Vitesse Energy (VTS) 10-K 26 Feb 24 2023 FY Annual report Financial data

Cover

Cover - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2023	Feb. 15, 2024	Jun. 30, 2023
Cover [Abstract]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2023
Current Fiscal Year End Date	--12-31
Document Transition Report	false
Entity File Number	001-41546
Entity Registrant Name	Vitesse Energy, Inc.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	88-3617511
Entity Address, Address Line One	9200 E. Mineral Avenue,
Entity Address, Address Line Two	Suite 200
Entity Address, City or Town	Centennial,
Entity Address, State or Province	CO
Entity Address, Postal Zip Code	80112
City Area Code	(720)
Local Phone Number	361-2500
Title of 12(b) Security	Common Stock, par value $0.01 per share
Trading Symbol	VTS
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	true
Entity Ex Transition Period	false
ICFR Auditor Attestation Flag	false
Document Financial Statement Error Correction	false
Entity Shell Company	false
Entity Public Float			$ 558
Entity Common Stock, Shares Outstanding		29,453,975
Documents Incorporated by Reference	Portions of the definitive proxy statement related to the registrant’s 2024 Annual Meeting of Shareholders (the “Proxy Statement”) are incorporated by reference into Part III of this report for the year ended December 31, 2023.
Entity Central Index Key	0001944558
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	FY
Amendment Flag	false

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2023
Audit Information [Abstract]
Auditor Name	Deloitte & Touche LLP
Auditor Location	Denver, Colorado
Auditor Firm ID	34

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Current Assets
Cash	$ 552	$ 10,007
Revenue receivable	44,915	41,393
Commodity derivatives (Note 6)	10,038	2,112
Prepaid expenses and other current assets	2,841	841
Total current assets	58,346	54,353
Oil and Gas Properties-Using the successful efforts method of accounting (Note 2)
Proved oil and gas properties	1,168,378	985,751
Less accumulated DD&A and impairment	(464,036)	(382,974)
Total oil and gas properties	704,342	602,777
Other Property and Equipment—Net	189	114
Other Assets
Commodity derivatives (Note 6)	1,109	1,155
Other noncurrent assets	1,984	2,085
Total other assets	3,093	3,240
Total assets	765,970	660,484
Current Liabilities
Accounts payable	27,692	7,207
Accrued liabilities (Note 7)	32,507	25,849
Commodity derivatives (Note 6)	0	3,439
Other current liabilities	204	184
Total current liabilities	60,403	36,679
Long-term Liabilities
Revolving credit facility (Note 5)	81,000	48,000
Deferred tax liability (Note 13)	64,329	0
Asset retirement obligations (Note 8)	8,353	6,823
Other noncurrent liabilities	5,479	0
Total liabilities	219,564	91,502
Commitments and contingencies (Note 11)
Redeemable Management Incentive Units (Note 12)		4,559
Equity (Note 12)
Preferred stock, $0.01 par value, 5,000,000 shares authorized; 0 shares issued at December 31, 2023	0
Common stock, $0.01 par value, 95,000,000 shares authorized; 32,812,007 shares issued at December 31, 2023	328
Additional paid-in capital	567,654
Accumulated deficit	(21,576)
Predecessor members' equity-common units-450,000,000 units outstanding (Note 12)		564,423
Total liabilities, redeemable units, and equity	$ 765,970	$ 660,484

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical)	Dec. 31, 2023 $ / shares shares
Statement of Financial Position [Abstract]
Preferred stock, par value (in USD per share) | $ / shares	$ 0.01
Preferred stock, authorized (in shares)	5,000,000
Preferred stock, issued (in shares)	0
Par value (in USD per share) | $ / shares	$ 0.01
Shares authorized (in shares)	95,000,000
Shares issued (in shares)	32,812,007

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Nov. 30, 2021
Revenue
Total revenue	$ 16,466	$ 233,905	$ 281,890	$ 167,835
Operating Expenses
Lease operating expense	2,272	39,514	31,133	26,567
Production taxes	1,340	21,625	24,092	14,535
General and administrative	950	23,934	19,833	10,581
Depletion, depreciation, amortization, and accretion	5,417	81,745	63,732	60,846
Equity-based compensation	2,628	32,233	(10,766)	1,409
Total operating expenses	12,607	199,051	128,024	113,938
Operating Income	3,859	34,854	153,866	53,897
Other Income (Expense)
Commodity derivative gain (loss), net	(10,982)	12,484	(30,830)	(32,590)
Interest expense	(237)	(5,276)	(4,153)	(3,207)
Other income	1	140	20	14
Total other income (expense)	(11,218)	7,348	(34,963)	(35,783)
Income (Loss) Before Income Taxes	(7,359)	42,202	118,903	18,114
(Provision for) Benefit from Income Taxes	0	(61,946)	0	0
Net (Loss) Income	(7,359)	(19,744)	118,903	18,114
Net income (loss) attributable to Predecessor common unit holders	(7,359)	1,832	118,903	18,114
Net Loss Attributable to Vitesse Energy, Inc.	$ 0	$ (21,576)	$ 0	$ 0
Weighted Average Common Units Outstanding (in shares)	438,625,000	29,556,967	438,625,000	438,625,000
Weighted Average Common Units Outstanding (in shares)	438,625,000	29,556,967	438,625,000	438,625,000
Net (loss) income per common share / Predecessor common unit, basic (in USD per share)	$ (0.02)	$ (0.73)	$ 0.26	$ 0.04
Net (loss) income per common share / Predecessor common unit, diluted (in USD per share)	(0.02)	$ (0.73)	0.26	0.04
Net loss per Predecessor non-founder MIUs classified as temporary equity–basic (in USD per share)	0		0	0
Diluted EPU (in USD per share)	$ 0		$ 0	$ 0
Oil
Revenue
Total revenue	$ 14,797	$ 218,396	$ 233,622	$ 144,818
Natural gas
Revenue
Total revenue	$ 1,669	$ 15,509	$ 48,268	$ 23,017

