Oil and Gas Reserves Information (Unaudited)

12 Months Ended

Dec. 31, 2020

Oil and Gas Reserves Information (Unaudited)

Set forth below is a summary of the Company's proved oil and natural gas reserves:


	Predecessor		Successor
	Period from January 1, 2018 through August 13, 2018		Period from August 14, 2018 through December 31, 2018		Year Ended December 31, 2019		Year Ended December 31, 2020
	Oil (MBbls)	Natural Gas (MMcf)	Oil (MBbls)	Natural Gas (MMcf)	Oil (MBbls)	Natural Gas (MMcf)	Oil (MBbls)	Natural Gas (MMcf)
Proved Reserves:
Beginning of period (1)	7,552	1,116,956	28,994	2,246,501	23,612	2,282,758	16,747	5,341,497
Revisions of previous estimates	4	17,778	5	23,949	(4,621)	62,697	(4,241)	306,552
Extensions and discoveries	5,651	950,032	—	30,126	259	315,286	2	365,663
Acquisitions of minerals in place	—	220,088	—	33,612	240	3,023,109	—	—
Sales of minerals in place	(6,870)	(54,341)	(4,002)	(6,399)	(58)	(49,520)	—	—
Production	(287)	(55,240)	(1,385)	(45,031)	(2,685)	(292,833)	(1,508)	(450,836)
End of period	6,050	2,195,273	23,612	2,282,758	16,747	5,341,497	11,000	5,562,876
Proved Developed Reserves:
Beginning of period (1)	7,552	436,114	22,845	550,198	21,466	583,107	15,104	1,890,357
End of period	403	500,031	21,466	583,107	15,104	1,890,357	11,000	1,967,288
Proved Undeveloped Reserves:
Beginning of period (1)	—	680,842	6,149	1,696,303	2,146	1,699,651	1,643	3,451,140
End of period	5,647	1,695,242	2,146	1,699,651	1,643	3,451,140	—	3,595,588

___________

(1)The beginning proved reserves balance at August 14, 2018 represents the contributed Bakken shale properties and the reserves of the Predecessor on a combined basis.

Revisions of previous estimates. Revisions of previous estimates in 2018, 2019 and 2020 were primarily attributable to higher production performance from the Company's wells as compared to expected performance from proved undeveloped locations included in proved reserves in the previous year which exceeded downward revisions that primarily related to changes related to oil and natural gas prices that were used to determine proved reserves in that year. Revisions of previous estimates associated with changes in oil prices were none in 2018, 0.5 MMBbls of negative revisions in 2019 and 2.9 MMBbls of negative revisions in 2020. Revisions of previous estimates associated with changes in natural gas prices were none in 2018, 228.5 Bcfe of negative revisions in 2019 and 68.2 Bcf of negative revisions in 2020.

Extensions and discoveries. Extensions and discoveries for 2018, 2019 and 2020 were primarily comprised of proved reserve additions attributable to the wells drilled in the current year that were not classified as proved undeveloped in prior years and additional proved undeveloped reserves added from the Company's drilling program.

Acquisitions of minerals in place. The significant acquisitions of minerals in place in 2019 is primarily related to the Covey Park Acquisition.

The following table sets forth the standardized measure of discounted future net cash flows relating to proved reserves:


	Predecessor		Successor
	As of August 13, 2018		As of December 31, 2018		As of December 31, 2019		As of December 31, 2020
	(In thousands)
Cash Flows Relating to Proved Reserves:
Future Cash Flows	$	6,384,203	$	8,054,092	$	13,078,155	$	9,871,616
Future Costs:
Production	(1,804,559)		(2,160,912)		(3,562,042)		(3,173,350)
Development and Abandonment	(1,945,141)		(1,800,335)		(3,171,351)		(2,592,520)
Future Income Taxes	(199,589)		(622,241)		(676,759)		(154,872)
Future Net Cash Flows	2,434,914		3,470,604		5,668,003		3,950,874
10% Discount Factor	(1,556,927)		(1,996,764)		(2,754,792)		(2,015,149)
Standardized Measure of Discounted Future Net Cash Flows	$	877,987	$	1,473,840	$	2,913,211	$	1,935,725

The following table sets forth the changes in the standardized measure of discounted future net cash flows relating to proved reserves:


	Predecessor		Successor
	For the Period from January 1, 2018 through August 13, 2018		For the Period from August 14, 2018 through December 31, 2018		Year Ended December 31, 2019		Year Ended December 31, 2020
	(In thousands)
Standardized Measure, Beginning of Year	$	881,544	$	1,317,383	$	1,473,840	$	2,913,211
Net change in sales price, net of production costs	(61,662)		223,731		(716,930)		(1,858,026)
Development costs incurred during the year which were previously estimated	86,086		112,073		311,331		302,135
Revisions of quantity estimates	19,815		27,090		16,340		215,268
Accretion of discount	53,413		55,692		175,514		326,074
Changes in future development and abandonment costs	(27,489)		23,139		(93,476)		313,191
Changes in timing and other	(17,723)		9,434		180,314		(127,663)
Extensions and discoveries	167,986		15,263		442,099		180,624
Acquisitions of minerals in place	72,738		54,143		1,813,491		—
Sales of minerals in place	(124,083)		(42,870)		(51,070)		—
Sales, net of production costs	(129,991)		(181,218)		(580,922)		(612,194)
Net changes in income taxes	(42,647)		(140,020)		(57,320)		283,105
Standardized Measure, End of Year	$	877,987	$	1,473,840	$	2,913,211	$	1,935,725

The standardized measure of discounted future net cash flows was determined based on the simple average of the first of month market prices for oil and natural gas for each year. Prices used in determining quantities of oil and natural gas reserves and future cash inflows from oil and natural gas reserves represent prices received at the Company's sales point. These prices have been adjusted from posted or index prices for both location and quality differences.

Prices used in determining oil and natural gas reserves quantities and cash flows are as follows:


	Predecessor		Successor
	For the Period from January 1, 2018 through August 13, 2018		For the Period from August 14, 2018 through December 31, 2018		Year Ended December 31, 2019		Year Ended December 31, 2020
Crude Oil: $/barrel	$	62.29	$	61.21	$	55.69	$	39.57
Natural Gas: $/Mcf	$	2.74	$	2.90	$	2.58	$	1.99

Proved reserve information utilized in the preparation of the financial statements were based on estimates prepared by the Company's petroleum engineering staff in accordance with guidelines established by the Securities and Exchange Commission and the Financial Accounting Standards Board, which require that reserve reports be prepared under existing economic and operating conditions with no provision for price and cost escalation except by contractual agreement. All of the Company's reserves are located onshore in the continental United States of America. The Company retained two independent petroleum consultants to conduct audits of the Company's 2020 reserve estimates. The purpose of these audits was to provide additional assurance on the reasonableness of internally prepared reserve estimates. The engineering firms were selected for their geographic expertise and their historical experience.

Future development and production costs are computed by estimating the expenditures to be incurred in developing and producing proved oil and gas reserves at the end of the year, based on year end costs and assuming continuation of existing economic conditions. Future income tax expenses are computed by applying the appropriate statutory tax rates to the future pre-tax net cash flows relating to proved reserves, net of the tax basis of the properties involved. The future income tax expenses give effect to permanent differences and tax credits, but do not reflect the impact of future operations.