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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