0001079973-24-001518.txt : 20241114 0001079973-24-001518.hdr.sgml : 20241114 20241113190212 ACCESSION NUMBER: 0001079973-24-001518 CONFORMED SUBMISSION TYPE: 10-Q PUBLIC DOCUMENT COUNT: 49 CONFORMED PERIOD OF REPORT: 20240930 FILED AS OF DATE: 20241114 DATE AS OF CHANGE: 20241113 FILER: COMPANY DATA: COMPANY CONFORMED NAME: OKMIN RESOURCES, INC. CENTRAL INDEX KEY: 0001848334 STANDARD INDUSTRIAL CLASSIFICATION: CRUDE PETROLEUM & NATURAL GAS [1311] ORGANIZATION NAME: 01 Energy & Transportation IRS NUMBER: 854401166 STATE OF INCORPORATION: NV FISCAL YEAR END: 0630 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 000-56381 FILM NUMBER: 241456258 BUSINESS ADDRESS: STREET 1: 16501 VENTURA BLVD. STREET 2: SUITE 400 CITY: ENCINO STATE: CA ZIP: 91436 BUSINESS PHONE: 818-201-3727 MAIL ADDRESS: STREET 1: 16501 VENTURA BLVD. STREET 2: SUITE 400 CITY: ENCINO STATE: CA ZIP: 91436 10-Q 1 okmin_10q-093024.htm FORM 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(MARK ONE)

☒

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2024

☐

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from __________ to __________

Commission File Number: 000-56381

OKMIN RESOURCES INC.

(Exact Name of Registrant as specified in its charter)

Nevada		85-4401166
(State of Incorporation)		(I.R.S. Employer Identification No.)

16501 Ventura Boulevard, Suite 400, Encino, CA		91436
(Address of principal executive offices)		(Zip Code)

(818) 201-3727

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. ☒ Yes ☐ No

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (Section 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer ☐	Accelerated filer ☐
Non-accelerated filer ☒	Smaller Reporting Company ☒
	Emerging growth company ☒

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

Securities registered pursuant to Section 12(b) of the Act:

Title of Each Class	Trading Symbol(s)	Name of each exchange on which registered
None	N/A	N/A

As of November 13, 2024, there were 117,174,921 shares of the registrant’s common stock, $0.0001 par value per share, issued and outstanding.

OKMIN RESOURCES INC.

FORM 10-Q

For the period ended

September 30, 2024

TABLE OF CONTENTS

	PART I – FINANCIAL INFORMATION

Item 1.	Financial Statements	1

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	13

Item 3.	Qualitative and Quantitative Disclosures about Market Risk	17

Item 4.	Controls and Procedures	17

	PART II – OTHER INFORMATION

Item 1.	Legal Proceedings	19

Item 1A.	Risk Factors	19

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	19

Item 3.	Defaults Upon Senior Securities	19

Item 4.	Mine Safety Disclosures	19

Item 5.	Other Information	19

Item 6.	Exhibits	20

SIGNATURES

FORWARD LOOKING STATEMENTS

This report contains forward-looking statements regarding our business, financial condition, results of operations and prospects. Words such as “expects,” “anticipates,” “intends,” “plans,” “believes,” “seeks,” “estimates” and similar expressions or variations of such words are intended to identify forward-looking statements but are not deemed to represent an all-inclusive means of identifying forward-looking statements as denoted in this report. Additionally, statements concerning future matters are forward-looking statements.

Although forward-looking statements in this report reflect the good faith judgment of our management, such statements can only be based on facts and factors currently known by us. Consequently, forward-looking statements are inherently subject to risks and uncertainties and actual results and outcomes may differ materially from the results and outcomes discussed in or anticipated by the forward-looking statements. Factors that could cause or contribute to such differences in results and outcomes include, without limitation, those specifically addressed under the headings “Risks Factors” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our annual report on Form 10-K, in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in this Form 10-Q, and information contained in other reports that we file with the Securities and Exchange Commission (“SEC”). You are urged not to place undue reliance on these forward-looking statements, which speak only as of the date of this report.

We file reports with the SEC. The SEC maintains a website (www.sec.gov) that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC, including us. You can also read and copy any materials we file with the SEC at the SEC’s Public Reference Room at 100 F Street, NE, Washington, DC 20549. You can obtain additional information about the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330.

We undertake no obligation to revise or update any forward-looking statements in order to reflect any event or circumstance that may arise after the date of this report, except as required by law. Readers are urged to carefully review and consider the various disclosures made throughout the entirety of this quarterly report, which are designed to advise interested parties of the risks and factors that may affect our business, financial condition, results of operations and prospects.

