Supplemental Oil And Gas Disclosures (Tables)

12 Months Ended

Dec. 31, 2020

Supplemental Oil and Gas Disclosures [Abstract]

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

The capitalized costs at year end were as follows:

	Successor		Predecessor
	2020		2019
	(In thousands)
Proved properties	$	238,581	$	6,341,582
Unproved properties (wells in progress)	1,591		252,874
	240,172		6,594,456
Accumulated depreciation, depletion, amortization, and impairment	(40,806)		(5,846,177)
Net capitalized costs	$	199,366	$	748,279

Schedule Of The Oil And Natural Gas Property Costs Not Being Amortized [Table Text Block]

The following table sets forth costs incurred related to our oil and natural gas activities for the periods indicated:

	Successor		Predecessor
	Period September 1, 2020 through December 31, 2020		Period January 1, 2020 through August 31, 2020		For the Year Ended December 31, 2019
	(In thousands)
Unproved properties acquired	$	26	$	2,373	$	34,668
Proved properties acquired	—		382		3,653
Exploration	—		—		16,480
Development	3,992		6,440		211,443
Asset retirement obligation	(1,702)		(29,189)		76
Total costs incurred	$	2,316	$	(19,994)	$	266,320

Results Of Operations For Producing Activities [Table Text Block]

The results of operations for producing activities are as follows:

	Successor		Predecessor
	Period September 1, 2020 through December 31, 2020		Period January 1, 2020 through August 31, 2020		For the Year Ended December 31, 2019
	(In thousands)
Revenues	$	55,272	$	96,033	$	314,925
Production costs	(20,510)		(46,633)		(116,051)
Depreciation, depletion, amortization, and impairment	(40,840)		(461,901)		(727,529)
	(6,078)		(412,501)		(528,655)
Income tax (expense) benefit	128		6,698		101,952
Results of operations for producing activities (excluding corporate overhead and financing costs)	$	(5,950)	$	(405,803)	$	(426,703)

Schedule Of Proved Developed And Undeveloped Oil And Gas Reserve Quantities [Table Text Block]

Estimated quantities of proved developed oil, NGLs, and natural gas reserves and changes in net quantities of proved developed and undeveloped oil, NGLs, and natural gas reserves were as follows:

	Oil Bbls	NGLs Bbls	Natural Gas Mcf	Total MBoe
	(In thousands)
2019
Proved developed and undeveloped reserves:
Beginning of year	22,558	47,796	535,963	159,681
Revision of previous estimates (1)	(8,263)	(20,961)	(234,852)	(68,366)
Extensions and discoveries (1)	703	845	8,798	3,015
Infill reserves in existing proved fields	271	434	4,806	1,506
Purchases of minerals in place	183	101	1,316	503
Production	(3,208)	(4,773)	(53,064)	(16,825)
Sales	(48)	(412)	(42,780)	(7,590)
Net proved reserves at December 31, 2019	12,196	23,030	220,187	71,924
Proved developed reserves, December 31, 2019	12,196	23,030	220,187	71,924
Proved undeveloped reserves, December 31, 2019	—	—	—	—
2020
Proved developed and undeveloped reserves:
Beginning of year	12,196	23,030	220,187	71,924
Revision of previous estimates	(1,909)	(4,477)	(38,901)	(12,870)
Extensions and discoveries	8	13	110	39
Infill reserves in existing proved fields	97	66	452	238
Purchases of minerals in place	62	20	172	112
Production	(2,186)	(3,444)	(37,567)	(11,891)
Sales	(1)	—	(62)	(11)
Net proved reserves at December 31, 2020	8,267	15,208	144,391	47,541
Proved developed reserves, December 31, 2020	8,267	15,208	144,391	47,541
Proved undeveloped reserves, December 31, 2020	—	—	—	—

_________________________

1.Revisions of previous estimates and extensions and discoveries decreased primarily due to the removal of proved undeveloped reserves due to uncertainty regarding our ability to finance the development of our proved undeveloped reserves over a five-year period and from lower commodity prices.

Standardized Measure Of Discounted Future Cash Flows Relating To Proved Reserves Disclosure [Table Text Block]

The standardized measure of discounted future net cash flows (SMOG) was calculated using 12-month average prices and year end costs adjusted for permanent differences that relate to existing proved oil, NGLs, and natural gas reserves. Future income tax expenses consider the Tax Act statutory tax rates. SMOG as of December 31 is as follows:

	Successor		Predecessor
	2020		2019
	(In thousands)
Future cash flows	$	698,685	$	1,386,777
Future production costs	(416,095)		(698,357)
Future development costs	—		—
Future income tax expenses	(39)		(321)
Future net cash flows	282,551		688,099
10% annual discount for estimated timing of cash flows	(89,530)		(226,390)
Standardized measure of discounted future net cash flows relating to proved oil, NGLs, and natural gas reserves	$	193,021	$	461,709

Schedule Of Principal Sources Of Changes In Standardized Measure Of Discounted Future Net Cash Flows [Table Text Block]

The principal sources of changes in the standardized measure of discounted future net cash flows were as follows:

	2020		2019
Sales and transfers of oil and natural gas produced, net of production costs	$	(84,163)	$	(200,233)
Net changes in prices and production costs	(165,978)		(508,066)
Revisions in quantity estimates and changes in production timing	(50,979)		(338,994)
Extensions, discoveries, and improved recovery, less related costs	2,827		53,123
Changes in estimated future development costs	—		311,190
Previously estimated cost incurred during the period	—		64,362
Purchases of minerals in place	852		6,416
Sales of minerals in place	(46)		(25,813)
Accretion of discount	46,203		110,571
Net change in income taxes	282		121,708
Changes in timing and other	(17,686)		(116,233)
Net change	(268,688)		(521,969)
Beginning of year	461,709		983,678
End of year	$	193,021	$	461,709