirmed the Magistrate Judge's recommendations in their entirety. An amended complaint was filed, which added additional allegations that include gas hedging receipts should have been used as the basis for royalty payments, severance tax should not be allowed as a post-production deduction from royalties, and damages incurred because gas was produced prior to the entry of pooling orders. A motion to dismiss the Amended Complaint was filed and denied. The Magistrate Judge heard oral arguments on plaintiff's Motion for Class Certification on November 30, 2012 and has not yet issued a Report and Recommendation. Discovery is proceeding in this litigation. CONSOL Energy believes that the case has meritorious defenses and intends to defend it vigorously. We have established an accrual to cover our estimated liability for this case. This accrual is immaterial to the overall financial position of CONSOL Energy and is included in Other Accrued Liabilities on the Consolidated Balance Sheet.

Addison Litigation: A purported class action lawsuit was filed on April 28, 2010 in the United States District Court in Abingdon, Virginia styled Addison v. CNX Gas Company, et al.  The lawsuit alleges that the plaintiff class consists of gas lessors whose gas ownership is in conflict. The lawsuit alleges that the Virginia Supreme Court and General Assembly have decided that the plaintiff owns the gas and is entitled to royalties held in escrow by the Commonwealth of Virginia or CNX.  The lawsuit also alleges CNX Gas failed to either pay royalties due these conflicting claimant lessors or paid them less than required because of the alleged practice of improper below market sales and/or taking alleged improper post-production deductions. Plaintiff seeks a declaratory judgment regarding ownership, an accounting and compensatory and punitive damages for breach of contract; conversion; negligence (voluntary undertaking) for improperly asserting that conflicting ownership exists, negligence (breach of duties as an operator); breach of fiduciary duties; and unjust enrichment. The Magistrate Judge issued a Report and Recommendation recommending dismissing some claims and allowing others to proceed. The District Judge affirmed the Magistrate Judge's recommendations in their entirety. An Amended Complaint was filed which added an additional allegation that gas hedging receipts should have been used as the basis for royalty payments. A motion to dismiss those claims was filed and was denied. The Magistrate Judge heard oral arguments on plaintiff's Motion for Class Certification on November 30, 2012 and has not yet issued a Report and Recommendation. Discovery is proceeding in this litigation. CONSOL Energy believes that the case has meritorious defenses and intends to defend it vigorously. We have established an accrual to cover our estimated liability for this case. This accrual is immaterial to the overall financial position of CONSOL Energy and is included in Other Accrued Liabilities on the Consolidated Balance Sheet.

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

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

The following royalty and land right lawsuits and claims include those for which a loss is reasonably possible, but not probable, and accordingly, no accrual has been recognized. These claims are influenced by many factors which prevent the estimation of a range of potential loss. These factors include, but are not limited to, generalized allegations of unspecified damages (such as improper deductions), discovery having not commenced or not having been completed, unavailability of expert reports on damages and non-monetary issues are being tried. For example, in instances where a gas lease termination is sought, damages would depend on speculation as to if and when the gas production would otherwise have occurred, how many wells would have been drilled on the lease premises, what their production would be, what the cost of production would be, and what the price of gas would be during the production period. An estimate is calculated, if applicable, when sufficient information becomes available.

Ratliff: On March 22, 2012, the Company was served with four complaints filed on May 31, 2011 by four individuals against CCC, ICCC, CNX Gas Company, subsidiaries of CONSOL Energy, as well as CONSOL Energy itself in the Circuit Court of Russell County, Virginia. The complaints seek damages and injunctive relief in connection with the deposit of water from mining activities at CCC's Buchanan Mine into nearby void spaces at some of the mines of ICCC. The suits allege damage to coal and coalbed methane and seek recovery in tort, contract and assumpsit (quasi-contract). The cases were removed to federal court, motions to dismiss were filed by CCC, and then were voluntarily dismissed by the plaintiffs. On January 30, 2013, the four plaintiffs filed a single consolidated complaint in the United States District Court for the Western District of Virginia, alleging the same damage and theories of recovery for storage of water in the mine voids ostensibly underlying their property. The suit seeks damages ranging from $4,000 to $8,000 plus punitive damages. Service was effected by April 1, 2013 by waiver, and defendants' responsive pleadings are due May 31, 2013. CONSOL energy intends to vigorously defend the suit.

Hall Litigation: A purported class action lawsuit was filed on December 23, 2010 styled Hall v. CONSOL Gas Company in Allegheny County Pennsylvania Common Pleas Court.  The named plaintiff is Earl D. Hall.  The purported class plaintiffs are all Pennsylvania oil and gas lessors to Dominion Exploration and Production Company, whose leases were acquired by CONSOL Energy.  The complaint alleges more than 1,000 similarly situated lessors.  The lawsuit alleges that CONSOL Energy incorrectly calculated royalties by (i) calculating line loss on the basis of allocated volumes rather than on a well-by-well basis, (ii) possibly calculating the royalty on the basis of an incorrect price, (iii) possibly taking unreasonable deductions for post-production costs and costs that were not arms-length, (iv) not paying royalties on gas lost or used before the point of sale, and (v) not paying royalties on oil production. The complaint also alleges that royalty statements were false and misleading.  The complaint seeks damages, interest and an accounting on a well-by-well basis. CONSOL Energy believes that the case is without merit and intends to defend it vigorously. Consequently, we have not recognized any liability related to these actions.

    Kennedy Litigation: The Company is a party to a case filed on March 26, 2008 captioned Earl Kennedy (and others) v. CNX Gas Company and CONSOL Energy in the Court of Common Pleas of Greene County, Pennsylvania. The lawsuit alleges that CNX Gas Company and CONSOL Energy trespassed and converted gas and other minerals allegedly belonging to the plaintiffs in connection with wells drilled by CNX Gas Company. The complaint, as amended, seeks injunctive relief, including removing CNX Gas Company from the property, and compensatory damages of $20,000. The suit also sought to overturn existing law as to the ownership of coalbed methane in Pennsylvania, but that claim was dismissed by the court; the plaintiffs are seeking to appeal that dismissal. The suit also seeks a determination that the Pittsburgh 8 coal seam does not include the “roof/rider” coal. The court denied the plaintiff's summary judgment motion on that issue. The court held a bench trial on the “roof/rider” coal issue in November 2011 and ruled for CNX Gas Company and CONSOL Energy, holding that the “roof/rider” coal is included in the Pittsburgh 8 coal seam. The plaintiffs have indicated that they intend to appeal that decision. A trial on the issue of whether a drilling that deviates from the coal seam results in damage to the gas owner is now scheduled for October 21, 2013. CNX Gas Company and CONSOL Energy believe this lawsuit to be without merit and intend to vigorously defend it. Consequently, we have not recognized any liability related to these actions.

Rowland Litigation: Rowland Land Company filed a complaint in May 2011 against CONSOL Energy, CNX Gas Company, Dominion Resources, and EQT Production Company (EQT) in Raleigh County Circuit Court, West Virginia. Rowland is the lessor on a 33,000 acre oil and gas lease in southern West Virginia. EQT was the original lessee, but farmed out the development of the lease to Dominion Resources in exchange for an overriding royalty. Dominion Resources sold the indirect subsidiary that held the lease to a subsidiary of CONSOL Energy on April 30, 2010. Subsequent to that acquisition, the subsidiary that held the lease was merged into CNX Gas Company as part of an internal reorganization. Rowland alleges that (i) Dominion Resources' sale of the subsidiary to CONSOL Energy was a change in control that required its consent under the terms of the farmout agreement and lease, and/or (ii) the subsequent merger of the subsidiary into CNX Gas Company was an assignment that required its consent under the lease. Rowland has amended its complaint twice to include allegations that CONSOL Energy and Dominion Resources are liable for their subsidiaries' actions and that Rowland's title has been slandered. Motions to dismiss have been denied, discovery is proceeding but stayed pending mediation. Initial mediation efforts have been unsuccessful but are continuing. CONSOL Energy believes that the case is without merit and intends to defend it vigorously. Consequently, we have not recognized any liability related to these actions.

