XML 67 R40.htm IDEA: XBRL DOCUMENT v3.22.0.1
Supplemental Oil and Gas Information (Unaudited) (Tables)
12 Months Ended
Dec. 31, 2021
Supplemental Oil and Gas Information (Unaudited)  
Schedule of Capitalized Costs Relating to Oil and Natural Gas Producing Activities

    

December 31, 

2021

2020

(In thousands)

Evaluated oil and natural gas properties

$

799,532

$

775,167

Support equipment and facilities

 

145,324

 

142,208

Accumulated depletion, depreciation, and amortization

 

(625,754)

 

(602,861)

Total

$

319,102

$

314,514

Costs Incurred in Oil and Natural Gas Property Acquisition, Exploration and Development Activities

    

For the Year Ended

December 31, 

2021

2020

(In thousands)

Property acquisition costs, proved

$

3

$

42

Property acquisition costs, unproved

 

 

(49,307)

Exploration

 

 

Development

 

27,478

 

29,543

Total

$

27,481

$

(19,722)

Schedule of Product Prices Used for Valuing the Reserves

The weighted-average benchmark product prices used for valuing the reserves are based upon the average of the first-day-of-the-month price for each month within the period January through December of each year presented:

    

2021

    

2020

Oil ($/Bbl):

 

  

 

  

WTI (1)

$

66.56

$

39.57

NGL ($/Bbl):

 

  

 

  

WTI (1)

$

66.56

$

39.57

Natural Gas ($/MMbtu):

 

  

 

  

Henry Hub (2)

$

3.60

$

1.99

(1)The weighted average WTI price was adjusted by lease for quality, transportation fees, and a regional price differential.
(2)The weighted average Henry Hub price was adjusted by lease for energy content, compression charges, transportation fees, and regional price differentials.
Schedule of Net Reserves

    

For the Year Ended December 31, 2021

Oil

Gas

NGLs

Total

(MBbls)

(MMcf)

(MBbls)

(MBoe)

Proved developed and undeveloped reserves:

 

  

 

  

 

  

 

  

Beginning of year

 

46,676

 

274,139

 

21,484

 

113,849

Extensions and discoveries

 

746

 

4,283

 

215

 

1,674

Production

 

(3,351)

 

(23,808)

 

(1,430)

 

(8,747)

Sale of minerals in place

(3)

(274)

(12)

(61)

Revision of previous estimates

 

933

 

60,010

 

3,580

 

14,515

End of year

 

45,001

 

314,350

 

23,837

 

121,230

Proved developed reserves (1):

 

  

 

  

 

  

 

  

Beginning of year

 

35,613

 

252,218

 

19,009

 

96,658

End of year

 

43,857

 

309,794

 

23,574

 

119,063

Proved undeveloped reserves (2):

 

  

 

  

 

  

 

  

Beginning of year

 

11,063

 

21,921

 

2,475

 

17,191

End of year

 

1,144

 

4,556

 

263

 

2,167

(1)Our reserves related to our Beta properties have been reclassified as proved developed non-producing at December 31, 2021.
(2)Change to the Company’s development plan has resulted in removal of PUD locations in Oklahoma, Rockies and California.

    

For the Year Ended December 31, 2020

Oil

Gas

NGLs

Total

(MBbls)

(MMcf)

(MBbls)

(MBoe)

Proved developed and undeveloped reserves:

 

  

 

  

 

  

 

  

Beginning of period

 

70,772

 

377,869

 

29,252

 

163,002

Extensions and discoveries

 

291

 

655

 

61

 

461

Production

 

(3,887)

 

(27,473)

 

(1,725)

 

(10,190)

Revision of previous estimates

 

(20,500)

 

(76,912)

 

(6,104)

 

(39,424)

End of period

 

46,676

 

274,139

 

21,484

 

113,849

Proved developed reserves:

 

  

 

  

 

  

 

  

Beginning of period

 

53,476

 

320,731

 

23,646

 

130,577

End of period

 

35,613

 

252,218

 

19,009

 

96,658

Proved undeveloped reserves:

 

  

 

  

 

 

  

Beginning of period

 

17,296

 

57,138

 

5,606

 

32,425

End of period

 

11,063

 

21,921

 

2,475

 

17,191

Standardized Measure of Discounted Future Net Cash Flows

    

For the Year Ended

December 31, 

    

2021

    

2020

(In thousands)

Future cash inflows

$

4,569,313

$

2,410,260

Future production costs (1)

 

(2,691,875)

 

(1,589,945)

Future development costs (1)

 

(231,040)

 

(375,146)

Future income tax expense

 

 

Future net cash flows for estimated timing of cash flows

 

1,646,398

 

445,169

10% annual discount for estimated timing of cash flows

 

(726,553)

 

(147,358)

Standardized measure of discounted future net cash flows

$

919,845

$

297,811

(1)For the year ended December 31, 2021 and 2020, onshore abandonment costs are included in future production cost and offshore abandonment costs are included in future development costs.
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves

    

For the Year Ended

December 31, 

2021

    

2020

(In thousands)

Beginning of year

$

297,811

$

916,561

Sale of oil and natural gas produced, net of production costs

 

(171,326)

 

(47,687)

Sale of minerals in place

 

(45)

 

Extensions and discoveries

 

17,035

 

3,687

Changes in prices and costs

 

572,897

 

(548,429)

Previously estimated development costs incurred

 

45,298

 

49,144

Net changes in future development costs

 

113,546

 

89,997

Revisions of previous quantities

 

46,271

 

(150,245)

Accretion of discount

 

29,781

 

91,657

Change in production rates and other

 

(31,423)

 

(106,874)

End of year

$

919,845

$

297,811