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Derivative Financial Instruments | 12 Months Ended
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Dec. 31, 2022
Derivative Instruments Not Designated as Hedging Instruments [Abstract] |
Derivative Financial Instruments | Note 10 – Derivative Financial Instruments Summary of Oil, Gas, and NGL Derivative Contracts in Place The Company regularly enters into commodity derivative contracts to mitigate a portion of its exposure to oil, gas, and NGL price volatility and location differentials, and the associated impact on cash flows. As of the filing of this report, all contracts were entered into for other-than-trading purposes. The Company’s commodity derivative contracts consist of price swap and collar arrangements for oil, gas, and NGL production. In a typical commodity swap agreement, if the agreed upon published third-party index price (“index price”) is lower than the swap price, the Company receives the difference between the index price and the agreed upon swap price. If the index price is higher than the swap price, the Company pays the difference. For collar arrangements, the Company receives the difference between an agreed upon index price and the floor price if the index price is below the floor price. The Company pays the difference between the agreed upon ceiling price and the index price if the index price is above the ceiling price. No amounts are paid or received if the index price is between the floor and ceiling prices. The Company has entered into fixed price oil and gas basis swaps in order to mitigate exposure to adverse pricing differentials between certain industry benchmark prices and the actual physical pricing points where the Company’s production is sold. As of December 31, 2022, the Company had basis swap contracts with fixed price differentials between: •NYMEX WTI and WTI Midland for a portion of its Midland Basin oil production with sales contracts that settle at WTI Midland prices; •NYMEX WTI and Argus WTI Houston Magellan East Houston Terminal ("MEH”) for a portion of its South Texas oil production with sales contracts that settle at Argus WTI Houston MEH (“WTI Houston MEH”) prices; •NYMEX HH and Inside FERC West Texas (“IF Waha”) for a portion of its Midland Basin gas production with sales contracts that settle at IF Waha prices; and •NYMEX HH and Inside FERC Houston Ship Channel (“IF HSC”) for a portion of its South Texas gas production with sales contracts that settle at IF HSC prices. The Company has also entered into oil swap contracts to fix the differential in pricing between the NYMEX calendar month average and the physical crude oil delivery month (“Roll Differential”) in which the Company pays the periodic variable Roll Differential and receives a weighted-average fixed price differential. The weighted-average fixed price differential represents the amount of net addition (reduction) to delivery month prices for the notional volumes covered by the swap contracts. As of December 31, 2022, the Company had commodity derivative contracts outstanding through the fourth quarter of 2025 as summarized in the table below:
|  | Contract Period |  |
|  | First Quarter |  | Second Quarter |  | Third Quarter |  | Fourth Quarter |  |  |  |  |  |  |  |
|  | 2023 |  | 2023 |  | 2023 |  | 2023 |  | 2024 |  | 2025 |  |  |  |
Oil Derivatives (volumes in MBbl and prices in $ per Bbl): |  |  |  |  |  |  |  |  |  |  |  |  |  |
Swaps |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
NYMEX WTI Volumes |  | 294 |  |  | 333 |  |  | 304 |  |  | 259 |  |  | — |  |  | — |  |  |  |  |
Weighted-Average Contract Price |  | $ | 45.20 |  |  | $ | 45.18 |  |  | $ | 45.20 |  |  | $ | 45.23 |  |  | $ | — |  |  | $ | — |  |  |  |  |
ICE Brent Volumes |  | 900 |  |  | 910 |  |  | 920 |  |  | 920 |  |  | 910 |  |  | — |  |  |  |  |
Weighted-Average Contract Price |  | $ | 86.50 |  |  | $ | 86.50 |  |  | $ | 86.50 |  |  | $ | 86.50 |  |  | $ | 85.50 |  |  | $ | — |  |  |  |  |
Collars |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
NYMEX WTI Volumes |  | 577 |  |  | 464 |  |  | 291 |  |  | — |  |  | 919 |  |  | — |  |  |  |  |
Weighted-Average Floor Price |  | $ | 60.00 |  |  | $ | 67.85 |  |  | $ | 75.00 |  |  | $ | — |  |  | $ | 75.00 |  |  | $ | — |  |  |  |  |
Weighted-Average Ceiling Price |  | $ | 74.02 |  |  | $ | 81.53 |  |  | $ | 93.05 |  |  | $ | — |  |  | $ | 81.47 |  |  | $ | — |  |  |  |  |
Basis Swaps |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
WTI Midland-NYMEX WTI Volumes |  | 1,294 |  |  | 1,357 |  |  | 1,414 |  |  | 1,294 |  |  | 893 |  |  | — |  |  |  |  |