Majorsville Storage Field Declaratory Judgment: On March 3, 2011, an attorney sent a letter to CNX Gas Company regarding certain leases that CNX Gas Company obtained from Columbia Gas in Greene County, Pennsylvania involving the Majorsville Storage Field. The letter was written on behalf of three lessors alleging that the leases totaling 525 acres are invalid, and had expired by their terms. The plaintiffs' theory is that the rights of storage and production are severable under the leases. Ignoring the fact that the leases have been used for gas storage, they claim that since there has been no production or development of production, the right to produce gas expired at the end of the primary terms. On June 16, 2011, in the Court of Common Pleas of Greene County, Pennsylvania, the Company filed a declaratory judgment action, seeking to have a court confirm the validity of the leases. 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, 2013, CONSOL Energy has provided the following financial guarantees, unconditional purchase obligations and letters of credit to certain third parties, as described by major category in the following table. These amounts represent the maximum potential total of future payments that we could be required to make under these instruments. These amounts have not been reduced for potential recoveries under recourse or collateralization provisions. Generally, recoveries under reclamation bonds would be limited to the extent of the work performed at the time of the default. No amounts related to these financial guarantees and letters of credit are recorded as liabilities on the financial statements. CONSOL Energy management believes that these guarantees will expire without being funded, and therefore the commitments will not have a material adverse effect on financial condition.

	Amount of Commitment Expiration Per Period
	Total Amounts Committed		Less Than 1  Year		1-3 Years		3-5 Years		Beyond 5  Years
Letters of Credit:
Employee-Related	$	190,158	$	126,654	$	63,504	$	—	$	—
Environmental	56,293		34,346		21,947		—		—
Other	83,398		46,452		36,946		—		—
Total Letters of Credit	329,849		207,452		122,397		—		—
Surety Bonds:
Employee-Related	204,884		204,884		—		—		—
Environmental	533,974		524,072		9,902		—		—
Other	29,487		29,476		11		—		—
Total Surety Bonds	768,345		758,432		9,913		—		—
Total Commitments	$	1,098,194	$	965,884	$	132,310	$	—	$	—

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

CONSOL Energy and CNX Gas enter into long-term unconditional purchase obligations to procure major equipment purchases, natural gas firm transportation, gas drilling services and other operating goods and services. These purchase obligations are not recorded on the Consolidated Balance Sheet. As of March 31, 2013, the purchase obligations for each of the next five years and beyond were as follows:

Obligations Due	Amount
Less than 1 year	$	349,513
1 - 3 years	227,586
3 - 5 years	128,338
More than 5 years	414,276
Total Purchase Obligations	$	1,119,713

Costs related to these purchase obligations include:

	Three Months Ended
	March, 31
	2013		2012
Major equipment purchases	$	33,426	$	13,166
Firm transportation expense	28,525		15,045
Gas drilling obligations	28,863		29,576
Other	—		298
Total costs related to purchase obligations	$	90,814	$	58,085

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Accounts Receivable Securitization

3 Months Ended

Mar. 31, 2013

ACCOUNTS RECEIVABLE SECURITIZATION: [Abstract]

Accounts Receivable Securitization

ACCOUNTS RECEIVABLE SECURITIZATION:

CONSOL Energy and certain of our U.S. subsidiaries are party to a trade accounts receivable facility with financial institutions for the sale on a continuous basis of eligible trade accounts receivable. The facility allows CONSOL Energy to receive on a revolving basis up to $200,000. The facility also allows for the issuance of letters of credit against the $200,000 capacity. At March 31, 2013, there were letters of credit outstanding against the facility of $159,281. CONSOL Energy management believes that these guarantees will expire without being funded, and therefore the commitments will not have a material adverse effect on the Company's financial condition. No amounts related to these financial guarantees and letters of credit are recorded as liabilities on the financial statements.

CNX Funding Corporation, a wholly owned, special purpose, bankruptcy-remote subsidiary, buys and sells eligible trade receivables generated by certain subsidiaries of CONSOL Energy. Under the receivables facility, CONSOL Energy and certain subsidiaries, irrevocably and without recourse, sell all of their eligible trade accounts receivable to CNX Funding Corporation, who in turn sells these receivables to financial institutions and their affiliates, while maintaining a subordinated interest in a portion of the pool of trade receivables. This retained interest, which is included in Accounts and Notes Receivable Trade in the Consolidated Balance Sheets, is recorded at fair value. Due to a short average collection cycle for such receivables, our collection experience history and the composition of the designated pool of trade accounts receivable that are part of this program, the fair value of our retained interest approximates the total amount of the designated pool of accounts receivable. CONSOL Energy will continue to service the sold trade receivables for the financial institutions for a fee based upon market rates for similar services.

In accordance with the Transfers and Servicing Topics of the Financial Accounting Standards Board (FASB) Accounting Standards Codification, CONSOL Energy records transactions under the securitization facility as secured borrowings on the Consolidated Balance Sheets. The pledge of collateral is reported as Accounts Receivable - Securitized and the borrowings are classified as debt in Borrowings under Securitization Facility.

The cost of funds under this facility is based upon commercial paper rates, plus a charge for administrative services paid to the financial institutions. Costs associated with the receivables facility totaled $472 and $419 for the three months ended March 31, 2013 and 2012, respectively. These costs have been recorded as financing fees which are included in Cost of Goods Sold and Other Operating Charges in the Consolidated Statements of Income. No servicing asset or liability has been recorded. The receivables facility expires in March 2017 with the underlying liquidity agreement renewing annually each March.

At March 31, 2013 and December 31, 2012, eligible accounts receivable totaled $199,800 and $200,000, respectively. There was subordinated retained interest of $10,400 at March 31, 2013. There was no subordinated retained interest at December 31, 2012. There were $30,119 borrowings under the Securitization Facility recorded on the Consolidated Balance Sheet as of March 31, 2013 and $37,846 at December 31, 2012. The accounts receivable securitization program decreased by $7,727 in the three months ended March 31, 2013 and there was no change in the three months ended March 31, 2012. The decrease is reflected in the Net Cash Used in Financing Activities in the Consolidated Statement of Cash Flows. In accordance with the facility agreement, the Company is able to receive proceeds based upon the eligible accounts receivable at the previous month end.

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Derivative Instruments (Details) (Cash Flow Hedging [Member], Price Swaps, Natural Gas, USD $)	3 Months Ended
	Mar. 31, 2013 MMcf	Dec. 31, 2010
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Notional Amount of Outstanding Natural Gas Forward Contracts (in MMcf)	147,400
Unrealized Gain Expected to be Reclassified from Other Comprehensive Income and into Earnings During the Next Twelve Months	$ 20,494,000
Derivative Assets Designated as Hedging Instruments	83,677,000	135,969,000
Derivative Liabilities Designated as Hedging Instruments	20,949,000	7,024,000
Prepaid Expenses
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative Assets, Current	46,837,000	80,057,000
Other Assets
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative Assets, Noncurrent	36,840,000	55,912,000
Other Accrued Liabilities [Member]
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative Assets, Current	10,877,000	970,000
Other Liabilities [Member]
Derivative Instruments and Hedging Activities Disclosure [Line Items]
Derivative Liabilities, Noncurrent	$ 10,072,000	$ 6,054,000

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Income Taxes

3 Months Ended

Mar. 31, 2013

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,
	2013					2012
	Amount			Percent		Amount			Percent
Statutory U.S. federal income tax rate	$	(455	)	35.0	%	$	41,502		35.0	%
Impact of excess tax depletion	1,428			(109.9	)	(26,514		)	(22.4	)
Net effect of state income taxes	(179		)	13.7		3,510			3.0
Other	(272		)	21.0		2,883			2.4
Income Tax Expense / Effective Rate	$	522		(40.2	)%	$	21,381		18.0	%

The effective rates for the three months ended March 31, 2013 and 2012 were calculated using the annual effective rate projection on recurring earnings and include tax liabilities related to certain discrete transactions which are described below. The effective tax rate is sensitive to changes in annual profitability and percentage depletion.

