OKMIN RESOURCES, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

** (Unaudited)**

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

CONDENSED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY (DEFICIT)

For the Three and Nine Months Ended March 31, 2025 and 2024

See accompanying notes to the unaudited consolidated financial statements

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

As of March 31, 2025

1. ORGANIZATION AND NATURE OF OPERATIONS

Business description

Okmin Resources, Inc. (collectively with its subsidiaries, “Okmin” or the “Company”) was incorporated in Nevada in December 2020 to engage in the business of the acquisition, exploration and development of oil and gas properties, mineral rights, and other natural resource assets.

Okmin has been focused on the acquisition and development of domestic oil and gas fields and investing in lower profile rework and recompletion opportunities with lower entry costs. The Company's initial projects are located in Oklahoma and Kansas.

The Company has two wholly owned subsidiaries that conduct oil and gas activities: Okmin Operations, LLC, organized on May 25, 2021 in the State of Kansas, and Okmin Energy LLC, organized on November 21, 2021 in the State of Oklahoma.

The Company has an interest in four separate projects:

The Company has not conducted any reserve evaluations or calculations, and there are currently no proven reserves on any of the Company’s properties.

The Company’s activities are subject to significant risks and uncertainties, including failing to secure additional funding to advance the Company’s current plan to rework and possibly develop its existing projects and to identify and acquire new projects.

The Company’s fiscal year end is June 30.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation

The Company maintains its accounts on the accrual method of accounting in accordance with accounting principles generally accepted in the United States of America (“GAAP”). Accounting principles followed and the methods of applying those principles, which materially affect the determination of financial position, results of operations and cash flows are summarized below.

The financial statements are presented on a consolidated basis and include all of the accounts of Okmin Resources, Inc and its subsidiaries. All significant intercompany balances and transactions have been eliminated.

Use of Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and certain assumptions that affect the amounts reported in these consolidated financial statements and accompanying notes. Actual results could differ from these estimates.

Cash and cash Equivalents

The Company considers all highly liquid temporary cash investments with an original maturity of three months or less to be cash equivalents. At March 31, 2025, the Company cash totaled $40,686.

OKMIN RESOURCES INC. AND SUBSIDIARIESNOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTSAs of March 31, 2025

Oil and gas properties

The Company uses the full cost method of accounting for exploration and development activities as defined by the Securities and Exchange Commission (“SEC”). Under this method of accounting, the costs of unsuccessful, as well as successful, exploration and development activities are capitalized as properties and equipment. This includes any internal costs that are directly related to property acquisition, exploration and development activities but does not include any costs related to production, general corporate overhead or similar activities. Gain or loss on the sale or other disposition of oil and gas properties is not recognized, unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves.

Oil and gas properties include costs that are excluded from costs being depleted or amortized. Oil and natural gas property costs excluded represent investments in unevaluated properties and include non-producing leasehold, geological, and geophysical costs associated with leasehold or drilling interests and exploration drilling costs. The Company allocates a portion of its acquisition costs to unevaluated properties based on relative value. Costs are transferred to the full cost pool as the properties are evaluated over the life of the reservoir. Unevaluated properties are reviewed for impairment annually and are determined through an evaluation considering, among other factors, seismic data, requirements to relinquish acreage, drilling results, remaining time in the commitment period, remaining capital plan, and political, economic, and market conditions.

Gains and losses on the sale of oil and gas properties are not generally reflected in income unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves. Sales of less than 100% of the Company’s interest in the oil and gas property are treated as a reduction of the capital cost of the field, with no gain or loss recognized, as long as doing so does not significantly affect the unit-of-production depletion rate. Costs of retired equipment, net of salvage value, are usually charged to accumulated depreciation.

Depreciation, depletion, and amortization

The depreciable base for oil and natural gas properties includes the sum of all capitalized costs net of accumulated depreciation, depletion, and amortization (“DD&A”), estimated future development costs and asset retirement costs not included in oil and natural gas properties, less costs excluded from amortization. The depreciable base of oil and natural gas properties is amortized on a unit-of-production method.

Asset retirement obligations

The fair value of a liability for an asset’s retirement obligation (“ARO”) is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made, with the corresponding charge capitalized as part of the carrying amount of the related long-lived asset. The liability is accreted to its then-present value each subsequent period, and the capitalized cost is depleted over the useful life of the related asset. Abandonment costs incurred are recorded as a reduction of the ARO liability.

Inherent in the fair value calculation of an ARO are numerous assumptions and judgments including the ultimate settlement amounts, inflation factors, credit adjusted discount rates, timing of settlement, and changes in the legal, regulatory, environmental, and political environments. To the extent future revisions to these assumptions impact the fair value of the existing ARO liability, a corresponding adjustment is made to the oil and gas property balance. Settlements greater than or less than amounts accrued as ARO are recorded as a gain or loss upon settlement.

Fair Value

The Company measures and discloses the estimated fair value of financial assets and liabilities using the fair value hierarchy in accordance with ASC 820, “Fair Value Measurements and Disclosures”. The fair value hierarchy has three levels, which are based on reliable available inputs of observable data. The hierarchy requires the use of observable market data when available.

ASC 820 requires that assets and liabilities measured at fair value are classified and disclosed in one of the following three categories:

Level 1*—*Quoted market prices for identical assets or liabilities in active markets or observable inputs.

Level 2*—*Significant other observable inputs that observable market data can corroborate; and

Level 3*—*Significant unobservable inputs that observable market data cannot corroborate.

Financial instruments consist principally of cash and cash equivalents, accounts receivable, prepaid expenses, oil and gas properties, accounts payable, accrued liabilities, note payable, and interest payable. The recorded values of all financial instruments approximate their current fair values because of their nature and respective relatively short maturity dates or durations.

Fair value estimates are made at a specific point in time, based on relevant market information and information about the financial statement. These estimates are subjective in nature and involve uncertainties and matters of significant judgment and therefore cannot be determined with precision. Changes in assumptions could significantly affect the estimates.

OKMIN RESOURCES INC. AND SUBSIDIARIESNOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTSAs of March 31, 2025

Revenue recognition

The Company is not the operator of any of its oil and gas properties. Sales of all oil and gas produced are the responsibility of the property operator. The operator recognizes revenue when production is sold at a fixed or determinable price, persuasive evidence of an arrangement exists, delivery has occurred, title has transferred, and collectability is reasonably assured in accordance with ASC 606. The Company only recognizes oil and gas revenues when the operator has provided the Company with confirmation of the completed sale and the amount of the revenue attributable to the Company’s working interest has been determined.

Stock-based compensation

The Company accounts for stock-based compensation in accordance with ASC 718, “Compensation - Stock Compensation” (“ASC 718”). Stock-based compensation is recognized as compensation expense in the financial statements based on the fair value which is measured on the grant date for stock-settled awards. That expense is recognized over the period during which a grantee is required to provide services in exchange for the award. Stock-based compensation expense recognized during the period is based on the value of the portion of share-based payment awards that is ultimately expected to vest during the period, or in the period of grant for awards that vest immediately without any future service condition. For awards that vest over time, previously recognized compensation cost is reversed if the service or performance conditions are not satisfied and the award is forfeited.

Income taxes

Income taxes are accounted for under the asset and liability method in accordance with ASC 740, “Income Taxes”. Deferred tax assets and liabilities are recognized for future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities, their respective tax bases and operating loss, and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years those temporary differences are expected to be recovered or settled. Under ASC 740, the effect on deferred tax assets and liabilities or a change in tax rate is recognized in income in the period that includes the enactment date. Deferred tax assets are reduced to estimated amounts to be realized using a valuation allowance. A valuation allowance is applied when in management’s view, it is more likely than not that such deferred tax asset will be unable to be utilized.

3. GOING CONCERN

The Company currently has limited operations. These consolidated financial statements have been prepared on a going concern basis, which contemplates the realization of assets and settlement of liabilities and commitments in the normal course of business.

As reflected in the accompanying condensed consolidated financial statements, the Company had a net loss of $353,785 for the nine months ended March 31, 2025 (year ended June 30, 2024 - $873,214) and an accumulated deficit of $2,062,303 as of March 31, 2025 (June 30, 2024 - $1,708,518). These factors, among others, raise doubt about the Company’s ability to continue as a going concern.

The Company had a working capital deficit of $675,745 as at March 31, 2025 (as of June 30, 2024 – deficit of $460,878) andfor the remainder of the 2025 fiscal year which started in July 2024, we anticipate cash needs of approximately $50,000 for general corporate overhead and for operations on our existing lease properties. This amount does not include funding for any potential workovers, re-entries, stimulation treatments and recompletions of existing non or low producing wells. Any new work on our properties will require additional capital. The Company anticipates receiving limited revenue from oil and gas sales and intends to obtain the remaining capital through private sales of securities and/or debt financing.

The Company’s future success is dependent upon its ability to achieve profitable operations, generate cash from operating activities and obtaining additional financing. If such additional financing is not available on terms acceptable to us or at all, then we may need to curtail our operations and/or take additional measures to conserve and manage our liquidity and capital resources, any of which would have a material adverse effect on our financial position, results of operations, and our ability to continue as a going concern. The condensed consolidated financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.

The accompanying consolidated financial statements do not include any adjustments related to the recoverability or classification of asset-carrying amounts or the amounts and classification of liabilities that may result should the Company be unable to continue as a going concern.

OKMIN RESOURCES INC. AND SUBSIDIARIESNOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTSAs of March 31, 2025

4. OIL AND GAS PROPERTIES

Blackrock Joint Venture - Oklahoma

In February 2021, Okmin entered into a Joint Venture Agreement and Operating Agreement with Blackrock Energy, LLC (“Blackrock”), committing $100,000 in the initial phase to acquire working interests and commence rehabilitation work on a package of ten oil and gas leases located in Okmulgee and Muskogee Counties in Oklahoma. Under the Operating Agreement, Blackrock is the operator of the project. Pursuant to a further agreement entered into on June 10, 2022, Okmin added an additional five oil and gas leases across 739 acres to the Joint Venture with Blackrock, thereby expanding the overall project to fifteen leases covering over 1,500 acres. In the nine months ended March 31, 2025, lease operating expenses including taxes across the extended Joint Venture totaled $15,120. Our share of revenues attributable to the Joint Venture totaled $15,719.

Pursuant to the foregoing Joint Venture Agreements, the Company has acquired working interests in the following leases:

50% Working Interest

•Chain Lease – 160 Acres in Okmulgee County

•Burke Lease – 40 Acres in Okmulgee County

•Preston Lease – 80 Acres in Okmulgee County

•Goldner Lease – 160 Acres in Okmulgee County

•Peavler Lease – 80 Acres in Okmulgee County

•Anthony Lease – 70 Acres in Muskogee County

•Calley Lease – 40 Acres in Okmulgee County

• Abbey Lease – 40 Acres in Okmulgee County

•Duffy Lease – 40 Acres in Okmulgee County

•Shanks Lease – 160 Acres in Okmulgee County

•Waldrip Lease – 80 Acres in Okmulgee County

•Circle V Lease – 236 Acres in Okmulgee County

•Hessom Lease – 183 Acres in Okmulgee County

•Chastain Lease – 80 Acres in Okmulgee County

25% Working Interest

•Hollingsworth Lease – 80 Acres in Okmulgee County

There are no proven reserves of any classification in the Blackrock Joint Venture leases.

OKMIN RESOURCES INC. AND SUBSIDIARIESNOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTSAs of March 31, 2025

Vitt Project – Kansas

In July 2021, the Company through its wholly owned Kansas subsidiary, Okmin Operations, LLC entered into an agreement to acquire a 72.5% Net Revenue Interest in the Vitt Lease located in Neosho County, Kansas. Okmin Operations, LLC acquired the lease with a cash payment of $25,000 together with a commitment to make additional expenditures, initially of at least $50,000 to rework the wells on the lease. The lease covers 160 acres and includes eleven existing oil and gas wells, of which two sit idle requiring equipment and four water injection wells. As of March 31, 2025, aggregate additional expenditures beyond the purchase totaled approximately $108,550. During the nine months ended March 31, 2025, the Company’s expenditures at the Vitt Lease totaled $550, and the Company received $355 in revenues from the project.

West Sheppard Pool Field in North East Oklahoma

The Company previously had a 50% joint venture interest in the West Sheppard Pool Field, a series of leases totaling 1,930 acres located in Okmulgee County, Oklahoma. The 26 existing wells on the leases range from 850 feet to 1,950 feet in depth with gas production from several zones as their main objective.

As of November 2024, the Company assigned its 50% interest in the West Sheppard Pool project to Sheppard Pool Operating, LLC, the operator of the project. After Sheppard Pool Operating has received $22,850 in revenue from the project, the Company will receive a 10% overriding royalty interest (“ORRI”) in the project. Sheppard Pool may elect to reduce the 10% ORRI to 5% by a one-time payment of $100,000 to the Company within 4 years of the effective date of the agreement.

During the nine months ended March 31, 2025, gas sales continued to be suspended on the property and the Company recordedno expenditures or revenues from the project.

Pushmataha in South East Oklahoma

In December 2021, the Company exercised its option and entered into definitive agreements with Blackrock to become a 50% joint venture partner in the Pushmataha Gas Field, comprising 6 leases covering an area of 3,840 acres located in Pushmataha County, Oklahoma. In connection with the acquisition, the Company expended $252,526 in cash. In the nine months ended March 31, 2025, lease operating expenditures at Pushmataha were $14,851, and production revenues received were $1,388.

5. IMPAIRMENT OF OIL AND GAS PROPERTIES

During the period ended March 31, 2025, the Company reviewed the capitalized value of its oil and gas properties and conducted a test to determine the current fair value and if any impairment of the capitalized values was necessary. As a result of this test, the Company determined that the capitalized value exceeded the current fair value. An impairment charge of $15,761 was recorded as an expense in the nine months ended March 31, 2025.

6. REVENUES AND COST OF REVENUES

For the nine months ended March 31, 2025, the Company had production revenue of $17,462 compared to revenue of $53,930 for the nine months ended March 31, 2024. Refer to the table below of production and revenue for the period ended March 31, 2025. For the nine months ended March 31, 2025 and March 31, 2024 our cost of revenue, consisting of lease operating expenses and production and excise taxes was $30,538 and $80,694 respectively.** **

OKMIN RESOURCES INC. AND SUBSIDIARIESNOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTSAs of March 31, 2025

Subject to the Company being able to secure adequate additional financing, Okmin may also acquire the rights to and participate in drilling and/or other mining operations. The Company will evaluate exploration and mining opportunities and other strategic corporate opportunities as they become available from time to time.

There are no proven reserves of any classification in any of the projects listed above.

7. STOCKHOLDERS’ EQUITY

Preferred stock

The Company is authorized to issue 50,000,000 shares of preferred stock with a par value of $0.0001 per share. As at March 31, 2025, the Company had a total of 5,000,000 shares of Series A preferred stock issued and outstanding. Each share of Series A Preferred Stock has voting rights of ten votes per share, though is not entitled to receive dividends. Additionally, each share of Series A preferred shares may be converted at $0.01 per preferred share into ten shares of common stock for each share of Series A Preferred Stock. Jonathan Herzog, the Company’s President and Chief Executive Officer owns all of the Series A Preferred Stock. At any shareholders meeting or in connection with the giving of shareholder consents, the holder of each share of Series A Preferred Stock is entitled to voting rights of ten votes per share, though is not entitled to receive dividends. Accordingly, by reason of his ownership of Series A Preferred Stock, Mr. Herzog exercises control of approximately 48% of the aggregate voting power in the Company. The Series A Preferred Stock upon liquidation, winding-up or dissolution of the Corporation, ranks on a parity, in all respects, with all the Common Stock.

Common stock

The Company is authorized to issue 750,000,000 shares of common stock with a par value of $0.0001 per share.

As of March 31, 2025, the Company had 117,399,921 shares of its common stock issued and outstanding.

8. INCOME (LOSS) PER COMMON SHARE

A reconciliation of the components of basic and diluted net loss per common share for the three months and six months ended March 31, 2025 is presented below:

The numerator for basic earnings per share is net income attributable to common stockholders. The numerator for diluted earnings per share is net income available to common stockholders.

OKMIN RESOURCES INC. AND SUBSIDIARIESNOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTSAs of March 31, 2025

9. INCOME TAXES

Net operating loss carry forwards of approximately $2,062,403 at March 31, 2025 are available to offset future taxable income.

10. RELATED PARTY TRANSACTIONS

As of November 1, 2021, the Company agreed to compensate its Chief Executive Officer, President, and Chief Financial Officer Jonathan Herzog, at a rate of $13,500 per month, consisting of $6,750 in cash compensation and $6,750 to be accrued and deferred until management determines that the Company is in a position to make such payments. Such accrued amounts may be paid in cash or may be satisfied through the issuance of common stock or preferred stock in lieu of cash payments. The Company and Mr. Herzog have not entered into a formal written employment agreement in relation to Mr. Herzog’s compensation and employment terms. Mr. Herzog has accrued the entire monthly compensation since October 2023 and as of March 31, 2025, the Company has a total amount accrued of $398,250 as accrued liabilities – related party.

11. CONVERTIBLE LOAN

In November 2021, the Company entered into a convertible loan agreement with an accredited investor (the “Investor”) pursuant to which the Company raised $231,000 in financing. The note has a 10% annual interest rate, with repayments set initially at of a minimum of $3,500 per month commencing as of May 2022 and any open balance is convertible at the Investor’s discretion into shares of the Company’s common stock at $0.03 per share with warrant coverage at the same price on the basis of one warrant per every three shares issued under the loan. As of March 31, 2025, the Company had an outstanding balance of $137,135 and accrued interest of $60,577 payable on the convertible loan with repayments revised in accordance with the lender at a minimum of $2,000 monthly. The principal amount of the loan is secured by a lien on the Vitt Lease. In the related security agreement, the Company has agreed to remit the first $125,000 in net revenue received from its interest in the Pushmataha Gas Field toward the payment and performance of the note.

On January 3, 2023, the convertible loan agreement was amended to limit the Investor’s ability to convert the loan to only that portion of the outstanding loan amount that would result in the Investor being the beneficial owner of not more than 9.99% of the Company’s class of common stock.

The Company has determined that the loan is accounted for as a liability and not equity as repayment is being made in cash pursuant to the repayment schedule, and no conversion of any of the principal or interest into common shares has been made. Management assessed there is no embedded derivative and therefore no need for the bifurcation of proceeds at initial recognition.

12. SUBSEQUENT EVENTS

The Company has evaluated subsequent events through the filing date of these financial statements and has disclosed that there are no such events that are material to the financial statements to be disclosed.