Consolidated Statements of Equi

Consolidated Statements of Equity - USD ($) $ in Thousands	Total	Predecessor Members' Equity	Accumulated Deficit	Common Stock	Preferred Stock	Additional Paid-In Capital
Beginning balance at Nov. 30, 2020	$ 489,808
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net (loss) income	18,114	$ 18,114
Distribution to common unit holders	(12,000)	(12,000)
Fair market value MIU adjustment	(1,530)	(1,530)
Ending balance at Nov. 30, 2021	494,392
Beginning balance at Nov. 30, 2020	489,808
Ending balance at Dec. 31, 2021	480,074
Beginning balance at Nov. 30, 2021	494,392
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net (loss) income	(7,359)	(7,359)
Distribution to common unit holders	(6,000)	(6,000)
Fair market value MIU adjustment	(959)	(959)
Ending balance at Dec. 31, 2021	480,074
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net (loss) income	118,903	118,903
Distribution to common unit holders	(36,000)	(36,000)
Fair market value MIU adjustment	1,446	1,446
Ending balance at Dec. 31, 2022	564,423	564,423
Ending balance at Dec. 31, 2022			$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net (loss) income	(19,744)	1,832	(21,576)
Issuance of common stock in exchange for Vitesse Energy, LLC (in shares)				25,914,891
Issuance of common stock in exchange for Vitesse Energy, LLC	0	(566,255)		$ 259		$ 565,996
Issuance of common stock in exchange for Non-Founder MIU's (in shares)				163,544
Issuance of common stock in exchange for Non-Founder MIU's	4,559			$ 2		4,557
Acquisition of Vitesse Oil, LLC (in shares)				2,120,312
Acquisition of Vitesse Oil, LLC	30,628			$ 21		30,607
Issuance of restricted stock units, net of forfeitures (in shares)				3,152,247
Issuance of restricted stock units, net of forfeitures	(121)			$ 32		(152)
Issuance of Transitional Plan awards (in shares)				1,475,613
Issuance of Transitional Plan awards	0			$ 15		(15)
Equity-based compensation	32,535					32,535
Common stock dividends declared	$ (65,626)					(65,626)
Repurchase of common stock (in shares)	(14,600)			(14,600)
Repurchase of common stock	$ (248)					(248)
Ending balance at Dec. 31, 2023		$ 0
Ending balance (in shares) at Dec. 31, 2023				32,812,007	0
Ending balance at Dec. 31, 2023	$ 546,406		$ (21,576)	$ 328	$ 0	$ 567,654

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Nov. 30, 2021
Cash Flows from Operating Activities
Net (loss) income	$ (7,359)	$ (19,744)	$ 118,903	$ 18,114
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depletion, depreciation, amortization, and accretion	5,417	81,745	63,732	60,846
Unrealized (gain) loss on derivative instruments	9,307	(11,318)	(16,294)	18,687
Equity-based compensation	2,628	32,233	(10,766)	1,409
Deferred income taxes	0	61,946	0	0
Amortization of debt issuance costs	27	655	472	276
Changes in operating assets and liabilities that provided (used) cash:
Revenue receivable	1,330	(810)	(10,764)	(15,959)
Prepaid expenses and other current assets	11	(1,860)	(842)	1,921
Accounts payable	669	2,407	(147)	(997)
Accrued liabilities	493	(3,308)	2,739	2,700
Other	(3)	(4)	8	(26)
Net cash provided by Operating Activities	12,520	141,942	147,041	86,971
Cash Flows from Investing Activities
Acquisition of oil and gas properties	(117)	(35,654)	(28,547)	(6,210)
Development of oil and gas properties	(3,837)	(84,832)	(56,024)	(36,986)
Purchase of property and equipment	(2)	(180)	(12)	(121)
Net cash used in Investing Activities	(3,956)	(120,666)	(84,583)	(43,317)
Cash Flows from Financing Activities
Proceeds from revolving credit facility	0	59,000	16,000	1,000
Repayments of revolving credit facility	0	(26,000)	(36,000)	(31,500)
Repayments of Vitesse Oil revolving credit facility	0	(5,000)	0	0
Dividends/distributions paid	(6,000)	(57,999)	(36,000)	(12,000)
Repurchases of common stock	0	(248)	0	0
Debt issuance costs	(9)	(484)	(1,807)	(87)
Net cash used in Financing Activities	(6,009)	(30,731)	(57,807)	(42,587)
Net (Decrease) Increase in Cash	2,555	(9,455)	4,651	1,067
Cash—Beginning of year	2,801	10,007	5,356	1,734
Cash—End of year	5,356	552	10,007	2,801
Supplemental Disclosure of Cash Flow Information
Cash paid for interest	182	4,734	3,595	2,896
Cash paid for income taxes	0	1,292	0	0
Supplemental Disclosure of Noncash Activity
Oil and gas properties included in accounts payable and accrued liabilities	14,352	46,338	21,266	15,174
Asset retirement obligations capitalized to oil and gas properties	0	951	347	192
Issuance of common stock to acquire Vitesse Oil	0	30,628	0	0
Unit-based compensation liability transferred to redeemable management incentive units	$ 0	$ 0	$ 481	$ 636

Nature of Business

Nature of Business	12 Months Ended
	Dec. 31, 2023
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Business	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.

Significant Accounting Policies

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2023
Accounting Policies [Abstract]
Significant Accounting Policies	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 held no 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 were no 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 for one 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.

Asset Acquisitions

Asset Acquisitions	12 Months Ended
	Dec. 31, 2023
Business Combination and Asset Acquisition [Abstract]
Asset Acquisitions	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.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2023
Fair Value Disclosures [Abstract]
Fair Value Measurements	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

Credit Facility

Credit Facility	12 Months Ended
	Dec. 31, 2023
Debt Disclosure [Abstract]
Credit Facility	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%.

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	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: (in thousands) GROSS RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES GROSS AMOUNTS OFFSET NET RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES Commodity derivative assets: Current derivative assets $ 10,038 $ — $ 10,038 Noncurrent derivative assets 1,109 — 1,109 Total $ 11,147 $ — $ 11,147 Commodity derivative liabilities: Current derivative liabilities $ — $ — $ — Noncurrent derivative liabilities — — — Total $ — $ — $ — 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: (in thousands) GROSS RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES GROSS AMOUNTS OFFSET NET RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES Commodity derivative assets: Current derivative assets $ 2,856 $ (744) $ 2,112 Noncurrent derivative assets 1,721 (566) 1,155 Total $ 4,577 $ (1,310) $ 3,267 Commodity derivative liabilities: Current derivative liabilities $ 4,183 $ (744) $ 3,439 Noncurrent derivative liabilities 566 (566) — Total $ 4,749 $ (1,310) $ 3,439 As of December 31, 2023, the Company had the following crude oil swaps: INDEX SETTLEMENT PERIOD VOLUME HEDGED (Bbls) WEIGHTED AVERAGE ROUNDED FIXED PRICE WTI-NYMEX Q1 2024 402,498 $ 79 WTI-NYMEX Q2 2024 382,500 79 WTI-NYMEX Q3 2024 327,500 79 WTI-NYMEX Q4 2024 262,500 79 WTI-NYMEX Q1 2025 90,000 75 WTI-NYMEX Q2 2025 90,000 75 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.

Accrued Liabilities

Accrued Liabilities	12 Months Ended
	Dec. 31, 2023
Payables and Accruals [Abstract]
Accrued Liabilities	Accrued Liabilities Accrued liabilities at December 31, 2023 and December 31, 2022 are summarized as follows: DECEMBER 31, (in thousands) 2023 2022 Accrued capital expenditures $ 22,800 $ 15,500 Accrued lease operating expenses, net 3,258 2,740 Accrued compensation 3,647 3,524 Accrued derivative settlement — 189 Other accrued liabilities 2,802 1,068 Accrued spin related expenditures — 2,828 Total $ 32,507 $ 25,849

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2023
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations A rollforward of AROs for the years ended December 31, 2023 and December 31, 2022 are presented below. DECEMBER 31, (in thousands) 2023 2022 Balance—Beginning of period $ 6,823 $ 6,156 Liabilities incurred 951 347 Accretion expense 579 320 Revisions — — Balance—End of year $ 8,353 $ 6,823

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2023
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions 3B acquired common units in the Predecessor which were funded by two Initial Loans with related parties. As part of the funding of the Predecessor, 3B entered into two 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 the two 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 into two 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.