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, 2013 and 2012 were $22,770 and $25,570, respectively. If these uncertain tax positions were recognized, approximately $2,071 and $3,891, respectively, would affect CONSOL Energy’s effective tax rate. There were no additions to the liability for unrecognized tax benefits during the three months ended March 31, 2013 and 2012.

CONSOL Energy recognizes interest accrued related to uncertain tax positions in its interest expense. As of March 31, 2013 and 2012, the Company reported an accrued interest liability relating to uncertain tax positions of $5,165 and $5,741, respectively. The accrued interest liability includes interest expense that is reflected in the Company’s Consolidated Statements of Income for the three months ended March 31, 2013 and 2012 of $335 and $368, respectively.

CONSOL Energy recognizes penalties related to uncertain tax positions in its income tax expense. As of March 31, 2013 and 2012, 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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Inventories

3 Months Ended

Mar. 31, 2013

INVENTORIES: [Abstract]

Inventories

INVENTORIES:

Inventory components consist of the following:

	March 31, 2013		December 31, 2012
Coal	$	51,954	$	78,825
Merchandise for resale	35,120		35,363
Supplies	129,960		133,578
Total Inventories	$	217,034	$	247,766

Inventories are stated at the lower of cost or market. The cost of coal inventories is determined by the first-in, first-out (FIFO) method. Coal inventory costs include labor, supplies, equipment costs, operating overhead, depreciation, depletion and amortization, and other related costs.

Merchandise for resale is valued using the last-in, first-out (LIFO) cost method. The excess of replacement cost of merchandise for resale inventories over carrying LIFO value was $19,726 and $19,700 at March 31, 2013 and December 31, 2012, respectively.

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Property, Plant and Equipment

3 Months Ended

Mar. 31, 2013

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

PROPERTY, PLANT AND EQUIPMENT:

	March 31, 2013		December 31, 2012
Coal and other plant and equipment	$	6,032,128	$	6,030,620
Intangible drilling cost	1,623,391		1,550,297
Proven gas properties	1,600,532		1,596,838
Coal properties and surface lands	1,351,271		1,346,151
Unproven gas properties	1,321,108		1,266,017
Gas gathering equipment	1,024,952		1,006,882
Airshafts	711,586		706,388
Mine development	561,288		537,939
Leased coal lands	529,741		529,758
Gas wells and related equipment	508,768		492,367
Coal advance mining royalties	394,438		391,501
Other gas assets	82,094		82,217
Gas advance royalties	8,226		8,229
Total Property Plant and Equipment	15,749,523		15,545,204
Less: Accumulated DD&A	5,516,319		5,354,237
Total Net PP&E	$	10,233,204	$	10,190,967

Industry Participation Agreements

CONSOL Energy has two significant industry participation agreements (referred to as "joint ventures" or "JVs") that provided drilling and completion carries for our retained interests.

On October 21, 2011, CNX Gas Company, a wholly owned subsidiary of CONSOL Energy, completed a sale to Hess Ohio Developments, LLC (Hess) of 50% of nearly 200 thousand net Utica Shale acres in Ohio. As part of the transaction, 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. Under the asset acquisition agreement, Hess had the right to perform due diligence on the title to the oil and gas interests which we conveyed to them and Hess's aggregate carried cost obligation under the joint venture agreements would be reduced by the value the parties allocated in the transaction to the acreage which subsequently proved to be defective. Based on title work performed by Hess as part of the title defect process, we believe that there are chain of title issues with respect to approximately 38 thousand of the joint venture acres (with a carry value of approximately $153,000), most of which likely cannot be cured. We are currently in discussions with Hess regarding an agreement to finally resolve the title defect process. If we are unable to reach an agreement, the title defects that Hess formally asserts will be resolved in arbitration in accordance with the asset acquisition agreement.

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. As part of the transaction, CNX Gas Company also received a commitment from Noble to pay one-third of the Company's working interest share of certain drilling and completion costs, up to approximately $2,100,000 with certain restrictions. These restrictions include the suspension of carry if average Henry Hub natural gas prices are below $4.00 per million British thermal units (MMBtu) for three consecutive months. The carry is currently suspended and will remain suspended until average natural gas prices are above $4.00/MMBtu for three consecutive months. Restrictions also include a $400,000 annual maximum on Noble's carried cost obligation. The aggregate amount of the drilling carry may also be adjusted downward under provisions of the joint venture agreements in certain events.

Under our joint venture agreement with Noble, Noble had the right to perform due diligence on the title to the oil and gas interests which we conveyed to them and to assert that title to the acreage is defective. CONSOL Energy can then review and respond to the asserted title defects, or cure them, and ultimately, if the claim is not resolved, either party can submit the defect to an arbitrator for resolution. If Noble establishes any title defects which are either not resolved in favor of CONSOL Energy or cured by us, then subject to certain deductibles, Noble's aggregate carried cost obligation under the joint venture agreement will be reduced by the value the parties previously allocated to the affected acreage in the transaction. If a significant percentage of the oil and gas interests we contributed have title defects which cannot be resolved or cured, the carried costs could be materially reduced and our aggregate share of the drilling and completion costs for wells in this joint venture could materially increase. Pursuant to the joint venture agreement, Noble Energy has submitted a final title defect notice to CONSOL Energy. Based on our review of this title defect notice, Noble has asserted title defects with respect to approximately 93 thousand gross deal acres, having a carry value of approximately $610,000, which we have not yet addressed. We are working closely with Noble to address these alleged defects and we believe that we will resolve or cure most of these defects favorably to CONSOL Energy. To date, we have conceded defects which have an aggregate value of approximately $37,000 in excess of the applicable deductible, and will attempt to cure as many of those defects as possible. The impact of these conceded defects on the Company's financial statements was $6,310 for the three months ended March 31, 2013.

The following table provides information about our industry participation agreements as of March 31, 2013:

Shale Play	Industry Participation Agreement Partner	Industry Participation Agreement Date	Drilling Carries Remaining*
Marcellus	Noble Energy, Inc.	September 30, 2011	$	2,052,790
Utica	Hess Ohio Developments, LLC	October 21, 2011	$	496,723

