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SUPPLEMENTAL INFORMATION - NATURAL GAS AND CRUDE OIL PROPERTIES Supplemental Information on Natural Gas and Crude Oil Exploration, Development and Production Activities (Tables) - bbl
 12 Months Ended
Dec. 31, 2017
Dec. 31, 2016
Dec. 31, 2015
Reserve Quantities [Line Items]      
Production (31,830,000) (22,176,000) (15,369,000)
Index price for reserves, by commodity [Table Text Block]
The indicated index prices for our reserves, by commodity, are presented below.
 
 
Average Benchmark Prices (1)
As of December 31,
 
Crude Oil
(per Bbl)
 
Natural Gas
(per Mcf)
 
NGLs
(per Bbl) (2)
 
 
 
 
 
 
 
2017
 
$
51.34

 
$
2.98

 
$
51.34

2016
 
42.75

 
2.48

 
42.75

2015
 
50.28

 
2.59

 
50.28

    
Schedule of Prices Used to Estimate Natural Gas and Crude Oil Reserves [Table Text Block]

The netted back price used to estimate our reserves, by commodity, are presented below.
 
 
Price Used to Estimate Reserves (3)
As of December 31,
 
Crude Oil
(per Bbl)
 
Natural Gas
(per Mcf)
 
NGLs
(per Bbl) (2)
 
 
 
 
 
 
 
2017
 
$
48.68

 
$
2.31

 
$
20.21

2016
 
38.67

 
1.85

 
11.97

2015
 
42.10

 
2.05

 
12.23

    
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities [Table Text Block]
The following tables present the changes in our estimated quantities of proved reserves:

 
Crude Oil, Condensate (MBbls)
 
Natural Gas
(MMcf)
 
NGLs
(MBbls)
 
Total
(MBoe)
Proved Reserves:
 
 
 
 
 
 
 
Proved reserves, January 1, 2015
100,515

 
536,972

 
60,119

 
250,129

Revisions of previous estimates
(43,268
)
 
(154,775
)
 
(24,407
)
 
(93,471
)
Extensions, discoveries, and other additions
48,707

 
311,709

 
30,835

 
131,494

Acquisition of reserves
17

 
215

 
23

 
76

Dispositions
(12
)
 
(82
)
 
(8
)
 
(34
)
Production
(6,984
)
 
(33,302
)
 
(2,835
)
 
(15,369
)
Proved reserves, December 31, 2015
98,975

 
660,737

 
63,727

 
272,825

Revisions of previous estimates
(22,097
)
 
(80,426
)
 
(7,130
)
 
(42,631
)
Extensions, discoveries, and other additions
494

 
4,094

 
355

 
1,531

Acquisition of reserves
50,126

 
305,224

 
32,586

 
133,583

Dispositions
(601
)
 
(4,202
)
 
(424
)
 
(1,725
)
Production
(8,728
)
 
(51,730
)
 
(4,826
)
 
(22,176
)
Proved reserves, December 31, 2016
118,169

 
833,697

 
84,288

 
341,407

Revisions of previous estimates
28,334

 
96,119

 
8,104

 
52,457

Extensions, discoveries, and other additions
2,923

 
11,541

 
1,158

 
6,005

Acquisition of reserves
18,971

 
289,223

 
19,604

 
86,778

Dispositions
(653
)
 
(4,597
)
 
(481
)
 
(1,900
)
Production
(12,902
)
 
(71,689
)
 
(6,981
)
 
(31,830
)
Proved reserves, December 31, 2017
154,842

 
1,154,294

 
105,692

 
452,917

 
 
 
 
 
 
 
 
Proved Developed Reserves, as of:
 
 
 
 
 
 
 
December 31, 2015
26,257

 
175,367

 
15,011

 
70,496

December 31, 2016
30,013

 
264,452

 
24,196

 
98,284

December 31, 2017
46,862

 
365,332

 
35,220

 
142,971

Proved Undeveloped Reserves, as of:
 
 
 
 

 
 
December 31, 2015
72,718

 
485,370

 
48,716

 
202,329

December 31, 2016
88,156

 
569,245

 
60,092

 
243,122

December 31, 2017
107,980

 
788,962

 
70,472

 
309,946

 
 
 
 
 
 
 
 


 
Developed
 
Undeveloped
 
Total
 
(MBoe)
 
 
 
 
 
 
Proved reserves, January 1, 2015
74,905

 
175,224

 
250,129

Undeveloped reserves converted to developed
29,090

 
(29,090
)
 
—

Revisions of previous estimates
(26,875
)
 
(66,596
)
 
