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Supplemental Oil and Natural Gas Disclosures (Unaudited) (Tables) | 12 Months Ended
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Dec. 31, 2021
Extractive Industries [Abstract] |
Schedule of Oil and Natural Gas Reserve Information | The following table presents our net proved reserves for the years ended December 31, 2021, 2020 and 2019 and the changes in net proved oil, natural gas and NGL reserves during such years. In addition, the net proved reserves for our equity method investment, Exaro, are presented based on our 37% ownership percentage. Because Exaro was acquired in 2021 as part of the Merger Transactions, prior periods are not presented.
Developed and Undeveloped | Oil (MBbls) |  | Natural Gas (MMcf) |  | Natural Gas Liquids (MBbls) |  | Total (MBoe)
Consolidated operations |  |  |  |  |  |  |
Net proved reserves at December 31, 2018 | 202,805 |  | 1,189,962 |  | 75,780 |  | 476,913
Revisions of previous estimates | 10,477 |  | 20,552 |  | (11,321) |  | 2,581
Extensions, discoveries, and other additions (1) | 12,003 |  | 24,472 |  | 1,855 |  | 17,936
Sales of reserves in place | — |  | — |  | — |  | —
Purchases of reserves in place | — |  | — |  | — |  | —
Production | (13,752) |  | (73,747) |  | (5,188) |  | (31,231)
Net proved reserves at December 31, 2019 | 211,533 |  | 1,161,239 |  | 61,126 |  | 466,199
Revisions of previous estimates (2) | (57,708) |  | (478,153) |  | (20,279) |  | (157,680)
Extensions, discoveries, and other additions | 4,088 |  | 21,479 |  | 603 |  | 8,271
Sales of reserves in place | — |  | — |  | — |  | —
Purchases of reserves in place (3) | 22,409 |  | 196,840 |  | 18,952 |  | 74,168
Production | (13,132) |  | (78,541) |  | (5,078) |  | (31,300)
Net proved reserves at December 31, 2020 | 167,190 |  | 822,864 |  | 55,324 |  | 359,658
Revisions of previous estimates (4) | 9,147 |  | 316,572 |  | 16,480 |  | 78,389
Extensions, discoveries, and other additions | 7,007 |  | 17,247 |  | 2,093 |  | 11,975
Sales of reserves in place | (6,333) |  | (48,977) |  | (3,265) |  | (17,762)
Purchases of reserves in place (5) | 46,386 |  | 451,702 |  | 11,960 |  | 133,630
Production | (13,237) |  | (89,455) |  | (6,099) |  | (34,245)
Net proved reserves at December 31, 2021 | 210,160 |  | 1,469,953 |  | 76,493 |  | 531,645
Equity affiliate |  |  |  |  |  |  |
Net proved reserves at December 31, 2020 | — |  | — |  | — |  | —
Revisions of previous estimates | — |  | — |  | — |  | —
Extensions, discoveries, and other additions | — |  | — |  | — |  | —
Sales of reserves in place | — |  | — |  | — |  | —
Purchases of reserves in place | 205 |  | 20,880 |  | — |  | 3,685
Production | (1) |  | (115) |  | — |  | (20)
Net proved reserves at December 31, 2021 | 204 |  | 20,765 |  | — |  | 3,665
Total company |  |  |  |  |  |  |
Net proved reserves at December 31, 2019 | 211,533 |  | 1,161,239 |  | 61,126 |  | 466,199
Net proved reserves at December 31, 2020 | 167,190 |  | 822,864 |  | 55,324 |  | 359,658
Net proved reserves at December 31, 2021 | 210,364 |  | 1,490,718 |  | 76,493 |  | 535,310
(1)During the year ended December 31, 2019, we added 17.9 MMBoe of proved reserves from drilling activities and technical evaluation of major proved areas, primarily in the Eagle Ford and Permian. Approximately 77% of the reserve additions for the year ended December 31, 2019 were crude oil and NGLs. (2)Revisions of previous estimates include 92.0 MMBoe downward revisions of our PUD reserves. The revisions are primarily due to declining commodity prices which decreased the quantity of reserves recoverable from our proved locations, and also resulted in the removal of certain PUD locations that were uneconomic at year end prices. (3)Purchases in place of 74.2 MMBoe were primarily related to the Permian and DJ Basins. (4)Revisions of previous estimates include 92.7 MMBoe upward revision due to pricing and cost changes, offset by 21.1 MMBoe downward revisions of our PUD reserves due to the removal of certain locations that are no longer part of our five-year consolidated development plan following the Merger Transactions. (5)Purchases in place included 125.6 MMBoe from our Merger Transactions, 5.6 MMBoe from our Central Basin Platform Acquisition and 2.5 MMBoe from our DJ Basin Acquisition. The following table sets forth our net proved oil, natural gas and NGL reserves for both our consolidated operations and our investment in Exaro as of the years ended December 31, 2021 and 2020, 2019 and 2018:
Proved Developed Reserves | Oil (MBbls) |  | Natural Gas (MMcf) |  | Natural Gas Liquids (MBbls) |  | Total (MBoe)
Consolidated operations |  |  |  |  |  |  |
December 31, 2021 | 158,091 |  |  | 1,404,570 |  |  | 66,402 |  |  | 458,588 |
December 31, 2020 | 92,024 |  |  | 748,496 |  |  | 44,307 |  |  | 261,079 |
December 31, 2019 | 103,728 |  |  | 870,491 |  |  | 48,997 |  |  | 297,808 |
Equity affiliate |  |  |  |  |  |  |
December 31, 2021 | 204 |  |  | 20,765 |  |  | — |  |  | 3,665 |
December 31, 2020 | — |  |  | — |  |  | — |  |  | — |
December 31, 2019 | — |  |  | — |  |  | — |  |  | — |
Proved Undeveloped Reserves | Oil (MBbls) |  | Natural Gas (MMcf) |  | Natural Gas Liquids (MBbls) |  | Total (MBoe)
Consolidated operations |  |  |  |  |  |  |
December 31, 2021 | 52,069 |  |  | 65,383 |  |  | 10,091 |  |  | 73,057 |
December 31, 2020 | 75,166 |  |  | 74,368 |  |  | 11,017 |  |  | 98,579 |
December 31, 2019 | 107,805 |  |  | 290,748 |  |  | 12,129 |  |  | 168,391 |
Equity affiliate |  |  |  |  |  |  |
December 31, 2021 | — |  |  | — |  |  | — |  |  | — |
December 31, 2020 | — |  |  | — |  |  | — |  |  | — |
December 31, 2019 | — |  |  | — |  |  | — |  |  | — |
Schedule of Capitalized Costs Relating to Oil and Gas Producing Activities | The following table summarizes the capitalized costs relating to our oil and natural gas producing activities for both our consolidated operations and our investment in Exaro as of December 31, 2021 and 2020:
| As of December 31,
| 2021 |  | 2020
| (in thousands)
Consolidated operations |  |  |
Proved oil and natural gas properties (successful efforts method) | $ | 6,043,602 |  |  | $ | 4,910,059 |
Unproved oil and natural gas properties | 308,721 |  |  | 288,459 |
Oil and natural gas properties, at cost | 6,352,323 |  |  | 5,198,518 |
Less accumulated depreciation, depletion and amortization | (1,881,933) |  |  | (1,666,620) |
Net capitalized costs | $ | 4,470,390 |  |  | $ | 3,531,898 |
Equity affiliate |  |  |
Proved oil and natural gas properties (successful efforts method) | $ | 9,043 |  | $ | — |
Unproved oil and natural gas properties | — |  |  | — |
Oil and natural gas properties, at cost | 9,043 |  |  | — |
Less accumulated depreciation, depletion and amortization | (67) |  |  | — |
Net capitalized costs | $ | 8,976 |  |  | $ | — |
Schedule of Costs Incurred in Oil and Gas Property Acquisition, Exploration and Development Activities | The following table summarizes costs incurred related to our oil and natural gas activities for both our consolidated operations and our investment in Exaro for the years ended December 31, 2021, 2020 and 2019:
| Year Ended December 31,
| 2021 |  | 2020 |  | 2019
| (in thousands)
Consolidated operations |  |  |  |  |
Acquisition costs: |  |  |  |  |
Proved | $ | 1,098,696 |  |  | $ | 355,010 |  |  | $ | 795 |
Unproved | 41,355 |  |  | 680 |  |  | 7,264 |
Exploration costs | 1,180 |  |  | — |  |  | 710 |
Development | 194,828 |  |  | 83,013 |  |  | 318,157 |
Total costs incurred | $ | 1,336,059 |  |  | $ | 438,703 |  |  | $ | 326,926 |
Equity affiliate |  |  |  |  |
Acquisition costs: |  |  |  |  |
Proved | $ | — |  |  | $ | — |  |  | $ | — |
Unproved | — |  |  | — |  |  | — |
Exploration costs | — |  |  | — |  |  | — |
Development | — |  |  | — |  |  | — |
Total costs incurred | $ | — |  |  | $ | — |  |  | $ | — |
Schedule of Average First-Day-of-the-Month Price for Oil, Natural Gas and Natural Gas Liquids | The following table provides the average benchmark prices per unit, before location and quality differential adjustments, used to calculate the related reserve category:
| Year Ended December 31,
| 2021 |  | 2020 |  | 2019
Average benchmark price per unit: |
Crude oil (Bbl) | $ | 66.56 |  |  | $ | 39.56 |  |  | $ | 55.69 |
Natural gas (MMBtu) | $ | 3.60 |  |  | $ | 1.99 |  |  | $ | 2.62 |