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

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Industry Segment Results (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Dec. 31, 2012
Segment Reporting Information [Line Items]
Sales-Outside	$ 1,226,165	$ 1,311,471
Sales-Purchased Gas	1,358	839
Sales-Gas Royalty Interests	14,204	12,206
Freight-Outside	14,061	49,293
Segment Reporting Information, Intersegment Revenue	0	0
Total Sales and Freight	1,255,788	1,373,809
Earnings Before Income Taxes	(1,299)	118,577
Total Assets	12,593,194	12,595,611	12,670,909
Depreciation, Depletion and Amortization	161,315	155,347
Capital Expenditures	405,972	306,446
Equity in Earnings of Unconsolidated Affiliates	(4,797)	(7,935)
Investments in Unconsolidated Equity Affiliates	248,127		222,830
Total Reportable Business Segments
Segment Reporting Information [Line Items]
Earnings Before Income Taxes	92,862	174,970
Total Assets	11,578,492	11,471,162
Coal
Segment Reporting Information [Line Items]
Sales-Outside	972,385	1,054,316
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	14,061	49,293
Segment Reporting Information, Intersegment Revenue	0	0
Total Sales and Freight	986,446	1,103,609
Earnings Before Income Taxes	93,502	162,470
Total Assets	5,698,504	5,360,577
Depreciation, Depletion and Amortization	102,711	100,762
Capital Expenditures	197,338	194,429
Equity in Earnings of Unconsolidated Affiliates	817	4,807
Investments in Unconsolidated Equity Affiliates	20,334	39,373
Gas
Segment Reporting Information [Line Items]
Sales-Outside	167,842	160,203
Sales-Purchased Gas	1,358	839
Sales-Gas Royalty Interests	14,204	12,206
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	836	466
Total Sales and Freight	184,240	173,714
Earnings Before Income Taxes	(640)	12,500
Total Assets	5,879,988	6,110,585
Depreciation, Depletion and Amortization	52,399	48,803
Capital Expenditures	207,130	98,455
Equity in Earnings of Unconsolidated Affiliates	3,182	1,944
Investments in Unconsolidated Equity Affiliates	167,058	108,858
All Other Segments [Member]
Segment Reporting Information [Line Items]
Sales-Outside	85,938	96,952
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	35,477	37,209
Total Sales and Freight	121,415	134,161
Earnings Before Income Taxes	(40,552)	4,083
Total Assets	358,663	358,746
Depreciation, Depletion and Amortization	6,205	5,782
Capital Expenditures	1,504	13,562
Intersegment 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
Segment Reporting Information, Intersegment Revenue	(36,313)	(37,675)
Total Sales and Freight	(36,313)	(37,675)
Earnings Before Income Taxes	(53,609)	(60,476)
Total Assets	656,039	765,703
Depreciation, Depletion and Amortization	0	0
Capital Expenditures	0	0
All Other
Segment Reporting Information [Line Items]
Equity in Earnings of Unconsolidated Affiliates	798	1,184
Investments in Unconsolidated Equity Affiliates	60,735	51,990
Steam [Member] | Coal
Segment Reporting Information [Line Items]
Sales-Outside	761,272	812,053
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	0	0
Total Sales and Freight	761,272	812,053
Earnings Before Income Taxes	128,432	128,449
Low Volatile Metallurgical [Member] | Coal
Segment Reporting Information [Line Items]
Sales-Outside	146,828	172,740
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	0	0
Total Sales and Freight	146,828	172,740
Earnings Before Income Taxes	54,717	79,341
High Volatile Metallurgical [member] | Coal
Segment Reporting Information [Line Items]
Sales-Outside	58,622	60,568
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	0	0
Total Sales and Freight	58,622	60,568
Earnings Before Income Taxes	13,352	15,936
Other Coal [Member] | Coal
Segment Reporting Information [Line Items]
Sales-Outside	5,663	8,955
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	14,061	49,293
Segment Reporting Information, Intersegment Revenue	0	0
Total Sales and Freight	19,724	58,248
Earnings Before Income Taxes	(102,999)	(61,256)
Coalbed Methane [Member] | Gas
Segment Reporting Information [Line Items]
Sales-Outside	83,640	99,535
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	0	0
Total Sales and Freight	83,640	99,535
Earnings Before Income Taxes	21,312	36,390
Marcellus Shale [Member] | Gas
Segment Reporting Information [Line Items]
Sales-Outside	48,411	23,791
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	0	0
Total Sales and Freight	48,411	23,791
Earnings Before Income Taxes	13,768	3,251
Conventional Gas [Member] | Gas
Segment Reporting Information [Line Items]
Sales-Outside	32,436	34,373
Sales-Purchased Gas	0	0
Sales-Gas Royalty Interests	0	0
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	0	0
Total Sales and Freight	32,436	34,373
Earnings Before Income Taxes	(4,161)	(3,722)
Other Gas | Gas
Segment Reporting Information [Line Items]
Sales-Outside	3,355	2,504
Sales-Purchased Gas	1,358	839
Sales-Gas Royalty Interests	14,204	12,206
Freight-Outside	0	0
Segment Reporting Information, Intersegment Revenue	836	466
Total Sales and Freight	19,753	16,015
Earnings Before Income Taxes	(31,559)	(23,419)
First Energy [Member] | Coal
Segment Reporting Information [Line Items]
Entity-Wide Revenue, Major Customer, Amount	170,982	144,155
XCoal Energy and Resources [Member] | Coal
Segment Reporting Information [Line Items]
Entity-Wide Revenue, Major Customer, Amount	$ 183,121	$ 138,341

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Reconciliation of Segment Information, Total Assets (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012
Assets:
Assets	$ 12,593,194	$ 12,670,909	$ 12,595,611
Items excluded from segment assets:
Recoverable Income Taxes	6,602	0
Total Reportable Business Segments
Assets:
Assets	11,578,492		11,471,162
Coal
Assets:
Assets	5,698,504		5,360,577
Gas
Assets:
Assets	5,879,988		6,110,585
All Other Segments [Member]
Assets:
Assets	358,663		358,746
Excludes Gas Segment [Member]
Items excluded from segment assets:
Cash and Other Investments	23,669		121,807
Intersegment Elimination [Member]
Assets:
Assets	656,039		765,703
Items excluded from segment assets:
Recoverable Income Taxes	6,602		0
Deferred Tax Assets	585,829		596,657
Bond Issuance Costs	$ 39,939		$ 47,239

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Carrying Amounts and Fair Values of Financial Instruments for Which the Fair Value Option Was Not Elected (Details) (USD $)	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012	Dec. 31, 2011
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]
Cash and Cash Equivalents	$ 25,058,000	$ 21,878,000	$ 287,313,000	$ 375,736,000
Notes and Loans Payable, Current	0	(25,073,000)
Secured Debt, Current	(30,119,000)	(37,846,000)
Long-term debt	(3,128,804,000)	(3,129,017,000)
Carrying Amount
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]
Cash and Cash Equivalents	25,058,000	21,878,000
Restricted cash	20,383,000	68,673,000
Long-term debt	(3,128,804,000)	(3,129,017,000)
Fair Value
Fair Value, Option, Disclosures Related to Election, Items Existing at Effective Date [Line Items]
Cash and Cash Equivalents	25,058,000	21,878,000
Restricted cash	20,383,000	68,673,000
Long-term debt	$ (3,396,271,000)	$ (3,378,058,000)

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Derivative Instruments (Tables)

3 Months Ended

Mar. 31, 2013

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,
	2013			2012
Natural Gas Price Swaps
Beginning Balance – Accumulated OCI	$	76,761		$	151,780
Gain/(Loss) recognized in Accumulated OCI	$	(18,595	)	$	76,076
Less: Gain reclassified from Accumulated OCI into Outside Sales	$	22,713		$	47,941
Ending Balance – Accumulated OCI	$	35,453		$	179,915
Gain/(Loss) recognized in Outside Sales for ineffectiveness	$	1,041		$	(835	)

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

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Inventory Components (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012
Schedule of Inventory [Line Items]
Coal	$ 51,954	$ 78,825
Merchandise for resale	35,120	35,363
Supplies	129,960	133,578
Total Inventories	217,034	247,766
Excess of replacement cost of merchandise for resl inventories over carrying LIFO value	$ 19,726	$ 19,700

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Fair Value of Financial Instruments

3 Months Ended

Mar. 31, 2013

Notes to Financial Statements [Abstract]

Fair Value of Financial Instruments

FAIR VALUE OF FINANCIAL INSTRUMENTS:

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

	Fair Value Measurements at March 31, 2013						Fair Value Measurements at December 31, 2012
Description	Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Quoted Prices in Active Markets for Identical Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
Gas Cash Flow Hedges	$	—	$	62,728	$	—	$	—	$	128,945	$	—

The following methods and assumptions were used to estimate the fair value for which the fair value option was not elected:

Cash and cash equivalents: The carrying amount reported in the balance sheets for cash and cash equivalents approximates its fair value due to the short-term maturity of these instruments.

Restricted cash: The carrying amount reported in the balance sheets for restricted cash approximates its fair value due to the short-term maturity of these instruments.

Short-term notes payable: The carrying amount reported in the balance sheets for short-term notes payable approximates its fair value due to the short-term maturity of these instruments.

Borrowings under Securitization Facility: The carrying amount reported in the balance sheets for borrowings under the securitization facility approximates its fair value due to the short-term maturity of these instruments.

Long-term debt: The fair value of long-term debt is measured using unadjusted quoted market prices or estimated using discounted cash flow analyses. The discounted cash flow analyses are based on current market rates for instruments with similar cash flows.

