Civitas Resources (CIVI) 10-Q2023 Q1 Quarterly report

CIVITAS RESOURCES, INC.

FORM 10-Q

FOR THE QUARTER ENDED MARCH 31, 2023

TABLE OF CONTENTS

CIVITAS RESOURCES, INC. AND SUBSIDIARIES

 

Description of Operations

When we use the terms “Civitas,” the “Company,” “we,” “us,” or “our,” we are referring to Civitas Resources, Inc. and its consolidated subsidiaries unless the context otherwise requires. Civitas is an independent exploration and production company focused on the acquisition, development, and production of oil and associated liquids-rich natural gas in the Rocky Mountain region, primarily in the Denver-Julesburg Basin of Colorado (the “DJ Basin”). Our operations are focused on developing the horizontal Niobrara and Codell formations that have a low-cost structure, mature infrastructure, strong production efficiencies, multiple producing horizons, multiple service providers, established reserves, and prospective drilling opportunities, which help facilitate predictable production and achieve our business strategies.

Basis of Presentation

The accompanying unaudited condensed consolidated financial statements include the accounts of the Company and have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim financial information, the instructions to Quarterly Report on Form 10-Q, and Regulation S-X. Accordingly, pursuant to such rules and regulations, certain notes and other financial information included in audited financial statements have been condensed or omitted. In the opinion of management, all adjustments, consisting of normal recurring adjustments considered necessary for a fair presentation of interim financial information, have been included. All significant intercompany balances and transactions have been eliminated in consolidation.

Significant Accounting Policies

Recently Issued and Adopted Accounting Standards

There are no accounting standards applicable to the Company that would have a material effect on the Company’s financial statements and disclosures that have been issued but not yet adopted by the Company as of March 31, 2023, and through the filing date of this report.

NOTE 2 - ACQUISITIONS AND DIVESTITURES

Bison Acquisition

On March 1, 2022, the Company completed the acquisition of privately held DJ Basin operator Bison Oil & Gas II, LLC (“Bison”) for merger consideration of approximately $280.4 million (the “Bison Acquisition”). The Bison Acquisition was accounted for under the acquisition method of accounting for business combinations. Accordingly, we conducted assessments of the net assets acquired and recognized amounts for identifiable assets acquired and liabilities assumed at their estimated acquisition date fair values, while transaction and integration costs associated with the acquisition were expensed as incurred. The fair value measurements of assets acquired and liabilities assumed were based on inputs that are not observable in the market, and therefore represent Level 3 inputs. The fair values of oil and natural gas properties and asset retirement obligations were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of oil and natural gas properties include estimates of reserves, future operating and development costs, future commodity prices, estimated future cash flows, and a market-based weighted-average cost of capital. These inputs required significant judgments and estimates by management at the time of the valuation. Net assets acquired under the purchase price allocation were $294.0 million and consequently resulted in a bargain purchase gain of $13.6 million. Because of the immateriality of the Bison Acquisition, the related revenue and earnings, supplemental pro forma financial information, and detailed purchase price allocation are not disclosed.

Merger transaction costs

Merger transaction costs related to the Bison Acquisition and other mergers completed in the fourth quarter of 2021 were accounted for separately from the assets acquired and liabilities assumed and are included in merger transaction costs in the accompanying unaudited condensed consolidated statements of operations (“statements of operations”). The Company incurred merger transaction costs of $0.5 million and $20.5 million during the three months ended March 31, 2023 and 2022, respectively.

Acquisition of additional working interests in Company-operated wells

On July 5, 2022, the Company acquired additional working interests in certain Company-operated wells for cash consideration of $80.7 million, after customary purchase price adjustments.

The Company records revenue in the month production is delivered and control is transferred to the purchaser. However, settlement statements and payment may not be received for 30 to 60 days after the date production is delivered and control is transferred. Until such time settlement statements and payment are received, the Company records a revenue accrual based on, amongst other factors, an estimate of the volumes delivered at estimated prices as determined by the applicable contractual terms. The Company records the differences between its estimates and the actual amounts received for product sales in the month in which payment is received from the purchaser. For the three months ended March 31, 2023 and 2022, revenue recognized in the reporting period related to performance obligations satisfied in prior reporting periods was insignificant. As of March 31, 2023 and December 31, 2022, the Company’s receivables from contracts with customers were $222.4 million and $343.5 million, respectively.