Weighted-Average Contract Price |  | $ | 0.99 |  |  | $ | 0.99 |  |  | $ | 0.88 |  |  | $ | 0.88 |  |  | $ | 1.10 |  |  | $ | — |  |  |  |  |
WTI Houston MEH-NYMEX WTI Volumes |  | 390 |  |  | 431 |  |  | 361 |  |  | 296 |  |  | 297 |  |  | — |  |  |  |  |
Weighted-Average Contract Price |  | $ | 1.65 |  |  | $ | 1.68 |  |  | $ | 1.59 |  |  | $ | 1.53 |  |  | $ | 1.75 |  |  | $ | — |  |  |  |  |
Roll Differential Swaps |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
NYMEX WTI Volumes |  | 1,220 |  |  | 1,243 |  |  | 1,304 |  |  | 1,201 |  |  | — |  |  | — |  |  |  |  |
Weighted-Average Contract Price |  | $ | 0.60 |  |  | $ | 0.62 |  |  | $ | 0.64 |  |  | $ | 0.62 |  |  | $ | — |  |  | $ | — |  |  |  |  |
Gas Derivatives (volumes in BBtu and prices in $ per MMBtu): |  |  |  |  |  |  |  |  |  |  |  |  |  |
Swaps |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
NYMEX HH Volumes |  | — |  |  | 1,420 |  |  | 1,470 |  |  | — |  |  | — |  |  | — |  |  |  |  |
Weighted-Average Contract Price |  | $ | — |  |  | $ | 5.05 |  |  | $ | 5.11 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  |  |  |
IF Waha Volumes |  | 900 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  |  |  |
Weighted-Average Contract Price |  | $ | 3.98 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  |  |  |
Collars |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
NYMEX HH Volumes |  | 7,919 |  |  | 5,181 |  |  | 6,194 |  |  | 8,362 |  |  | 13,722 |  |  | — |  |  |  |  |
Weighted-Average Floor Price |  | $ | 3.84 |  |  | $ | 3.83 |  |  | $ | 3.75 |  |  | $ | 3.90 |  |  | $ | 4.00 |  |  | $ | — |  |  |  |  |
Weighted-Average Ceiling Price |  | $ | 9.75 |  |  | $ | 4.68 |  |  | $ | 4.62 |  |  | $ | 5.70 |  |  | $ | 6.39 |  |  | $ | — |  |  |  |  |
IF HSC Volumes |  | 900 |  |  | 1,345 |  |  | 1,389 |  |  | 1,451 |  |  | — |  |  | — |  |  |  |  |
Weighted-Average Floor Price |  | $ | 3.38 |  |  | $ | 4.25 |  |  | $ | 4.25 |  |  | $ | 4.25 |  |  | $ | — |  |  | $ | — |  |  |  |  |
Weighted-Average Ceiling Price |  | $ | 7.75 |  |  | $ | 5.00 |  |  | $ | 4.95 |  |  | $ | 5.55 |  |  | $ | — |  |  | $ | — |  |  |  |  |
Basis Swaps |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
IF Waha-NYMEX HH Volumes |  | 1,816 |  |  | 2,462 |  |  | 2,442 |  |  | 2,337 |  |  | 20,958 |  |  | 20,501 |  |  |  |  |
Weighted-Average Contract Price |  | $ | (0.81) |  |  | $ | (1.93) |  |  | $ | (1.05) |  |  | $ | (1.01) |  |  | $ | (0.86) |  |  | $ | (0.66) |  |  |  |  |
IF HSC-NYMEX HH Volumes |  | 6,737 |  |  | 1,774 |  |  | 1,813 |  |  | 2,008 |  |  | — |  |  | — |  |  |  |  |
Weighted-Average Contract Price |  | $ | 0.19 |  |  | $ | (0.25) |  |  | $ | (0.25) |  |  | $ | (0.25) |  |  | $ | — |  |  | $ | — |  |  |  |  |
Commodity Derivative Contracts Entered Into Subsequent to December 31, 2022 Subsequent to December 31, 2022, and through the filing of this report, the Company entered into the following commodity derivative contracts: •NYMEX WTI price swap contracts for the third and fourth quarters of 2023 for a total of 0.6 MMBbl of oil production at a weighted-average contract price of $73.89 per Bbl; •WTI Midland-NYMEX WTI basis swap contracts for 2024 for a total of 2.1 MMBbl of oil production at a weighted-average contract price of $1.20 per Bbl; •WTI Houston MEH-NYMEX WTI basis swap contract for 2024 for a total of 0.6 MMBbl of oil production at a contract price of $1.90 per Bbl; •NYMEX WTI Roll Differential swap contracts for 2024 for a total of 2.2 MMBbl of oil production at a weighted-average contract price of $0.42 per Bbl; •NYMEX HH collar contracts for 2024 for a total of 5,735 BBtu of gas production at a weighted-average floor contract price of $3.00 per MMBtu and a weighted-average ceiling contract price of $4.70 per MMBtu; and •OPIS Propane Mont Belvieu Non-TET swap contract for the second through fourth quarters of 2023 for a total of 0.4 MMBbl of NGL production at a contract price of $36.12 per Bbl. Derivative Assets and Liabilities Fair Value The Company’s commodity derivatives are measured at fair value and are included in the accompanying balance sheets as derivative assets and liabilities, with the exception of derivative instruments that meet the “normal purchase normal sale” exclusion. The Company does not designate its commodity derivative contracts as hedging instruments. The fair value of the commodity derivative contracts at December 31, 2022, and 2021, was a net asset of $15.8 million and a net liability of $320.9 million, respectively. The following table details the fair value of commodity derivative contracts recorded in the accompanying balance sheets, by category:
| As of December 31, 2022 |  | As of December 31, 2021
| (in thousands)
Derivative assets: |  |  |