The carrying amounts and fair values of financial instruments for which the fair value option was not elected are as follows:

	March 31, 2013						December 31, 2012
	Carrying Amount			Fair Value			Carrying Amount			Fair Value
Cash and Cash Equivalents	$	25,058		$	25,058		$	21,878		$	21,878
Restricted Cash	$	20,383		$	20,383		$	68,673		$	68,673
Short-Term Notes Payable	$	—		$	—		$	(25,073	)	$	(25,073	)
Borrowings Under Securitization Facility	$	(30,119	)	$	(30,119	)	$	(37,846	)	$	(37,846	)
Long-Term Debt	$	(3,128,804	)	$	(3,396,271	)	$	(3,129,017	)	$	(3,378,058	)

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Basis of Presentation (Tables)

3 Months Ended

Mar. 31, 2013

BASIS OF PRESENTATION: [Abstract]

Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]

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

	Three Months Ended March 31,
	2013			2012
Net (Loss) Income Attributable to CONSOL Energy Inc. Shareholders	$	(1,564	)	$	97,196
Weighted average shares of common stock outstanding:
Basic	228,318,123			227,269,269
Effect of stock-based compensation awards	—			2,854,742
Dilutive	228,318,123			230,124,011
Earnings per share:
Basic	$	(0.01	)	$	0.43
Dilutive	$	(0.01	)	$	0.42

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]

The table below sets forth the share-based awards that have been excluded from the computation of the diluted earnings per share because their effect would be anti-dilutive:

	Three Months Ended March 31,
	2013	2012
Anti-Dilutive Options	5,011,771	1,574,922
Anti-Dilutive Restricted Stock Units	1,459,228	12,203
Anti-Dilutive Performance Share Units	700,040	—
Anti-Dilutive Performance Share Options	602,101	100,350
Anti-Dilutive CONSOL Share Units	891,921	—
	8,665,061	1,687,475

Schedule of Changes in Accumulated Other Comprehensive Income/(Loss) by Component [Table Text Block]

Changes in Accumulated Other Comprehensive Income / (Loss) by component, net of tax, were as follows:

	Gains and Losses on Cash Flow Hedges			Postretirement Benefits			Total
Balance at December 31, 2012	$	76,761		$	(824,103	)	$	(747,342	)
Other comprehensive income before reclassifications	(18,595		)	18,497			(98		)
Amounts reclassified from accumulated other comprehensive income	(22,713		)	27,260			4,547
New current period other comprehensive income	(41,308		)	45,757			4,449
Balance at March 31, 2013	$	35,453		$	(778,346	)	$	(742,893	)

Schedule of Reclassification of Adjustments to Accumulated Other Comprehensive Income [Table Text Block]

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

	Three Months Ended March 31,
	2013			2012
Derivative Instruments (Note 12)
Natural gas price swaps	$	(34,697	)	$	(79,321	)
Tax benefit	11,984			31,380
Net of tax	$	(22,713	)	$	(47,941	)
Actuarially Determined Long-Term Liability Adjustments*(Note 3 and Note 4)
Amortization of prior service costs	$	(8,212	)	$	(12,106	)
Recognized net actuarial loss	25,188			27,005
Settlement loss	27,115			—
Total	44,091			14,899
Tax expense	(16,831		)	(5,602		)
Net of tax	$	27,260		$	9,297

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,
	2013	2012
Options	84,994	11,716
Restricted Stock Units	478,509	458,018
Performance Share Units	159,228	229,730
	722,731	699,464

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Income Taxes Additional Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Deferred Tax Liability Not Recognized [Line Items]
Uncertain tax positions	$ 22,770	$ 25,570
Uncertain tax positions that, if recognized, would impact effective tax rate	2,071	3,891
Accrued interest liability relating to uncertain tax positions	5,165	5,741
Interest expense included in accrued interest liability	$ 335	$ 368

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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, 2013	Mar. 31, 2012
Net Income (Loss)	$ (1,564)	$ 97,196
Weighted average shares of common stock outstanding:
Basic	228,318,123	227,269,269
Effect of stock-based compensation awards	0	2,854,742
Dilutive	228,318,123	230,124,011
Earnings per share:
Basic	$ (0.01)	$ 0.43
Dilutive	$ (0.01)	$ 0.42

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Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012
Current Assets:
Cash and Cash Equivalents	$ 25,058	$ 21,878
Accounts and Notes Receivable:
Trade	408,350	428,328
Notes, Loans and Financing Receivable, Net, Current	322,406	318,387
Other Receivables	153,697	131,131
Accounts Receivable - Securitized	30,119	37,846
Inventories	217,034	247,766
Deferred Income Taxes	160,750	148,104
Recoverable Income Taxes	6,602	0
Restricted Cash and Cash Equivalents, Current	0	48,294
Prepaid Expenses	115,156	157,360
Total Current Assets	1,439,172	1,539,094
Property, Plant and Equipment:
Property, Plant and Equipment	15,749,523	15,545,204
Less-Accumulated Depreciation, Depletion and Amortization	5,516,319	5,354,237
Total Property, Plant and Equipment-Net	10,233,204	10,190,967
Other Assets:
Deferred Income Taxes	425,079	444,585
Restricted Cash	20,383	20,379
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures	248,127	222,830
Notes, Loans and Financing Receivable, Net, Noncurrent	25,995	25,977
Other	201,234	227,077
Total Other Assets	920,818	940,848
Total Assets	12,593,194	12,670,909
Current Liabilities:
Accounts Payable	463,886	507,982
Current Portion of Long-Term Debt	13,353	13,485
Short-Term Notes Payable	0	25,073
Accrued Income Taxes, Current	0	34,219
Secured Debt, Current	30,119	37,846
Other Accrued Liabilities	839,294	768,494
Total Current Liabilities	1,346,652	1,387,099
Long-Term Debt:
Long-Term Debt	3,124,240	3,124,473
Capital Lease Obligations	48,299	50,113
Total Long-Term Debt	3,172,539	3,174,586
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	2,825,925	2,832,401
Pneumoconiosis Benefits	175,952	174,781
Mine Closing	449,891	446,727
Gas Well Closing	150,973	148,928
Workers' Compensation	154,573	155,648
Salary Retirement	172,306	218,004
Reclamation	43,833	47,965
Other	128,316	131,025
Total Deferred Credits and Other Liabilities	4,101,769	4,155,479
TOTAL LIABILITIES	8,620,960	8,717,164
Stockholders' Equity:
Common Stock, $.01 Par Value; 500,000,000 Shares Authorized, 228,609,116 Issued and 228,574,361 Outstanding at March 31, 2013; 228,129,467 Issued and 228,094,712 Outstanding at December 31, 2012	2,289	2,284
Capital in Excess of Par Value	2,320,223	2,296,908
Preferred Stock, 15,000,000 shares authorized, None issued and outstanding	0	0
Retained Earnings	2,393,528	2,402,551
Accumulated Other Comprehensive Loss	(742,893)	(747,342)
Common Stock in Treasury, at Cost—34,755 Shares at March 31, 2013 and 34,755 Shares at December 31, 2012	(609)	(609)
Stockholders' Equity Attributable to Parent	3,972,538	3,953,792
Stockholders' Equity Attributable to Noncontrolling Interest	(304)	(47)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	3,972,234	3,953,745
TOTAL LIABILITIES AND EQUITY	$ 12,593,194	$ 12,670,909

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Acquisitions and Dispositions

3 Months Ended

Mar. 31, 2013

ACQUISITIONS AND DISPOSITIONS: [Abstract]

Acquisitions and Dispositions:

ACQUISITIONS AND DISPOSITIONS:

During the three months ended March 31, 2013, CNX Gas Company LLC (CNX Gas Company), a wholly owned subsidiary of CONSOL Energy, completed negotiations with the Allegheny County Airport Authority, which operates the Pittsburgh International Airport and the Allegheny County Airport, for the lease of the oil and gas rights on approximately 9.3 thousand acres.  A majority of these contiguous acres are in the liquids area of the Marcellus Shale play.  CNX Gas Company paid $46,315 as an up-front bonus payment at closing.  Approximately 7.6% of the bonus payment was placed into escrow while negotiations continue for a portion of the acres associated with the Allegheny County Airport and other acres that have potentially defective title.  CNX Gas Company must spud a well by February 21, 2015 and proceed with due diligence to complete the well or the lease terminates and CNX Gas Company foregoes the bonus. Our joint venture partner, Noble Energy, has indicated that it intends to acquire 50% of the acreage and accordingly, incur 50% of the associated costs.