Unless otherwise indicated, references in this report to “we,” “us” or the “Company” refer to Okmin Resources, Inc. and its subsidiaries.

OKMIN RESOURCES INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS


	September 30,			June 30
	2024			2024
		(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	73,602		$	72,281
Total current assets		73,602			72,281

Oil and gas properties, net		138,911			139,619
Black Rock Joint Venture		153,967			154,618
Other assets and restricted cash		136			103
Total noncurrent assets		293,014			294,340

TOTAL ASSETS	$	366,616		$	366,621


LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
Current liabilities:
Accounts payable	$	36,480		$	32,698
Accrued liabilities – related party		317,250			276,750
Accrued interest payable – current portion		53,371			49,542
Note payable – current portion		149,135			155,135
Other liabilities		44,703			19,034
Total current liabilities		600,939			533,159

Stockholders’ Equity (Deficit):
Preferred Stock, $0.0001 par value, 50,000,000 shares authorized, 5,000,000 shares issued and outstanding at September 30, 2024 and June 30, 2024, respectively		500			500
Common stock, $0.0001 par value, 750,000,000 shares authorized, 114,424,921 shares issued and outstanding at September 30, 2024 and June 30, 2024, respectively		11,443			11,443
Additional paid-in capital		1,530,037			1,530,037
Accumulated deficit		(1,776,303	)		(1,708,518	)
Total stockholder’s equity (deficit)		(234,323	)		(166,538	)

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY (DEFICIT)	$	366,616		$	366,621

The accompanying notes are an integral part of these financial statements.

OKMIN RESOURCES INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS


	Three Months			Three Months
	Ended			Ended
	September 30, 2024			September 30, 2023
Revenue
Oil and gas sales	$	5,991		$	22,677

Cost of revenue		(9,717	)		(32,247	)
Gross profit (loss)		(3,726	)		(9,570	)

Operating expenses:
General and administrative expense		59,379			104,928
Depreciation, depletion and amortization		1,359			1,238
Total operating expenses		60,738			106,166


(Loss) income from operations		(64,464	)		(115,736	)
Other Income (Expense)

Interest (expense) income		(3,321	)		3,901

(Loss) income before taxes		(67,785	)		(111,835	)

Provision for income taxes		—			—


Total net loss	$	(67,785	)	$	(111,835	)

Net income (loss) per share
Basic	$	(0.00	)	$	(0.00	)
Diluted	$	(0.00	)	$	(0.00	)

Weighted average number of shares outstanding
Basic		114,424,921			113,759,443
Diluted		171,199,610			170,656,308

The accompanying notes are an integral part of these financial statements.

OKMIN RESOURCES INC. AND SUBSIDIARIES

CONDENSED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (DEFICIT)

For the Three Months Ended September 30, 2024 and 2023


									Additional					Stockholders'
	Preferred Stock				Common Stock				Paid-In		Accumulated			Equity/
	Shares		Amount		Shares		Amount		Capital		Deficit			(Deficit)

Balance June 30, 2023		5,000,000	$	500		113,432,500	$	11,344	$	1,393,006	$	(835,304	)	$	569,546

Shares issued for services		—		—		519,375		51		108,274		—			108,325
Net loss		—		—		—		—		—		(111,835	)		(111,835	)

Balance, September 30, 2023		5,000,000	$	500		113,951,875	$	11,395	$	1,501,280	$	(947,139	)	$	566,036

Shares issued for services		—		—		473,046		48		28,757		—			28,805
Net loss		—		—		—		—		—		(761,379	)		(761,379	)

Balance June 30, 2024		5,000,000		500		114,424,921	$	11,443	$	1,530,037	$	(1,708,518	)	$	(166,538	)

Net loss		—		—		—		—		—		(67,785	)		(67,785	)

Balance September 30, 2024		5,000,000	$	500		114,424,921	$	11,443	$	1,530,037	$	(1,776,303	)	$	(234,323	)

The accompanying notes are an integral part of these financial statements.

OKMIN RESOURCES INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOW


	Three Months			Three Months
	Ended			Ended
	September 30, 2024			September 30, 2023
Cash Flows from Operating Activities
Net loss	$	(67,785	)		(111,835	)
Adjustments to reconcile net loss to net cash from operations:
Depreciation and Amortization		1,359			1,238
Accrued Product Sale (O&G)		(33	)		—
Deferred Expense		—			(75,912	)
Production revenue receivable		—			(8,724	)
Accounts receivable related party		—			(258	)
Accrued interest payable		3,828			—
Accounts payable and accrued liabilities		69,951			17,745
Net cash from operating activities		7,320			(177,746	)

Cash Flows from Investing Activities
Investment in Oil and Gas Properties		—			—
Net cash from investing activities		—			—

Cash Flows from Financing Activities
Note Payable		(6,000	)		—
Issuance of Common Stock		—			108,325
Net cash (used) from financing activities		(6,000	)		108,325


Net change in cash		1,320			(69,421	)
Cash - beginning of period		72,281			214,316
Cash - end of period		73,602			144,895

The accompanying notes are an integral part of these financial statements.