Leases

Leases	12 Months Ended
	Dec. 31, 2023
Leases [Abstract]
Leases	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 Other current liabilities 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.

Commitment and Contingencies

Commitment and Contingencies	12 Months Ended
	Dec. 31, 2023
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	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.

Equity

Equity	12 Months Ended
	Dec. 31, 2023
Equity [Abstract]
Equity	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’s two 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 currently no 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: Shares of restricted stock unit awards Weighted-Average Price on Date of Grant Outstanding at January 1, 2023 — $ — Granted 3,333,122 14.96 Vested — — Forfeited (180,875) 14.40 Outstanding at December 31, 2023 3,152,247 $ 14.99 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 and none 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, 2023 103,653 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. Year Restricted stock units Restricted stock awards Total 2024 115,728 57,580 173,308 2025 93,580 17,262 110,842 2026 323,138 48,619 371,757 2027 837 54,269 55,106 Thereafter 131,823 52,781 184,604 Total 665,106 230,511 895,617 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: FOR THE YEAR ENDED (in thousands except share and per share amounts) DECEMBER 31, 2023 Numerator for earnings per common share: Net (loss) attributable to Vitesse Energy, Inc. $ (21,576) Allocation of earnings to participating securities (1) — Net (loss) attributable to common shareholders $ (21,576) Adjustment to allocation of earnings to participating securities related to diluted shares — Net (loss) attributable to common shareholders for diluted EPS $ (21,576) Denominator for earnings per common share: Weighted average common shares outstanding - basic 28,741,995 Weighted average Transitional Share RSUs outstanding 814,972 Denominator for basic earnings per common share 29,556,967 LTIP RSUs — Transitional Share options — Denominator for diluted earnings per common share 29,556,967 Net (loss) per common share: Basic $ (0.73) Diluted $ (0.73) Shares excluded from diluted earnings per share due to anti-dilutive effect: LTIP RSUs 3,143,715 Transitional Share options 270,181 Transitional Share RSUs with remaining performance/service obligation 103,653 (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 had two classes of membership units, with the following units authorized, issued, and outstanding as of December 31, 2022: AUTHORIZED ISSUED AND OUTSTANDING Common units 450,000,000 450,000,000 Management incentive units 1,000,000 953,750 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 and two managers designated by 3B. For voting purposes, each manager was entitled to one 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 the two 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: FOR THE YEAR ENDED DECEMBER 31, FOR THE MONTH ENDED DECEMBER 31, FOR THE YEAR ENDED NOVEMBER 30, 2022 2021 2021 Nonvested at period end 28,750 45,000 45,000 Granted during the period — — — Vested during the period 16,250 — 37,500 Forfeited during the period — — — Fair value of MIUs vested during the period $0.2 million $ — $ 0.7 million 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: FOR THE YEAR ENDED DECEMBER 31, FOR THE MONTH ENDED DECEMBER 31, FOR THE YEAR ENDED NOVEMBER 30, (in thousands) 2022 2021 2021 Common Unit Option Grant $ (2,089) $ 383 $ (569) Founder MIU Option Grant (8,680) 2,170 1,625 Non-Founder MIUs 3 75 353 Total $ (10,766) $ 2,628 $ 1,409 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. DECEMBER 31, NOVEMBER 30, Founder MIU Option Grant 2021 2021 Expected volatility 105% - 140% 125% - 170% Weighted-average volatility 140% 150% Expected dividends/distributions 0% 0% Expected term (in years) 0.5 1 Risk-free rate 0.69% 0.24% DECEMBER 31, NOVEMBER 30, Common Unit Option Grant 2021 2021 Expected volatility 55% 50% Weighted-average volatility 50% 50% Expected dividends/distributions 0% 0% Expected term (in years) 0.5 1 Risk-free rate 0.69% 0.24% 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 had two 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: FOR THE YEAR ENDED DECEMBER 31, FOR THE MONTH ENDED DECEMBER 31, FOR THE YEAR ENDED NOVEMBER 30, 2022 2021 2021 Common Units Net income (loss) 118,903 (7,359) 18,114 less: income allocable to participating securities In-substance options on common units (Common Unit Option) (3,006) — (458) In-substance options on Founder MIUs (Founder MIU Option) — — — Non-Founder MIUs classified as temporary equity — — — Non-Founder MIUs classified as liabilities — — — Net income (loss) attributable to common unitholders 115,897 (7,359) 17,656 Weighted Average Common Units Outstanding (in 000s) 450,000 450,000 450,000 less: Common Units accounted for as in-substance options (11,375) (11,375) (11,375) Weighted Average Common Units Outstanding (in 000s) 438,625 438,625 438,625 Basic and Diluted EPU $ 0.26 $ (0.02) $ 0.04 Temporary Equity Classified MIUs Income allocable to Non-Founder MIUs classified as temporary equity $ — $ — $ — MIUs classified in temporary equity (in 000s) 250 234 234 Basic and Diluted EPU $ — $ — $ —

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2023
Income Tax Disclosure [Abstract]
Income Taxes	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: FOR THE YEAR ENDED DECEMBER 31, (in thousands) 2023 Current taxes: Federal $ — State — Total current income tax benefit (expense) $ — Deferred taxes: Federal $ (55,687) State (6,259) Total deferred income tax benefit (expense) $ (61,946) Total income tax benefit (expense) $ (61,946) 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: FOR THE YEAR ENDED DECEMBER 31, (in thousands) 2023 Income tax benefit (expense) at the federal statutory rate $ (8,862) State income taxes benefit (expense) - net of federal income tax benefits (1,801) GAAP and tax differences of Predecessor (44,118) Equity-based compensation (6,148) Other (1,017) Total income tax benefit (expense) $ (61,946) 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 YEARS ENDED DECEMBER 31, (in thousands) 2023 2022 Deferred tax assets: Asset retirement obligations $ 1,951 $ — Net operating loss 1,414 — Interest expense 905 — Equity-based compensation 691 — Accrued compensation 831 — Other assets 874 — Total deferred tax assets $ 6,666 $ — Deferred tax liabilities: Oil and gas properties $ (68,391) $ — Derivatives (2,604) — Total deferred tax liabilities $ (70,995) $ — Valuation Allowance $ — $ — Total deferred tax (liability) asset $ (64,329) $ — 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.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2023
Subsequent Events [Abstract]
Subsequent Events	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.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Nov. 30, 2021
Pay vs Performance Disclosure
Net Income (Loss)	$ (7,359)	$ (19,744)	$ 118,903	$ 18,114

Insider Trading Arrangements

Insider Trading Arrangements	3 Months Ended
	Dec. 31, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

Significant Accounting Polici_2

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2023
Accounting Policies [Abstract]
Change in Estimate that is Inseparable from a Change in Accounting Principle	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	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	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	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	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	Cash and Cash Equivalents
Oil and Gas Properties	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.
Asset Retirement Obligations (AROs)	Asset Retirement Obligations (AROs)
Equity-Based Compensation and Predecessor Equity-Based Compensation	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	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 for one 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	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 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	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	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.
New Accounting Pronouncements	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.

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	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: (in thousands) GROSS RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES GROSS AMOUNTS OFFSET NET RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES Commodity derivative assets: Current derivative assets $ 10,038 $ — $ 10,038 Noncurrent derivative assets 1,109 — 1,109 Total $ 11,147 $ — $ 11,147 Commodity derivative liabilities: Current derivative liabilities $ — $ — $ — Noncurrent derivative liabilities — — — Total $ — $ — $ — 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: (in thousands) GROSS RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES GROSS AMOUNTS OFFSET NET RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES Commodity derivative assets: Current derivative assets $ 2,856 $ (744) $ 2,112 Noncurrent derivative assets 1,721 (566) 1,155 Total $ 4,577 $ (1,310) $ 3,267 Commodity derivative liabilities: Current derivative liabilities $ 4,183 $ (744) $ 3,439 Noncurrent derivative liabilities 566 (566) — Total $ 4,749 $ (1,310) $ 3,439
Schedule of Crude Oil Swaps	As of December 31, 2023, the Company had the following crude oil swaps: INDEX SETTLEMENT PERIOD VOLUME HEDGED (Bbls) WEIGHTED AVERAGE ROUNDED FIXED PRICE WTI-NYMEX Q1 2024 402,498 $ 79 WTI-NYMEX Q2 2024 382,500 79 WTI-NYMEX Q3 2024 327,500 79 WTI-NYMEX Q4 2024 262,500 79 WTI-NYMEX Q1 2025 90,000 75 WTI-NYMEX Q2 2025 90,000 75

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	12 Months Ended
	Dec. 31, 2023
Payables and Accruals [Abstract]
Schedule of Accrued Liabilities	Accrued liabilities at December 31, 2023 and December 31, 2022 are summarized as follows: DECEMBER 31, (in thousands) 2023 2022 Accrued capital expenditures $ 22,800 $ 15,500 Accrued lease operating expenses, net 3,258 2,740 Accrued compensation 3,647 3,524 Accrued derivative settlement — 189 Other accrued liabilities 2,802 1,068 Accrued spin related expenditures — 2,828 Total $ 32,507 $ 25,849

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2023
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	A rollforward of AROs for the years ended December 31, 2023 and December 31, 2022 are presented below. DECEMBER 31, (in thousands) 2023 2022 Balance—Beginning of period $ 6,823 $ 6,156 Liabilities incurred 951 347 Accretion expense 579 320 Revisions — — Balance—End of year $ 8,353 $ 6,823

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2023
Equity [Abstract]
Schedule of Share-Based Payment Arrangement, Restricted Stock and Restricted Stock Unit, Activity	The following is a summary of LTIP activity during the year ended December 31, 2023: Shares of restricted stock unit awards Weighted-Average Price on Date of Grant Outstanding at January 1, 2023 — $ — Granted 3,333,122 14.96 Vested — — Forfeited (180,875) 14.40 Outstanding at December 31, 2023 3,152,247 $ 14.99
Schedule of Share-Based Payment Arrangement, Awards Scheduled to be Released in Future	Year Restricted stock units Restricted stock awards Total 2024 115,728 57,580 173,308 2025 93,580 17,262 110,842 2026 323,138 48,619 371,757 2027 837 54,269 55,106 Thereafter 131,823 52,781 184,604 Total 665,106 230,511 895,617
Schedule of Basic and Diluted Net Income (Loss)	The components of basic and diluted net income (loss) per share attributable to common stockholders are as follows: FOR THE YEAR ENDED (in thousands except share and per share amounts) DECEMBER 31, 2023 Numerator for earnings per common share: Net (loss) attributable to Vitesse Energy, Inc. $ (21,576) Allocation of earnings to participating securities (1) — Net (loss) attributable to common shareholders $ (21,576) Adjustment to allocation of earnings to participating securities related to diluted shares — Net (loss) attributable to common shareholders for diluted EPS $ (21,576) Denominator for earnings per common share: Weighted average common shares outstanding - basic 28,741,995 Weighted average Transitional Share RSUs outstanding 814,972 Denominator for basic earnings per common share 29,556,967 LTIP RSUs — Transitional Share options — Denominator for diluted earnings per common share 29,556,967 Net (loss) per common share: Basic $ (0.73) Diluted $ (0.73) Shares excluded from diluted earnings per share due to anti-dilutive effect: LTIP RSUs 3,143,715 Transitional Share options 270,181 Transitional Share RSUs with remaining performance/service obligation 103,653 (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. FOR THE YEAR ENDED DECEMBER 31, FOR THE MONTH ENDED DECEMBER 31, FOR THE YEAR ENDED NOVEMBER 30, 2022 2021 2021 Common Units Net income (loss) 118,903 (7,359) 18,114 less: income allocable to participating securities In-substance options on common units (Common Unit Option) (3,006) — (458) In-substance options on Founder MIUs (Founder MIU Option) — — — Non-Founder MIUs classified as temporary equity — — — Non-Founder MIUs classified as liabilities — — — Net income (loss) attributable to common unitholders 115,897 (7,359) 17,656 Weighted Average Common Units Outstanding (in 000s) 450,000 450,000 450,000 less: Common Units accounted for as in-substance options (11,375) (11,375) (11,375) Weighted Average Common Units Outstanding (in 000s) 438,625 438,625 438,625 Basic and Diluted EPU $ 0.26 $ (0.02) $ 0.04 Temporary Equity Classified MIUs Income allocable to Non-Founder MIUs classified as temporary equity $ — $ — $ — MIUs classified in temporary equity (in 000s) 250 234 234 Basic and Diluted EPU $ — $ — $ —
Schedule of Classes of Membership Units	The Predecessor had two classes of membership units, with the following units authorized, issued, and outstanding as of December 31, 2022: AUTHORIZED ISSUED AND OUTSTANDING Common units 450,000,000 450,000,000 Management incentive units 1,000,000 953,750
Schedule of Share-Based Payment Arrangement, Outstanding Award, Activity, Excluding Option	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: FOR THE YEAR ENDED DECEMBER 31, FOR THE MONTH ENDED DECEMBER 31, FOR THE YEAR ENDED NOVEMBER 30, 2022 2021 2021 Nonvested at period end 28,750 45,000 45,000 Granted during the period — — — Vested during the period 16,250 — 37,500 Forfeited during the period — — — Fair value of MIUs vested during the period $0.2 million $ — $ 0.7 million
Schedule of Disclosure of Share-Based Compensation Arrangements by Share-Based Payment Award	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: FOR THE YEAR ENDED DECEMBER 31, FOR THE MONTH ENDED DECEMBER 31, FOR THE YEAR ENDED NOVEMBER 30, (in thousands) 2022 2021 2021 Common Unit Option Grant $ (2,089) $ 383 $ (569) Founder MIU Option Grant (8,680) 2,170 1,625 Non-Founder MIUs 3 75 353 Total $ (10,766) $ 2,628 $ 1,409
Schedule of Share-Based Payment Award, Stock Options, Valuation Assumptions	DECEMBER 31, NOVEMBER 30, Founder MIU Option Grant 2021 2021 Expected volatility 105% - 140% 125% - 170% Weighted-average volatility 140% 150% Expected dividends/distributions 0% 0% Expected term (in years) 0.5 1 Risk-free rate 0.69% 0.24% DECEMBER 31, NOVEMBER 30, Common Unit Option Grant 2021 2021 Expected volatility 55% 50% Weighted-average volatility 50% 50% Expected dividends/distributions 0% 0% Expected term (in years) 0.5 1 Risk-free rate 0.69% 0.24%

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2023
Income Tax Disclosure [Abstract]
Schedule of Income Tax Expense And Benefit	Income tax expenses and benefits included in the consolidated statements of operations are detailed below: FOR THE YEAR ENDED DECEMBER 31, (in thousands) 2023 Current taxes: Federal $ — State — Total current income tax benefit (expense) $ — Deferred taxes: Federal $ (55,687) State (6,259) Total deferred income tax benefit (expense) $ (61,946) Total income tax benefit (expense) $ (61,946)
Schedule of Reconciliation of The Statutory Federal Income Tax Expense	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: FOR THE YEAR ENDED DECEMBER 31, (in thousands) 2023 Income tax benefit (expense) at the federal statutory rate $ (8,862) State income taxes benefit (expense) - net of federal income tax benefits (1,801) GAAP and tax differences of Predecessor (44,118) Equity-based compensation (6,148) Other (1,017) Total income tax benefit (expense) $ (61,946)
Schedule of Tax Effects of Temporary Differences of Deferred Tax Assets and Liabilities	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 YEARS ENDED DECEMBER 31, (in thousands) 2023 2022 Deferred tax assets: Asset retirement obligations $ 1,951 $ — Net operating loss 1,414 — Interest expense 905 — Equity-based compensation 691 — Accrued compensation 831 — Other assets 874 — Total deferred tax assets $ 6,666 $ — Deferred tax liabilities: Oil and gas properties $ (68,391) $ — Derivatives (2,604) — Total deferred tax liabilities $ (70,995) $ — Valuation Allowance $ — $ — Total deferred tax (liability) asset $ (64,329) $ —

Nature of Business (Details)

Nature of Business (Details) - USD ($) $ / shares in Units, $ in Millions	Jan. 13, 2023	Feb. 18, 2020	Dec. 31, 2023
Entity Information [Line Items]
Par value (in USD per share)			$ 0.01
Income tax expense (benefit), spin-off	$ 44.1
Vitesse Energy, LLC | Jefferies Financial Group
Entity Information [Line Items]
Membership interest (as a percent)		97.50%
Vitesse Energy, LLC | 3B Energy, LLC
Entity Information [Line Items]
Membership interest (as a percent)		2.50%

Significant Accounting Polici_3

Significant Accounting Policies - Cash and Cash Equivalents (Details) - USD ($)	Dec. 31, 2023	Dec. 31, 2022
Accounting Policies [Abstract]
Cash equivalents	$ 0	$ 0

Significant Accounting Polici_4

Significant Accounting Policies - Oil and Gas Properties (Details)	1 Months Ended	12 Months Ended
	Dec. 31, 2021 USD ($) $ / bbl	Dec. 31, 2023 USD ($) $ / bbl	Dec. 31, 2022 USD ($) $ / bbl	Nov. 30, 2021 USD ($) $ / bbl
Accounting Policies [Abstract]
Depletion expense	$ 5,400,000	$ 81,100,000	$ 63,300,000	$ 60,400,000
Depletion rate (in dollars per barrels of oil equivalent) | $ / bbl	16.97	18.68	16.71	16.73
Impairment of oil and gas	$ 0	$ 0	$ 0	$ 0

Significant Accounting Polici_5

Significant Accounting Policies - Revenue Recognition (Details)	12 Months Ended
	Dec. 31, 2023
Minimum
Concentration Risk [Line Items]
Revenue from contract with customer, payment term	1 month
Maximum
Concentration Risk [Line Items]
Revenue from contract with customer, payment term	6 months

Significant Accounting Polici_6

Significant Accounting Policies - Concentrations of Credit Risk (Details) - Operator Concentration Risk	1 Months Ended	11 Months Ended	12 Months Ended
	Dec. 31, 2021	Nov. 30, 2021	Dec. 31, 2023	Dec. 31, 2022
Revenue | Three Operators
Concentration Risk [Line Items]
Concentration risk (as a percent)	42%	37%	49%
Revenue | Four Operators
Concentration Risk [Line Items]
Concentration risk (as a percent)				54%
Accounts Receivable | Three Operators
Concentration Risk [Line Items]
Concentration risk (as a percent)			56%
Accounts Receivable | Four Operators
Concentration Risk [Line Items]
Concentration risk (as a percent)				65%

Asset Acquisitions (Details)

Asset Acquisitions (Details) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Nov. 30, 2021
Asset Acquisition [Line Items]
Payments to acquire oil and gas properties	$ 117	$ 35,654	$ 28,547	$ 6,210
Acquisition of Vitesse Oil, LLC		30,628
Vitesse Oil
Asset Acquisition [Line Items]
Asset acquisition, proved oil and gas property		35,600
Net liabilities		$ 5,000

Credit Facility (Details)

Credit Facility (Details) - Credit Facility - Line of Credit $ in Thousands	1 Months Ended			12 Months Ended
	Jan. 31, 2023	Apr. 30, 2022	May 31, 2015 USD ($)	Dec. 31, 2023 USD ($) quarter	Jan. 17, 2024 USD ($)	Nov. 03, 2023 USD ($)	May 02, 2023 USD ($)	Jan. 13, 2023 USD ($)	Dec. 31, 2022 USD ($)
Revolving Credit Facility
Line of Credit Facility [Line Items]
Maximum borrowing capacity			$ 500,000	$ 500,000				$ 500,000
Current borrowing capacity				245,000			$ 245,000		$ 200,000
Elected commitment			$ 180,000			$ 180,000	$ 170,000		170,000
Revolving credit facility				$ 81,000					$ 48,000
Commitment fee percentage (as a percent)		0.50%	0.50%
Interest rate at the end of the period (as a percent)				8.46%					7.42%
Minimum percentage of proved PV10 reserve value			85%
Maximum outstanding credit usage percentage				80%
Debt Instrument, EBITDAX Ratio				1.50
Free cash flow amount				$ 0
Total funded debt to consolidated EBITDAX ratio				3
Consolidated current assets to consolidated current liabilities ratio				1
Utilization percentage, not less than				40%
Debt instrument, covenant term, number of covered quarters, scenario one | quarter				4
Utilization percentage (less than)				50%
Utilization percentage, covering at least				50%
Debt instrument, covenant term, number of covered quarters, scenario two | quarter				8
Utilization percentage				50%
Revolving Credit Facility | Subsequent Event
Line of Credit Facility [Line Items]
Elected commitment					$ 210,000
Revolving Credit Facility | Federal Funds Rate
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)				0.50%
Revolving Credit Facility | Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)		1%		1%
Revolving Credit Facility | Federal Funds Effective Rate
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)		0.50%
Revolving Credit Facility | Minimum | Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)	2.75%	2.75%
Revolving Credit Facility | Minimum | Adjusted Base Rate
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)	1.75%
Revolving Credit Facility | Maximum
Line of Credit Facility [Line Items]
Debt Instrument, EBITDAX Ratio				2.25
Revolving Credit Facility | Maximum | Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)	3.75%	3.75%
Revolving Credit Facility | Maximum | Adjusted Base Rate
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)	2.75%
Eurodollar Loan | Minimum | London Interbank Offered Rate (LIBOR)
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)			2.75%
Eurodollar Loan | Maximum | London Interbank Offered Rate (LIBOR)
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)			3.75%
Alternative Base Rate Loan | Federal Funds Effective Rate
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)			0.50%
Alternative Base Rate Loan | Minimum | Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)		1.75%
Alternative Base Rate Loan | Minimum | London Interbank Offered Rate (LIBOR)
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)			1.75%
Alternative Base Rate Loan | Maximum | Secured Overnight Financing Rate (SOFR)
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)		2.75%
Alternative Base Rate Loan | Maximum | London Interbank Offered Rate (LIBOR)
Line of Credit Facility [Line Items]
Spread on margin rate (as a percent)			2.75%