In March 2013, CONSOL Energy completed a sale-leaseback of longwall shields for the Shoemaker Mine. Cash proceeds for the sale were $63,839. A loss of $279 was recognized due to transaction fees and is included in Other Income in the Consolidated Statement of Income. The lease has been accounted for as an operating lease. The lease term is five years.

In January 2013, CONSOL Energy completed a sale-leaseback of longwall shields for the Bailey Mine. Cash proceeds for the sale were $71,166. A loss of $358 was recognized due to transaction fees and is included in Other Income in the Consolidated Statement of Income. The lease has been accounted for as an operating lease. The lease term is five years.

On December 21, 2012, CONSOL Energy completed the disposition of its non-producing Ram River & Scurry Ram assets in Western Canada which consisted of 36 thousand acres of coal lands. In December 2012, cash proceeds of $51,869, of which $48,294 was restricted, were received related to this transaction. These proceeds were net of $637 in transaction fees. The restrictions on the cash were removed during the three months ended March 31, 2013 and are reflected as a Change in Restricted Cash in the Investing section of the Consolidated Statement of Cash Flows. Additionally, a note receivable was recognized in 2012 related to the two additional cash payments to be received in June 2013 and June 2014. Notes receivables of $25,500 and $24,500 were recorded in Accounts and Notes Receivables and Other Assets in the Consolidated Balance Sheet, respectively. The gain on the transaction was $89,943 and was included in Other Income in the Consolidated Statement of Income for the year ended December 31, 2012.

On February 9, 2012, CONSOL Energy completed the disposition of its Burning Star No. 4 property in Illinois, which consisted of 4.3 thousand acres of coal lands and surface rights, for proceeds of $13,023. The gain on the transaction was $11,261 and is included in Other Income in the Consolidated Statements of Income for the three month period ended March 31, 2012.

XML

Unrecorded Unconditional Purchase Obligation (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 1,098,194
Purchase Commitment [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Less than 1 year	349,513
1 - 3 years	227,586
3 - 5 years	128,338
More than 5 years	414,276
Total Purchase Obligations	1,119,713
Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	965,884
More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	132,310
More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Standby Letters of Credit [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	329,849
Standby Letters of Credit [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	207,452
Standby Letters of Credit [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	122,397
Standby Letters of Credit [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Standby Letters of Credit [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Surety Bonds [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	768,345
Surety Bonds [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	758,432
Surety Bonds [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	9,913
Surety Bonds [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Surety Bonds [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Employee Related Commitments [Member] | Standby Letters of Credit [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	190,158
Employee Related Commitments [Member] | Standby Letters of Credit [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	126,654
Employee Related Commitments [Member] | Standby Letters of Credit [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	63,504
Employee Related Commitments [Member] | Standby Letters of Credit [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Employee Related Commitments [Member] | Standby Letters of Credit [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Employee Related Commitments [Member] | Surety Bonds [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	204,884
Employee Related Commitments [Member] | Surety Bonds [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	204,884
Employee Related Commitments [Member] | Surety Bonds [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Employee Related Commitments [Member] | Surety Bonds [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Employee Related Commitments [Member] | Surety Bonds [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Environment Related Commitments [Member] | Standby Letters of Credit [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	56,293
Environment Related Commitments [Member] | Standby Letters of Credit [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	34,346
Environment Related Commitments [Member] | Standby Letters of Credit [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	21,947
Environment Related Commitments [Member] | Standby Letters of Credit [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Environment Related Commitments [Member] | Standby Letters of Credit [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Environment Related Commitments [Member] | Surety Bonds [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	533,974
Environment Related Commitments [Member] | Surety Bonds [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	524,072
Environment Related Commitments [Member] | Surety Bonds [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	9,902
Environment Related Commitments [Member] | Surety Bonds [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Environment Related Commitments [Member] | Surety Bonds [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Other Commitments [Member] | Standby Letters of Credit [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	83,398
Other Commitments [Member] | Standby Letters of Credit [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	46,452
Other Commitments [Member] | Standby Letters of Credit [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	36,946
Other Commitments [Member] | Standby Letters of Credit [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Other Commitments [Member] | Standby Letters of Credit [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Other Commitments [Member] | Surety Bonds [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	29,487
Other Commitments [Member] | Surety Bonds [Member] | Balance on First Anniversary [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	29,476
Other Commitments [Member] | Surety Bonds [Member] | More Than One And Within Three Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	11
Other Commitments [Member] | Surety Bonds [Member] | More Than Three And Within Five Years From Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	0
Other Commitments [Member] | Surety Bonds [Member] | Beyond Five Years of Balance Sheet Date [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 0

