Vitesse Energy Inc

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacity and on the dates indicated:

INDEX TO FINANCIAL STATEMENTS

To the shareholders and the Board of Directors of Vitesse Energy, Inc.

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of Vitesse Energy, Inc. and subsidiaries (the "Company") as of December 31, 2023 and 2022, the related consolidated statements of operations, equity, and cash flows for the years ended December 31, 2023 and 2022, the one-month period ended December 31, 2021, and for the year ended November 30, 2021, and the related notes (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2023 and 2022, and the results of its operations and its cash flows for the years ended December 31, 2023 and 2022, the one-month period ended December 31, 2021, and year ended November 30, 2021, in conformity with accounting principles generally accepted in the United States of America.

Basis for Opinion

These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

/s/Deloitte & Touche LLP

Denver, Colorado

February 26, 2024

We have served as the Company’s auditor since 2021.

Consolidated Statements of Equity

Notes to the Consolidated Financial Statements

Note 1—Nature of Business

Vitesse Energy, Inc. (“Vitesse” or the “Company”) was incorporated under the General Corporation Law of the State of Delaware on August 5, 2022 as a wholly owned subsidiary of an affiliate of Jefferies Financial Group Inc. (“JFG”) for the purpose of effecting the Spin-Off of Vitesse Energy, LLC (the “Predecessor”) by JFG. On January 13, 2023, JFG completed the legal and structural separation of the Predecessor from JFG. To effect the separation, first, JFG and Jefferies Capital Partners (“JCP”), among others, undertook certain pre-Spin-Off Transactions described below:

*Certain members of management of the Predecessor transferred all of their equity interest in the Predecessor to JFG as repayment for loans from affiliates of JFG;

*JFG and other holders of the Predecessor’s equity interests transferred all of their interest in the Predecessor to Vitesse in exchange for newly issued shares of common stock, par value $0.01 per share (“common stock”), of Vitesse;

*Vitesse Oil, LLC ("Vitesse Oil") equity holders transferred their interests in Vitesse Oil to Vitesse in exchange for newly issued shares of Vitesse common stock (the “Vitesse Oil Transaction”);

*Compensation agreements and compensation plans of the Predecessor were eliminated and replaced with new compensation plans of Vitesse, including a long-term incentive plan;

*Vitesse entered into a Revolving Credit Facility, which amended and restated the Predecessor’s credit facility, and used the proceeds to repay in full and terminate the Vitesse Oil Revolving Credit Facility and repay the Predecessor’s credit facility.

*The Predecessor entered into a Separation and Distribution Agreement and Tax Matters Agreement with JFG related to the Spin-Off.

JFG and JCP then distributed the Vitesse outstanding common stock held by each to their respective shareholders, and Vitesse became an independent, publicly traded company. The Company’s common stock began trading on the New York Stock Exchange on January 17, 2023 under the symbol “VTS.”

The issued and outstanding member interests of the Predecessor and Vitesse Oil together represented substantially all of those businesses or investments of JFG and JCP that acquire, develop, manage and monetize non-operated oil and natural gas working, royalty and mineral interests in the United States.

Immediately prior to the completion of the Spin-Off, the Company succeeded to the operations of the Predecessor. As the Predecessor and the Company were under common control, and because the Company was not a substantive entity prior to the Spin-Off, for accounting purposes the Company has succeeded to the operations of the Predecessor. The Vitesse Oil Transaction is accounted for as an asset acquisition by the Company as Vitesse Oil and the Company were not under common control.

The Predecessor is a Delaware limited liability company formed on April 29, 2014. Prior to the Spin-Off, the membership interests in the Predecessor were held approximately 97.5% by affiliates of JFG and approximately 2.5% by 3B Energy, LLC (“3B”), an entity whose members are comprised of certain executives of the Company. Financial information presented for periods ended prior to January 13, 2023 is that of the Predecessor, which was organized as a tax partnership. Therefore, for periods prior to January 13, 2023 the financial statements of the Company do not reflect the impact of income taxes. As noted above, as a result of the Spin-Off, the Predecessor became a wholly owned subsidiary of Vitesse, which is organized as a taxable corporation. Therefore, the financial statements of the Company reflect the impact of income taxes applied to the consolidated results of operations of the Company, including the initial basis differences between tax and financial accounting for our assets and liabilities at the Spin-Off resulting in a one-time charge of $44.1 million to income tax expense. Financial information presented for periods ended on and after January 13, 2023 is that of the Company, which reflects the combined results of the Predecessor and Vitesse Oil.

The business purpose of the Company is to acquire, own, explore, develop, manage, produce, exploit, and dispose of oil and gas properties. The Company is focused on returning capital to stockholders through owning and acquiring non-operated working interest and royalty interest ownership primarily in the core of the Bakken and Three Forks formations in the Williston Basin of North Dakota and Montana. The Company also owns non-operated interests in oil and gas properties in the Central Rockies, including the Denver-Julesburg Basin and the Powder River Basin.

Note 2—Significant Accounting Policies

Change in Estimate that is Inseparable from a Change in Accounting Principle

Effective January 1, 2023, the Company changed its method of recording gathering and transportation (“GT”) costs. Under the current method, GT costs are presented as a deduction to oil and gas revenue, following how these items are reported to us by operators of our oil and gas properties. Prior to January 1, 2023, under our previous method, we determined the GT costs that were reported within production expense versus revenue deductions based on our best estimates using information from all our operators in aggregate. Both methods of determining classification of GT costs are acceptable given that we do not operate any of our oil and gas properties and do not have access to such GT contracts with the customer.

The change represents a change in estimate effected by a change in accounting principle. Although the change does not have a material impact to the financial statements the change in methodology has been applied on a retrospective basis to the prior periods presented in order to conform to the current period presentation. This change results in a reclassification within the statements of operations and has no balance sheet impact, nor does it impact net income, operating income, the gross margin we generate from our interests in oil and gas properties, or cash flows for any period.

Principles of Consolidation

The accompanying consolidated financial statements (the “financial statements”) include the accounts of the Company and its subsidiaries, including the Predecessor, Vitesse Oil, Vitesse Management Company LLC (“Vitesse Management”) and Vitesse Oil, Inc. Intercompany balances and transactions have been eliminated in consolidation.

Segment and Geographic Information

The Company operates in a single reportable segment. The Company’s chief operating decision maker is the Chief Executive Officer. All of the Company’s operations are conducted in the continental United States.

Use of Estimates

The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States (“GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates.

Depletion, depreciation, and amortization (“DD&A”) and the evaluation of proved oil and gas properties for impairment are determined using estimates of oil and gas reserves. There are numerous uncertainties in estimating the quantity of reserves and in projecting the future rates of production and timing of development expenditures, which includes lack of control over future development plans as a non-operator. Oil and gas reserve engineering is a subjective process of estimating underground accumulations of oil and gas that cannot be measured in an exact way. In addition, significant estimates include, but are not limited to, estimates relating to certain crude oil and natural gas revenues and expenses, fair value of assets acquired and liabilities assumed in business combinations, valuation of unit-based compensation, and valuation of commodity derivative instruments. Further, these estimates and other factors, including those outside of the Company’s control, such as the impact of lower commodity prices, may have a significant adverse impact to the Company’s business, financial condition, results of operations and cash flows.

Change in Fiscal Year End

On November 30, 2022, the board of managers of the Predecessor approved a change in the Company's fiscal year end from November 30 to December 31. The Company's 2022 fiscal year began on January 1, 2022 and ended on December 31, 2022. As a result of this change, the Company has also presented financial statements for the month ended December 31, 2021.