Schedule of Standardized Measure Discounted Future Net Cash Flows | The following table sets forth the standardized measure of discounted future net cash flows for both our consolidated operations and our investment in Exaro from projected production of oil and natural gas reserves, for the years ended December 31, 2021, 2020 and 2019:
| Year Ended December 31,
2021 |  | 2020 |  | 2019
(in thousands)
Consolidated operations |  |  |  |  |
Future cash inflows | $ | 21,063,117 |  |  | $ | 8,232,932 |  |  | $ | 15,745,942 |
Future production costs | (10,194,648) |  |  | (4,280,563) |  |  | (6,766,410) |
Future development costs (1) | (1,477,562) |  |  | (1,353,957) |  |  | (2,323,420) |
Future income taxes | (352,136) |  |  | (30,155) |  |  | (63,136) |
Future net cash flows | 9,038,771 |  |  | 2,568,257 |  |  | 6,592,976 |
Annual discount of 10% for estimated timing | (4,080,471) |  |  | (1,240,397) |  |  | (3,482,128) |
Standardized measure of discounted future net cash flows | $ | 4,958,300 |  |  | $ | 1,327,860 |  |  | $ | 3,110,848 |
Equity affiliate (2) |  |  |  |  |
Future cash inflows | $ | 99,290 |  |  | $ | — |  |  | $ | — |
Future production costs | (55,371) |  |  | — |  |  | — |
Future development costs | (2,309) |  |  | — |  |  | — |
Future income taxes | (1,730) |  |  | — |  |  | — |
Future net cash flows | 39,880 |  |  | — |  |  | — |
Annual discount of 10% for estimated timing | (16,702) |  |  | — |  |  | — |
Standardized measure of discounted future net cash flows | $ | 23,178 |  |  | $ | — |  |  | $ | — |
(1) Future development costs include future abandonment and salvage costs. (2) The average benchmark prices used for the equity affiliate were $66.55 per barrel for crude oil and $3.64 per MMBtu for natural gas.
Schedule of Changes in the Standardized Measure of Discounted Future Net Cash Flows | The following table sets forth the changes in the standardized measure of discounted future net cash flows for both our consolidated operations and our investment in Exaro for the years ended December 31, 2021, 2020 and 2019:
| Year Ended December 31,
| 2021 |  | 2020 |  | 2019
| (in thousands)
Consolidated operations |  |  |  |  |
Balance at beginning of period | $ | 1,327,860 |  |  | $ | 3,110,848 |  |  | $ | 4,207,347 |
Net change in prices and production costs | 3,330,299 |  |  | (1,184,939) |  |  | (821,874) |
Net change in future development costs | 117,333 |  |  | 160,465 |  |  | (59,359) |
Sales and transfers of oil and natural gas produced, net of production expenses | (872,521) |  |  | (290,053) |  |  | (568,665) |
Extensions, discoveries, additions and improved recovery, net of related costs | 162,657 |  |  | 31,688 |  |  | 182,697 |
Purchases of reserves in place | 1,236,388 |  |  | 176,480 |  |  | — |
Sales of reserves in place | (84,095) |  |  | — |  |  | — |
Revisions of previous quantity estimates | (295,234) |  |  | (887,395) |  |  | (226,561) |
Previously estimated development costs incurred | 95,879 |  |  | 32,873 |  |  | 15,676 |
Net change in taxes | (184,419) |  |  | 19,350 |  |  | (19) |
Accretion of discount | 124,153 |  |  | 283,954 |  |  | 424,278 |
Changes in timing and other | — |  |  | (125,411) |  |  | (42,672) |
Balance at end of period | $ | 4,958,300 |  |  | $ | 1,327,860 |  |  | $ | 3,110,848 |
Equity affiliate |  |  |  |  |
Balance at beginning of period | $ | — |  |  | $ | — |  |  | $ | — |
Net change in prices and production costs | — |  |  | — |  |  | — |
Net change in future development costs | — |  |  | — |  |  | — |
Sales and transfers of oil and natural gas produced, net of production expenses | (1,246) |  |  | — |  |  | — |
Extensions, discoveries, additions and improved recovery, net of related costs | — |  |  | — |  |  | — |
Purchases of reserves in place | 26,154 |  |  | — |  |  | — |
Sales of reserves in place | — |  |  | — |  |  | — |
Revisions of previous quantity estimates | — |  |  | — |  |  | — |
Previously estimated development costs incurred | — |  |  | — |  |  | — |
Net change in taxes | (1,730) |  |  | — |  |  | — |
Accretion of discount | — |  |  | — |  |  | — |
Changes in timing and other | — |  |  | — |  |  | — |
Balance at end of period | $ | 23,178 |  |  | $ | — |  |  | $ | — |

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