XML

Guarantor Subsidiaries Balance Sheet (Detail) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2012	Mar. 31, 2012	Dec. 31, 2011
Current Assets:
Cash and Cash Equivalents	$ 25,058	$ 21,878	$ 287,313	$ 375,736
Accounts and Notes Receivable:
Trade	408,350	428,328
Notes Receivable, Related Parties, Current	322,406	318,387
Other Receivables	153,697	131,131
Accounts Receivable - Securitized	30,119	37,846
Inventories	217,034	247,766
Recoverable Income Taxes	6,602	0
Deferred Income Taxes	160,750	148,104
Restricted Cash and Cash Equivalents, Current	0	48,294
Prepaid Expenses	115,156	157,360
Total Current Assets	1,439,172	1,539,094
Property, Plant and Equipment:
Property, Plant and Equipment	15,749,523	15,545,204
Less-Accumulated Depreciation, Depletion and Amortization	5,516,319	5,354,237
Total Property, Plant and Equipment-Net	10,233,204	10,190,967
Other Assets:
Deferred Income Taxes	425,079	444,585
Restricted Cash and Cash Equivalents, Noncurrent	20,383	20,379
Investments in Unconsolidated Equity Affiliates	248,127	222,830
Notes, Loans and Financing Receivable, Net	25,995	25,977
Other	201,234	227,077
Total Other Assets	920,818	940,848
Total Assets	12,593,194	12,670,909	12,595,611
Current Liabilities:
Accounts Payable	463,886	507,982
Accounts Payable (Recoverable)- Related Parties	0	0
Short-Term Notes Payable		25,073
Current Portion Long-Term Debt	13,353	13,485
Short-Term Notes Payable	0	25,073
Secured Debt, Current	30,119	37,846
Accrued Income Taxes, Current	0	34,219
Other Accrued Liabilities	839,294	768,494
Total Current Liabilities	1,346,652	1,387,099
Long-Term Debt:	3,172,539	3,174,586
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	2,825,925	2,832,401
Pneumoconiosis	175,952	174,781
Mine Closing	449,891	446,727
Gas Well Closing	150,973	148,928
Workers' Compensation	154,573	155,648
Salary Retirement	172,306	218,004
Reclamation	43,833	47,965
Other	128,316	131,025
Total Deferred Credits and Other Liabilities	4,101,769	4,155,479
Total CONSOL Energy Inc. Stockholders' Equity	3,972,538	3,953,792
Noncontrolling Interest	(304)	(47)
TOTAL LIABILITIES AND EQUITY	12,593,194	12,670,909
Parent Issuer
Current Assets:
Cash and Cash Equivalents	22,152	17,491
Accounts and Notes Receivable:
Trade	0	0
Notes Receivable, Related Parties, Current	194	154
Other Receivables	5,081	6,335
Accounts Receivable - Securitized	0	0
Inventories	0	0
Recoverable Income Taxes	20,580
Deferred Income Taxes	169,920	174,176
Restricted Cash and Cash Equivalents, Current		0
Prepaid Expenses	20,814	29,589
Total Current Assets	238,741	227,745
Property, Plant and Equipment:
Property, Plant and Equipment	218,234	216,448
Less-Accumulated Depreciation, Depletion and Amortization	130,556	126,048
Total Property, Plant and Equipment-Net	87,678	90,400
Other Assets:
Deferred Income Taxes	855,493	884,310
Restricted Cash and Cash Equivalents, Noncurrent	0	0
Investments in Unconsolidated Equity Affiliates	9,992,921	9,917,050
Notes, Loans and Financing Receivable, Net	212	239
Other	115,911	118,938
Total Other Assets	10,964,537	10,920,537
Total Assets	11,290,956	11,238,682
Current Liabilities:
Accounts Payable	195,092	177,734
Accounts Payable (Recoverable)- Related Parties	3,687,347	3,599,216
Short-Term Notes Payable		25,073
Current Portion Long-Term Debt	1,568	1,554
Short-Term Notes Payable	0
Secured Debt, Current	0	0
Accrued Income Taxes, Current		20,488
Other Accrued Liabilities	161,155	135,407
Total Current Liabilities	4,045,162	3,959,472
Long-Term Debt:	3,005,254	3,005,515
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	0	0
Pneumoconiosis	0	0
Mine Closing	0	0
Gas Well Closing	0	0
Workers' Compensation	0	0
Salary Retirement	172,306	218,004
Reclamation	0	0
Other	95,696	101,899
Total Deferred Credits and Other Liabilities	268,002	319,903
Total CONSOL Energy Inc. Stockholders' Equity	3,972,538	3,953,792
Noncontrolling Interest	0	0
TOTAL LIABILITIES AND EQUITY	11,290,956	11,238,682
CNX Gas Guarantor
Current Assets:
Cash and Cash Equivalents	2,170	3,352
Accounts and Notes Receivable:
Trade	55,755	58,126
Notes Receivable, Related Parties, Current	319,756	315,730
Other Receivables	112,802	214,748
Accounts Receivable - Securitized	0	0
Inventories	13,979	14,133
Recoverable Income Taxes	(13,978)
Deferred Income Taxes	(9,170)	(26,072)
Restricted Cash and Cash Equivalents, Current		0
Prepaid Expenses	52,271	86,186
Total Current Assets	533,585	666,203
Property, Plant and Equipment:
Property, Plant and Equipment	6,122,433	5,956,207
Less-Accumulated Depreciation, Depletion and Amortization	1,012,595	960,613
Total Property, Plant and Equipment-Net	5,109,838	4,995,594
Other Assets:
Deferred Income Taxes	(430,414)	(439,725)
Restricted Cash and Cash Equivalents, Noncurrent	0	0
Investments in Unconsolidated Equity Affiliates	167,058	143,876
Notes, Loans and Financing Receivable, Net	0	0
Other	46,350	65,935
Total Other Assets	(217,006)	(229,914)
Total Assets	5,426,417	5,431,883
Current Liabilities:
Accounts Payable	173,468	166,182
Accounts Payable (Recoverable)- Related Parties	24,929	23,981
Short-Term Notes Payable		0
Current Portion Long-Term Debt	5,939	5,953
Short-Term Notes Payable	29,000
Secured Debt, Current	0	0
Accrued Income Taxes, Current		13,731
Other Accrued Liabilities	68,331	57,074
Total Current Liabilities	301,667	266,921
Long-Term Debt:	44,671	46,081
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	0	0
Pneumoconiosis	0	0
Mine Closing	0	0
Gas Well Closing	81,296	80,097
Workers' Compensation	0	0
Salary Retirement	0	0
Reclamation	0	0
Other	26,151	24,518
Total Deferred Credits and Other Liabilities	107,447	104,615
Total CONSOL Energy Inc. Stockholders' Equity	4,972,936	5,014,313
Noncontrolling Interest	(304)	(47)
TOTAL LIABILITIES AND EQUITY	5,426,417	5,431,883
Other Guarantors Subsidiaries [Member]
Current Assets:
Cash and Cash Equivalents	171	175
Accounts and Notes Receivable:
Trade	0	0
Notes Receivable, Related Parties, Current	2,456	2,503
Other Receivables	32,024	33,289
Accounts Receivable - Securitized	0	0
Inventories	167,935	198,269
Recoverable Income Taxes	0
Deferred Income Taxes	0	0
Restricted Cash and Cash Equivalents, Current		48,294
Prepaid Expenses	40,544	40,215
Total Current Assets	243,130	322,745
Property, Plant and Equipment:
Property, Plant and Equipment	9,383,357	9,347,370
Less-Accumulated Depreciation, Depletion and Amortization	4,354,755	4,249,507
Total Property, Plant and Equipment-Net	5,028,602	5,097,863
Other Assets:
Deferred Income Taxes	0	0
Restricted Cash and Cash Equivalents, Noncurrent	20,383	20,379
Investments in Unconsolidated Equity Affiliates	798,589	769,058
Notes, Loans and Financing Receivable, Net	25,783	25,738
Other	28,940	32,016
Total Other Assets	873,695	847,191
Total Assets	6,145,427	6,267,799
Current Liabilities:
Accounts Payable	85,104	154,936
Accounts Payable (Recoverable)- Related Parties	(3,969,054)	(3,749,584)
Short-Term Notes Payable		0
Current Portion Long-Term Debt	5,084	5,222
Short-Term Notes Payable	0
Secured Debt, Current	0	0
Accrued Income Taxes, Current		0
Other Accrued Liabilities	599,867	566,485
Total Current Liabilities	(3,278,999)	(3,022,941)
Long-Term Debt:	121,151	121,523
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	2,825,925	2,832,401
Pneumoconiosis	175,952	174,781
Mine Closing	449,891	446,727
Gas Well Closing	69,677	68,831
Workers' Compensation	154,261	155,342
Salary Retirement	0	0
Reclamation	43,833	47,965
Other	6,469	4,608
Total Deferred Credits and Other Liabilities	3,726,008	3,730,655
Total CONSOL Energy Inc. Stockholders' Equity	5,577,267	5,438,562
Noncontrolling Interest	0	0
TOTAL LIABILITIES AND EQUITY	6,145,427	6,267,799
Non-Guarantors
Current Assets:
Cash and Cash Equivalents	565	860
Accounts and Notes Receivable:
Trade	352,595	370,202
Notes Receivable, Related Parties, Current	0	0
Other Receivables	3,790	5,159
Accounts Receivable - Securitized	30,119	37,846
Inventories	35,120	35,364
Recoverable Income Taxes	0
Deferred Income Taxes	0	0
Restricted Cash and Cash Equivalents, Current		0
Prepaid Expenses	1,527	1,370
Total Current Assets	423,716	450,801
Property, Plant and Equipment:
Property, Plant and Equipment	25,499	25,179
Less-Accumulated Depreciation, Depletion and Amortization	18,413	18,069
Total Property, Plant and Equipment-Net	7,086	7,110
Other Assets:
Deferred Income Taxes	0	0
Restricted Cash and Cash Equivalents, Noncurrent	0	0
Investments in Unconsolidated Equity Affiliates	0	0
Notes, Loans and Financing Receivable, Net	0	0
Other	10,033	10,188
Total Other Assets	10,033	10,188
Total Assets	440,835	468,099
Current Liabilities:
Accounts Payable	10,222	9,130
Accounts Payable (Recoverable)- Related Parties	227,778	254,787
Short-Term Notes Payable		0
Current Portion Long-Term Debt	762	756
Short-Term Notes Payable	0
Secured Debt, Current	30,119	37,846
Accrued Income Taxes, Current		0
Other Accrued Liabilities	9,941	9,528
Total Current Liabilities	278,822	312,047
Long-Term Debt:	1,463	1,467
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	0	0
Pneumoconiosis	0	0
Mine Closing	0	0
Gas Well Closing	0	0
Workers' Compensation	312	306
Salary Retirement	0	0
Reclamation	0	0
Other	0	0
Total Deferred Credits and Other Liabilities	312	306
Total CONSOL Energy Inc. Stockholders' Equity	160,238	154,279
Noncontrolling Interest	0	0
TOTAL LIABILITIES AND EQUITY	440,835	468,099
Consolidation, Eliminations [Member]
Current Assets:
Cash and Cash Equivalents	0	0
Accounts and Notes Receivable:
Trade	0	0
Notes Receivable, Related Parties, Current	0	0
Other Receivables	0	(128,400)
Accounts Receivable - Securitized	0	0
Inventories	0	0
Recoverable Income Taxes	0
Deferred Income Taxes	0	0
Restricted Cash and Cash Equivalents, Current		0
Prepaid Expenses	0	0
Total Current Assets	0	(128,400)
Property, Plant and Equipment:
Property, Plant and Equipment	0	0
Less-Accumulated Depreciation, Depletion and Amortization	0	0
Total Property, Plant and Equipment-Net	0	0
Other Assets:
Deferred Income Taxes	0	0
Restricted Cash and Cash Equivalents, Noncurrent	0	0
Investments in Unconsolidated Equity Affiliates	(10,710,441)	(10,607,154)
Notes, Loans and Financing Receivable, Net	0	0
Other	0	0
Total Other Assets	(10,710,441)	(10,607,154)
Total Assets	(10,710,441)	(10,735,554)
Current Liabilities:
Accounts Payable	0	0
Accounts Payable (Recoverable)- Related Parties	29,000	(128,400)
Short-Term Notes Payable		0
Current Portion Long-Term Debt	0	0
Short-Term Notes Payable	(29,000)
Secured Debt, Current	0	0
Accrued Income Taxes, Current		0
Other Accrued Liabilities	0	0
Total Current Liabilities	0	(128,400)
Long-Term Debt:	0	0
Deferred Credits and Other Liabilities
Postretirement Benefits Other Than Pensions	0	0
Pneumoconiosis	0	0
Mine Closing	0	0
Gas Well Closing	0	0
Workers' Compensation	0	0
Salary Retirement	0	0
Reclamation	0	0
Other	0	0
Total Deferred Credits and Other Liabilities	0	0
Total CONSOL Energy Inc. Stockholders' Equity	(10,710,441)	(10,607,154)
Noncontrolling Interest	0	0
TOTAL LIABILITIES AND EQUITY	$ (10,710,441)	$ (10,735,554)