Cash and Cash Equivalents

The Company considers all investments with an original maturity of three months or less when purchased to be cash equivalents. As of the consolidated balance sheet date and periodically throughout the year, balances of cash exceeded the federally insured limit. As of December 31, 2023 and December 31, 2022 the Company heldno cash equivalents.

Oil and Gas Properties

The Company follows the successful efforts method of accounting for oil and gas activities. Under this method of accounting, costs associated with the acquisition, drilling, and equipping of successful exploratory wells and costs of successful and unsuccessful development wells are capitalized and depleted, net of estimated salvage values, using the units-of-production method on the basis of a reasonable aggregation of properties within a common geological structural feature or stratigraphic condition, such as a reservoir or field. The Company’s proved oil and gas reserve information was computed by applying the average first-day-of-the-month oil and gas price during the 12-month period ended on the balance sheet date. During the years ended December 31, 2023, December 31, 2022 and November 30, 2021 and the month ended December 31, 2021, the Company recorded depletion expense of $81.1 million, $63.3 million, $60.4 million and $5.4 million, respectively. The Company’s depletion rate per BOE for the years ended December 31, 2023, December 31, 2022 and November 30, 2021 and the month ended December 31, 2021 was $18.68, $16.71, $16.73 and $16.97, respectively.

Exploration, geological and geophysical costs, delay rentals, and drilling costs of unsuccessful exploratory wells are charged to expense as incurred. The sale of a partial interest in a proved property is accounted for as a cost recovery, and no gain or loss is recognized as long as this treatment does not significantly affect the units-of-production amortization rate. A gain or loss is recognized for all other sales of proved properties.

Costs associated with unevaluated exploratory wells are excluded from the depletable base until the determination of proved reserves, at which time those costs are reclassified to proved oil and gas properties and subject to depletion. If it is determined that the exploratory well costs were not successful in establishing proved reserves, such costs are expensed at the time of such determination.

The Company reviews its oil and gas properties for impairment whenever events and circumstances indicate a decline in the recoverability of their carrying value. The Company estimates the expected future cash flows of its oil and gas properties and compares such cash flows to the carrying amount of the proved oil and gas properties to determine if the amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, the Company will adjust its proved oil and gas properties to estimated fair value. The factors used to estimate fair value include estimates of reserves, future commodity prices adjusted for basis differentials, future production estimates, anticipated capital expenditures, and a discount rate commensurate with the risk associated with realizing the projected cash flows. The discount rate is a rate that management believes is representative of current market conditions and includes estimates for a risk premium and other operational risks. There wereno proved oil and gas property impairments during the years ended December 31, 2023, December 31, 2022 and November 30, 2021 and the month ended December 31, 2021.

Asset Retirement Obligations (AROs)

AROs relate to estimated plugging and abandonment costs of oil and gas properties, including facilities, and the reclamation of the Company’s well locations. The Company records the fair value of an ARO in the period in which it is incurred. When the liability is initially recorded, the Company capitalizes an estimated cost by increasing the carrying amount of proved oil and gas properties. Over time, the liability is accreted each period toward an estimated future cost, and the capitalized cost is depleted. The Company uses the income valuation technique to estimate the fair value of AROs using the amounts and timing of expected future dismantlement costs, credit-adjusted risk-free rates, and the time value of money. For business combinations, the valuation utilizes a discount rate commensurate with what a market participant would use for AROs recorded. Revisions to the liability could occur due to changes in estimated abandonment costs or well economic lives or if federal or state regulators enact new requirements regarding the abandonment of wells. Adjustments to the liability are made as these estimates change. Upon settlement of the liability, the Company reports a gain or loss to the extent the actual costs differ from the recorded liability.

Equity-Based Compensation

The Company recognizes equity-based compensation expense associated with its long-term incentive plan (“LTIP”) awards using the straight-line method over the requisite service period, which is generally the vesting period of the award except when provisions are present that accelerate vesting, based on their grant date fair values. The Company has elected to account for forfeitures of equity awards as they occur.

Predecessor Equity-Based Compensation

In 2020, the Predecessor amended its Limited Liability Company Agreement (the “Predecessor Company Agreement”) which modified certain terms and conditions related to management incentive units (“MIUs”) (see Note 12) and common units held by the founding members of management. The Predecessor accounted for MIUs granted to employees (which excludes the founding members of management) as liability awards under accounting guidance related to share-based compensation, whereby vested awards are recognized as liabilities, with changes in the estimated value of the awards recorded in earnings, until the holders have borne the risk of unit ownership, at which point the liability associated with the employee MIUs is reclassified to temporary equity, and changes in the estimated value of the employee MIUs are recorded as an adjustment to members’ equity.

Equity-based compensation was also recognized for in-substance call options granted to the founding members of management which were classified as liabilities, recorded at estimated fair market value at each period end. Changes in the estimated fair value were recorded in earnings. As the Predecessor was a private entity whose units were not traded, we considered the average volatility of comparable entities to develop an estimate of expected volatility which resulted in a reasonable estimate of fair value. Refer to Note 12 for further information regarding these awards.

Revenue Recognition

The Company’s revenue is derived from the sale of its produced oil and natural gas from wells in which the Company has non-operated revenue or royalty interests. The Company’s oil and natural gas are produced and sold primarily in the core of the Williston Basin in North Dakota and Montana.

The sales of produced oil and natural gas are made under contracts that the operators of the wells have negotiated with customers, which typically include variable consideration based on monthly pricing tied to local indices and volumes delivered. Revenue is recorded at the point in time when control of the produced oil and natural gas transfers to the customer. Statements and payment may not be received via the operator of the wells forone tosix months after the date the produced oil and natural gas is delivered, and, as a result, the amount of production delivered to the customer and the price that will be received for the sale of the product is estimated utilizing production reports, market indices, and estimated differentials. At the end of each month when the performance obligation is satisfied, the variable consideration can be reasonably estimated, and revenue due to the Company is recorded within revenue receivable in the accompanying balance sheets until payment is received. Differences between the estimated amounts and the actual amounts received from the sale of the produced oil and natural gas are recorded when known, which is generally when statements and payment are received. Such differences have historically been immaterial.

For the oil and natural gas produced from wells in which the Company has non-operated revenue or royalty interests, the Company recognizes revenue based on the details included in the statements received from the operator. Any gathering, transportation, processing, production taxes, and other deductions included on the statements are recorded based on the information provided by the operator. The Company does not disclose the value of unsatisfied performance obligations as it applies the practical exemption which applies to variable consideration that is recognized as control of the product is transferred to the customer. Since each unit of product represents a separate performance obligation, future volumes are wholly unsatisfied, and disclosure of the transaction price allocated to remaining performance obligations is not required.

Concentrations of Credit Risk

For the years ended December 31, 2023, December 31, 2022 and November 30, 2021 and the month ended December 31, 2021, three, four, three and three operators accounted for 49 percent,54 percent,37 percent and 42 percent, respectively, of oil and natural gas revenue. As of December 31, 2023 and December 31, 2022, three and four operators accounted for 56 percent and 65 percent, respectively, of oil and natural gas revenue receivable. The Company’s oil and natural gas revenue receivable is generated from the sale of oil and natural gas by operators on its behalf. The Company monitors the financial condition of its operators.

Income Taxes

Income taxes are provided for the tax effects of transactions reported in the financial statements and consist of taxes currently payable plus deferred income taxes related to certain income and expenses recognized in different periods for financial and income tax reporting purposes. Deferred income tax liabilities represent the future income tax consequences of those differences, which will be taxable when liabilities are settled. Deferred income taxes may also include tax credits and net operating losses that are available to offset future income taxes. Deferred income taxes are measured by applying currently enacted tax rates.

The Company accounts for uncertainty in income taxes for tax positions taken or expected to be taken in a tax return. Only tax positions that meet the more-likely-than-not recognition threshold are recognized. The Company does not have any uncertain tax positions recorded as of December 31, 2023.

