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Supplemental Gas Data (Tables)
 12 Months Ended
Dec. 31, 2016
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,
 
 
2016
 
2015
 
2014
Future Cash Flows (a)
 
 
 
 
 
 
Revenues
 
$
11,303,409

 
$
11,837,732

 
$
28,502,852

Production costs
 
(5,850,941
)
 
(6,584,947
)
 
(10,100,868
)
Development costs
 
(1,550,294
)
 
(1,220,010
)
 
(3,368,621
)
Income tax expense
 
(1,482,826
)
 
(1,532,454
)
 
(5,711,989
)
Future Net Cash Flows
 
2,419,348

 
2,500,321

 
9,321,374

Discounted to present value at a 10% annual rate
 
(1,464,231
)
 
(1,481,017
)
 
(6,337,216
)
Total standardized measure of discounted net cash flows
 
$
955,117

 
$
1,019,304

 
$
2,984,158


(a)
For 2016, the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2016, adjusted for energy content and a regional price differential. For 2016, this adjusted natural gas price was $1.73 per mcf, the adjusted oil price was $25.04 per barrel and the adjusted NGL price was $15.77 per barrel.

For 2015, the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2015, adjusted for energy content and a regional price differential. For 2015, this adjusted natural gas price was $2.02 per mcf, the adjusted oil price was $25.29 per barrel and the adjusted NGL price was $15.59 per barrel.

For 2014, the reserves were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2014, adjusted for energy content and a regional price differential. For 2014, this adjusted natural gas price was $3.85 per mcf, the adjusted oil price was $77.30 per barrel and the adjusted NGL price was $46.54 per barrel.









The following are the principal sources of change in the standardized measure of discounted future net cash flows for consolidated operations during:
 
 
December 31,
 
 
2016
 
2015
 
2014
Balance at beginning of period
 
$
1,019,304

 
$
2,984,158

 
$
1,680,811

Net changes in sales prices and production costs
 
(172,812
)
 
(4,151,684
)
 
517,731

Sales net of production costs
 
(150,819
)
 
(589,533
)
 
(559,563
)
Net change due to revisions in quantity estimates
 
(35,502
)
 
408,006

 
151,233

Net change due to extensions, discoveries and improved recovery
 
(54,628
)
 
157,016

 
418,775

Development costs incurred during the period
 
138,813

 
666,315

 
952,733

Difference in previously estimated development costs compared to actual costs incurred during the period
 
(39,821
)
 
8,911

 
(102,949
)
Purchase of Reserves In-Place
 
238,819

 
—

 
—

Sales of Reserves In-Place
 
(137,998
)
 
—

 
—

Changes in estimated future development costs
 
(158,000
)
 
374,982

 
595,221

Net change in future income taxes
 
36,513

 
1,259,744

 
(798,470
)
Accretion of discount and other
 
271,248

 
(98,611
)
 
128,636

     Total discounted cash flow at end of period
 
$
955,117

 
$
1,019,304

 
$
2,984,158
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]
Capitalized Costs:
 
 
As of December 31,
 
 
2016
 
2015
Proved gas properties
 
$
2,016,916

 
$
1,922,602

Unproved gas properties
 
1,116,282

 
1,421,083

Intangible drilling costs
 
3,583,565

 
3,452,989

Gas wells and related equipment
 
791,996

 
785,744

Gas gathering assets
 
1,138,299

 
1,147,173

Gas well plugging
 
176,961

 
115,121

Total Property, Plant and Equipment
 
8,824,019

 
8,844,712

Accumulated Depreciation, Depletion and Amortization
 
(3,099,622
)
 
(2,691,005
)
Net Capitalized Costs
 
$
5,724,397

 
$
6,153,707
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,
 
 
2016
 
2015
 
2014
Property acquisitions
 
 
 
 
 
 
Proved properties
 
$
—

 
$
—

 
$
—

Unproved properties
 
1,537

 
76,676

 
119,597

Development
 
138,813

 
666,315

 
952,733

Exploration
 
32,259

 
95,371

 
45,006

Total
 
$
172,609

 
$
838,362

 
$
1,117,336

__________
(*)
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,
 
 
2016
 
2015
 
2014
Natural Gas, NGLs and Oil Sales
 
$
793,673

 
$
728,458

 
$
1,007,381

(Loss) Gain on Commodity Derivative Instruments
 
(141,021
)
 
392,942

 
23,193

Purchased Gas Sales
 
43,256

 
14,450

 
8,999

Total Revenue
 
695,908

 
1,135,850

 
1,039,573

Lease Operating Expense
 
96,434

 
121,847

 
139,242

Production, Ad Valorem, and Other Fees
 
31,049

 
30,438

 
39,418

Transportation, Gathering and Compression
 
374,350

 
343,403

 
239,591

Purchased Gas Costs
 
42,717

 
10,721

 
7,251

Impairment of Exploration and Production Properties
 
—

 
828,905

 
—

Other Costs
 
14,519

 
10,120

 
22,718

DD&A
 
417,853

 
370,374

 
323,600

Total Costs
 
976,922

 
1,715,808

 
771,820

Pre-tax Operating Income / (Loss)
 