(93,471
)
Extensions, discoveries, and other additions
8,703

 
122,791

 
131,494

Acquisition of reserves
76

 
—

 
76

Dispositions
(34
)
 
—

 
(34
)
Production
(15,369
)
 
—

 
(15,369
)
Proved reserves, December 31, 2015
70,496

 
202,329

 
272,825

Undeveloped reserves converted to developed
32,192

 
(32,192
)
 
—

Revisions of previous estimates
6,112

 
(48,743
)
 
(42,631
)
Extensions, discoveries, and other additions
1,531

 
—

 
1,531

Acquisition of reserves
10,229

 
123,354

 
133,583

Dispositions
(99
)
 
(1,626
)
 
(1,725
)
Production
(22,176
)
 
—

 
(22,176
)
Proved reserves, December 31, 2016
98,285

 
243,122

 
341,407

Undeveloped reserves converted to developed
54,648

 
(54,648
)
 
—

Revisions of previous estimates
18,291

 
34,166

 
52,457

Extensions, discoveries, and other additions
2,292

 
3,713

 
6,005

Acquisition of reserves
1,305

 
85,473

 
86,778

Dispositions
(20
)
 
(1,880
)
 
(1,900
)
Production
(31,830
)
 
—

 
(31,830
)
Proved reserves, December 31, 2017
142,971

 
309,946

 
452,917

 
 
 
 
 
 
    
Results of Operations for Oil and Gas Producing Activities Disclosure [Table Text Block]
The results of operations for crude oil and natural gas producing activities are presented below. The results include activities related to both continuing and discontinued operations and exclude activities related to gas marketing and other income. Comprehensive income (loss) includes net income (loss), as well as other changes in stockholders' equity that result from transactions and economic events other than those with shareholders. There was no difference between our net income (loss) and comprehensive income (loss) for any of the periods presented in the results of operations for crude oil and natural gas producing activities shown.


Year Ended December 31,

2017
 
2016
 
2015

(in thousands)
Revenue:

 

 

Crude oil, natural gas and NGLs sales
$
913,084

 
$
497,353

 
$
378,713

Commodity price risk management gain (loss), net
(3,936
)
 
(125,681
)
 
203,183


909,148

 
371,672

 
581,896

Expenses:
 
 
 
 
 
Lease operating expenses
89,641

 
59,950

 
56,992

Production taxes
60,717

 
31,410

 
18,443

Transportation, gathering and processing expenses
33,220

 
18,415

 
10,151

Exploration expense
47,334

 
4,669

 
1,102

Impairment of properties and equipment
285,887

 
9,973

 
161,620

Depreciation, depletion, and amortization
462,482

 
413,105

 
298,760

Accretion of asset retirement obligations
6,306

 
7,080

 
6,293

Gain on sale of properties and equipment
(766
)
 
(43
)
 
(385
)

984,821

 
544,559

 
552,976

Results of operations for crude oil and natural gas producing
activities before provision for income taxes
(75,673
)
 
(172,887
)
 
28,920

Provision for income taxes
47,247

 
64,733

 
(10,394
)
Results of operations for crude oil and natural gas producing activities, excluding corporate overhead and interest costs
$
(28,426
)
 
$
(108,154
)
 
$
18,526

    
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure [Table Text Block]
Exploration Expenses. The following table presents the major components of exploration, geologic, and geophysical expense:
 
Year Ended December 31,
 
2017
 
2016
 
2015
 
(in thousands)
 
 
 
 
 
 
Exploratory dry hole costs
$
41,297

 
$
—

 
$
—

Geological and geophysical costs, including seismic purchases
3,881

 
3,472

 
—

Operating, personnel and other
2,156

 
1,197

 
1,102

Total exploration, geologic, and geophysical expense
$
47,334

 
$
4,669

 
$
1,102

 
 
 
 
 
 
Costs incurred in crude oil and natural gas property acquisition, exploration, and development are presented below.

 
Year Ended December 31,
 
2017
 
2016
 
2015
 
(in thousands)
Acquisition of properties: (1)
 
 
 
 
 
Proved properties
$
172

 
$
268,567

 
$
3,561

Unproved properties
18,914

 
1,843,985

 
15

Development costs (2)
688,165

 
383,336

 
552,104

Exploration costs: (3)
 
 
 
 
 
Exploratory drilling
80,103

 
—

 
—

Geological and geophysical
3,881

 
4,669

 
—

Total costs incurred (4)
$
791,235

 
$
2,500,557

 
$
555,680

 
 
 
 
 
 