The Predecessor and Vitesse Oil were limited liability companies that passed tax liability through to its members and accordingly did not record income tax expense.

Deferred Finance Charges

Costs associated with the revolving credit facility are deferred and amortized to interest expense over the term of the related financing. The amount of deferred financing costs incurred, and the amortization of deferred financing costs, was immaterial for all periods presented.

Derivative Financial Instruments

The Company enters into derivative contracts to manage its exposure to oil and gas price volatility. Commodity derivative contracts may take the form of swaps, puts, calls, or collars. Cash settlements from the Company’s commodity price risk management activities are recorded in the month the contracts mature. Any realized gains and losses on settled derivatives, as well as mark-to-market gains or losses, are aggregated and recorded to Commodity derivative (loss) gain, net on the consolidated statements of operations.

GAAP requires recognition of all derivative instruments on the consolidated balance sheets as either assets or liabilities measured at fair value. Subsequent changes in the derivatives’ fair value are recognized currently in earnings unless specific hedge accounting criteria are met. Gains and losses on derivative hedging instruments must be recorded in either other comprehensive income or current earnings, depending on the nature and designation of the instrument. The Company has elected to not designate any derivative instruments as accounting hedges, and therefore marks all commodity derivative instruments to fair value and records changes in fair value in earnings. Amounts associated with deferred premiums on derivative instruments are recorded as a component of the derivatives’ fair values (see Note 6).

New Accounting Pronouncements

In June 2016, FASB issued ASU No. 2016-13, Financial Instruments—Credit Losses: Measurement of Credit Losses on Financial Instruments. The ASU includes changes to the accounting and measurement of financial assets requiring the Company to recognize an allowance for all expected credit related losses over the life of the financial asset at origination. This is different from the current practice, where an allowance is not recognized until the losses are considered probable. The new guidance was effective for the Company on January 1, 2023. Upon adoption, the ASU was applied using a modified retrospective transition method to the beginning of the earliest period in which the new guidance is effective. The adoption of the new guidance did not have a material impact on the Company’s financial statements and related disclosures.

In November 2023, FASB issued ASU No. 2023-07, Improvements to Reportable Segment Disclosures. The ASU updates reportable segment disclosure requirements primarily through enhanced disclosures about significant segment expenses. The new guidance will be effective for the Company’s year ending December 31, 2024. The Company does not believe the new guidance will have a material impact on its consolidated financial statements and related disclosures.

In December 2023, FASB issued ASU 2023-09, Improvements to Income Tax Disclosures. The ASU establishes new income tax disclosure requirements in addition to modifying and eliminating certain existing requirements. The guidance will be applied on a prospective basis with the option to apply the standard retrospectively. The new guidance will be effective for the Company’s year ending December 31, 2025. The Company does not believe the new guidance will have a material impact on its consolidated financial statements and related disclosures.

Note 3—Asset Acquisitions

During the years ended December 31, 2023, December 31, 2022 and November 30, 2021 and the month ended December 31, 2021, the Company purchased a number of proved oil and gas properties and proved leaseholds for an aggregate purchase price of $35.7 million, $28.5 million, $6.2 million, and $0.1 million, respectively. In addition, as part of the Spin-Off during the year ended December 31, 2023, $35.6 million of oil and gas properties and $5.0 million of net liabilities of Vitesse Oil were contributed in exchange for 2,120,312 shares of common stock of the Company for total consideration of $30.6 million.

The transactions qualified as asset acquisitions; therefore, the oil and gas properties were recorded based on the fair value of the total consideration transferred on the acquisition dates, and transaction costs were capitalized as a component of the assets acquired. Transaction costs during the years ended December 31, 2023, December 31, 2022 and November 30, 2021 and the month ended December 31, 2021 were immaterial. The purpose of the acquisitions was to acquire proved developed and proved undeveloped oil and gas properties that were proximate and complementary to existing properties and leases for strategic purposes.

Note 4—Fair Value Measurements

Accounting standards require certain assets and liabilities be reported at fair value in the consolidated financial statements and provide a framework for establishing that fair value. The framework for determining fair value is based on a hierarchy that prioritizes the inputs and valuation techniques used to measure fair value.

Fair values determined by Level 1 inputs use quoted prices in active markets for identical assets or liabilities that the Company has the ability to access.

Fair values determined by Level 2 inputs use other inputs that are observable, either directly or indirectly. These Level 2 inputs include quoted prices for similar assets and liabilities in active markets and other inputs, such as interest rates, yield curves, and forward commodity price curves, that are observable at commonly quoted intervals.

Level 3 inputs are unobservable inputs, including inputs that are available in situations where there is little, if any, market activity for the related asset or liability. These Level 3 fair value measurements are based primarily on management’s own estimates using pricing models, discounted cash flow methodologies, or similar techniques taking into account the characteristics of the asset or liability. Significant Level 3 inputs include estimated future cash flows used in determining the fair value of purchased oil and gas properties.

In instances where inputs used to measure fair value fall into different levels in the above fair value hierarchy, fair value measurements in their entirety are categorized based on the lowest level input that is significant to the valuation. The Company’s assessment of the significance of particular inputs to these fair value measurements requires judgment and considers factors specific to each asset or liability.

Recurring Fair Value Measurements

As of December 31, 2023, the Company’s derivative financial instruments are composed of commodity swaps. The fair value of the swap agreements is determined under the income valuation technique using a discounted cash flow model. The fair values of options are determined under the income valuation technique using an option pricing model along with the stated amount of deferred premiums if applicable. The valuation models require a variety of inputs, including contractual terms, published forward commodity prices, volatilities for options, and discount rates, as appropriate. The Company’s estimates of fair value of derivatives include consideration of the counterparty’s creditworthiness, the Company’s creditworthiness, and the time value of money. The consideration of these factors results in an estimated exit price for each derivative asset or liability under a marketplace participant’s view. All of the significant inputs are observable, either directly or indirectly; therefore, the Company’s commodity derivative instruments are included within Level 2 of the fair value hierarchy (see Note 6).

Nonrecurring Fair Value Measurements

Nonrecurring measurements include the fair value of impaired proved oil and gas properties. The Company determines the estimated fair value of the impaired proved oil and gas properties by using a discounted cash flow approach with unobservable Level 3 inputs (see Note 2) at the time of impairment.

The Company uses the income valuation technique to estimate the fair value of asset retirement obligations, at initial recognition, arising from the development of proved properties using the amounts and timing of expected future dismantlement costs and credit-adjusted risk-free rates. Accordingly, the fair value is based on unobservable inputs and, therefore, is included within Level 3 of the fair value hierarchy. The significant unobservable inputs include the gross cost of abandoning oil and gas wells; the economic lives of the properties; the inflation rate; and the credit-adjusted risk-free rate of the Company.

Financial Instruments Not Measured at Fair Value

The carrying amounts of the majority of the Company’s financial instruments, namely cash, receivables, accounts payable, and accrued liabilities, approximate their fair values due to the short-term nature of these instruments. The Company’s credit facility (see Note 5) has a recorded value that approximates fair market value, as it bears interest at a floating rate that approximates a current market rate.