(281,014
)
 
(579,958
)
 
267,753

Income Taxes / (Benefit)
 
(69,308
)
 
(250,220
)
 
45,162

Results of Operations for Producing Activities excluding Corporate and Interest Costs
 
$
(211,706
)
 
$
(329,738
)
 
$
222,591
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,
 
 
2016
 
2015
 
2014
Production (MMcfe)
 
394,387

 
328,657

 
235,714

Total average sales price before effects of financial settlements (per Mcfe)
 
$
2.01

 
$
2.22

 
$
4.27

Average effects of financial settlements (per Mcfe)
 
$
0.62

 
$
0.60

 
$
0.10

Total average sales price including effects of financial settlements (per Mcfe)
 
$
2.63

 
$
2.82

 
$
4.37

Average lifting costs, excluding ad valorem and severance taxes (per Mcfe)
 
$
0.24

 
$
0.37

 
$
0.59
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, 2016, the number of producing wells, developed acreage and undeveloped acreage:
 
 
Gross
 
Net(1)
Producing Gas Wells (including gob wells)
 
17,314

 
12,846

Producing Oil Wells
 
189

 
30

Acreage Position:
 
 
 
 
   Proved Developed Acreage
 
549,816

 
541,282

   Proved Undeveloped Acreage
 
34,467

 
30,038

   Unproved Acreage
 
4,804,804

 
3,745,533

Total Acreage
 
5,389,087

 
4,316,853

____________
(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 reserves estimates are as follows:
 
 
 
 
 
 
Condensate
 
Consolidated
 
 
Natural Gas
 
NGLs
 
& Crude Oil
 
Operations
 
 
(MMcf)
 
(Mbbls)
 
(Mbbls)
 
(MMcfe)
Balance December 31, 2013 (a)
 
5,585,107

 
21,546

 
2,806

 
5,731,214

Revisions (b)
 
(46,560
)
 
40,363

 
3,756

 
218,168

Price Changes
 
15,512

 
—

 
—

 
15,512

Extensions and Discoveries (c)
 
979,801

 
18,459

 
1,314

 
1,098,436

Production
 
(216,260
)
 
(2,578
)
 
(664
)
 
(235,714
)
Balance December 31, 2014 (a)
 
6,317,600

 
77,790

 
7,212

 
6,827,616

Revisions (d)
 
1,052,978

 
45,993

 
6,662

 
1,368,909

Price Changes
 
(2,866,123
)
 
(45,675
)
 
(3,208
)
 
(3,159,421
)
Extensions and Discoveries (e)
 
840,800

 
13,916

 
1,707

 
934,542

Production
 
(285,041
)
 
(5,812
)
 
(1,458
)
 
(328,657
)
Balance December 31, 2015 (a)
 
5,060,214

 
86,212

 
10,915

 
5,642,989

Revisions (f)
 
21,280

 
(20,669
)
 
481

 
(99,849
)
Price Changes
 
(179,914
)
 
(1,647
)
 
(35
)
 
(190,009
)
Extensions and Discoveries (g)
 
643,688

 
10,960

 
1,783

 
720,146

Production
 
(358,474
)
 
(5,119
)
 
(867
)
 
(394,387
)
Purchases of Reserves In-Place (h)
 
1,352,759

 
13,177

 
1,970

 
1,443,642

Sales of Reserves In-Place (h)
 
(711,155
)
 
(22,382
)
 
(4,240
)
 
(870,884
)
Balance December 31, 2016 (a)
 
5,828,398

 
60,532

 
10,007

 
6,251,648

 
 
 
 
 
 
 
 
 
Proved developed reserves (i):
 
 
 
 
 
 
 
 
December 31, 2014
 
2,979,906

 
32,405

 
4,061

 
3,198,706

December 31, 2015
 
3,310,894

 
59,196

 
5,180

 
3,697,152

December 31, 2016
 
3,478,464

 
30,666

 
3,474

 
3,683,302

 
 
 
 
 
 
 
 
 
Proved undeveloped reserves:
 
 
 
 
 
 
 
 
December 31, 2014
 
3,337,694

 
45,385

 
3,151

 
3,628,910

December 31, 2015
 
1,749,320

 
27,016

 
5,736

 
1,945,837

December 31, 2016
 
2,349,934

 
29,866

 
6,536

 
2,568,346

__________
(a)
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,
 
 
2016
 
2015
 
2014
Costs reclassified to wells, equipment and facilities based on the determination of proved reserves
 
$
40,917

 
$
17,179

 
$
27,453

Costs expensed due to determination of dry hole or abandonment of project
 
$
—

 
$
—

 
$
2,041
Capitalized Exploratory Well Costs, Roll Forward [Table Text Block]
 
 
December 31,
 
 
2016
 
2015
 
2014
Costs reclassified to wells, equipment and facilities based on the determination of proved reserves
 
$
40,917

 
$
17,179

 
$
27,453

Costs expensed due to determination of dry hole or abandonment of project
 
$
—

 
$
—

 
$
2,041