Derivative Instruments - Fair V

Derivative Instruments - Fair Value (Details) - Commodity Contract - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Commodity derivative assets:
GROSS RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES	$ 11,147	$ 4,577
GROSS AMOUNTS OFFSET	0	(1,310)
NET RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES	11,147	3,267
Total
GROSS RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES	0	4,749
GROSS AMOUNTS OFFSET	0	(1,310)
NET RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES	0	3,439
Current derivative assets
Commodity derivative assets:
GROSS RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES	10,038	2,856
GROSS AMOUNTS OFFSET	0	(744)
NET RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES	10,038	2,112
Noncurrent derivative assets
Commodity derivative assets:
GROSS RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES	1,109	1,721
GROSS AMOUNTS OFFSET	0	(566)
NET RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES	1,109	1,155
Current derivative liabilities
Total
GROSS RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES	0	4,183
GROSS AMOUNTS OFFSET	0	(744)
NET RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES	0	3,439
Noncurrent derivative liabilities
Total
GROSS RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES	0	566
GROSS AMOUNTS OFFSET	0	(566)
NET RECOGNIZED FAIR VALUE ASSETS/ LIABILITIES	$ 0	$ 0

Derivative Instruments - Swaps

Derivative Instruments - Swaps (Details) - Designated as Hedging Instrument	12 Months Ended
	Dec. 31, 2023 $ / bbl bbl
Crude Oil Swap, Settlement Period Q1 2024
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional amount, volume | bbl	402,498
Rounded swap fixed rate | $ / bbl	79
Crude Oil Swap, Settlement Period Q2 2024
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional amount, volume | bbl	382,500
Rounded swap fixed rate | $ / bbl	79
Crude Oil Swap, Settlement Period Q3 2024
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional amount, volume | bbl	327,500
Rounded swap fixed rate | $ / bbl	79
Crude Oil Swap, Settlement Period Q4 2024
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional amount, volume | bbl	262,500
Rounded swap fixed rate | $ / bbl	79
Crude Oil Swap One, Settlement Period Q1 2025
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional amount, volume | bbl	90,000
Rounded swap fixed rate | $ / bbl	75
Crude Oil Swap Two, Settlement Period Q1 2025
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Notional amount, volume | bbl	90,000
Rounded swap fixed rate | $ / bbl	75

Accrued Liabilities (Details)

Accrued Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Payables and Accruals [Abstract]
Accrued capital expenditures	$ 22,800	$ 15,500
Accrued lease operating expenses, net	3,258	2,740
Accrued compensation	3,647	3,524
Accrued derivative settlement	0	189
Other accrued liabilities	2,802	1,068
Accrued spin related expenditures	0	2,828
Total	$ 32,507	$ 25,849

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2023	Dec. 31, 2022
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance—Beginning of period	$ 6,823	$ 6,156
Liabilities incurred	951	347
Accretion expense	579	320
Revisions	0	0
Balance—End of year	$ 8,353	$ 6,823

Related Party Transactions (Det

Related Party Transactions (Details) $ in Thousands						1 Months Ended	12 Months Ended				116 Months Ended
	Nov. 30, 2022 USD ($)	Nov. 30, 2021	Jan. 01, 2018 USD ($)	Jul. 01, 2016 USD ($)	May 07, 2014	Dec. 31, 2021 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Nov. 30, 2021 USD ($)	Dec. 31, 2023	Jul. 31, 2018 USD ($) promissory_note	May 31, 2017 USD ($) loan
Related Party Transaction [Line Items]
Payments of distributions						$ 6,000		$ 36,000		$ 12,000
Total revenue						16,466	$ 233,905	281,890		167,835
Related Party | Employee Participation Plan | Employees, Consultants, Or Independent Contractors
Related Party Transaction [Line Items]
Maximum capital expenditure			$ 2,000
Payment to acquire outstanding EPP working interest	$ 4,900
VE Holding LLC | 2018 Notes | Related Party
Related Party Transaction [Line Items]
Number of promissory note | promissory_note												2
Promissory note												$ 10,000
Accrued interest rate												3%
Annual reduction in recourse, percentage												33%
3B Energy, LLC
Related Party Transaction [Line Items]
Payments of distributions								$ 900
Vitesse Oil | Related Party | Services Agreement
Related Party Transaction [Line Items]
Related party, services agreement, allocation of costs percent		90%			50%			90%	90%		100%
Total revenue								$ 1,100	$ 100	1,100
JETX Energy, LLC | Related Party
Related Party Transaction [Line Items]
Monthly service provider fee				$ 200
JETX Energy, LLC | Related Party | Services Agreement
Related Party Transaction [Line Items]
Total revenue						200	$ 2,700	$ 2,400		$ 2,400
3B Energy, LLC | VE Holdings LLC | Related Party
Related Party Transaction [Line Items]
Notes payable, related party | loan													2
3B Energy, LLC | VE Holdings LLC | Initial Loans, Promissory Note 1 | Related Party
Related Party Transaction [Line Items]
Promissory note						7,875			7,875				$ 7,875
Accrued interest rate													10%
3B Energy, LLC | VE Holdings LLC | Initial Loans, Promissory Note 2 | Related Party
Related Party Transaction [Line Items]
Promissory note						$ 3,500			$ 3,500				$ 3,500
Accrued interest rate						10%			10%				3.50%
Vitesse Oil | Related Party | Services Agreement
Related Party Transaction [Line Items]
Related party, services agreement, allocation of costs percent					50%

Leases (Details)