Note 5—Credit Facility

Revolving Credit Facility

In connection with the Spin-Off in January 2023, the Company entered into a secured revolving credit facility with Wells Fargo Bank, N.A., as administrative agent, and a syndicate of banks, as lenders (the “Revolving Credit Facility”). The Revolving Credit Facility amends and restates the revolving credit facility of the Predecessor (the “Prior Revolving Credit Facility”). The Predecessor, as predecessor borrower under the Predecessor Revolving Credit Facility, assigned the liens and existing rights, liabilities and obligations under the Prior Revolving Credit Facility to the Company pursuant to the Revolving Credit Facility. The Revolving Credit Facility will mature on April 29, 2026. The Revolving Credit Facility permits borrowing on a revolving credit basis with availability equal to the least of (1) the aggregate elected commitments, (2) the borrowing base and (3) the maximum credit amount of $500.0 million. The borrowing base under the Revolving Credit Facility is subject to regular, semi-annual redeterminations on or about April 1 and October 1 of each year based on, among other things, the value of the Company’s proved oil and natural gas reserves, as determined by the lenders in their discretion. As of December 31, 2023, the Company’s borrowing base was $245.0 million with an aggregate elected commitment of $180.0 million of which $81.0 million was outstanding.

At the Company’s option, borrowings under the Revolving Credit Facility bear interest at a rate unchanged from the Predecessor Revolving Credit Facility, which is either an adjusted forward-looking term rate based on SOFR (“Term SOFR”) or an adjusted base rate (“Base Rate”) (the highest of the administrative agent’s prime rate, the federal funds rate plus 0.50% or the 30-day Term SOFR rate plus 1.0%), plus an applicable margin expected to range from 1.75% to 2.75% with respect to Base Rate borrowings and 2.75% to 3.75% with respect to Term SOFR borrowings, in each case based on the current commitment utilization percentage. Interest is calculated and paid monthly in arrears. Additionally, the Company incurs an unused credit facility fee, paid quarterly, of 0.50% of the unutilized commitment regardless of the borrowing base utilization percentage. As of December 31, 2023, the interest rate on the outstanding balance under the Revolving Credit Facility was 8.46%.

Consistent with the Prior Revolving Credit Facility, the Revolving Credit Facility is guaranteed by all of the Company’s subsidiaries and is collateralized by a first priority lien on substantially all assets of Vitesse and its subsidiaries, including a first priority lien on properties representing a minimum of 85% of the total present value of the Company’s proved oil and natural gas properties.

The Revolving Credit Facility contains various affirmative, negative and financial maintenance covenants. These covenants limit the Company’s ability to, among other things, incur or guarantee additional debt, make distributions to equity holders, make certain investments and acquisitions, incur certain liens or permit them to exist, enter into certain types of transactions with affiliates, merge or consolidate with another company and transfer, sell or otherwise dispose of assets.

Under the Revolving Credit Facility, the Company is permitted to make cash distributions without limit to our equity holders if (i) no event of default or borrowing base deficiency (i.e., outstanding debt (including loans and letters of credit) exceeds the borrowing base) then exists or would result from such distribution and (ii) after giving effect to such distribution, (a) total outstanding credit usage does not exceed 80% of the least of (the following collectively referred to as “Commitments”): (1)$500.0 million (2) then effective borrowing base, and (3) the then-effective aggregate amount of the aggregate elected commitments and (b) as of the date of such distribution, the EBITDAX Ratio does not exceed 1.50 to 1.00. If the EBITDAX Ratio does not exceed 2.25 to 1.00, and if total outstanding credit usage does not exceed 80% of the Commitments, the Company may also make distributions if free cash flow (as defined under the Revolving Credit Facility) is greater than $0 and the Company has delivered a certificate to lenders attesting to the foregoing.

The Revolving Credit Facility contains covenants requiring us to maintain the following financial ratios tested on a quarterly basis (terms below are as defined in the Revolving Credit Facility): (1) a consolidated Total Funded Debt to consolidated EBITDAX ratio of not greater than 3.0 to 1.0; and (2) a ratio of consolidated current assets to consolidated current liabilities of not less than 1.0 to 1.0. These financial covenants are consistent with the Predecessor Revolving Credit Facility. The Revolving Credit Facility also contains covenants that require that the Company enter into swap agreements covering not less than 40% of reasonably anticipated PDP production for the following four quarters when the Utilization Percentage, as defined in the Revolving Credit Facility, is less than 50% and covering at least 50% of reasonably anticipated PDP production for the following eight quarters if the Utilization Percentage is 50% or greater. The Revolving Credit Facility contains customary events of default, including non-payment, breach of covenants, materially incorrect representations, cross default, bankruptcy and change in control. If an event of default exists under the Revolving Credit Facility, the lenders will be able to terminate the lending commitments, accelerate the maturity of the Revolving Credit Facility and exercise other rights and remedies with respect to the collateral. The Company was in compliance with all financial covenants of the Revolving Credit Facility at December 31, 2023.

On May 2, 2023, the Company entered into an amendment to the Revolving Credit Facility in conjunction with the regular semi-annual borrowing base redetermination that reduced the borrowing base to $245 million (primarily related to lower commodity prices), reaffirmed elected commitments at $170 million and reduced hedging requirements in certain circumstances, among other items. On November 3, 2023, in conjunction with the regular semi-annual borrowing base redetermination, the Company’s borrowing based was reaffirmed and the elected commitments were increased to $180 million.

On January 17, 2024, the Company entered into an amendment to the Revolving Credit Facility that increased the elected commitments to $210 million and added a fifth lender to the syndicate of banks.

Prior Revolving Credit Facility

In May 2015, the Predecessor entered into a credit facility with a syndicate of banks as lenders led by Wells Fargo Bank, N.A. as the administrative agent with the Predecessor as the borrower, which originally matured in May 2020. The Prior Revolving Credit Facility was subsequently amended, and the maturity date was extended to April 2026. The most recent amendment was executed in April 2022 (the “April 2022 amendment”). The Prior Revolving Credit Facility specified an aggregate maximum credit amount equal to $500.0 million and a maximum borrowing base, as determined by the lenders. The determination of the borrowing base took into consideration the estimated value of the Predecessor’s oil and gas properties in accordance with the lenders’ customary practices for oil and gas loans. The borrowing base was subject to scheduled redeterminations on a semiannual basis. The amount available for borrowing could be increased or decreased as a result of such redeterminations. As of December 31, 2022, the borrowing base under the Prior Revolving Credit Facility was $200.0 million with an elected commitment of $170.0 million of which $48.0 million was outstanding.

Prior to the April 2022 amendment, the Predecessor had the option to request borrowings under either a eurodollar loan or an alternative base rate loan. Eurodollar loans bore interest at the adjusted LIBOR plus an applicable margin ranging from 2.75% to 3.75% depending on the borrowing base utilization percentage. Alternative base rate loans bore interest at the higher of (a) the prime rate in effect on such day, (b) the federal funds effective rate in effect on such day plus 0.50%, or (c) the adjusted LIBOR for a one-month interest period on such day plus an applicable margin ranging from 1.75% to 2.75% depending on the borrowing base utilization percentage. With the April 2022 amendment, at the Predecessor’s option, borrowings under the Prior Revolving Credit Facility bore interest at either an adjusted forward-looking term rate based on the Secured Overnight Financing Rate (“SOFR”) or an adjusted base rate (“Predecessor Base Rate”) (the highest of the administrative agent’s prime rate, the Federal Funds rate plus 0.50% or the 30-day SOFR rate plus 1.0%), plus a spread ranging from 1.75% to 2.75% with respect to Predecessor Base Rate borrowings and 2.75% to 3.75% with respect to SOFR borrowings, in each case based on the borrowing base utilization percentage. Interest was calculated and paid monthly in arrears. Additionally, the Predecessor incurred an unused credit facility fee of 0.50% regardless of the borrowing base utilization percentage. As of December 31, 2022, the interest rate on the outstanding balance under the Prior Revolving Credit Facility was 7.42%.

