US ENERGY CORP

1. ORGANIZATION, OPERATIONS AND SIGNIFICANT ACCOUNTING POLICIES

Organization and Operations

U.S. Energy Corp. (collectively with its wholly-owned subsidiaries, Energy One LLC (“Energy One”), New Horizon Resources LLC (“New Horizon Resources”) and Coyote Resources LLC ("Coyote Resources"), which was formed on* August 6, 2024,*are referred to as the “Company” in these notes to unaudited Condensed Consolidated Financial Statements) is incorporated in the State of Delaware. The Company’s principal business activities are focused on the acquisition, exploration, and development of onshore helium, oil and natural gas properties (collectively referred to as "commodities" or "helium, oil and natural gas") in the United States, which the Company considers a single operating segment. Our principal properties and operations are in the Rockies region (Montana, Wyoming and North Dakota), the Mid-Continent (Oklahoma, Kansas and North and East Texas) region, and the West Texas, South Texas, and Gulf Coast region.

Basis of Presentation

The accompanying unaudited Condensed Consolidated Financial Statements are presented in accordance with U.S. generally accepted accounting principles (“GAAP”) and have been prepared by the Company pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) regarding interim financial reporting. Accordingly, certain information and footnote disclosures required by GAAP for complete financial statements have been condensed or omitted in accordance with such rules and regulations. In the opinion of management, all adjustments (consisting of normal recurring adjustments) considered necessary for a fair presentation of the Condensed Consolidated Financial Statements have been included.

For further information, refer to the consolidated financial statements and footnotes thereto included in our Annual Report on Form10-K for the year ended* December 31, 2023*, as filed with the SEC on* March 26, 2024*. Our financial condition as of* September 30, 2024*, and operating results for thethree andnine months ended* September 30, 2024*, arenot necessarily indicative of the financial condition and results of operations that* maybe expected for any future interim period or for the year ending December 31, 2024*.

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates include the fair value of helium, oil and gas properties acquired, oil and natural gas reserves that are used in the calculation of depreciation, depletion, amortization, and impairment of the carrying value of proved and unproved property; production and commodity price estimates used to record accrued sales receivables; future prices of commodities used in the valuation of commodity derivative contracts; and the cost and timing of future asset retirement obligations. The Company evaluates its estimates on an on-going basis and bases its estimates on historical experience and on various other assumptions the Company believes to be reasonable. Due to inherent uncertainties, including the future commodity prices, these estimates could change in the near term and such changes could be material.

Principles of Consolidation

The accompanying Condensed Consolidated Financial Statements have been prepared in conformity with GAAP and include the accounts of U.S. Energy Corp. and its wholly-owned subsidiaries Energy One, New Horizon Resources and Coyote Resources. U.S. Energy Corp. accounts for its share of helium, oil and gas exploration and production activities, in which it has a direct working interest, by reporting its proportionate share of assets, liabilities, revenues, costs, and cash flows within the relevant lines on the Condensed Consolidated Balance Sheets, Statements of Operations, and Statements of Cash Flows. All inter-company balances and transactions have been eliminated in consolidation.

Segments

Based on the Company’s organization structure, the Company hasone operating segment, which is the development, exploration and production of oil, natural gas and helium. In addition, the Company has a single company-wide management team that allocates capital resources to maximize profitability and measures financial performance as a single enterprise.

Reclassifications

Certain prior year amounts are reclassified to conform to the current year presentation.

Historically, the Company included gathering, transportation, and treating costs within lease operating expense on the Condensed Consolidated Statements of Operations. Effective* July**1,* 2023, the Company began classifying gathering, treating, and transportation costs in a separate line item, titled Gathering, transportation, and treating, on the Condensed Consolidated Statements of Operations and recast prior period results for this reclassification. This reclassification hadno impact on the Company's net income, earnings per share, cash flows, or financial position. The Company revised historical periods to reflect this change in presentation.

