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Fair Value Measurements
 6 Months Ended
Jun. 30, 2024
Fair Value Disclosures [Abstract]  
Fair Value Measurements Fair Value Measurements
In accordance with the FASB’s authoritative guidance on fair value measurements, certain of the Company’s financial assets and liabilities are measured at fair value on a recurring basis. The Company’s financial instruments, including certain cash and cash equivalents, accounts receivable, accounts payable and other payables, are carried at cost, which approximates their respective fair market values due to their short-term maturities. The Company recognizes its non-financial assets and liabilities, such as ARO and properties acquired in a business combination or upon impairment, at fair value on a non-recurring basis.
Financial Assets and Liabilities
Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.
The following tables set forth by level, within the fair value hierarchy, the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis:
Fair value at June 30, 2024
Level 1Level 2Level 3Total
(In thousands)
Assets:
Commodity derivative contracts (see Note 6)
$— $1,100 $— $1,100 
Contingent consideration (see Note 6)
— 46,734 — 46,734 
Investment in unconsolidated affiliate (see Note 10)
117,738 — — 117,738 
Total assets$117,738 $47,834 $— $165,572 
Liabilities:
Commodity derivative contracts (see Note 6)
$— $15,371 $— $15,371 
Total liabilities$— $15,371 $— $15,371 

 Fair value at December 31, 2023
 Level 1Level 2Level 3Total
 (In thousands)
Assets:
Commodity derivative contracts (see Note 6)
$— $11,312 $5,877 $17,189 
Contingent consideration (see Note 6)
— 42,706 — 42,706 
Investment in unconsolidated affiliate (see Note 10)
100,172 — — 100,172 
Total assets$100,172 $54,018 $5,877 $160,067 
Liabilities:
Commodity derivative contracts (see Note 6)
$— $14,926 $— $14,926 
Total liabilities$— $14,926 $— $14,926 
Commodity derivative contracts. The Company enters into commodity derivative contracts to manage risks related to changes in crude oil, NGL and natural gas prices. The Company’s swaps, collars and basis swaps are valued by a third-party preparer based on an income approach. The significant inputs used are commodity prices, discount rate and the contract terms of the derivative instruments. These assumptions are observable in the marketplace throughout the full term of the contract, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace and are therefore designated as Level 2 within the fair value hierarchy. The Company recorded a credit risk adjustment to reduce the fair value of its net derivative liability for these contracts by $0.4 million and $0.5 million at June 30, 2024 and December 31, 2023, respectively. See Note 6—Derivative Instruments for additional information.
Transportation derivative contracts. The Company had buy/sell transportation contracts that were derivative contracts for which the Company had not elected the “normal purchase normal sale” exclusion under FASB ASC 815, Derivatives and Hedging. These transportation derivative contracts were valued by a third-party preparer based on an income approach. The significant inputs used were quoted forward prices for commodities, market differentials for crude oil and either the Company’s or the counterparty’s nonperformance risk, as appropriate. The assumptions used in the valuation of these contracts included certain market differential metrics that were unobservable during the term of the contracts. Such unobservable inputs were significant to the contract valuation methodology, and the contracts’ fair values were therefore designated as Level 3 within the fair value hierarchy as of December 31, 2023. As of June 30, 2024, the terms of these contracts expired. See Note 6—Derivative Instruments for additional information.
Contingent consideration. In June 2021, the Company completed the divestiture of oil and gas properties in the Texas region of the Permian Basin. In connection with the divestiture, the Company is entitled to receive up to three earn-out payments of $25.0 million per year for each of 2023, 2024 and 2025 if the average daily settlement price of NYMEX WTI exceeds $60 per barrel for such year (the “Permian Basin Sale Contingent Consideration”). If NYMEX WTI for calendar year 2023 or 2024 is less than $45 per barrel, then each calendar year thereafter the buyer’s obligation to make any remaining earn-out payments is terminated. The fair value of the Permian Basin Sale Contingent Consideration is determined by a third-party preparer using a Monte Carlo simulation model and Ornstein-Uhlenbeck pricing process. The significant inputs used are NYMEX WTI forward price curve, volatility, mean reversion rate and counterparty credit risk adjustment. The Company determined these were Level 2 fair value inputs that are substantially observable in active markets or can be derived from observable data. During the six months ended June 30, 2024, the Company received $25.0 million related to the 2023 earn-out payment. See Note 6—Derivative Instruments for additional information.