Note 6—Derivative Instruments

The Company periodically enters into various commodity hedging instruments to mitigate a portion of the effect of oil and natural gas price fluctuations. The Company classifies the fair value amounts of commodity derivative assets and liabilities as current or noncurrent commodity derivative assets or current or noncurrent commodity derivative liabilities, whichever the case may be.

The following table summarizes the location and fair value amounts of commodity derivative instruments in the consolidated balance sheet as of December 31, 2023, as well as the gross recognized derivative assets, liabilities, and amounts offset in the consolidated balance sheet:

The following table summarizes the location and fair value amounts of all commodity derivative instruments in the consolidated balance sheet as of December 31, 2022, as well as the gross recognized derivative assets, liabilities, and amounts offset in the consolidated balance sheet:

As of December 31, 2023, the Company had the following crude oil swaps:

Due to the volatility of oil prices, the estimated fair values of the Company’s commodity derivative instruments are subject to large fluctuations from period to period.

The counterparties in the Company’s derivative instruments also participate in the Company’s Credit Facility; accordingly, the Company is not required to post collateral, as the counterparties have the right of offset for any derivative liabilities, and the Credit Facility is secured by the Company’s oil and gas assets. For further discussion related to the fair value of the Company’s derivatives, see Note 4.

Note 7—Accrued Liabilities

Accrued liabilities at December 31, 2023 and December 31, 2022 are summarized as follows:

Note 8—Asset Retirement Obligations

A rollforward of AROs for the years ended December 31, 2023 and December 31, 2022 are presented below.

Note 9—Related Party Transactions

3B acquired common units in the Predecessor which were funded bytwo Initial Loans with related parties. As part of the funding of the Predecessor, 3B entered intotwo different promissory notes with VE Holding LLC, an entity owned by JFG. The promissory notes allowed 3B to borrow up to $7.875 million and $3.5 million, initially accruing interest at 10.0 percent and 3.5 percent, respectively, and had maturity dates of May 7, 2021 (the “Initial Loans”). Initially, repayment of the $3.5 million promissory note was fully guaranteed by one of the members of 3B. Each of thetwo Initial Loans were collateralized by all of the common units held by 3B. In 2021, the $3.5 million promissory note was amended to remove the guarantee, change the interest rate to 10.0 percent and extend the maturity date to December 31, 2023. At the same time the $7.875 million promissory note was amended to extend the maturity date to December 31, 2023. The Initial Loans between 3B and VE Holding LLC were held outside of the Predecessor and were not a liability of the Predecessor. During 2022, there were $36.0 million of ratable distributions made to the common unit holders. The 3B distribution of $0.9 million was used to pay down a pro rata portion of the outstanding interest on the Initial Loans. The 3B common units and related loans were liquidated and terminated in connection with the Spin-Off.

In connection with the Predecessor Company Agreement, in July 2018 certain executives entered intotwo separate promissory notes aggregating to $10.0 million with VE Holding LLC (the “2018 Notes”), which are collateralized by MIUs granted to the respective executive. The 2018 Notes accrued interest at 3.0 percent per annum payable annually on December 31 and matured the earlier of July 1, 2024, an MIU exchange, or an acceleration event. The 2018 Notes could have been prepaid at any time but were subject to mandatory prepayment upon the issuance of any distributions from the Predecessor related to the MIUs held by such executives. Additionally, the 2018 Notes were considered full recourse to each respective executive for a limited time, with such recourse reduced by one-third each December 31 through 2020. As the 2018 Notes were between VE Holding LLC and the executives, they did not represent liabilities of the Predecessor. The Founder MIUs and related promissory notes were liquidated and terminated in connection with the Spin-Off.

The Predecessor entered into an amended and restated services agreement (the “Services Agreement”) by and between the Predecessor, Vitesse Management, and Vitesse Oil, LLC (“Vitesse Oil”) on May 7, 2014. Vitesse Oil was an entity with management common to that of the Predecessor. Per the Services Agreement, costs incurred by Vitesse Management were allocable between the Predecessor and Vitesse Oil initially at 50 percent each and adjusted automatically each quarter, such that the Predecessor’s share of allocable costs were the greater of 50 percent or the quotient of the total contributed capital to the Predecessor made by its members and the sum of the total contributed capital to the Predecessor and Vitesse Oil by their respective members. As such, the Predecessor incurred 90 percent of the Vitesse Management costs for the years ended December 31, 2022, and November 30, 2021 and the month ended December 31, 2021. The amount of costs reimbursed from Vitesse Oil to the Predecessor for management services was $1.1 million, $1.1 million, and $0.1 million for each of the years ended December 31, 2022, and November 30, 2021 and the month ended December 31, 2021, respectively. The amount due to the Predecessor from Vitesse Oil as of December 31, 2022 was immaterial. Vitesse Oil was acquired as part of the Spin-Off and accordingly 100 percent of Vitesse Management costs were incurred by the Company subsequent to the Spin-Off.

On July 1, 2016, the Predecessor entered into a separate services agreement with Vitesse Management and JETX Energy, LLC (“JETX”), formerly known as Juneau Energy, LLC, another entity owned by JFG with common management. Per this services agreement, Vitesse Management is to provide JETX certain administrative services and supervise, administer, and manage the business affairs and operations of JETX and its subsidiaries for a service provider fee of $0.2 million per month. The term of this service agreement extends for an unlimited amount of time; however, it is subject to termination by either Vitesse Management or JETX if provided written consent following the first anniversary or a final exit event. During each of the years ended December 31, 2023, December 31, 2022, and November 30, 2021 and the month ended December 31, 2021, the Company recorded its net share of fees from JETX of approximately $2.7 million, $2.4 million, $2.4 million and $0.2 million, respectively, which is classified as a reduction to general and administrative expenses on the accompanying consolidated statements of operations.

On July 1, 2016, the Predecessor implemented the Employee Participation Plan (“EPP”) pursuant to which employees, consultants, or independent contractors of the Predecessor were invited to personally acquire a working interest in new oil and gas wells in which the Predecessor elected to participate. The EPP was subsequently amended on January 1, 2018. The tranches were not to exceed a maximum of $2.0 million of capital expenditures in the aggregate for each year. Participants in the EPP were required to fund their proportion of development costs and ongoing operating expenses of those specific wellbores. Compensation expense was measured by the allocable amount of the value of the assigned wellbore leasehold costs which was historically immaterial. On November 30, 2022, the Predecessor repurchased the outstanding EPP working interest for $4.9 million in accordance with the terms of the plan and terminated the EPP.

Note 10—Leases

The Company is obligated under noncancelable leases primarily for facilities. Total expense under these operating leases was $0.4 million, $0.4 million, $0.4 million and immaterial for the years ended December 31, 2023, December 31, 2022, and November 30, 2021 and the month ended December 31, 2021, respectively.

Leases with an initial term of 12 months or less are not recorded on the consolidated balance sheets.

The Company’s lease agreements do not provide an implicit borrowing rate; therefore, an internal incremental borrowing rate is determined based on information available at the lease commencement date for the purpose of determining the present value of lease payments. The right-of-use assets of $0.2 million and $0.2 million as of December 31, 2023 and 2022, respectively, are recorded within Other noncurrent assets on the consolidated balance sheets. The related lease obligations of $0.2 million and $0.2 million as of December 31, 2023 and 2022, respectively, are recorded within Other current liabilities on the consolidated balance sheets.

The Company entered into an agreement in December 2022 to lease office space in Greenwood Village, CO to be its future principal executive office space. The lessor is required to complete certain agreed upon tenant improvements and the lease is scheduled to commence when construction of the asset is completed in 2024.

Note 11—Commitments and Contingencies

Litigation

From time to time, the Company may be involved in litigation relating to claims arising out of its operations in the normal course of business. As of the date of this report, management of the Company was unaware of any material legal proceedings against the Company. The Company maintains insurance to cover certain actions.