XML

Pension and OPEB - Periodic Cost (Tables)

3 Months Ended

Mar. 31, 2013

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,
	2013			2012			2013			2012
Service cost	$	5,706		$	5,153		$	4,849		$	5,200
Interest cost	8,843			9,378			29,619			35,527
Expected return on plan assets	(12,144		)	(11,627		)	—			—
Amortization of prior service cost (credits)	(408		)	(408		)	(7,804		)	(11,599		)
Recognized net actuarial loss	12,175			12,263			17,595			20,345
Settlement loss	27,115			—			—			—
Net periodic benefit cost	$	41,287		$	14,759		$	44,259		$	49,473

XML

Related Party Transaction (Tables)

3 Months Ended

Mar. 31, 2013

NOTE 16- RELATED PARTY TRANSACTIONS [Abstract]

Related Party Receivables Payables [Table Text Block]

	March 31,			December 31,
	2013			2012			Location on Balance Sheet
Reimbursement for CONE Expenses	$	(655	)	$	(1,336	)	Accounts Receivable–Other
Reimbursement for Services Provided to CONE	(288		)	(341		)	Accounts Receivable–Other
CONE Gathering Capital Reimbursement	—			(18		)	Accounts Receivable–Other
CONE Gathering Fee Payable	11,918			4,837			Accounts Payable
Net Payable due CONE	$	10,975		$	3,142

XML

Derivative Instruments

3 Months Ended

Mar. 31, 2013

Notes to Financial Statements [Abstract]

Derivative Instruments:

DERIVATIVE INSTRUMENTS:

CONSOL Energy enters into financial derivative instruments to manage our exposure to commodity price volatility. The fair value of CONSOL Energy's derivatives (natural gas price swaps) are based on intra-bank pricing models which utilize inputs that are either readily available in the public market, such as natural gas forward curves, or can be corroborated from active markets or broker quotes. These values are then compared to the values given by our counterparties for reasonableness. Changes in the fair value of the derivatives are recorded currently in earnings unless special hedge accounting criteria are met. For derivatives designated as fair value hedges, the changes in fair value of both the derivative instrument and the hedged item are recorded in earnings. For derivatives designated as cash flow hedges, the effective portions of changes in the fair value of the derivatives are reported in Other Comprehensive Income or Loss (OCI) on the Consolidated Balance Sheets and reclassified into Outside Sales on the Consolidated Statements of Income in the same period or periods which the forecasted transaction affects earnings. The ineffective portions of hedges are recognized in earnings in the current period. CONSOL Energy currently utilizes only cash flow hedges that are considered highly effective.

CONSOL Energy formally assesses both at inception of the hedge and on an ongoing basis whether each derivative is highly effective in offsetting changes in the fair values or the cash flows of the hedged item. If it is determined that a derivative is not highly effective as a hedge or if a derivative ceases to be a highly effective hedge, CONSOL Energy will discontinue hedge accounting prospectively.

CONSOL Energy is exposed to credit risk in the event of nonperformance by counterparties. The creditworthiness of counterparties is subject to continuing review. The Company has not experienced any issues of non-performance by derivative counterparties.

None of our counterparty master agreements currently requires CONSOL Energy to post collateral for any of its hedges. However, as stated in the counterparty master agreements, if CONSOL Energy's obligations with one of its counterparties cease to be secured on the same basis as similar obligations with the other lenders under the credit facility, CONSOL Energy would have to post collateral for hedges in a liabilities position in excess of defined thresholds.  

                Each of CONSOL Energy's counterparty master agreements allows, in the event of default, the ability to elect early termination of outstanding contracts. If early termination is elected, CONSOL Energy and the applicable counterparty would net settle all open hedge positions.

CONSOL Energy has entered into swap contracts for natural gas to manage the price risk associated with the forecasted natural gas revenues. The objective of these hedges is to reduce the variability of the cash flows associated with the forecasted revenues from the underlying commodity. As of March 31, 2013, the total notional amount of the Company’s outstanding natural gas swap contracts was 147.4 billion cubic feet. These swap contracts are forecasted to settle through December 31, 2015 and meet the criteria for cash flow hedge accounting. As these contracts settle, the cash received and/or paid will be shown on the Consolidated Statements of Cash Flows as Changes in Prepaid Expenses, Changes in Other Assets, Changes in Other Operating Liabilities and/or Changes in Other Liabilities. During the next twelve months, $20,494 of unrealized gain is expected to be reclassified from Other Comprehensive Income on the Consolidated Balance Sheets and into Outside Sales on the Consolidated Statements of Income, as a result of the gross settlements of cash flow hedges. No gains or losses have been reclassified into earnings as a result of the discontinuance of cash flow hedges.

The gross fair value at March 31, 2013 of CONSOL Energy's derivative instruments, which were all natural gas swaps and qualify as cash flow hedges, was an asset of $83,677 and a liability of $20,949. The total asset is comprised of $46,837 and $36,840 which were included in Prepaid Expense and Other Assets, respectively, on the Consolidated Balance Sheets. The total liability is comprised of $10,877 and $10,072 which were included in Other Accrued Liabilities and Other Liabilities, respectively, on the Consolidated Balance Sheets.

The gross fair value at December 31, 2012 of CONSOL Energy's derivative instruments, which were all natural gas swaps and qualify as cash flow hedges, was an asset of $135,969 and a liability of $7,024. The total asset is comprised of $80,057 and $55,912 which were included in Prepaid Expense and Other Assets, respectively, on the Consolidated Balance Sheets. The total liability is comprised of $970 and $6,054 which were included in Other Accrued Liabilities and Other Liabilities, respectively, on the Consolidated Balance Sheets.

The effect of derivative instruments in cash flow hedging relationships on the Consolidated Statements of Income and the Consolidated Statements of Stockholders' Equity were as follows:

	Three Months Ended March 31,
	2013			2012
Natural Gas Price Swaps
Beginning Balance – Accumulated OCI	$	76,761		$	151,780
Gain/(Loss) recognized in Accumulated OCI	$	(18,595	)	$	76,076
Less: Gain reclassified from Accumulated OCI into Outside Sales	$	22,713		$	47,941
Ending Balance – Accumulated OCI	$	35,453		$	179,915
Gain/(Loss) recognized in Outside Sales for ineffectiveness	$	1,041		$	(835	)

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