NOTE 4 - ACCOUNTS PAYABLE AND ACCRUED EXPENSES

NOTE 5 - LONG-TERM DEBT

5.0% Senior Notes

On October 13, 2021, the Company issued $400.0 million aggregate principal amount of 5.0% Senior Notes due 2026 (the “5.0% Senior Notes”) pursuant to an indenture (the “5.0% Indenture”), among Civitas Resources, Wells Fargo Bank, National Association, as trustee, and the guarantors party thereto. Interest accrues at the rate of 5.0% per annum and is payable semiannually in arrears on April 15 and October 15 of each year. Payments commenced on April 15, 2022.

The 5.0% Indenture contains covenants that limit, among other things, the Company’s ability to: (i) incur or guarantee additional indebtedness; (ii) create liens securing indebtedness; (iii) pay dividends on or redeem or repurchase stock or subordinated debt; (iv) make specified types of investments and acquisitions; (v) enter into or permit to exist contractual limits on the ability of the Company’s subsidiaries to pay dividends to Civitas Resources; (vi) enter into transactions with affiliates; and (vii) sell assets or merge with other companies. These covenants are subject to a number of important limitations and exceptions. The Company was in compliance with all covenants under the 5.0% Indenture as of March 31, 2023, and through the filing of this report. In addition, certain of these covenants will be terminated before the 5.0% Senior Notes mature if at any time no default or event of default exists under the 5.0% Indenture and the 5.0% Senior Notes receive an investment-grade rating from at least two ratings agencies. The 5.0% Indenture also contains customary events of default.

At any time prior to October 15, 2023, the Company may redeem the 5.0% Senior Notes, in whole or in part, at a redemption price equal to the sum of (i) the principal amount thereof, plus (ii) the “make-whole” premium at the redemption date, plus (iii) accrued and unpaid interest, if any. On or after October 15, 2023, the Company may redeem all or part of the 5.0% Senior Notes at redemption prices (expressed as percentages of the principal amount redeemed) equal to (i) 102.5% for the twelve-month period beginning on October 15, 2023; (ii) 101.25% for the twelve-month period beginning on October 15, 2024; and (iii) 100.0% for the twelve-month period beginning October 15, 2025 and at any time thereafter, plus accrued and unpaid interest, if any.

The Company may redeem up to 35% of the aggregate principal amount of the 5.0% Senior Notes at any time prior to October 15, 2023 with an amount not to exceed the net cash proceeds from certain equity offerings at a redemption price equal to 105.0% of the principal amount of the 5.0% Senior Notes redeemed, plus accrued and unpaid interest, if any, provided, however, that (i) at least 65.0% of the aggregate principal amount of the 5.0% Senior Notes originally issued on the issue date (but excluding 5.0% Senior Notes held by the Company) remains outstanding immediately after the occurrence of such redemption (unless all such 5.0% Senior Notes are redeemed substantially concurrently) and (ii) the redemption occurs within 180 days after the date of the closing of such equity offering.

The 5.0% Senior Notes are fully and unconditionally guaranteed on a senior unsecured basis by all of Civitas’ existing subsidiaries.

The 5.0% Senior Notes are recorded net of unamortized deferred financing costs within senior notes on the accompanying balance sheets, with no associated discounts or premiums. The table below presents the related carrying value as of March 31, 2023 and December 31, 2022 (in thousands):

7.5% Senior Notes

In April 2021, the Company issued $100.0 million aggregate principal amount of 7.5% Senior Notes due 2026 (the “7.5% Senior Notes”) pursuant to an indenture by and among Civitas Resources, U.S. Bank National Association, as trustee, and the guarantors party thereto. Interest accrued at the rate of 7.5% per annum and was payable semiannually in arrears on April 30 and October 31 of each year. On May 1, 2022, the Company redeemed all of the issued and outstanding 7.5% Senior Notes at 100.0% of their aggregate principal amount, plus accrued and unpaid interest thereon to the redemption date.

Credit Facility

The Company is party to a reserve-based revolving facility, as the borrower, with JPMorgan Chase Bank, N.A. (“JPMorgan”), as the administrative agent, and a syndicate of financial institutions, as lenders, that has an aggregate maximum commitment amount of $2.0 billion and matures on November 1, 2025 (with all subsequent amendments, the “Credit Facility” or the “Credit Agreement”).

The Credit Facility is guaranteed by all restricted domestic subsidiaries of the Company, and is secured by first priority security interests on substantially all assets, including a mortgage on at least 90% of the total value of the proved properties evaluated in the most recently delivered reserve reports prior to the amendment effective date, including any engineering reports relating to the oil and natural gas properties of the restricted domestic subsidiaries of the Company, subject to customary exceptions.

The Credit Facility contains customary representations and affirmative covenants. The Credit Facility also contains customary negative covenants, which, among other things, and subject to certain exceptions, include restrictions on (i) liens, (ii) indebtedness, guarantees and other obligations, (iii) restrictions in agreements on liens and distributions, (iv) mergers or consolidations, (v) asset sales, (vi) restricted payments, (vii) investments, (viii) affiliate transactions, (ix) change of business, (x) foreign operations or subsidiaries, (xi) name changes, (xii) use of proceeds, letters of credit, (xiii) gas imbalances, (xiv) hedging transactions, (xv) additional subsidiaries, (xvi) changes in fiscal year or fiscal quarter, (xvii) operating leases, (xviii) prepayments of certain debt and other obligations, (xix) sales or discounts of receivables, (xx) dividend payment thresholds, and (xxi) cash balances. 

In addition, the Company is subject to certain financial covenants under the Credit Facility, as tested on the last day of each fiscal quarter, including, without limitation, (a) permitted net leverage ratio of 3.00 to 1 and (b) a current ratio, inclusive of the unused commitments then available to be borrowed, to not be less than 1.00 to 1. The Company was in compliance with all covenants under the Credit Facility as of March 31, 2023 and through the filing of this report.

On April 20, 2022, the Company entered into an amendment to the Credit Agreement that increased the Company’s borrowing base from $1.0 billion to $1.7 billion and increased the aggregate elected commitments from $800.0 million to $1.0 billion.

In addition, this amendment resulted in the removal and replacement of LIBOR with the Secured Overnight Financing Rate (“SOFR”) as a mechanism to determine interest for borrowings made under the Credit Facility using a term-specific SOFR. As a result, borrowings under the Credit Facility bear interest at a per annum rate equal to, at the option of the Company, either (i) the Alternate Base Rate (“ABR”, for ABR Revolving Credit Loans) plus the applicable margin, or (ii) the term-specific SOFR plus the applicable margin. ABR is established as a rate per annum equal to the greatest of (a) the rate of interest publicly announced by JPMorgan as its prime rate, (b) the applicable rate of interest published by the Federal Reserve Bank of New York plus 0.5%, or (c) the term-specific SOFR plus 1.0%, subject to a 1.5% floor plus the applicable margin of 1.0% to 2.0%, based on the utilization of the Credit Facility. Term-specific SOFR is based on one-, three-, or six-month terms as selected by the Company and is subject to a 0.5% floor plus the applicable margin of 2.0% to 3.0%, based on the utilization of the Credit Facility. Interest on borrowings that bear interest at the SOFR are payable on the last day of the applicable interest period selected by the Company, and interest on borrowings that bear interest at the ABR are payable quarterly in arrears. 

As part of the regularly scheduled, semi-annual borrowing base redeterminations under the Credit Facility, on October 27, 2022, the Company’s aggregate elected commitments of $1.0 billion were reaffirmed and borrowing base was increased from $1.7 billion to $1.85 billion, and on April 28, 2023, the Company’s aggregate elected commitments of $1.0 billion and borrowing base of $1.85 billion were reaffirmed. The next scheduled borrowing base redetermination date is set to occur in October 2023.

The following table presents the outstanding balance, total amount of letters of credit outstanding, and available borrowing capacity under the Credit Facility as of May 3, 2023, March 31, 2023, and December 31, 2022 (in thousands):

In connection with the amendments to the Credit Facility, the Company capitalized a total of approximately $11.9 million in deferred financing costs. Of the total post-amortization net capitalized amounts, (i) $4.8 million and $5.5 million are presented within other noncurrent assets on the accompanying balance sheets as of March 31, 2023 and December 31, 2022, respectively, and (ii) $3.0 million is presented within prepaid expenses and other on the accompanying balance sheets as of both March 31, 2023 and December 31, 2022.

For the three months ended March 31, 2023 and 2022, the Company incurred interest expense of $7.4 million and $9.1 million, respectively. No interest was capitalized during the three months ended March 31, 2023 and 2022.

NOTE 6 - COMMITMENTS AND CONTINGENCIES

Legal Proceedings 

From time to time, the Company is involved in various commercial and regulatory claims, litigation, and other legal proceedings that arise in the ordinary course of its business. The Company assesses these claims in an effort to determine the degree of probability and range of possible loss for potential accrual in its consolidated financial statements. In accordance with authoritative accounting guidance, an accrual is recorded for a loss contingency when its occurrence is probable and damages can be reasonably estimated based on the most likely anticipated outcome or the minimum amount within a range of possible outcomes. Because legal proceedings are inherently unpredictable and unfavorable resolutions could occur, assessing contingencies is highly subjective and requires judgments about uncertain future events. When evaluating contingencies, the Company may be unable to provide a meaningful estimate due to a number of factors, including the procedural status of the matter in question, the presence of complex or novel legal theories, and/or the ongoing discovery and development of information important to the matters. The Company regularly reviews contingencies to determine the adequacy of its accruals and related disclosures.

As of the filing date of this report, there were no probable, material pending, or overtly threatened legal actions against the Company of which it was aware, other than the following:

In May 2022, Boulder County alleged new legal theories and requested termination of the leases previously at issue in the Blue Paintbrush litigation. Boulder has raised these same claims in opposition to the Company’s pooling application before the Colorado Oil & Gas Conservation Commission (“COGCC”), which is set for hearing in May of 2023. The Company intends to vigorously defend against all claims alleged by Boulder County, both in the pooling hearing and in any subsequent action brought by Boulder County. If an action is brought by Boulder County, an adverse outcome in any such litigation could result in the Company failing to meet its development objectives in Blue Paintbrush.

Commitments

Additionally, the Company is also party to a gas gathering and processing agreement with several third-party producers and a third-party midstream provider to deliver to two different plants over terms that end in August 2025 and July 2026. The Company’s share of these commitments requires an incremental 51.5 and 20.6 million cubic feet of natural gas (“MMcf”) per day, respectively, over a baseline volume of 65 MMcf per day for a period of seven years following the in-service dates of the plants. The Company may be required to pay a shortfall fee for any incremental volume deficiencies under these commitments. These contractual obligations can be reduced by the Company’s proportionate share of the collective volumes delivered to the plants by other incremental third-party volumes available to the midstream provider that are in excess of the total commitments. Because of the third-party producer reduction provision, we believe that the aggregate financial commitment fee over the remaining term is zero as of March 31, 2023. The Company has not and does not expect to incur any deficiency payments.

The Company is also party to additional individually immaterial agreements that require the Company to pay a fee associated with the minimum volumes over various terms ending in April 2025, regardless of the amount delivered. The aggregate financial commitment fee over the remaining term for these contracts was $7.5 million as of March 31, 2023.

Long Term Incentive Plans

In April 2017, the Company adopted the 2017 Long Term Incentive Plan (“2017 LTIP”), which provides for the issuance of restricted stock units, performance stock units, and stock options, and reserved 2,467,430 shares of common stock. In June 2021, the Company adopted the 2021 Long Term Incentive Plan (“2021 LTIP”), which reserved an incremental 700,000 shares of common stock to those previously reserved under the 2017 LTIP. Finally, in conjunction with the Company’s merger with Extraction Oil & Gas, Inc. (“Extraction”) in November 2021, Civitas assumed Extraction’s 2021 Long Term Incentive Plan (the “Extraction Equity Plan”), which reserved 3,305,080 shares of common stock now issuable by Civitas. The 2017 LTIP, 2021 LTIP, and Extraction Equity Plan are collectively referred to herein as the “LTIP”.

The Company records compensation expense associated with the issuance of awards under the LTIP on a straight-line basis over the vesting period based on the fair value of the awards as of the date of grant within general and administrative expense. The following table outlines the compensation expense recorded by type of award (in thousands):

Restricted Stock Units and Deferred Stock Units

The Company grants time-based Restricted Stock Units (“RSUs”) to its officers, executives, and employees and time-based Deferred Stock Units (“DSUs”) to its non-employee directors as part of its LTIP. Each RSU and DSU represents a right to receive one share of the Company’s common stock at the end of the specified vesting period. RSUs generally vest and settle either over a (i) one-year vesting period, with the entire grant vesting and settling on the anniversary date or (ii) three-year vesting period, with one-third of the total grant vesting and settling on each anniversary date. Each RSU is entitled to a dividend equivalent right to receive, upon settlement, a cash payment based on the regular cash dividends that would have been paid on a share of the Company’s common stock during the period between the grant date and the date the RSUs vest and are settled. Accrued but unpaid dividend equivalents are recognized as a liability on the accompanying balance sheets, until the recipients receive the dividend equivalents upon vesting and settlement. DSUs generally vest in quarterly installments over a one-year period following the grant date. DSUs are settled in shares of the Company’s common stock upon the non-employee director’s separation of service from the Board of Directors (the “Board”). Each DSU is entitled to a dividend equivalent right to receive, on a current basis, a cash payment based on the regular cash dividends that would have been paid on a share of the Company’s common stock. The grant-date fair value of RSUs and DSUs is equal to the closing price of the Company’s common stock on the date of the grant.

The aggregate grant-date fair value of the RSUs and DSUs granted under the LTIP during the three months ended March 31, 2023 was $16.5 million.

Performance Stock Units

The Company grants market-based performance stock units (“PSUs”) to its officers and certain executives as part of its LTIP. The number of shares of the Company’s common stock issued to settle PSUs ranges from zero to 225% (or, for PSUs granted prior to fiscal year 2023, 200%) of the number of PSUs granted and is determined based on performance achievement against certain market-based criteria over a three-year performance period. PSUs generally vest and settle on December 31 of the year preceding the third anniversary of the date of grant. Each PSU is entitled to a dividend equivalent right to receive, upon settlement, a cash payment based on the regular cash dividends that would have been paid on a share of the Company’s common stock during the period between the grant date and the date the PSUs vest and are settled. Accrued but unpaid dividend equivalents are recognized as a liability on the accompanying balance sheets, until the recipients receive the dividend equivalents upon vesting and settlement.

Performance achievement is determined based on either, or a combination of, (1) the Company’s annualized absolute total shareholder return (“TSR”) or (2) for certain PSUs granted prior to fiscal year 2023, the Company’s absolute TSR relative to that of a defined peer group. Absolute TSR is determined based upon the performance of the Company's common stock over the performance period relative to the price of the Company’s common stock at the grant date. For awards with a relative TSR component, the Company’s absolute TSR is compared with the absolute TSRs of a group of peer companies over the performance period. The absolute TSR for the Company and each of the peer companies is determined by dividing (A) (i) the volume-weighted average share price for the last 30 trading days of the performance period, minus (ii) the volume-weighted average share price for the 30 trading days preceding the beginning of the performance period, plus (iii) dividends paid by (B) the volume-weighted average share price for the 30 trading days preceding the beginning of the performance period. The resultant amount is then annualized based on the length of the performance period.