The Company has historically included revenue and royalties payable within accounts payables and accrued liabilities on the Condensed Consolidated Balance Sheets. Effective* December**31,* 2023, the Company began classifying revenue and royalties payable as a separate line item on the Condensed Consolidated Balance Sheet. The Condensed Consolidated Statements of Cash Flows has been updated to separate changes in operating assets and liabilities from revenue and royalties payable and accounts payable and accrued liabilities. This reclassification hadno impact on the Company's net income (loss), income (loss) per share, cash flows, or financial position. The Company revised historical periods to reflect this change in presentation.

2. ACQUISITIONS AND DIVESTITURES

Acquisition of helium acreage

On* June 26, 2024,the Company entered into and closed the transactions contemplated by, a purchase and sale agreement with Wavetech Helium ("Wavetech" and the "Purchase Agreement"). Pursuant to the Purchase Agreement, effective June 1, 2024,the Company acquired 82.5% of Wavetech's rights under a farmout agreement for approximately 144 thousand net acres located across the Kevin Dome Structure in Toole County, Montana ("the Assigned Rights"). The Assigned Rights vest upon the drilling oftwo wells on the property. In consideration for the Assigned Rights, the Company paid Wavetech $2.0 million in cash and 2.6 million shares of restricted common stock, which were valued at $2.7 million on June 26, 2024.*In addition, prior to the closing of the Purchase Agreement, the Company incurred $0.4 million of transaction costs related to the acquisition of the Assigned Rights. Additionally, the Company agreed to be responsible for 100% of capital costs, including costs related to project exploration, appraisal, development drilling and completion until $20 million has been incurred related to Wavetech's 17.5% interest. The Company accounted for the acquisition of the Assigned Rights as an asset acquisition.

Acquisition, exploration and development costs related to our helium acreage are accounted for under the full cost method of accounting in a separate cost center from our domestic oil and gas activities. Details about our application of full cost accounting can be found in our Annual Report on Form10-K for the year ended* December 31, 2023,as filed with the SEC on March 26, 2024.*

On* June 25, 2024,the Company entered into a related party non-binding letter of intent with Synergy Offshore LLC ("Synergy") relating to the proposed acquisition by the Company of 24 thousand net operated acres located across the Kevin Dome structure in Toole County, Montana, which are highly contiguous to the property acquired from Wavetech. Synergy is controlled by Mr. Duane H. King, a member of the Board of Directors of the Company, who serves as the Chief Executive Officer and Manager of Synergy, and John A. Weinzierl, the Company’s Chairman, who was then an approximatethirty* percent beneficial owner of Synergy.

In* September 2024,the related party non-binding letter of intent expired with the Company and Synergy unable to reach agreement on the definitive terms of a purchase and sale agreement. Through September 30, 2024* the Company incurred $547 thousand of transaction costs related to the related-party non-binding letter of intent of which $368 thousand were written-off during the period and reflected as acquisition transaction costs on the Condensed Consolidated Statement of Operations. The remaining $179 thousand, which is recorded in other assets on the Condensed Consolidated Balance Sheet, relates to land and helium reserve evaluation. The Company is continuing negotiations with Synergy for a potential joint venture for the development of their helium acreage.

Divestitures

During thenine months ended* September 30, 2024*, the Company closed several divestment transactions of its oil and gas properties for net proceeds totaling $5.9 million. The divestitures included a total of 245 wells in Karnes County and Archer County, Texas and Lea County, New Mexico. These divestitures didnot have a significant impact to reserves volumes or the full cost pool depletion rate. As such, the Company recorded the proceeds, net of transaction costs and purchase price adjustments, to the full cost pool, withno gain or loss recognized in the Condensed Consolidated Statement of Operations. Relief of associated asset retirement obligations of $1.4 million were also recorded to the full cost pool.

During the year ended* December 31, 2023,the Company closed on a series of individual divestitures for a total of $7.0 million in net proceeds before transaction costs of $0.4 million. The divestitures included the Company’s non-operated interests in 152 wells across North Dakota, New Mexico, and Texas, and overriding royalty interests inseven wells in Karnes County, Texas. These divestitures didnot* have a significant impact to reserves volumes or the full cost pool depletion rate. As such, the Company recorded the proceeds, net of transaction costs and purchase price adjustments, to the full cost pool, withno gain or loss recognized. Relief of associated asset retirement obligations of $0.5 million were also recorded to the full cost pool.