Current assets | $ | 48,677 |  |  | $ | 24,095 |
Noncurrent assets | 24,465 |  |  | 239 |
Total derivative assets | $ | 73,142 |  |  | $ | 24,334 |
Derivative liabilities: |  |  |
Current liabilities | $ | 56,181 |  |  | $ | 319,506 |
Noncurrent liabilities | 1,142 |  |  | 25,696 |
Total derivative liabilities | $ | 57,323 |  |  | $ | 345,202 |
Offsetting of Derivative Assets and Liabilities As of December 31, 2022, and 2021, all derivative instruments held by the Company were subject to master netting arrangements with various financial institutions. In general, the terms of the Company’s agreements provide for offsetting of amounts payable or receivable between it and the counterparty, at the election of both parties, for transactions that settle on the same date and in the same currency. The Company’s agreements also provide that in the event of an early termination, the counterparties have the right to offset amounts owed or owing under that and any other agreement with the same counterparty. The Company’s accounting policy is to not offset these positions in its accompanying balance sheets. The following table provides a reconciliation between the gross assets and liabilities reflected on the accompanying balance sheets and the potential effects of master netting arrangements on the fair value of the Company’s commodity derivative contracts:
|  | Derivative Assets as of |  | Derivative Liabilities as of
|  | December 31, 2022 |  | December 31, 2021 |  | December 31, 2022 |  | December 31, 2021
|  | (in thousands)
Gross amounts presented in the accompanying balance sheets |  | $ | 73,142 |  |  | $ | 24,334 |  |  | $ | (57,323) |  |  | $ | (345,202) |
Amounts not offset in the accompanying balance sheets |  | (26,136) |  |  | (22,862) |  |  | 26,136 |  |  | 22,862 |
Net amounts |  | $ | 47,006 |  |  | $ | 1,472 |  |  | $ | (31,187) |  |  | $ | (322,340) |
The Company recognizes all gains and losses from changes in commodity derivative fair values immediately in earnings rather than deferring such amounts in accumulated other comprehensive loss. The Company had no commodity derivative contracts designated as hedging instruments for the years ended December 31, 2022, 2021, and 2020. Please refer to Note 8 – Fair Value Measurements for more information regarding the Company’s derivative instruments, including its valuation techniques. The following table summarizes the commodity components of the derivative settlement (gain) loss, and the net derivative (gain) loss line items presented within the accompanying statements of cash flows and the accompanying statements of operations, respectively:
| For the Years Ended December 31,
| 2022 |  | 2021 |  | 2020
| (in thousands)
Derivative settlement (gain) loss: |  |  |  |  |
Oil contracts | $ | 514,641 |  |  | $ | 523,245 |  |  | $ | (331,559) |
Gas contracts | 171,598 |  |  | 152,361 |  |  | (11,898) |
NGL contracts | 24,461 |  |  | 73,352 |  |  | (7,804) |
Total derivative settlement (gain) loss: | $ | 710,700 |  |  | $ | 748,958 |  |  | $ | (351,261) |
Net derivative (gain) loss: |  |  |  |  |
Oil contracts | $ | 284,863 |  |  | $ | 650,959 |  |  | $ | (205,180) |
Gas contracts | 82,769 |  |  | 172,248 |  |  | 30,038 |
NGL contracts | 6,380 |  |  | 78,452 |  |  | 13,566 |
Total net derivative (gain) loss: | $ | 374,012 |  |  | $ | 901,659 |  |  | $ | (161,576) |
Credit Related Contingent Features As of December 31, 2022, all of the Company’s derivative counterparties were members of the Company’s Credit Agreement lender group. The Company does not enter into derivative contracts with counterparties that are not part of the lender group. Under the Credit Agreement, the Company is required to provide mortgage liens on assets having a value equal to at least 85 percent of the total PV-9, as defined in the Credit Agreement, of the Company’s proved oil and gas properties evaluated in the most recent reserve report. Collateral securing indebtedness under the Credit Agreement also secures the Company’s derivative agreement obligations.

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- Definition The entire disclosure for derivative instruments and hedging activities including, but not limited to, risk management strategies, non-hedging derivative instruments, assets, liabilities, revenue and expenses, and methodologies and assumptions used in determining the amounts. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -URI https://asc.fasb.org/topic&trid=2229140 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 40 -Section 50 -Paragraph 5 -Subparagraph (f) -URI https://asc.fasb.org/extlink&oid=126731327&loc=d3e90205-114008 + Details
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