__________
(1)
Property acquisition costs represent costs incurred to purchase, lease, or otherwise acquire a property. Proved properties
include approximately $40.9 million of infrastructure and pipeline costs in 2016.    
(2)
Development costs represent costs incurred to gain access to and prepare development well locations for drilling, drill and equip development wells, recomplete wells, and provide facilities to extract, treat, gather, and store crude oil, natural gas, and NGLs. Of these costs incurred for the years ended December 31, 2017, 2016, and 2015, $463.4 million, $204.6 million, and $207.8 million, respectively, were incurred to convert proved undeveloped reserves to proved developed reserves from the prior year end. These costs also include approximately $32.8 million of infrastructure and pipeline costs in 2017.
(3)
Exploration costs represent costs incurred in identifying areas that may warrant examination and in examining specific areas that are considered to have prospects of containing crude oil, natural gas, and NGLs. These costs include, but are not limited to, dry hole contributions and costs of drilling and equipping exploratory wells.
(4)
During the year ended 2017, we finalized our purchase price allocation for the 2016 Delaware Basin acquisition within the one year measurement period. The finalization included a reduction to our proved, undeveloped and development costs of $24.6 million. We excluded this reduction from our 2017 costs incurred as it did not relate to any cash acquisitions in 2017.

    
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Table Text Block]
Aggregate capitalized costs related to crude oil and natural gas exploration and production activities with applicable accumulated DD&A are presented below:

 
As of December 31,
 
2017
 
2016
 
 (in thousands)
 
 
 
 
Proved crude oil and natural gas properties
$
4,356,922

 
$
3,499,718

Unproved crude oil and natural gas properties
1,097,317

 
1,874,671

Uncompleted wells, equipment and facilities
265,526

 
150,424

Capitalized costs
5,719,765

 
5,524,813

Less accumulated DD&A
(1,803,847
)
 
(1,534,678
)
Capitalized costs, net
$
3,915,918

 
$
3,990,135

 
 
 
 

    
    
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure [Table Text Block]
The following table presents information with respect to the standardized measure of discounted future net cash flows relating to proved reserves. Changes in the demand for crude oil, natural gas, and NGLs, inflation and other factors make such estimates inherently imprecise and subject to substantial revision. This table should not be construed to be an estimate of the current market value of our proved reserves.

 
As of December 31,
 
2017
 
2016
 
2015
 
(in thousands)
 
 
 
 
 
 
Future estimated cash flows
$
12,340,407

 
$
7,122,525

 
$
6,297,298

Future estimated production costs*
(3,245,627
)
 
(1,624,167
)
 
(1,493,040
)
Future estimated development costs
(2,893,335
)
 
(2,219,914
)
 
(2,036,685
)
Future estimated income tax expense
(748,494
)
 
(597,476
)
 
(508,332
)
Future net cash flows
5,452,951

 
2,680,968

 
2,259,241

10% annual discount for estimated timing of cash flows
(2,572,846
)
 
(1,260,339
)
 
(1,162,377
)
Standardized measure of discounted future estimated net cash flows
$
2,880,105

 
$
1,420,629

 
$
1,096,864

 
 
 
 
 
 
___________
*
Represents future estimated lease operating expenses, production taxes, transportation, gathering, and processing expenses.
    
    
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows [Table Text Block]
The following table presents the principal sources of change in the standardized measure of discounted future estimated net cash flows:
 
Year Ended December 31,
 
2017
 
2016
 
2015
 
(in thousands)
 
 
 
 
 
 
Beginning of period
$
1,420,629

 
$
1,096,864

 
$
2,306,465

Sales of crude oil, natural gas and NGLs production, net of production costs
(729,506
)
 
(387,576
)
 
(293,127
)
Net changes in prices and production costs (1)
841,713

 
(205,760
)
 
(1,752,921
)
Extensions, discoveries, and improved recovery, less related costs
47,240

 
15,128

 
489,178

Sales of reserves
(2,613
)
 
(3,745
)
 
(463
)
Purchases of reserves
224,483

 
487,636

 
374

Development costs incurred during the period
419,047

 
268,672

 
368,840

Revisions of previous quantity estimates
484,431

 
(320,286
)
 
(1,286,462
)
Changes in estimated income taxes
(138,560
)
 
(13,630
)
 
902,994

Net changes in future development costs
25,183

 
391,145

 
112,958

Accretion of discount
167,487

 
133,747

 
345,007

Timing and other
120,571

 
(41,566
)
 
(95,979
)
End of period
$
2,880,105

 
$
1,420,629

 
$
1,096,864

 
 
 
 
 
 
__________
(1)
Our weighted-average price, net of production costs per Boe, in our 2017 reserve report increased to $20.08 as compared to $15.73 for 2016 and $17.30 for 2015.