Note 12—Equity

Authorized Capital Stock

The Amended and Restated Certificate of Incorporation authorized capital stock consisting of 95,000,000 shares of common stock, par value $0.01 per share and 5,000,000 shares of preferred stock, par value $0.01 per share.

Common Stock

During the year ended December 31, 2023 the following transactions related to our common stock occurred:

■3B transferred all of its Predecessor equity interests to JFG as repayment for the Initial Loans;

■JFG distributed the remaining Predecessor equity interests to its shareholders in the Spin-Off, which amounted to 25,628,162 shares of common stock in the Company;

■the Transitional Equity Award Adjustment Plan (the “Transitional Plan”), as discussed further below, was implemented and resulted in the following issuances to current and former directors and employees of JFG:

◦286,729 restricted stock awards (included in issuance of common stock in exchange for Vitesse Energy, LLC on the Consolidated Statements of Equity), of which 56,218 were issued as common shares during the period;

◦1,475,613 restricted stock units, of which 810,507 were issued as common shares during the period, net of shares cashed out as fractional unit;

■Predecessor MIUs granted to Predecessor employees other than the Predecessor’stwo founders were exchanged for 163,544 shares of common stock;

■Vitesse Oil was contributed in exchange for 2,120,312 common shares;

■3,152,247 restricted stock units were issued, net of forfeitures, to officers, directors and employees;

■14,600 shares of common stock were repurchased and retired as part of our Stock Repurchase Program, as discussed further below.

■Declared dividends of $65.6 million, or $2.00 per share, on common stock during the period.

Preferred Stock

Our Amended and Restated Certificate of Incorporation authorizes our board of directors to designate and issue from time to time one or more series of preferred stock without stockholder approval. Our board of directors may fix and determine the designation, relative rights, preferences and limitations of the shares of each such series of preferred stock. There are no present plans to issue any shares of preferred stock and there are currentlyno shares outstanding.

Long-Term Incentive Plan

The Company’s long-term incentive plan (“LTIP”) provides for the granting of various forms of equity-based awards, including stock option awards, stock appreciation rights awards, restricted stock awards, restricted stock unit awards, performance awards, cash awards and other stock-based awards to employees, directors and consultants of the Company. Under the LTIP,3,960,000 shares were initially available to be awarded and as of December 31, 2023, there were 807,753 shares available to be granted.

The following is a summary of LTIP activity during the year ended December 31, 2023:

For restricted stock units, the Company recognizes the grant date fair-value of awards over the requisite service period as stock-based compensation expense on a straight-line basis except when provisions are present that accelerate vesting. Restricted stock units are considered issued but not outstanding when granted. Accumulated accrued stock based compensation expense and any accrued dividends are reversed in the period when units are forfeited and the units are no longer considered issued.

During the year ended December 31, 2023, the Company recognized $32.2 million of equity-based compensation expense relating to these restricted stock units of which $26.8 million, or 1,863,000 restricted stock units, was for awards that had a retirement provision and were granted to retirement-eligible employees and therefore resulted in immediate recognition of expense.

As of December 31, 2023, there is $15.0 million of unrecognized equity-based compensation expense related to unvested restricted stock unit awards. The cost is expected to be recognized through January 2027, over a weighted-average period of 2.56 years.

Transitional Equity Award Adjustment Plan

JFG’s outstanding compensatory equity awards were adjusted into equity incentive awards denominated in part in shares of Vitesse common stock in connection with the Spin-Off. All adjusted awards are subject to generally the same vesting, exercisability, expiration, settlement and other material terms and conditions as applied to the applicable original JFG award immediately before the Spin-Off, except that equity awards relating to our common stock were subject to accelerated vesting, exercisability and in some cases settlement in the event of a change in control of the Company. All of the Transitional Plan equity awards discussed below were granted by JFG and therefore do not result in any compensation cost to the Company.

Transitional Plan Options

Each JFG stock option that did not remain an option to purchase shares of only JFG common stock was converted into both a post-Spin-Off option to purchase shares of JFG common stock and an option to purchase shares of Vitesse common stock. The exercise price of such JFG stock option and the exercise price and number of shares subject to such Vitesse stock option was adjusted so that (i) the aggregate intrinsic value of such post-Spin-Off JFG stock option and Vitesse stock option immediately after the Spin-Off equals the aggregate intrinsic value of the JFG stock option as measured immediately before the Spin-Off and (ii) the aggregate exercise price of such post-Spin-Off JFG stock option and Vitesse stock option equals the aggregate exercise price of the JFG stock option immediately before the Spin-Off, subject to rounding. Upon completion of the Spin-Off,457,866 options were granted andnone were exercised during the year ended December 31, 2023. The intrinsic option value of the options was $5.9 million at December 31, 2023 and the maximum number of shares of common stock that could be issued under the plan is 457,866.

Transitional Plan Restricted Units

Each JFG restricted stock unit award and performance stock unit award (other than those that will remain awards denominated in shares of only JFG stock, which includes the portion of any performance stock unit award that may be earned above the designated target level), including any additional stock units accrued as a result of dividend equivalents, was adjusted by the grant of a Vitesse restricted stock unit award. Upon completion of the Spin-Off, restricted stock units were granted in respect of these JFG awards. These restricted stock unit awards are capped at 1,475,613 and at December 31, 2023103,653 have a remaining performance, service or vesting condition to satisfy. These restricted stock unit awards generally accrue dividends declared on common stock but have deferred issuance dates through January 2, 2099. During the year ended December 31, 2023,810,507 restricted stock units were released as common stock, net of shares cashed out as fractional units.

Transitional Plan Restricted Stock Awards

Holders of a JFG restricted stock award received 286,729 shares of our common stock upon completion of the Spin-Off, which shares are subject to the provisions of the Transitional Plan, including generally the same risk of forfeiture and other conditions as applied to the original JFG restricted stock award. These restricted stock awards have no remaining performance or service conditions to satisfy, or any other vesting condition, and are paid dividends on common stock as declared but have deferred issuance dates through September 28, 2029. During the year ended December 31, 2023,56,218 restricted stock awards were released as common stock.

The Transitional Plan governs the terms and conditions of the new Vitesse awards issued as an adjustment to JFG awards at the effective time of the Spin-Off, but will not be used to make any grants following the Spin-Off.

Stock Repurchase Program

In February 2023, the Board approved a stock repurchase program authorizing the repurchase of up to $60 million of the Company’s common stock.

Under the Stock Repurchase Program, we may repurchase shares of our common stock from time to time in open market transactions or such other means as will comply with applicable rules, regulations and contractual limitations. The Board of Directors may limit or terminate the Stock Repurchase Program at any time without prior notice. The extent to which the Company repurchases its shares of common stock, and the timing of such repurchases, will depend upon market conditions and other considerations as may be considered in the Company’s sole discretion.

During the year ended December 31, 2023, the Company repurchased 14,600 shares for $0.2 million and the shares were subsequently retired.

Net Loss Per Common Share

The Company uses the two-class method of calculating earnings per share because certain of the Company’s unvested LTIP RSUs qualify as participating securities.

Basic earnings per share amounts have been computed as (i) net income (loss) (ii) less distributed and undistributed earnings allocated to participating securities (iii) divided by the weighted average number of basic shares outstanding for the periods presented. Diluted earnings per share amounts have been computed as (i) basic net income attributable to common stockholders (ii) plus the adjustment of distributed and undistributed earnings allocated to participating securities (iii) divided by the weighted average number of diluted shares outstanding for the periods presented.