Investment in unconsolidated affiliate. The Company owns common units in Energy Transfer LP (“Energy Transfer”) which are accounted for using the fair value option under FASB ASC 825-10, Financial Instruments. The fair value of the Company’s investment in Energy Transfer was determined using Level 1 inputs based upon the quoted market price of Energy Transfer’s publicly traded common units at June 30, 2024 and December 31, 2023. See Note 10—Investment in Unconsolidated Affiliate for additional information.
Non-Financial Assets and Liabilities
The fair value of the Company’s non-financial assets and liabilities measured on a non-recurring basis are determined using valuation techniques that include Level 3 inputs.
Asset retirement obligations. The initial measurement of ARO at fair value is recorded in the period in which the liability is incurred. Fair value is determined by calculating the present value of estimated future cash flows related to the liability. Estimating the future ARO requires management to make estimates and judgments regarding the timing and existence of a liability, as well as what constitutes adequate restoration when considering current regulatory requirements. Inherent in the fair value calculation are numerous assumptions and judgments, including the ultimate costs, inflation factors, credit-adjusted discount rates, timing of settlement and changes in the legal, environmental and regulatory environments.
Oil and gas and other properties. The Company records its properties at fair value when acquired in a business combination or upon impairment for proved oil and gas properties and other properties. Fair value is determined using a discounted cash flow model. The inputs used are subject to management’s judgment and expertise and include, but are not limited to, future production volumes based upon estimates of proved reserves, future commodity prices (adjusted for basis differentials), estimates of future operating and development costs and a risk-adjusted discount rate.
Enerplus Arrangement. On May 31, 2024, the Company completed the Arrangement with Enerplus. The assets acquired and liabilities assumed were recorded at fair value as of May 31, 2024. The fair value of Enerplus’ oil and gas properties was calculated using an income approach based on the net discounted future cash flows from the producing properties and related assets. The inputs utilized in the valuation of the oil and gas properties and related assets acquired included mostly unobservable inputs which fall within Level 3 of the fair value hierarchy. Such inputs included estimates of future oil and gas production from the properties’ reserve reports, forecasted commodity prices (adjusted for basis differentials), operating and development costs, expected future development plans for the properties and the utilization of a discount rate based on a market-based weighted-average cost of capital. The Company also recorded ARO assumed from Enerplus at fair value. The inputs utilized in valuing the assumed ARO were mostly Level 3 unobservable inputs, including estimated economic lives of oil and natural gas wells as of May 31, 2024, anticipated future plugging and abandonment costs and an appropriate credit-adjusted risk-free rate to discount such costs. In addition, the Company recorded goodwill as a result of the Enerplus Arrangement. Goodwill is subject to ongoing impairment evaluation as described in Note 1—Organization and Summary of Significant Accounting Policies—Goodwill. See Note 8—Acquisitions for additional information.
2023 Williston Basin Acquisition. On June 30, 2023, the Company completed the 2023 Williston Basin Acquisition (defined in Note 8—Acquisitions). The assets acquired and liabilities assumed were recorded at fair value as of June 30, 2023. The fair value of the oil and gas properties acquired was calculated using an income approach based on the net discounted future cash flows from the oil and gas properties. The inputs utilized in the valuation of the oil and gas properties acquired included mostly unobservable inputs which fall within Level 3 of the fair value hierarchy. Such inputs included estimates of future oil and gas production from the properties’ reserve reports, commodity prices based on forward strip price curves (adjusted for basis differentials), operating and development costs, expected future development plans for the properties and the utilization of a discount rate based on a market-based weighted-average cost of capital. The Company also recorded the ARO assumed from the 2023 Williston Basin Acquisition at fair value. The inputs utilized in valuing the ARO were mostly Level 3 unobservable inputs, including estimated economic lives of oil and natural gas wells as of June 30, 2023, anticipated future plugging and abandonment costs and an appropriate credit-adjusted risk-free rate to discount such costs. See Note 8—Acquisitions for additional information.