The grant-date fair value of the PSUs was estimated using a Monte Carlo valuation model. The Monte Carlo valuation model is based on random projections of stock price paths and must be repeated numerous times to achieve a probabilistic assessment. Significant assumptions used in this valuation include the Company’s expected volatility as well as the volatilities for each of the Company’s peers and an interpolated risk-free interest rate based on U.S. Treasury yields with maturities consistent with the performance period.

The aggregate grant-date fair value of the PSUs granted under the LTIP during the three months ended March 31, 2023 was $20.3 million.

Stock Options

The LTIP allows for the issuance of stock options to the Company’s employees at the sole discretion of the Board. Options expire ten years from the grant date unless otherwise determined by the Board.

Stock options are valued using a Black-Scholes Model where expected volatility is based on an average historical volatility of a peer group selected by management over a period consistent with the expected life assumption on the grant date, the risk-free rate of return is based on the U.S. Treasury constant maturity yield on the grant date with a remaining term

equal to the expected term of the awards, and the Company’s expected life of stock option awards is derived from the midpoint of the average vesting time and contractual term of the awards.

The aggregate intrinsic value of options exercised during the three months ended March 31, 2023 was $0.5 million.

The Company follows authoritative accounting guidance for measuring the fair value of assets and liabilities in its financial statements. This guidance defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Further, this guidance establishes a hierarchy for inputs used in measuring fair value that maximizes the use of observable inputs and minimizes the use of unobservable inputs by requiring that the most observable inputs be used when available.

The fair value hierarchy is broken down into three levels based on the reliability of the inputs as follows:

Financial and non-financial assets and liabilities are classified 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 to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy.

Derivatives

Long-Term Debt

Warrants

Warrants issued are indexed to the Company’s common stock and required to be net share settled via a cashless exercise. Accordingly, they are classified as equity instruments. The Company’s share price traded below the exercise price of the warrants and therefore were not exercisable during the three months ended March 31, 2023 and 2022.

The fair value of the warrants on the issuance date was determined using Level 3 inputs including, but not limited to, volatility, risk-free rate, and dividend yield under the Cox-Ross-Rubinstein binomial option pricing model. The warrants are recorded within additional paid-in capital on the accompanying balance sheets at a fair value of $77.5 million, with no recurring fair value measurement required. There have been no changes to the initial carrying amount of the warrants since issuance.

Acquisitions and Impairments of Proved and Unproved Properties

The Company periodically enters into commodity derivative contracts to mitigate a portion of its exposure to potentially adverse market changes in commodity prices for its expected future oil and natural gas production and the associated impact on cash flows. The Company’s commodity derivative contracts consist of swaps, collars, and basis protection swap arrangements. As of March 31, 2023, all derivative counterparties were members of the Credit Facility lender group and all commodity derivative contracts are entered into for other-than-trading purposes. The Company does not designate its commodity derivative contracts as hedging instruments.

A typical swap arrangement guarantees a fixed price on contracted volumes. If the agreed upon published third-party index price (“index price”) is lower than the fixed contract price at the time of settlement, the Company receives the difference between the index price and the fixed contract price. If the index price is higher than the fixed contact price at the time of settlement, the Company pays the difference between the index price and the fixed contract price.

A typical collar arrangement establishes a floor and ceiling price on contracted volumes through the use of a short call and a long put (“two-way collar”). When the index price is above the ceiling price at the time of settlement, the Company pays the difference between the index price and the ceiling price. When the index price is below the floor price at the time of settlement, the Company receives the difference between the index price and floor price. When the index price is between the floor price and ceiling price, no payment or receipt occurs. A minority of our collar arrangements combine a two-way collar with a short put that holds an exercise price below the floor price (“three-way collar”). In these arrangements, when the index price is below the floor price at the time of settlement, the Company receives the difference between the index price and the floor price, capped at the difference between the floor price and the exercise price of the short put.

Basis protection swaps are arrangements that guarantee a price differential for natural gas from a specified delivery point. For basis protection swaps, the Company receives a payment from the counterparty if the price differential is greater than the stated terms of the contract and pays the counterparty if the price differential is less than the stated terms of the contract.