Leases (Details) - USD ($) $ in Millions	1 Months Ended	11 Months Ended	12 Months Ended
	Dec. 31, 2021	Nov. 30, 2021	Dec. 31, 2023	Dec. 31, 2022
Leases [Abstract]
Operating lease expense	$ 0	$ 0.4	$ 0.4	$ 0.4
Right-of-use assets			0.2	0.2
Lease obligations			$ 0.2	$ 0.2
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]			Other Assets, Noncurrent	Other Assets, Noncurrent
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]			Other current liabilities	Other current liabilities

Equity - Narrative (Details)

Equity - Narrative (Details) $ / shares in Units, $ in Thousands		1 Months Ended	12 Months Ended			13 Months Ended
	Jan. 13, 2023 shares	Dec. 31, 2021 USD ($) shares	Dec. 31, 2023 USD ($) vote class member manager $ / shares shares	Dec. 31, 2022 USD ($) class shares	Nov. 30, 2021 USD ($) shares	Dec. 31, 2021 USD ($) shares	Feb. 28, 2023 USD ($)
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Shares authorized (in shares)			95,000,000
Par value (in USD per share) | $ / shares			$ 0.01
Preferred stock, authorized (in shares)			5,000,000
Preferred stock, par value (in USD per share) | $ / shares			$ 0.01
Distribution of predecessor equity interests (in shares)			25,628,162
Number of founding members | member			2
Repurchase of common stock (in shares)			14,600
Common stock dividends declared | $			$ (65,626)
Common stock dividends declared (usd per share) | $ / shares			$ 2
Preferred stock, shares outstanding (in shares)			0
Equity-based compensation | $		$ 2,628	$ 32,233	$ (10,766)	$ 1,409
Authorized stock repurchase amount | $							$ 60,000
Stock repurchased and retired | $			$ 248
Number of classes of membership units | class			2	2
Common units, issued, value per unit (in dollars per share) | $ / shares			$ 1
Common unit, aggregate issuance value | $			$ 450,000
Number of managers | manager			5
Number of votes each manager is entitled to | vote			1
Increase (decrease) fair market value MIU adjustment | $		959		$ (1,446)	1,530
Payments of distributions | $		$ 6,000		$ 36,000	$ 12,000
Managers Designated By JFG
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Number of managers | manager			3
Managers Designated By 3B
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Number of managers | manager			2
Common Stock
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Issuance of Transitional Plan awards (in shares)			1,475,613
Issuance of common stock in exchange for Non-Founder MIU's (in shares)			163,544
Acquisition of Vitesse Oil, LLC (in shares)			2,120,312
Repurchase of common stock (in shares)			14,600
Transitional Equity Award Adjustment Plan
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Maximum shares authorized (in shares)			457,866
Options granted in period (in shares)			457,866
Options exercised (in shares)			0
Intrinsic value | $			$ 5,900
Long-Term Incentive Plan
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Maximum shares authorized (in shares)			3,960,000
Number of shares available for grant (in shares)			807,753
Unrecognized compensation costs | $			$ 15,000
Compensation cost expected to be recognized (in years)			2 years 6 months 21 days
Restricted Stock | Transitional Equity Award Adjustment Plan
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Granted (in shares)	286,729		286,729
Restricted Stock | Transitional Equity Award Adjustment Plan | Common Stock
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Issuance of Transitional Plan awards (in shares)			56,218
Transitional Share RSUs | Officers, Directors, and Employees
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Granted (in shares)			3,152,247
Transitional Share RSUs | Transitional Equity Award Adjustment Plan
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Granted (in shares)	1,475,613		1,475,613
Nonvested at period end (in shares)			103,653
Transitional Share RSUs | Transitional Equity Award Adjustment Plan | Common Stock
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Issuance of Transitional Plan awards (in shares)			810,507
Restricted stock units were released as common stock released as common stock (in shares)			810,507
Transitional Share RSUs | Long-Term Incentive Plan
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Granted (in shares)			3,333,122
Equity-based compensation | $			$ 32,200
RSUs accelerated cost amount | $			$ 26,800
RSUs accelerated cost amount (in shares)			1,863,000
Nonvested at period end (in shares)			3,152,247	0
Non Founder MIUs
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Granted (in shares)		0		0	0
Nonvested at period end (in shares)		45,000		28,750	45,000	45,000
Increase (decrease) fair market value MIU adjustment | $				$ (1,500)	$ 1,500	$ 1,000

Equity - Long-Term Incentive Pl

Equity - Long-Term Incentive Plan (Details) - Transitional Share RSUs - Long-Term Incentive Plan	12 Months Ended
	Dec. 31, 2023 $ / shares shares
Shares of restricted stock unit awards
Outstanding, beginning balance (in shares) | shares	0
Granted (in shares) | shares	3,333,122
Vested (in shares) | shares	0
Forfeited (in shares) | shares	(180,875)
Outstanding, ending balance (in shares) | shares	3,152,247
Weighted-Average Price on Date of Grant
Outstanding, weighted average price on date of grant, beginning balance ( in USD per share) | $ / shares	$ 0
Granted, weighted average price on date of grant (in USD per share) | $ / shares	14.96
Vested, weighted average price on date of grant (in USD per share) | $ / shares	0
Forfeited, weighted average price on date of grant (in USD per share) | $ / shares	14.40
Outstanding, weighted average price on date of grant, ending balance ( in USD per share) | $ / shares	$ 14.99

Equity - Shares Released in Fut

Equity - Shares Released in Future (Details)	Dec. 31, 2023 shares
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	895,617
2024
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	173,308
2025
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	110,842
2026
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	371,757
2027
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	55,106
Thereafter
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	184,604
Transitional Share RSUs
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	665,106
Transitional Share RSUs | 2024
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	115,728
Transitional Share RSUs | 2025
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	93,580
Transitional Share RSUs | 2026
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	323,138
Transitional Share RSUs | 2027
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	837
Transitional Share RSUs | Thereafter
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	131,823
Restricted Stock
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	230,511
Restricted Stock | 2024
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	57,580
Restricted Stock | 2025
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	17,262
Restricted Stock | 2026
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	48,619
Restricted Stock | 2027
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	54,269
Restricted Stock | Thereafter
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Stock released in future (in shares)	52,781

Equity - Net Income (Loss) Per

Equity - Net Income (Loss) Per Common Share (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Nov. 30, 2021
Numerator for earnings per common share:
Net (loss) attributable to Vitesse Energy, Inc.	$ 0	$ (21,576)	$ 0	$ 0
Allocation of earnings to participating securities		0
Net income (loss) attributable to common unitholders	$ (7,359)	(21,576)	$ 115,897	$ 17,656
Adjustment to allocation of earnings to participating securities related to diluted shares		0
Net (loss) attributable to common shareholders for diluted EPS		$ (21,576)
Denominator for earnings per common share:
Weighted Average Common Units outstanding (in shares)	450,000,000	28,741,995	450,000,000	450,000,000
Weighted average Transitional Share RSUs outstanding with no future service (in shares)		814,972
Weighted Average Common Units Outstanding (in shares)	438,625,000	29,556,967	438,625,000	438,625,000
Weighted Average Common Units Outstanding (in shares)	438,625,000	29,556,967	438,625,000	438,625,000
Net (loss) per common share:
Basic (in USD per share)	$ (0.02)	$ (0.73)	$ 0.26	$ 0.04
Diluted (in USD per share)	$ (0.02)	$ (0.73)	$ 0.26	$ 0.04
LTIP RSUs
Denominator for earnings per common share:
Share-based payment arrangements (in shares)		0
Transitional Share options
Denominator for earnings per common share:
Share-based payment arrangements (in shares)		0
LTIP RSUs
Net (loss) per common share:
Shares excluded from diluted earnings per share due to anti-dilutive effect (in shares)		3,143,715
Transitional Share options
Net (loss) per common share:
Shares excluded from diluted earnings per share due to anti-dilutive effect (in shares)		270,181
Transitional Share RSUs
Net (loss) per common share:
Shares excluded from diluted earnings per share due to anti-dilutive effect (in shares)		103,653