The components of basic and diluted net income (loss) per share attributable to common stockholders are as follows:

(1)Certain unvested LTIP RSUs represent participating securities because they participate in nonforfeitable dividends with the common equity holders of the Company. Participating earnings represent the distributed and undistributed earnings of the Company attributable to the participating securities. These unvested LTIP RSUs do not participate in undistributed net losses as they are not contractually obligated to do so.

Predecessor Members’ Equity

The Predecessor hadtwo classes of membership units, with the following units authorized, issued, and outstanding as of December 31, 2022:

Common Units

Common units of the Predecessor were issued at $1 per unit, with an aggregate capital commitment from all common members of $450 million. There initially were five managers on the board of managers of the Predecessor, with three managers designated by JFG andtwo managers designated by 3B. For voting purposes, each manager was entitled toone vote, and the affirmative vote of a majority of the board of managers, including at least one JFG manager, was required to ratify any significant decisions.

Management Incentive Units

Predecessor MIUs were issued by the Predecessor to eligible employees and/or consultants. All MIUs were nonvoting and provided the MIU holders the opportunity to participate in distributions after the common unit holders received a specified return.

MIUs were granted to thetwo founding members of management (“Founder MIUs”) and certain other employees of the Predecessor (“Non-Founder MIUs”). MIUs were subject to vesting requirements and forfeiture provisions specific to the Founder

MIUs and Non-Founder MIUs, as outlined in the Predecessor Company Agreement, employment agreement, grant letters, and other supporting MIU documentation.

The Predecessor accounted for Non-Founder MIUs as liability-based awards until the respective holder had borne the risk of unit ownership, at which point the value of the liability was reclassified outside of permanent equity. While the awards were classified as liabilities, compensation expense was recorded through the vesting period, and changes in the estimated fair market value of the liability, were recorded in earnings. Once reclassified outside of permanent equity increases in the estimated fair market value of the award were recorded through members’ equity. During the years ended December 31, 2022 and November 30, 2021 and the month ended December 31, 2021, the Predecessor recorded an increase of $1.5 million, a reduction of $1.5 million, and a reduction of $1.0 million respectively, through members’ equity to adjust the Non-Founder MIUs to fair market value.

A summary of the Predecessor’s activity related to Non-Founder MIUs for the years ended the years ended December 31, 2022 and November 30, 2021 and the month ended December 31, 2021, is presented below:

As of December 31, 2022, there was no unrecognized compensation cost related to nonvested unit-based compensation arrangements.

As a result of each of the management founders’ receipt of an in-substance nonrecourse note (see Note 9) that were each collateralized by all of the Founder MIUs held by the respective executive, for accounting purposes, the Predecessor granted each of the management founders an in-substance call option that is within the scope of accounting guidance related to share-based compensation (the “Founder MIU Option Grant”). Due to the nature and terms of the Founder MIU Put Option, the Founder MIU Option Grant was classified as a liability award, remeasured at fair market value at each reporting date with the change in fair market value recorded to earnings.

Total compensation cost (income) recognized in the consolidated statements of operations within Equity-based compensation for the years ended December 31, 2022 and November 30, 2021 and the month ended December 31, 2021 is as follows:

As of December 31, 2022, the intrinsic value of the Founder MIU Option Grant and the Common Unit Option Grant was determined to be de minimis given the limited amount of time until the instruments were settled and prevailing economic factors. The Option Grants were forfeited on January 13, 2023 with the executives agreeing to settle their common units and Founder MIUs in exchange for JFG forgiving the 2018 Notes and any accrued interest. The December 31, 2022 liability and the factors considered in valuing the liability at December 31, 2022 are not presented due to the immaterial nature of these items.

Measurement of unit-based compensation

The Predecessor recorded the Non-Founder MIUs, Founder MIU Option Grant, and Common Unit Option Grant at fair value at the date of grant and at each balance sheet date, which results in compensation cost being measured at fair value. As noted above, vested Non-Founder MIUs, where the respective holder had borne the risk of ownership, are recorded within temporary equity, with changes in fair value recorded within members’ equity.

The fair value of each of the Founder MIU Option Grant and the Common Unit Option Grant (collectively the “Options”) were estimated using a Black Scholes Model. As the Predecessor did not have publicly-traded equity, it incorporated data from a group of publicly-traded peer companies when estimating fair value. Expected volatilities were based on the historical volatility of our identified peer group of companies. The expected term of the Options was determined based on the timing of an exit or liquidity event. The risk-free rate for periods within the expected life of the option was interpolated from the US constant maturity treasury rate, for a term corresponding to the expected term.

Distributions

Distributions of funds associated with common units follow a prescribed framework, which is outlined in detail in the Predecessor Company Agreement. In general, distributions were first allocated to those unitholders based on their allocable share, as defined in the Predecessor Company Agreement. Each unitholder then received a distribution in accordance with the tiered waterfall, as defined in the Predecessor Company Agreement. The Company made $36.0 million, $12.0 million and $6.0 million of distributions on common units during the years ended December 31, 2022 and November 30, 2021 and the month ended December 31, 2021, respectively.

Earnings Per Unit

The Predecessor hadtwo classes of equity in the form of common units and MIUs that were vested and where the holder had borne the risks and rewards of ownership at which point the MIU was reclassified from liabilities to outside of permanent equity. Both common units and temporary equity classified MIUs were considered common units, and distributions were made in accordance with the Predecessor Company Agreement. As such, the Company presents earnings per unit (“EPU”) for both classes of equity. In calculating EPU, we applied the two-class method. Under the two-class method net income (loss) attributable to common units is allocated to common units and other participating securities in proportion to the claim on earnings of each participating security after giving effect to distributions declared during the period, if any. The following table sets forth the computation of basic and diluted net income (loss) per unit:

Note 13—Income Taxes

Historically, Vitesse Energy and Vitesse Oil have been treated as partnerships for U.S. federal applicable state and local income tax purposes. As partnerships, Vitesse Energy and Vitesse Oil were not subject to U.S. federal and certain state and local income taxes, and any taxable income or loss generated by Vitesse Energy and Vitesse Oil was passed through to and included in the taxable income or loss of their members. Following the Spin-Off, the Company is now subject to U.S. federal and applicable state and local income taxes for taxable income or loss.

Income tax expenses and benefits included in the consolidated statements of operations are detailed below:

A reconciliation of the statutory federal income tax expense, which is calculated at the federal statutory rate of 21% for the year ended December 31, 2023 to the income tax expense from continuing operations provided for the periods presented, is as follows:

The tax effects of temporary differences that give rise to significant positions of the deferred income tax assets and liabilities are presented below:

For the year ended December 31, 2023 the Company recorded a federal and state tax expense of $61.9 million. During Q1 the Predecessor was contributed into Vitesse resulting in a change in tax status and the recording of a $44.1 million federal and state deferred tax expense. In addition, a $2.4 million deferred tax liability was recorded in 2023 related to the acquisition of Vitesse Oil. For the years ended December 31, 2022 and November 30, 2021 and the month ended December 31, 2021, the Predecessor and Vitesse Oil were limited liability companies that passed tax liability through to its members and accordingly did not record income tax expense or deferred tax assets and liabilities.

As of December 31, 2023, the Company had $6.1 million and $4.1 million of U.S. federal and state net operating loss carryovers, respectively, and did not have any U.S. federal or state net operating loss carryovers at December 31, 2022. Approximately $0.1 million of the state net operating loss carryovers expire in 2033.

The Company periodically assesses whether it is more-likely-than-not that it will generate sufficient taxable income to realize its deferred income tax assets. In making this determination, the Company considers all available positive and negative evidence and makes certain assumptions. The Company considers, among other things, its deferred tax liabilities, the overall business environment, its historical earnings and losses, current industry trends, and its outlook for future years. Based on when the Company expects existing taxable differences to be realized, management determined that sufficient positive evidence exists as of December 31, 2023 to conclude that it is more-likely-than-not that all of its deferred tax assets will realized.