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3. REVENUE RECOGNITION

The Company disaggregates revenues from its share of revenue from the sale of oil and natural gas and liquids by region. The Company’s revenues in the Rockies region, West Texas, South Texas, and Gulf Coast region, and Mid-Continent region for thethree andnine months ended* September 30, 2024and2023*, are presented in the following table:

Significant concentrations of credit risk

The Company has exposure to credit risk in the event of non-payment of oil and natural gas receivables by purchasers of its operated oil and natural gas properties. The following table presents the purchasers that accounted for10% or more of the Company’s total oil and natural gas revenue for at leastone of the periods presented:

4. LEASES

The Company’s operating lease right-of-use asset and lease liability are recognized at their discounted present value under the following captions in the Condensed Consolidated Balance Sheets on* September 30, 2024* and* December 31, 2023*:

The Company recognizes lease expense on a straight-line basis excluding short-term and variable lease payments, which are recognized as incurred. Short-term lease cost represents payments for oilfield equipment with original lease terms less thanone year. Following are the amounts recognized as components of lease cost for thethree andnine months ended* September 30, 2024and2023*:

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The Company’s Houston office operating lease doesnot contain implicit interest rates that can be readily determined; therefore, the Company used the incremental borrowing rates in effect at the time the Company entered into the leases.

Maturity of operating lease liabilities with terms ofone year or more as of* September 30, 2024* are presented in the following table:

5. OIL AND NATURAL GAS PRODUCING ACTIVITIES

Full Cost Method Ceiling Test and Impairment

The reserves used in the ceiling test incorporate assumptions regarding pricing and discount rates over which management hasno influence in the determination of present value. In the calculation of the ceiling test as of* September 30, 2024*, the Company used $78.64 per barrel for oil and $2.21 perone million British Thermal Units (MMbtu) for natural gas (as further adjusted for property, specific gravity, quality, local markets and distance from markets) to compute the future cash flows of the Company’s producing properties. The discount factor used was 10%.

During thethree andnine months ended* September 30, 2024*, the Company recorded ceiling test write-downs of its oil and gas properties of $1.4 million and $6.8 million, respectively due to a reduction in the value of proved oil and natural gas reserves primarily as a result of a decrease in crude oil and natural gas prices, the divestment of properties, reserves revisions related to wells shut-in during thefirst quarter of2024 and updates to the decline curves for certain wells.

6. DEBT

On* January 5, 2022,the Company entered into afour*-year credit agreement (“Credit Agreement”) with FirstBank Southwest (“FirstBank”) as administrative agent forone or more lenders (the “Lenders”), which provided for a revolving line of credit with an initial borrowing base of $15 million, and a maximum credit amount of $100 million. Borrowings under the Credit Agreement are collateralized by afirst priority, perfected lien and security interests on substantially all assets of the Company (subject to permitted liens and other customary exceptions). On* July 26, 2022,*the Company entered into a letter agreement with FirstBank whereby it increased the borrowing base under the Credit Agreement from $15 million to $20 million.

Under the Credit Agreement, revolving loans* maybe borrowed, repaid and re-borrowed until January 5, 2026,when all outstanding amounts must be repaid. Interest on the outstanding amounts under the Credit Agreement will accrue at an interest rate equal to the greater of (i) the prime rate in effect on such day, and (ii) the Federal Funds rate in effect on such day (as determined in the Credit Agreement) plus 0.50%, and an applicable margin that ranges between 0.25% to 1.25% depending on utilization of the amount of the borrowing base (the “Applicable Margin”). Interest expense recognized on the Credit Agreement and the weighted average interest rates for thethree* andnine months ended* September 30, 2024and2023* are presented in the following table:

The Credit Agreement contains various restrictive covenants and compliance requirements, which include: (i) maintenance of certain financial ratios, as defined in the Credit Agreement tested quarterly, that limit the Company’s ratio of total debt to EBITDAX (as defined in the Credit Agreement) to 3:1 and require its ratio of consolidated current assets to consolidated current liabilities (as each is described in the Credit Agreement) to remain at 1:1 or higher; (ii) restrictions on making restricted payments as defined in the Credit Agreement, including the payment of cash dividends and repurchases of equity interests (subject to certain limited rights to make restricted payments as long asno event of default has occurred, or would result from the restricted payment, certain financial ratios are met and the borrowing availability after giving pro forma effect to any borrowing to be made on the date of the restricted payment is greater than, or equal to,20% of the then existing borrowing base); (iii) limits on the incurrence of additional indebtedness; (iv) a prohibition on the entry into commodity swap contracts exceeding a specified percentage of our expected production; and (v) restrictions on the disposition of assets. As of* September 30, 2024*, the borrowing base was $20 million, and the Company was in compliance with all financial covenants related to the Credit Agreement.

On* September 10, 2024,with the proceeds of $1.8 million from the settlement of the unwinding of its derivative contracts and cash on hand, the Company repaid the remaining balance of $2.0 million borrowed under the Credit Agreement. Therefore, the amount outstanding on the Credit Agreement as of September 30, 2024* and* December 31, 2023*, was $0.0 million and $5.0 million respectively.

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7. COMMODITY DERIVATIVES

The Company’s results of operations and cash flows are affected by changes in market prices for crude oil and natural gas. To manage a portion of its exposure to price volatility from producing crude oil and natural gas, the Company* mayenter into commodity derivative contracts to protect against price declines in future periods. The Company doesnot* enter into derivative contracts for speculative purposes. The Company doesnot apply hedge accounting. Accordingly, changes in the fair value of the derivative contracts are recorded in the Condensed Consolidated Statements of Operations and are included as a non-cash adjustment to net loss in the operating activities section in the Condensed Consolidated Statements of Cash Flows.

On* September 10, 2024,the Company settled all of its then outstanding commodity derivative contracts for2024* and2025 production receiving $1.8 million. As of* September 30, 2024*, the Companyno longer has any commodity derivative contracts outstanding.

The following table summarizes the components of the commodity derivative settlement gain (loss) as well as the components of the net commodity derivative (gain) loss line-item presentation in the accompanying Condensed Consolidated Statements of Operations:

8. COMMITMENTS AND CONTINGENCIES

Contingencies

The Company is subject to litigation and claims arising in the ordinary course of business. The Company accrues for such items when a liability is both probable and the amount can be reasonably estimated. In the opinion of management, the anticipated results of any pending litigation and claims arenot expected to have a material effect on the results of operations, the financial position, or the cash flows of the Company.

On* January 5, 2022,the Company acquired certain oil and gas producing properties from Synergy Offshore LLC and contemporaneously entered into a farmout agreement concerning certain leases located in Glacier and Toole Counties, Montana. The farmout agreement gives Synergy Offshore LLC the right, subject to certain conditions, to purchase from the Company, any unit or field on the farmout properties once they have commenced enhanced recovery operations on the properties. The price of said purchase is to be based on the greater of present value of said unit or field discounted at10* percent, based on its current production rate at either the prevailing commodity price at the time of purchase or flat pricing of $65.00 per barrel of oil and $3.25 per thousand cubic feet of natural gas (“Repurchase Price”). If a proposed purchase price for the sale to Synergy of the applicable farmout properties is less than the Repurchase Price, the sale will be subject to the affirmative approval by the disinterested members of the Board of Directors of the Company. The farmout agreement has a term of10 years, expiring* January 5, 2032.*

9. SHAREHOLDERS’** EQUITY**

At* September 30, 2024and December 31, 2023* the Company had 28,035,613 and 25,333,870 shares of common stock outstanding, respectively and 245,000,000 authorized shares. In addition, as of* September 30, 2024*, and* December 31, 2023* the Company had 5,000,000 authorized but unissued shares of preferred stock.

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Stock Option Plans

From time to time, the Company* may*grant stock options under its incentive plan covering shares of common stock to employees of the Company. Stock options, when exercised, are settled through the payment of the exercise price in exchange for new shares of stock underlying the option. These awards typically expireten years from the grant date.

For thethree andnine months ended* September 30, 2024and2023*, there wasno compensation expense related to stock options. As of* September 30, 2024* and* September 30, 2023*, all stock options had vested. No stock options were granted or exercised during thethree andnine months ended* September 30, 2024and2023*. Stock options for 1,000 shares expired during thethree months ended* September 30, 2024*. The stock options had de minimis intrinsic values for the periods reported. Presented below is information for stock options outstanding and exercisable as of* September 30, 2024*, and* December 31, 2023*:

The following table summarizes information for stock options outstanding and for stock options exercisable at* September 30, 2024* by the remaining contractual term:

Restricted Stock

The Company grants restricted stock under its incentive plans covering shares of common stock to employees and directors of the Company. Significantly all of the restricted stock awards are time-based awards and are amortized ratably over a requisite service period. Time-based awards vest ratably following the grant date, provided the grantee is employed on the vesting dates. The Company hasone restricted stock award that vests if the Company's share price is equal to or greater than $2.00 for20 consecutive trading days within the period beginning* March 19, 2025and ending March 18, 2027.The grant date fair value of this award is amortized over a derived requisite service period from the fair value model. Forfeitures of restricted stock awards are recognized as they occur. Restricted stock granted to employees, when vested, maybe settled through the net issuance of shares, reduced by the number of shares required to pay withholding taxes. Non-vested shares of restricted stock arenot* included in common shares outstanding until vesting has occurred.

The following table presents the changes in non-vested restricted stock awards to all employees and directors for thenine months ended* September 30, 2024*:

For thenine months ended* September 30, 2024and2023*, the Company recognized $0.9 million and $2.0 million, respectively, of stock compensation expense related to restricted stock grants. Total compensation cost related to non-vested awardsnot yet recognized in the Company’s Condensed Consolidated Statements of Operations as of* September 30, 2024* was $0.7 million. This cost is expected to be recognized over a weighted average period of 1.5 years.

Dividends

On* August 9, 2023,the Board of Directors suspended the Company’s dividend payment program. As a result, no dividends were paid for thenine* months ended* September 30, 2024*. During thethree-month periods ended* March 31, 2023,and June 30, 2023,the Company declared and paid dividends of $0.0225 per share of common stock. Dividends paid for thethree* andsix months ended* June 30, 2023,*were $0.6 million and $1.2 million, respectively.

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Share Repurchase Program

On* April 26, 2023,the Board of Directors of the Company authorized and approved a share repurchase program for up to $5.0 million of the outstanding shares of the Company’s common stock. On March 19, 2024,the Board of Directors authorized and approved an extension of the ongoing share repurchase program. Subject to any future extensions, the repurchase program is scheduled to expire on the earlier of June 30, 2025,*when a maximum of $5.0 million of the Company’s common stock has been repurchased, or when the program is discontinued by the Board of Directors.

Under the stock repurchase program, shares are repurchased from time to time in the open market or through negotiated transactions at prevailing market prices, or by other means in accordance with federal securities laws. Repurchases are made at management’s discretion at prices management considers to be attractive and in the best interests of both the Company and its stockholders, subject to the availability of stock, general market conditions, the trading price of the stock, alternative uses for capital, and the Company’s financial performance. The repurchase program is funded using the Company’s working capital. The repurchased shares are cancelled and therefore willnot be held in treasury or reissued.

The following table presents the activity in the share repurchase program for thethree andnine months ended* September 30, 2024and2023*:

10. ASSET RETIREMENT OBLIGATIONS

The Company has asset retirement obligations (“ARO”) associated with the future plugging and abandonment of proved properties. Initially, the fair value of a liability for an ARO is recorded in the period in which the ARO is incurred with a corresponding increase in the carrying amount of the related asset. The liability is accreted to its present value each period and the capitalized cost is depleted over the life of the related asset. If the liability is settled for an amount other than the recorded amount, an adjustment to the full cost pool is recognized. The Company hadno assets that are restricted for the purpose of settling ARO.

In the fair value calculation for the ARO there are numerous assumptions and judgments, including the ultimate retirement cost, inflation factors, credit-adjusted risk-free discount rates, timing of retirement and changes in legal, regulatory, environmental, and political environments. To the extent future revisions to assumptions and judgments impact the present value of the existing ARO, a corresponding adjustment is made to the oil and natural gas property balance.

The following is a reconciliation of the changes in the Company’s liabilities for asset retirement obligations as of* September 30, 2024* and* December 31, 2023*:

11. INCOME TAXES

The Company’s tax provision or benefit from income taxes for interim periods is determined using an estimate of its annual effective tax rate, adjusted for discrete items, if any. Each quarter the Company updates its estimate of the annual effective tax rate and makes a year-to-date adjustment to the provision. The Company’s effective tax rate was approximately 0% and 3% for thenine months ended* September 30, 2024and2023*, respectively. The primary difference in the Company’s effective tax rate and the statutory rate for both periods is related to the movement in the valuation allowance against the Company’s net deferred tax assets.

Deferred taxes are recognized for the expected future tax consequences of temporary differences between the financial statement and tax basis of assets, liabilities, net operating losses and tax credit carry-forwards. We review our deferred tax assets (“DTAs”) and valuation allowance on a quarterly basis. As part of our review, we consider positive and negative evidence, including cumulative results in recent years. The Company has limitations on net operating losses (“NOLs”) generated prior to2022 and other tax attributes as a result of an Internal Revenue Code ("IRC") Section382 ownership change from a* January 5, 2022acquisition. As such, the Company is projecting that as of September 30, 2024*, it willnot have sufficient DTAs available to fully offset the expected future taxable income that will be generated by the realization of the Company’s deferred tax liabilities and thus has recorded a net deferred tax liability.

The Company recognizes, measures, and discloses uncertain tax positions whereby tax positions must meet a “more-likely-than-not” threshold to be recognized. During thenine months ended* September 30, 2024and2023*, the Company hadno uncertain tax positions.

12. INCOME (LOSS) PER SHARE

Basic net income (loss) per common share is calculated by dividing net income (loss) attributable to common shareholders by the weighted-average number of common shares outstanding for the respective period. Diluted net income per common share is calculated by dividing adjusted net income by the diluted weighted average number of common shares outstanding, which includes the effect of potentially dilutive securities. Potentially dilutive securities for this calculation consist of stock options and unvested shares of restricted common stock, which are measured using the treasury stock method. When the Company recognizes a net loss, all potentially dilutive shares are anti-dilutive and are consequently excluded from the calculation of dilutive net loss per common share. Unvested shares of restricted stock participate in dividend distributions; however, they donot participate in losses. Therefore, dividends attributable to participating securities arenot included as a reduction in the calculation of loss attributable to common shareholders.

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The following table sets forth the calculation of basic and diluted net income (loss) per share for thethree andnine months ended* September 30, 2024and2023*:

For thethree andnine months ended* September 30, 2024and2023*, potentially dilutive securities excluded from the calculation of weighted average shares because they were anti-dilutive were as follows:

13. FAIR VALUE MEASUREMENTS

The Company’s fair value measurements are estimated pursuant to a fair value hierarchy that requires us to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The valuation hierarchy is based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date, giving highest priority to quoted prices in active markets (Level1) and the lowest priority to unobservable data (Level3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. The lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability, and* mayaffect the valuation of the assets and liabilities and their placement within the hierarchy level. Thethree* levels of inputs that* may*be used to measure fair value are defined as:

Level1 - Quoted prices for identical assets and liabilities traded in active markets.

Level2 - Observable inputs other than Level1 that are directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in active markets, or other observable inputs that can be corroborated by observable market data.

Level3 - Unobservable inputs supported by little orno market activity for financial instruments whose value is determined using pricing models, discounted cash flow methodologies, or similar techniques, as well as instruments for which the determination of fair value requires significant management judgment or estimation.

While the Company believes its valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different estimate of fair value at the reporting date. The following is a description of the valuation methodologies used for complex financial instruments measured at fair value:

Recurring Fair Value Measurements

Commodity Derivative Instruments

On* September 10, 2024,the Company received $1.8 million on the settlement of all outstanding commodity derivative contracts. The Company measures the fair value of commodity derivative contracts using an income valuation technique based on the contract price of the underlying positions, crude oil and natural gas forward curves, discount rates, and Company or counterparty non-performance risk. The fixed-price swaps and collar derivative contracts are included in Level2.* The fair value of commodity derivative contracts and their presentation in our unaudited Condensed Consolidated Balance Sheet as of* December 31, 2023* is presented below:

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Marketable Equity Securities

We measure the fair value of marketable equity securities based on quoted market prices obtained from independent pricing services. The Company has an investment in the marketable equity securities of Anfield Energy (“Anfield”), which it acquired as consideration for sales of certain mining operations. Anfield is traded in an active market under the trading symbol AEC:TSXV and has been classified as Level1.

Credit Facility

The Company’s credit facility approximates fair value because the interest rate is variable and reflective of market rates.

Other Financial Instruments

The carrying value of financial instruments included in current assets and current liabilities approximate fair value due to the short-term nature of those instruments.

Nonrecurring Fair Value Measurements

Unproved Properties

Unproved property costs are evaluated for impairment and reduced to fair value when there is an indication that the carrying costs* may**not* be recoverable. The estimate of what couldnot be recoverable is based on the Company's intent to develop the properties or renew leases. To measure the fair value the Company uses a market approach which takes into account the following significant assumptions: remaining lease terms, future development plans, potential resource recovery, estimated reserve value and estimated acreage values based on prices received for similar recent acreage transactions by the Company or other market participants. If there is an indication that the value of unproved property has been impaired, the value being impaired is transferred to the full cost pool subject to depletion and the ceiling test limitation.

Asset Retirement Obligations

The Company measures the fair value of asset retirement obligations as of the date a well is acquired, the date a well begins drilling, or the date the Company revises its ARO assumptions. The Company’s estimated asset retirement obligations are based on historical experience in plugging and abandoning wells, estimated economic lives, estimated plugging and abandonment costs and federal and state regulatory requirements, all unobservable inputs, and therefore, are designated as Level3 within the valuation hierarchy. The liability is discounted using the credit-adjusted risk-free rate estimated at the time the liability is incurred or revised upwards. The credit adjusted risk-free rate used to discount the Company’s plugging and abandonment liabilities range from 7.30% to 19.00%. SeeNote10**-Asset Retirement Obligations.

14. OTHER CURRENT ASSETS AND ACCOUNTS PAYABLE AND ACCRUED LIABILITIES

Other Current Assets

The following table presents the components of other current assetsas of the dates indicated:

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Accounts Payable and Accrued Liabilities.

The following table presents the components of accounts payable and accrued liabilities as of the dates indicated:

15. SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION

16. SUBSEQUENT EVENTS

Divestiture

On* October 31, 2024,*the Company closed on the divestment of oil and gas properties in Pratt County and Sumner County, Kansas and Kay County, Oklahoma for net proceeds of $1.2 million.

Expected Write-Down of Oil and Gas Properties

Under the full-cost method of accounting, the net book value of proved oil and gas properties, less related deferred income taxes,* may**not* exceed a calculated “ceiling.” The ceiling limitation is the estimated after-tax future net cash flows from proved oil and gas reserves. Estimated future net cash flows are calculated using the unweighted arithmetic average of commodity prices in effect on thefirst day of each of the previous12 months, adjusted for location and quality differentials, held flat for the life of the production (except where prices are defined by contractual arrangements), less estimated operating costs, production taxes and future development costs, all discounted at10 percent per annum. Future cash outflows associated with settling accrued asset retirement obligations are excluded from the calculation.

For thethree andnine months ended* September 30, 2024*, we recorded ceiling test write-downs of our oil and natural gas properties of $1.4 million and $6.8 million, respectively. We expect to record a further write-down of our oil and gas properties in thefourth quarter of2024 due to the sale of oil and natural gas properties in Pratt County and Sumner County, Kansas and Kay County, Oklahoma, which closed on* October 31, 2024and lower commodity prices used in the calculation of the ceiling test as higherfourth* quarter2023 commodity prices will be removed from the ceiling test calculation and replaced with what we expect to be lowerfourth quarter2024 commodity prices. Depending on actual commodity prices, estimated price differentials, lease operating costs, revisions to reserve estimates, and the amount and timing of capital expenditures, the write-down could be approximately $3.0 million to $4.0 million in thefourth quarter of2024.

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