Supplemental Gas Data (Tables)

12 Months Ended

Dec. 31, 2012

SUPPLEMENTAL GAS DATA: [Abstract]

Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]

The standardized measure is intended to provide a better means for comparing the value of CONSOL Energy's proved reserves at a given time with those of other gas producing companies than is provided by a comparison of raw proved reserve quantities.

	December 31,
	2012			2011			2010
Future Cash Flows:
Revenues	$	11,777,550		$	14,804,398		$	16,723,795
Production costs	(4,823,670		)	(5,262,635		)	(5,175,563		)
Development costs	(2,450,589		)	(1,674,829		)	(2,720,243		)
Income tax expense	(1,711,251		)	(2,989,435		)	(3,354,444		)
Future Net Cash Flows	2,792,040			4,877,499			5,473,545
Discounted to present value at a 10% annual rate	(2,055,834		)	(3,130,318		)	(3,812,724		)
Total standardized measure of discounted net cash flows	$	736,206		$	1,747,181		$	1,660,821

The following are the principal sources of change in the standardized measure of discounted future net cash flows for consolidated operations during:

	December 31,
	2012			2011			2010
Balance at beginning of period	$	1,747,181		$	1,660,821		$	894,351
Net changes in sales prices and production costs	(1,480,573		)	(339,098		)	721,997
Sales net of production costs	(104,518		)	(217,186		)	(286,883		)
Net change due to revisions in quantity estimates	(104,158		)	(83,580		)	414,704
Net change due to extensions, discoveries and improved recovery	14,645			324,755			326,584
Net change due to (divestiture) acquisition	—			(559,132		)	500,376
Development costs incurred during the period	333,640			463,401			295,142
Difference in previously estimated development costs compared to actual costs incurred during the period	(96,749		)	154,137			(12,060		)
Changes in estimated future development costs	(153,104		)	155,619			(426,870		)
Net change in future income taxes	619,045			130,746			(612,114		)
Accretion of discount and other	(39,203		)	56,698			(154,406		)
Total discounted cash flow at end of period	$	736,206		$	1,747,181		$	1,660,821

Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]

Capitalized Costs:

	As of December 31,
	2012			2011
Proven properties	$	1,549,773		$	1,495,772
Unproven properties	1,266,444			1,258,455
Wells and related equipment	2,113,414			1,755,617
Gathering assets	1,006,882			963,494
Total Property, Plant and Equipment	5,936,513			5,473,338
Accumulated Depreciation, Depletion and Amortization	(953,873		)	(773,027		)
Net Capitalized Costs	$	4,982,640		$	4,700,311

Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]

Costs incurred for property acquisition, exploration and development (*):

	For the Years Ended December 31,
	2012		2011		2010
Property acquisitions
Proven properties	$	50,005	$	6,673	$	1,476,470
Unproven properties	28,634		58,731		1,922,334
Development	339,608		463,401		472,691
Exploration	130,312		131,419		58,655
Total	$	548,559	$	660,224	$	3,930,150

__________

(*) Includes costs incurred whether capitalized or expensed.

Results of Operations for Oil and Gas Producing Activities Disclosure [Table Text Block]

Results of Operations for Producing Activities:

	For the Years Ended December 31,
	2012		2011		2010
Production Revenue	$	660,442	$	751,767	$	745,809
Royalty Interest Gas Revenue	49,405		66,929		62,869
Purchased Gas Revenue	3,316		4,344		11,227
Total Revenue	713,163		823,040		819,905
Lifting Costs	90,835		106,477		64,820
Ad Valorem, Severance & Other Taxes
Gathering Costs	160,575		142,339		127,927
Royalty Interest Gas Costs	38,922		59,377		53,839
Direct Administrative, Selling & Other Costs	47,567		60,355		63,941
Other Costs	39,029		18,095		25,220
Purchased Gas Costs	2,711		3,831		9,736
DD&A	202,956		206,821		190,424
Total Costs	608,740		623,556		559,148
Pre-tax Operating Income	104,423		199,484		260,757
Income Taxes	39,827		79,873		106,598
Results of Operations for Producing Activities excluding Corporate and Interest Costs	$	64,596	$	119,611	$	154,159

Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure [Table Text Block]

The following is production, average sales price and average production costs, excluding ad valorem and severance taxes, per unit of production:

	For the Years Ended December 31,
	2012		2011		2010
Production in million cubic feet	156,325		153,504		127,875
Average gas sales price before effects of financial settlements (per thousand cubic feet)	$	3.01	$	4.27	$	4.53
Average effects of financial settlements (per thousand cubic feet)	$	1.21	$	0.63	$	1.30
Average gas sales price including effects of financial settlements (per thousand cubic feet)	$	4.22	$	4.90	$	5.83
Average lifting costs, excluding ad valorem and severance taxes (per thousand cubic feet)	$	0.58	$	0.68	$	0.50

Schedule of Gas and Oil Acreage [Table Text Block]

Most of our development wells and proved acreage are located in Virginia, West Virginia and Pennsylvania. Some leases are beyond their primary term, but these leases are extended in accordance with their terms as long as certain drilling commitments or other term commitments are satisfied. The following table sets forth, at December 31, 2012, the number of producing wells, developed acreage and undeveloped acreage:

	Gross	Net(1)
Producing Wells (including gob wells)	14,906	12,819
Proved Developed Acreage	555,160	465,392
Proved Undeveloped Acreage	118,384	83,574
Unproved Acreage	4,930,181	4,038,515
Total Acreage	5,603,725	4,587,481

____________

(1) Net acres include acreage attributable to our working interests of the properties. Additional adjustments (either increases or decreases) may be required as we further develop title to and further confirm our rights with respect to our various properties in anticipation of development. We believe that our assumptions and methodology in this regard are reasonable.

Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]

The gas reserve estimates are as follows:

	Consolidated Operations
	2012		2011		2010
Net Reserve Quantity (MMcfe)
Beginning reserves	3,480,027		3,731,597		1,911,391
Price Changes	(526,611	)	(9,976	)	13,612
Plan and other revisions (a­)	241,989		(73,837	)	366,365
Extensions and discoveries(b)	954,378		517,178		621,270
Production	(156,325	)	(153,504	)	(127,875	)
Purchases of reserves in-place	—		—		946,834
Sale of reserves in-place	—		(531,431	)	—
Ending reserves(c)	3,993,458		3,480,027		3,731,597

__________

(a) Plan and other revisions are due to corporate planning changes that affect the number of wells forecasted to be drilled in our various areas and reservoirs. These changes along with upward revisions attributable to efficiencies in operations and well performance had the total affect of a positive revision.

(b) Extensions and Discoveries are due to the addition of wells on our Marcellus Shale acreage more than one offset location away with reliable technology.

(c) Proved developed and proved undeveloped gas reserves are defined by SEC Rule 4.10(a) of Regulation S-X. Generally, these reserves would be commercially recovered under current economic conditions, operating methods and government regulations. CONSOL Energy cautions that there are many inherent uncertainties in estimating proved reserve quantities, projecting future production rates and timing of development expenditures. Proved oil and gas reserves are estimated quantities of natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operat

Schedule of Aging of Capitalized Exploratory Well Costs [Table Text Block]

The following table represents the capitalized exploratory well cost activity as indicated:

	December 31,
	2012
Costs pending the determination of proved reserves at December 31, 2012(a)
Less than one year	$	11,736
More than one year but less than five years	7
More than five years	5,649
Total	$	17,392

__________

(a) Costs held in exploratory for more than one year represent exploration wells away from existing infrastructure. The additional planned exploration expenditures will allow us to invest in infrastructure to support these fields. There were no wells removed from the previous year-end schedule.

Capitalized Exploratory Well Costs, Roll Forward [Table Text Block]

	December 31,
	2012		2011		2010
Costs reclassified to wells, equipment and facilities based on the determination of proved reserves	$	14,447	$	189	$	93,482
Costs expensed due to determination of dry hole or abandonment of project	$	3,320	$	5,108	$	9,614