The Company’s commodity price derivatives are measured at fair value and are included in the accompanying balance sheets as derivative assets and liabilities. The following table contains a summary of all the Company’s derivative positions reported on the accompanying balance sheets as well as a reconciliation between the gross assets and liabilities and the potential effects of master netting arrangements on the fair value of the Company’s commodity derivative contracts as of March 31, 2023 and December 31, 2022 (in thousands):

The Company recognizes an estimated liability for future costs associated with the abandonment of its oil and gas properties, including facilities requiring decommissioning. A liability for the fair value of an asset retirement obligation and corresponding increase to the carrying value of the related long-lived asset are recorded at the time a well is drilled or acquired, or a facility is constructed. The increase in carrying value is included in proved properties in the accompanying balance sheets. The Company depletes the amount added to proved properties and recognizes expense in connection with the accretion of the discounted liability over the remaining estimated economic lives of the respective long-lived assets. Cash paid to settle asset retirement obligations is included in the cash flows from operating activities section of the accompanying unaudited condensed consolidated statements of cash flows.

The Company’s estimated asset retirement obligation liability is based on historical experience plugging and abandoning wells, estimated economic lives, estimated plugging and abandonment cost, and regulatory requirements. The liability is discounted using the credit-adjusted risk-free rate estimated at the time the liability is incurred or revised.

Earnings per basic and diluted share are calculated under the treasury stock method. Basic net income per common share is calculated by dividing net income by the basic weighted-average common shares outstanding for the respective period. Diluted net income per common share is calculated by dividing net income by the diluted weighted-average common shares outstanding, which includes the effect of potentially dilutive securities. Potentially dilutive securities consist of unvested RSUs, DSUs, PSUs as well as outstanding in-the-money stock options and warrants. When the Company recognizes a loss from continuing operations, all potentially dilutive shares are anti-dilutive and are consequently excluded from the calculation of diluted earnings per share.

The Company has also issued stock options and warrants, which both represent the right to purchase the Company’s common stock at a specified exercise price. The number of potentially dilutive shares related to the stock options and warrants is based on the number of shares, if any, that would be exercisable at the end of the respective reporting period, assuming that

Deferred tax assets and liabilities are measured by applying the provisions of enacted tax laws to determine the amount of taxes payable or refundable currently or in future years related to cumulative temporary differences between the tax basis of assets and liabilities and amounts reported in the accompanying balance sheets. The tax effect of the net change in the cumulative temporary differences during each period in the deferred tax assets and liabilities determines the periodic provision for deferred taxes.

The Company assesses the recoverability of its deferred tax assets each period by considering whether it is more likely than not that all or a portion of the deferred tax assets will be realized. In making such determination, the Company considers all available (both positive and negative) evidence, including future reversals of temporary differences, tax-planning strategies, projected future taxable income, and results of operations. As a result of merger activity in 2021, the Company had a valuation allowance of $25.4 million as of both March 31, 2023 and December 31, 2022 against certain acquired net operating losses and other tax attributes due to the limitation on realizability caused by the change of ownership provisions of Section 382 of the Internal Revenue Code. The Company will continue to monitor facts and circumstances in the reassessment of the likelihood that the deferred tax assets will be realized.

The net deferred tax liability as of March 31, 2023 and December 31, 2022 was $365.6 million and $319.6 million, respectively. Additionally, prepaid income taxes under current assets as of March 31, 2023 and December 31, 2022 were $7.7 million and $29.6 million, respectively.

Federal income tax expense differs from the amount that would be provided by applying the statutory United States federal income tax rate of 21% to income before income taxes primarily due to the effect of state income taxes, excess tax benefits and deficiencies on stock-based compensation awards, tax limitations on compensation of covered individuals, changes in valuation allowances, and other permanent differences including bargain purchase gain. During the three months ended March 31, 2023 and 2022, the Company recorded income tax expense of $65.1 million and $23.4 million, respectively.

The Company had no unrecognized tax benefits as of March 31, 2023 and December 31, 2022. The Company’s management does not believe that there are any new items or changes in facts or judgments that would impact the Company’s tax position taken thus far in 2023.

Supplemental cash flow disclosures are presented below (in thousands):

Share Repurchases

On January 24, 2023, we entered into a privately-negotiated share purchase agreement with CPPIB Crestone Peak Resources Canada Inc. for the purchase of approximately 4.9 million shares of the Company’s common stock at a price of $61.00 per share for a total purchase price of approximately $300.0 million. The purchase closed on January 27, 2023 and was funded from the Company’s cash on hand. The shares repurchased were immediately retired. We record share repurchases at cost, which includes incremental direct transaction costs, as a reduction to stockholder’s equity. As part of the incremental direct transaction costs, we recorded a 1% excise tax, as imposed by the IRA, with the corresponding liability recorded within accounts payable and accrued expenses on the accompanying balance sheets. Any excess of cost over the par value is charged to additional paid-in-capital on a pro-rata basis, with any remaining cost charged to retained earnings.

Dividends

In May 2021, we announced the initiation of a quarterly base cash dividend on our common stock. In March 2022, the Board approved the initiation of a quarterly variable cash dividend in addition to the aforementioned base dividend, equal to 50% of free cash flow after the base cash dividend for the preceding twelve-month period and pro forma for all acquisition and divestiture activity, assuming pro forma compliance with certain leverage targets.

The decision to pay any future dividends is solely within the discretion of, and subject to approval by, the Board. The Board’s determination with respect to any such dividends, including the record date, the payment date, and the actual amount of the dividend, will depend upon our profitability and financial condition, contractual restrictions, restrictions imposed by applicable law, and other factors that the Board deems relevant at the time of such determination. The following table summarizes the dividends paid for the three months ended March 31, 2023 and 2022 (per share):

We are an independent exploration and production company focused on the acquisition, development, and production of oil and associated liquids-rich natural gas in the Rocky Mountain region, primarily in the DJ Basin of Colorado. We believe our acreage in the DJ Basin has been significantly delineated by our own drilling success and by the success of offset operators, providing confidence that our results are repeatable and will continue to generate economic returns. The majority of our revenues are generated through the sale of oil, natural gas, and natural gas liquids production.

Our financial and operational results include:

The Company’s midstream assets provide reliable gathering, treating, and storage for the Company’s operated production while reducing facility site footprints, leading to more cost-efficient operations and reduced emissions and surface disturbance per Boe produced. Additionally, this infrastructure helps ensure that the Company’s production is not constrained by any single midstream service provider. The net book value of the Company’s midstream assets was $327.8 million as of March 31, 2023.

Commodity prices continue to be impacted by various macro-economic factors influencing the balance of supply and demand. In 2022 and continuing into 2023, commodity prices have remained strong, which significantly improved our earnings and ability to generate free cash flow. The strength in commodity prices has been primarily driven by increased demand resulting from the global recovery from the COVID-19 pandemic. Additionally, Russia’s invasion of Ukraine and related economic sanctions imposed on Russia, as well as OPEC+ restraining production growth, further augmented supply shortages, causing upward pressure on oil prices.

These drivers of upward price pressure are tempered by economic uncertainty surrounding inflation and increased interest rates. These inflationary pressures could also result in increases to our capital and operating expenses and could impact the cost of oilfield services, equipment, and personnel retention, among other things. Increases in interest rates as a result of inflation and a potentially recessionary economic environment in the United States could also have a negative effect on the demand for oil and natural gas. The foregoing destabilizing factors have caused dramatic fluctuations in global financial markets and uncertainty about world-wide oil and natural gas supply and demand, which in turn has increased the volatility of oil and natural gas prices.

The below graph depicts monthly average NYMEX WTI oil and NYMEX natural gas HH spot price over the periods ended March 31, 2023 and 2022.

In light of uncertainty associated with oil and natural gas demand, future monetary policy relating to inflationary pressures, and governmental policies aimed at transitioning toward lower carbon energy, we cannot predict any future volatility in or levels of commodity prices or demand for oil and natural gas.

The following discussion and analysis should be read in conjunction with our condensed consolidated financial statements and the notes thereto contained in Part I, Item 1 of this report. Comparative results of operations for the period indicated are discussed below.