The calculation of the Company’s tax liabilities involves uncertainties in the application of complex tax laws and regulations. The Company gives financial statement recognition to those tax positions that it believes are more-likely-than-not to be sustained upon the examination by the Internal Revenue Service or other taxing authority. As of December 31, 2023 and 2022, the Company did not have any accrued liability for uncertain tax positions and does not anticipate recognition of any significant liabilities for uncertain tax positions during the next 12 months. Interest and penalties related to uncertain tax positions are reported in income tax expense.

The Company is subject to the following material taxing jurisdictions: United States, Colorado, Montana and North Dakota. As of December 31, 2023, the Company has no tax years under audit. The Company remains subject to examination for federal income taxes and state income taxes for tax year 2023. The Predecessor and Vitesse Oil remain subject to examination for federal income taxes and state income taxes for tax years 2020 through 2023, which could have an impact on the deferred tax liability at Spin-Off.

Note 14—Subsequent Events

Other than the above disclosure or other subsequent events disclosed elsewhere in the notes to the financial statements, there were no material subsequent events.

Supplemental Oil and Gas Information (Unaudited)

Oil and Natural Gas Exploration and Production Activities

Oil and natural gas sales reflect the market prices of net production sold or transferred with appropriate adjustments for any contractual provisions. Production expenses include lifting costs incurred to operate and maintain productive wells and related equipment including such costs as operating labor, repairs and maintenance, materials, supplies and fuel consumed. Production taxes include ad valorem and severance taxes. Depletion of crude oil and natural gas properties relates to capitalized costs incurred in acquisition, exploration, and development activities. Results of operations do not include interest expense and general corporate amounts. The results of operations for the Company’s crude oil and natural gas production activities are provided in the Company’s related consolidated statements of operations. Capitalized costs relating the Company’s oil and natural gas producing activities as of December 31, 2023 and December 31, 2022 are provided in the Company’s consolidated balance sheets.

Costs Incurred

The costs incurred in crude oil and natural gas acquisition, exploration and development activities are highlighted in the table below.

Oil and Natural Gas Reserve Data

The following tables present the Company’s net proved crude oil and natural gas reserves as prepared by Cawley, and include changes as estimated by the Company’s engineering staff. The Company emphasizes that reserves are approximations and are expected to change as additional information becomes available. Reservoir engineering is a subjective process of estimating underground accumulations of crude oil and natural gas that cannot be measured in an exact way, and the accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment.

Proved reserves are estimated quantities of crude oil and natural gas, which geological and engineering data indicate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved developed reserves are proved reserves that can be expected to be recovered through existing wells with existing equipment and operating methods. Proved undeveloped reserves are included for reserves for which there is a high degree of confidence in their recoverability and they are scheduled to be drilled within the next five years.

Notable changes in proved reserves for the year ended December 31, 2023 included the following:

■Acquisitions: We acquired 3,932 MBoe of proved undeveloped reserves in the Williston Basin and Central Rockies during 2023 (See Note 3).

■Revisions to previous estimates: In 2023, revisions to previous estimates decreased proved reserves by a net amount of 6,906 MBoe. These revisions were primarily attributable to the reclassification of undeveloped drilling locations totaling 4,184 MBoe of proved reserves from proved to non-proved and were made proactively as a result of lower-than-expected rig activity in the Williston Basin during the year and continued compliance with the SEC 5-year development rule. In addition, the revisions included decreases in proved reserves of 1,072 MBoe related to forecast/timing/interest changes and 1,650 MBoe associated with lower commodity prices and slightly higher lease operating expenses due to increased workover activity.

■Extensions and discoveries: During 2023, extensions and discoveries of 4,112 MBoe were attributable to additions of 1,520 MMBoe of proved developed reserves and 2,592 MMboe of proved undeveloped reserves in the Williston Basin.

Notable changes in proved reserves for the year ended December 31, 2022 included the following:

■Acquisitions. In 2022, total acquisitions of 3.2 MMBoe were primarily attributable to asset acquisitions of oil and gas properties (see Note 3).

■Revisions to previous estimates. In 2022, revisions to previous estimates increased proved reserves by a net amount of 0.2 MMBoe. Included in these revisions were 1.3 MMBoe of upward adjustments caused by higher crude oil and natural gas prices, 0.3 MMBoe of downward adjustments related to the removal of undeveloped drilling locations related to the SEC 5-year development rule, 0.3 MMBoe of downward adjustments related to changes in development plan, and 0.5 MMBoe of downward adjustments attributable to well performance when comparing the Company’s reserve estimates at December 31, 2022 to December 31, 2021.

■Extensions and discoveries. In 2022, total extensions and discoveries of 1.8 MMBoe were attributable to additions of 1.6 MMBoe of proved developed reserves and 0.2 MMBoe of proved undeveloped reserves, respectively, in the Williston Basin.

Notable changes in proved reserves for the month ended December 31, 2021 included the following:

■Revisions to previous estimates. In the month ended December 31, 2021, revisions to previous estimates increased proved reserves by a net amount of 0.1 MMBoe that were primarily related to upward adjustments caused by higher crude oil and natural gas prices.

Notable changes in proved reserves for the year ended November 30, 2021 included the following:

■Revisions to previous estimates. In 2021, revisions to previous estimates increased proved developed and decreased proved undeveloped reserves by a net amount of 3.7 MMBoe. Included in these revisions were 4.3 MMBoe of upward adjustments caused by higher crude oil and natural gas prices and 6.9 MMBoe of downward adjustments related to the removal of undeveloped drilling locations due to a slower recovery of rig activity than expected in the Williston Basin, 0.5 MMBoe of downward adjustments related to the removal of drilled uncompleted wells in the Central Rockies related to the SEC 5-year development rule and 0.6 MMBoe of downward adjustments attributable to well performance when comparing the Company’s reserve estimates at November 30, 2021 to November 30, 2020.

■Extensions and discoveries. In 2021, total extensions and discoveries of 1.3 MMBoe were attributable to additions of proved undeveloped locations in the Williston Basin.

Standardized Measure of Discounted Future Net Cash Inflows and Changes Therein

The following table presents a standardized measure of discounted future net cash flows relating to proved crude oil and natural gas reserves, and the changes in standardized measure of discounted future net cash flows relating to proved crude oil and natural gas were prepared in accordance with the provisions of ASC 932 Extractive Activities— Oil and Gas. Future cash inflows were computed by applying average prices of crude oil and natural gas for the last 12 months to estimated future production. Future production and development costs were computed by estimating the expenditures to be incurred in developing and producing the proved crude oil and natural gas reserves at the end of the year (including asset retirement costs), based on year-end costs and assuming continuation of existing economic conditions. Future income tax expenses were calculated by applying appropriate year-end tax rates to future pretax cash flows relating to proved crude oil and natural gas reserves, less the tax basis of properties involved and tax credits and loss carry forwards relating to crude oil and natural gas producing activities. Income taxes for the Company are zero for the years ended December 31, 2022 and November 30, 2021 and the month ended December 31, 2021 due to the Predecessors’s tax status as a pass-through entity. Future net cash flows are then discounted at the rate of 10%. Actual future cash inflows may vary considerably, and the standardized measure does not represent the fair value of the Company’s crude oil and natural gas reserves.

The twelve-month average prices were adjusted to reflect applicable transportation and quality differentials on a well-by-well basis to arrive at realized sales prices used to estimate the Company’s reserves. The price of other liquids is included in natural gas. The prices for the Company’s reserve estimates were as follows:

Changes in the Standardized Measure of Discounted Future Net Cash Flows at 10% per annum follow: