Supplementary Financial Information for Oil and Gas Producing Activities (Unaudited)

12 Months Ended

Dec. 31, 2023

Supplementary Financial Information for Oil and Gas Producing Activities (Unaudited)

All of our operations are directly related to oil and gas producing activities located in the United States primarily in the San Juan Basin of New Mexico and Colorado and the Permian Basin of West Texas and New Mexico.

Costs Incurred Related to Oil and Gas Producing Activities

The following table summarizes costs incurred whether such costs are capitalized or expensed for financial reporting purposes for each year:


(in thousands)
	2023		2022		2021
Acquisition of proved properties, net	$	8,895	$	57,392	$	181,651
Acquisition of unproved properties	72		50		67
Development	29,820		29,833		8,142
Asset retirement obligation incurred upon acquisition	1,420		3,357		10,741
Total costs incurred	$	40,207	$	90,632	$	200,601

Proved Reserves

Our proved oil and gas reserves have been estimated by independent petroleum engineers. Proved reserves are those quantities of oil and natural gas, which, by analysis of geoscience and engineering data can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs and under existing economic conditions, operating methods, and government regulation before the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain. Proved developed reserves are the quantities expected to be recovered through existing wells with existing equipment and operating methods in which the cost of the required equipment is relatively minor compared with the cost of a new well. Due to the inherent uncertainties and the limited nature of reservoir data, such estimates are subject to change as additional information becomes available. The reserves actually recovered and the timing of production of these reserves may be substantially different from the original estimate. Revisions result primarily from new information obtained from development drilling and production history and from changes in economic factors. Proved reserves exclude volumes deliverable to others under production payments or retained interests.

Standardized Measure

The standardized measure of discounted future net cash flows and changes in such cash flows are prepared using assumptions required by the Financial Accounting Standards Board. Such assumptions include the use of 12-month average prices for oil and gas, based on the first-day-of-the-month price for each month in the period, and year end costs for estimated future development and production expenditures to produce year-end estimated proved reserves. Discounted future net cash flows are calculated using a 10% rate. No provision is included for federal income taxes since our future net cash flows are not subject to taxation. Limited liability companies are subject to the Texas margin tax.

Estimated well abandonment costs, net of salvage values, are deducted from the standardized measure using year-end costs and discounted at the 10% rate. Such abandonment costs are recorded as a liability on the consolidated balance

sheet, using estimated values as of the projected abandonment date and discounted using a risk-adjusted rate at the time the well is drilled or acquired (Note 7).

The standardized measure does not represent management’s estimate of our future cash flows or the value of proved oil and natural gas reserves. Probable and possible reserves, which may become proved in the future, are excluded from the calculations. Furthermore, prices used to determine the standardized measure are influenced by supply and demand as effected by recent economic conditions as well as other factors and may not be the most representative in estimating future revenues or reserve data.


Proved Reserves	Oil (Bbls)	Natural Gas Liquids (Bbls)	Gas (Mcf)	Oil Equivalents (Boe)
(in thousands)
December 31, 2020	19,604.8	8,311.2	243,172.9	68,444.8
Extensions, additions and discoveries	38.3	14.5	6,048.3	1,060.9
Revisions	2,758.8	7,277.1	152,978.3	35,532.3
Production	(1,033.0)	(1,088.8)	(30,589.7)	(7,220.1)
Purchase in place	27,236.7	3,513.6	7,666.1	32,028.0
December 31, 2021	48,605.6	18,027.6	379,275.9	129,845.9
Extensions, additions and discoveries	943.6	131.0	1,804.9	1,375.4
Revisions	925.3	4,320.1	56,198.3	14,611.7
Production	(2,205.7)	(1,334.3)	(29,556.9)	(8,466.1)
Purchase in place	5,240.4	788.0	155.0	6,054.2
December 31, 2022	53,509.2	21,932.4	407,877.2	143,421.1
Extensions, additions and discoveries	71.7	0.0	7,050.2	1,246.7
Revisions	(11,628.5)	(5,245.0)	(121,848.5)	(37,181.5)
Production	(2,375.6)	(1,231.8)	(28,738.7)	(8,397.2)
Purchase in place	876.3	27.4	1,487.4	1,151.6
December 31, 2023	40,453.1	15,483.0	265,827.6	100,240.7


Proved Developed Reserves	Oil (Bbls)	Natural Gas Liquids (Bbls)	Gas (Mcf)	Oil Equivalents (Boe)
(in thousands)
December 31, 2020	9,787.7	8,311.2	218,396.9	54,498.4
December 31, 2021	30,207.9	17,434.2	353,214.9	106,511.3
December 31, 2022	34,672.0	20,723.6	385,188.6	119,593.7
December 31, 2023	30,959.4	15,110.9	264,934.4	90,226.0


Proved Undeveloped Reserves	Oil (Bbls)	Natural Gas Liquids (Bbls)	Gas (Mcf)	Oil Equivalents (Boe)
(in thousands)
December 31, 2020	9,817.1	—	24,776.0	13,946.4
December 31, 2021	18,397.7	593.4	26,061.0	23,334.6
December 31, 2022	18,837.2	1,208.8	22,688.6	23,827.4
December 31, 2023	9,493.7	372.1	893.2	10,014.7

In 2023, the 1.2 Mboe of purchases in place represent the reserves acquired from multiple acquisitions. The 1.2 MBoe of extensions, additions and discoveries in proved reserves in 2023 were primarily related to drilling the San Juan

Basin and Permian Basin. The 37.2 MBoe of downward revisions in proved reserves for 2023 were the result of a combination of lower commodity prices and higher costs (22.6 MBoe) and changes in the development plan (14.6 MBoe).

In 2022, the 6.1 Mboe of purchases in place represent the reserves acquired from Vendera (5.6 MBoe) and Kaiser Francis (0.4 MBoe). The 1.4 MBoe of extensions, additions and discoveries in proved reserves in 2022 were primarily related to drilling the San Juan Basin and Permian Basin. The 14.6 MBoe of upward revisions in proved reserves for 2022 were the result of a combination of higher commodity prices (14.9 MBoe) partially offset by changes in the development plan (0.2 MBoe).

In 2021, the 32.0 Mboe of purchases in place represent the reserves acquired from Chevron in November 2021 (24.9 Mboe) and in December 31, 2022 (7.1 Mboe). The 1.1 MBoe of extensions, additions and discoveries in proved reserves in 2021 were primarily related to drilling the San Juan Basin. The 35.5 Mboe of upward revisions in proved reserves for 2021 were the result of a combination of higher commodity prices (34.9 Mboe) and changes in the development plan (0.6 Mboe).


Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Reserves	December 31,		December 31,		December 31,
	2023		2022		2021
(in thousands)
Future cash inflows	$	4,101,171	$	7,663,099	$	4,468,597
Future costs:
Production	(2,091,880)		(2,906,249)		(1,988,988)
Development	(353,191)		(414,061)		(365,289)
Future income tax	(2,143)		(7,467)		(4,110)
Future net cash flows	1,653,957		4,335,322		2,110,210
10% annual discount	(763,365)		(2,365,504)		(1,123,593)
Standardized measure	$	890,592	$	1,969,818	$	986,617


Changes in Standardized Measure of Discounted Future Net Cash Flows	For the Year Ended December 31,
	2023			2022			2021
(in thousands)
Standardized measure, beginning of period	$	1,969,818		$	986,617		$	154,438
Revisions:
Prices and costs	(1,053,775)			745,577			205,842
Quantity estimates	(147,398)			213,687			76,737
Income tax	2,250			(1,491)			(1,933)
Future development costs	(106)			(2,521)			2,715
Accretion of discount	196,982			98,662			15,444
Production rates and other	22,868			(39,947)			42,064
Net revisions	(979,179)			1,013,967			340,869
Additions and discoveries	(8,047)			25,502			20,272
Production	(137,393)			(226,960)			(93,042)
Development costs	29,820			29,833			13,973
Purchases in place	15,573			140,859			550,107
Net change	(1,079,226)			983,201			832,179
Standardized measure, December 31	$	890,592	(a)	$	1,969,818	(b)	$	986,617	(c)

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(a)The December 31, 2023 standardized measure includes a reduction of $292.0 million ($292.5 million before income tax) for estimated property abandonment costs. The consolidated balance sheet at December 31, 2023 includes a liability of $154.0 million for the same asset retirement obligation, which was calculated using different cost and present value assumptions.

(b)The December 31, 2022 standardized measure includes a reduction of $248.0 million ($248.4 million before income tax) for estimated property abandonment costs. The consolidated balance sheet at December 31, 2022 includes a liability of $126.5 million for the same asset retirement obligation, which was calculated using different cost and present value assumptions.

(c)The December 31, 2021 standardized measure includes a reduction of $213.1 million ($213.6 million before income tax) for estimated property abandonment costs. The consolidated balance sheet at December 31, 2021 includes a liability of $104.5 million for the same asset retirement obligation, which was calculated using different cost and present value assumptions.

Price and cost revisions are primarily the net result of changes in prices, based on beginning of year reserve estimates. Quantity estimate revisions are primarily the result of the extended economic life of proved reserves and proved undeveloped reserve additions attributable to increased development activity.

Average realized oil prices used in the estimation of proved reserves and calculation of the standardized measure were $76.58 for 2023, $92.94 for 2022 and $64.76 for 2021. Average realized natural gas liquids prices were $18.44 for 2023, $29.72 for 2022 and $19.62 for 2021. Average realized gas prices were $1.58 for 2023, $4.35 for 2022 and $2.31 for 2021. We used 12-month average oil and gas prices, based on the first-day-of-the-month price for each month in the period.