Equity - Classes of Membership

Equity - Classes of Membership Units Authorized, Issued, and Outstanding (Details)	Dec. 31, 2023 class	Dec. 31, 2022 class shares
Equity [Abstract]
Number of classes of membership units | class	2	2
Common units, authorized (in shares)		450,000,000
Common units, issued (in shares)		450,000,000
Common units, outstanding (in shares)		450,000,000
Management incentive units, authorized (in shares)		1,000,000
Management incentive units, issued (in shares)		953,750
Management incentive units, outstanding (in shares)		953,750

Equity - Non-Founder MIUs (Deta

Equity - Non-Founder MIUs (Details) - Non Founder MIUs - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2022	Nov. 30, 2021
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Nonvested at period end (in shares)	45,000	28,750	45,000
Granted (in shares)	0	0	0
Vested (in shares)	0	16,250	37,500
Forfeited (in shares)	0	0	0
Fair value of MIUs vested during the period	$ 0	$ 0.2	$ 0.7

Equity - Total Compensation Cos

Equity - Total Compensation Cost (Income) recognized in Statements of Operations within Unit-based Compensation (Details) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2022	Nov. 30, 2021
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Total compensation cost (income)	$ 2,628	$ (10,766)	$ 1,409
Common Unit Option Grant
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Total compensation cost (income)	383	(2,089)	(569)
Founder MIU Option Grant
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Total compensation cost (income)	2,170	(8,680)	1,625
Non Founder MIUs
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Total compensation cost (income)	$ 75	$ 3	$ 353

Equity - Schedule of MIU Option

Equity - Schedule of MIU Option Grant And Common Unit Option Grant (Details)	12 Months Ended
	Dec. 31, 2021	Nov. 30, 2021
Founder MIU Option Grant
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Expected volatility, minimum	105%	125%
Expected volatility, maximum	140%	170%
Weighted-average volatility	140%	150%
Expected dividends/distributions	0%	0%
Expected term (in years)	6 months	1 year
Risk-free rate	0.69%	0.24%
Common Unit Option Grant
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Expected volatility	55%	50%
Weighted-average volatility	50%	50%
Expected dividends/distributions	0%	0%
Expected term (in years)	6 months	1 year
Risk-free rate	0.69%	0.24%

Equity - Basic and Diluted Net

Equity - Basic and Diluted Net Income (Loss) Per Unit (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Nov. 30, 2021
Common Units
Net (loss) income	$ (7,359)	$ (19,744)	$ 118,903	$ 18,114
In-substance options on common units (Common Unit Option)	0		(3,006)	(458)
In-substance options on Founder MIUs (Founder MIU Option)	0		0	0
Non-Founder MIUs classified as temporary equity	0		0	0
Non-Founder MIUs classified as liabilities	0		0	0
Net income (loss) attributable to common unitholders	$ (7,359)	$ (21,576)	$ 115,897	$ 17,656
Weighted Average Common Units outstanding (in shares)	450,000,000	28,741,995	450,000,000	450,000,000
Less: Common Unites accounted for as in-substance options (in shares)	(11,375,000)		(11,375,000)	(11,375,000)
Weighted Average Common Units Outstanding (in shares)	438,625,000	29,556,967	438,625,000	438,625,000
Basic (in USD per share)	$ (0.02)	$ (0.73)	$ 0.26	$ 0.04
Diluted (in USD per share)	$ (0.02)	$ (0.73)	$ 0.26	$ 0.04
Temporary Equity Classified MIUs
Income allocable to Non-Founder MIUs classified as temporary equity	$ 0		$ 0	$ 0
MIUs classified in temporary equity (in shares)	234,000		250,000	234,000
Basic EPU (in USD per share)	$ 0		$ 0	$ 0
Diluted EPU (in USD per share)	$ 0		$ 0	$ 0

Income Taxes - Schedule of Inco

Income Taxes - Schedule of Income Tax Expense And Benefit (Details) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Nov. 30, 2021
Current taxes:
Federal		$ 0
State		0
Total current income tax benefit (expense)		0
Deferred taxes:
Federal		(55,687)
State		(6,259)
Total deferred income tax benefit (expense)	$ 0	(61,946)	$ 0	$ 0
Total income tax benefit (expense)	$ 0	$ (61,946)	$ 0	$ 0

Income Taxes - Schedule of Effe

Income Taxes - Schedule of Effective Tax Rate Reconciliation (Details) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2023	Dec. 31, 2022	Nov. 30, 2021
Income Tax Disclosure [Abstract]
Income tax benefit (expense) at the federal statutory rate		$ (8,862)
State income taxes benefit (expense) - net of federal income tax benefits		(1,801)
GAAP and tax differences of Predecessor		(44,118)
Equity-based compensation		(6,148)
Other		(1,017)
Total income tax benefit (expense)	$ 0	$ (61,946)	$ 0	$ 0

Income Taxes - Schedule Of Tax

Income Taxes - Schedule Of Tax Effects of Temporary Differences Of Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2023	Dec. 31, 2022
Deferred tax assets:
Asset retirement obligations	$ 1,951	$ 0
Net operating loss	1,414	0
Interest expense	905	0
Equity-based compensation	691	0
Accrued compensation	831	0
Other assets	874	0
Total deferred tax assets	6,666	0
Deferred tax liabilities:
Oil and gas properties	(68,391)	0
Derivatives	(2,604)	0
Total deferred tax liabilities	(70,995)	0
Valuation Allowance	0	0
Total deferred tax (liability) asset	$ (64,329)	$ 0

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended	12 Months Ended
	Dec. 31, 2021	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022	Nov. 30, 2021
Operating Loss Carryforwards [Line Items]
Income tax expense (benefit)	$ 0		$ 61,946	$ 0	$ 0
Federal and state deferred tax expenses due to change in tax status		$ 44,100
Deferred tax expense related to business acquisition			2,400
State tax expense			0
Federal tax expense			0
U.S. Federal and State | Internal Revenue Service (IRS)
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards			6,100
State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards			4,100
State and Local Jurisdiction | Operating Loss Carryforwards, Expiration Year, 2023
Operating Loss Carryforwards [Line Items]
Operating loss carryforwards			$ 100