OKMIN RESOURCES INC. AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

As of September 30, 2024

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:

	1)	The Blackrock Joint Venture encompassing 15 oil and gas leases in Oklahoma;
	2)	A 72.5% Net Revenue Interest in the Vitt oil lease located in Neosho County, Kansas;
	3)	A 50% Joint Venture interest in West Sheppard Pool, a natural gas project in North East Oklahoma; and
	4)	A 50% Joint Venture interest in Pushmataha, a natural gas project in Southeast Oklahoma.

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 September 30, 2024, the Company cash totaled $73,602.

OKMIN RESOURCES INC. AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

As of September 30, 2024

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 SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

As of September 30, 2024

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 $67,785 for the three months ended September 30, 2024 (year ended June 30, 2024 - $873,214) and an accumulated deficit of $1,776,303 as of September 30, 2024 (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 $527,337 as at September 30, 2024 (as of June 30, 2024 – deficit of $460,878) and for the 2025 fiscal year which started in July, we anticipate cash needs of approximately $300,000 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 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.

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 three months ended September 30, 2024, lease operating expenses including taxes across the extended Joint Venture totaled $5,334. Our share of revenues attributable to the Joint Venture totaled $4,808.

OKMIN RESOURCES INC. AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

As of September 30, 2024

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.

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 September 30, 2024, aggregate additional expenditures beyond the purchase totaled $108,250. During the three months ended September 30, 2024, the Company’s expenditures at the Vitt Lease totaled $250, and the Company received $Nil 0 in revenues from the project.

West Sheppard Pool Field in North East Oklahoma

In August 2021, the Company entered into an option agreement with Blackrock to acquire a 50% joint venture interest in the West Sheppard Pool Field, a series of leases totaling 1,930 acres located in Okmulgee County, Oklahoma. In November 2021, the Company exercised its option and entered into a definitive joint venture and operating agreement with Blackrock at a cost of $150,000 in cash.

OKMIN RESOURCES INC. AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

As of September 30, 2024

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. During the year ended June 30, 2024, gas sales continued to be suspended on the property due the failure of equipment owned by the gas pipeline company at its compressor station. In order to replace the failed equipment, the gas pipeline company is requiring additional gas throughput to justify the investment. As a result of this, in quarter ending September 30, 2024, the Company recorded no revenues from the project.

During the second half of calendar 2023, our partner and operator, Blackrock Energy, LLC agreed to a farmout agreement of its working interests in West Sheppard Pool (with the exception of a 2% overriding royalty interest maintained by Blackrock). Blackrock’s interests were transferred to Sheppard Pool Operating, LLC (hereinafter referred to as “SPO”), the owner of the adjacent East Sheppard Pool leases. SPO also became the Operator of record on the project. This transaction does not change the Company’s working interests in the project.

The Company and SPO had already previously entered into a gas gathering agreement in June 2023 in an effort to restore and ultimately improve gas flows into the gas transit pipeline system. SPO has completed some work to upgrade the West Sheppard Pool leases, though to date gas sales have not resumed. In the three months ended September 30, 2024, the Company recorded expenditures at West Sheppard Pool of $Nil 0.

Pushmataha in South East Oklahoma

In December 2021, the Company exercised its option and entered into definitive agreements with Blackrock to acquire a 50% joint venture interest 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 three months ended September 30, 2024, lease operating expenditures at Pushmataha were $3,538, and production revenues received were $1,242.

5. REVENUES AND COST OF REVENUES

For the three months ended September 30, 2024, the Company had production revenue of $5,991 compared to revenue of $22,677 for the three months ended September 30, 2023. Refer to the table below of production and revenue for the period ended September 30, 2024. For the three months ended September 30, 2024 and September 30, 2023 our cost of revenue, consisting of lease operating expenses and production and excise taxes was $9,717 and $32,247 respectively.

Schedule of oil & gas revenue
	Oil						Natural Gas
Project	Production (BBLS)		Avg. Cost ($)		Avg. Sales Price ($)		Production (MCF)		Avg. Cost ($)		Avg. Sales Price ($)		Total Revenue ($)

Black Rock JV		75.69		65.90		63.52		-		-		-		4,808

Pushmataha		—		—		—		572		6.19		2.07		1,183

West Sheppard		—		—		—		—		—		—		—

Vitt Lease		—		—		—		—		—		—		—

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.

OKMIN RESOURCES INC. AND SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

As of September 30, 2024

6. 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 September 30, 2024, 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 September 30, 2024, the Company had 114,424,921 shares of its common stock issued and outstanding.

On October 1, 2023, the Company established an Advisory Board to include seasoned professionals and industry experts to assist in the development of the Company. On October 1, 2023, the Company entered into an Advisory Board Member Agreement with Dr. John N. O’Brien pursuant to which Dr. O’Brien was appointed by the Company as Senior Advisory Board Member to its Board of Advisors. In consideration of Dr. O’Brien’s appointment to the Company’s Board of Advisors, the Company agreed to issue Dr. O’Brien an aggregate of 200,000 restricted shares of its common stock (the “Shares”), subject to a vesting schedule. No Shares have been issued to Dr. O’Brien as of September 30, 2024.

7. INCOME (LOSS) PER COMMON SHARE

A reconciliation of the components of basic and diluted net loss per common share for the three months ended September 30, 2024 is presented below:


	Three Months Ended September 30, 2024
	Net Loss			Weighted Average Shares		Per Share

Basic Earnings per Share:

Net loss attributable to common stock basic	$	(67,785	)		114,424,921	$	(0.00	)
Net loss attributable to common stock fully diluted	$	(67,785	)		171,199,610	$	(0.00	)

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 SUBSIDIARIES

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

As of September 30, 2024

8. INCOME TAXES

Net operating loss carry forwards of approximately $1,776,303 at September 30, 2024 are available to offset future taxable income.

9. 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. As of September 30, 2024, the Company has accrued $317,250 as accrued liabilities – related party.

10. 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 September 30, 2024, the Company had an outstanding balance of $149,135 and accrued interest of $53,371 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. In the quarter ended September 30, 2023, the Company, in agreement with the Investor, temporarily suspended monthly repayments. The loan continued to accrue interest during this period.

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.

11. SUBSEQUENT EVENTS

On November 12, 2024, the board of directors approved the issuance of 250,000 shares of common stock at $0.04 per share in connection with consulting services for the Company’s filings preparation, compliance matters and business activities. Additionally, in connection with ongoing services, the Company issued 2,500,000 at $0.04 per share to Shmuel Naparstek, who has been a corporate consultant to the Company since 2021 and took up a position to join the Board of Directors as of July 31, 2024.

Outside of this, 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.

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.

Special Note Regarding Forward-Looking Information

The following discussion and analysis of the results of operations and financial condition of Okmin Resources, Inc., and its subsidiaries (“Okmin” or the “Company”) as of September 30, 2024 should be read in conjunction with our unaudited financial statements and the notes to those unaudited financial statements that are included elsewhere in this Quarterly Report on Form 10-Q. References in this Management’s Discussion and Analysis of Financial Condition and Results of Operations to “us”, “we”, “our” and similar terms refer to Okmin. This Quarterly Report contains forward-looking statements as that term is defined in the federal securities laws. The events described in forward-looking statements contained in this Quarterly Report may not occur. Generally, these statements relate to business plans or strategies, projected or anticipated benefits or other consequences of our plans or strategies, projected or anticipated benefits from acquisitions to be made by us, or projections involving anticipated revenues, earnings or other aspects of our operating results. The words “may,” “will,” “expect,” “believe,” “anticipate,” “project,” “plan,” “intend,” “estimate,” and “continue,” and their opposites and similar expressions, are intended to identify forward-looking statements. We caution you that these statements are not guarantees of future performance or events and are subject to a number of uncertainties, risks and other influences, many of which are beyond our control, which may influence the accuracy of the statements and the projections upon which the statements are based.

Our actual results, performance and achievements could differ materially from those expressed or implied in these forward-looking statements. Except as required by federal securities laws, we undertake no obligation to publicly update or revise any forward-looking statements, whether from new information, future events or otherwise.

U.S. Dollars are denoted herein by “USD,” “$” and “dollars”.

Overview

Okmin Resources, Inc. was organized in 2020 to engage in the business of the acquisition, exploration and development of mineral rights and natural resource assets.

As a development stage company, Okmin has been focused on the acquisition and development of domestic oil and gas fields, 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, incorporated on May 25, 2021 in the State of Kansas, and Okmin Energy LLC, incorporated on November 21, 2021 in the State of Oklahoma.

The Company has an interest in four separate projects:

	1)	The Blackrock Joint Venture encompassing 15 oil and gas leases in Oklahoma
	2)	A 72.5% Net Revenue Interest in the Vitt oil lease located in Neosho County, Kansas
	3)	A 50% joint venture interest in West Sheppard Pool, a natural gas project in North East Oklahoma
	4)	A 50% joint venture interest in Pushmataha, a natural gas project in South East Oklahoma.

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

Blackrock Joint Venture

Okmin entered into a Joint Venture Agreement and Operating Agreement in February 2021, committing $100,000 in the initial phase to acquire working interests in ten oil and gas leases located in Okmulgee and Muskogee Counties in Oklahoma. Under the Operating Agreement, Okmin has a 50% Working Interest in 710 acres and a 25% interest in 80 acres. The Company’s Joint Venture partner, Blackrock Energy LLC (“Blackrock”), is the operator of the project. Pursuant to a further agreement entered into on June 10, 2022, the Company added an additional five oil and gas leases across 739 acres to its Joint Venture with Blackrock, thereby expanding the overall project to fifteen leases covering over 1,500 acres. In the three months ended September 30, 2024, lease operating expenses including taxes recorded across the extended Joint Venture totaled $5,334 and our share of the Joint Venture recorded revenues of $4,808 from oil and gas sales, predominantly oil, compared with $14,556 in revenues for the corresponding three months ended September 30, 2023.

Vitt Lease

The Company through its wholly owned Kansas subsidiary, Okmin Operations, LLC entered into an agreement in July 2021 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 capital and operating expenditures to rework the wells on the lease. The lease covers 160 acres and after initial reworking now includes nine oil wells, two idle wells and four water injection wells. At present the wells are not pumping, as they require additional maintenance work. As of the fiscal year ending on June 30, 2024, aggregate additional expenditures beyond the purchase totaled approximately $108,000. During the three months ended September 30, 2024, the Company did not conduct any work on the Vitt lease, so expenditures totaled $250. For the three months ended September 30, 2024, the Company received no revenue from the project compared to revenues for the three months ending September 30, 2023 of $1,972.

The Vitt Lease has now become a small nominal lease able to produce oil, though not on a consistent basis as we continue to encounter various maintenance issues that have to be addressed. The Company continues to explore a number of possibilities for the Vitt Lease, which may include involving a partner in its further development.

West Sheppard Pool

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.

The Company and SPO had previously entered into a gas gathering agreement in June 2023 in an effort to restore and ultimately improve gas flows into the gas transit pipeline system. During the year ended June 30, 2024 and the three months ended September 30, 2024, we received no revenue from the property as gas sales continued to be suspended due to further required pipeline work and the failure of equipment owned by the gas pipeline company at its compressor station. In order to replace the failed equipment, the gas pipeline company is requiring additional gas throughput to justify the investment. SPO has been working to upgrade the gas gathering system on the property, including replacing older gas gathering lines with new modern lines. The older lines were discovered to contain numerous leaks which likely contributed to a lack of throughput to the compressor station.

Prior to the suspension of activities following a compressor outage, only 6 of the 26 wells on the property were selling into the pipeline. Subsequently an additional 4 wells were connected in late 2022, so in total there are now 10 of the 26 wells at West Sheppard Pool connected to the gas gathering system. Many of those wells would likely benefit from workovers to increase their production potential, and six wells were identified by the operator for reentry to perforate and fracture new zones for both oil and gas. The property also has the potential for infill drilling for new wells within the property. Any work is dependent upon obtaining additional capital, which could include adding an additional partner to fund this work program.

Pushmataha

In December 2021, the Company exercised its option and entered into a definitive joint venture and operating agreement with Blackrock to acquire 50% of Blackrock’s interest in the Pushmataha Gas Field, comprising 6 leases covering an area of 3,840 acres located in Pushmataha County, Oklahoma. Blackrock had previously entered into a separate option to acquire working interests ranging from 92 -100% in the existing wells and lease acreage from a third party. In connection with the initial acquisition, the Company expended approximately $253,000 in cash. Under the terms of the Joint Venture agreement, after deducting operating costs including a flat sum of $1,000 per month to Blackrock as operator, the Company shall receive all net income from revenues of the project until it has recouped $125,000, thereafter, the parties shall equally split the income.

The Company has a 50% ownership interest in the Joint Venture with Blackrock. The leases owned by the Joint Venture are subject to landowner royalties and other commitments resulting in net revenue interests to the joint venture of between 71% - 76%, with the exception of the Stephenson well, which has a net revenue interest of approximately 68%.

Pushmataha has seven existing gas wells ranging in depth from 10,000 - 12,300 feet. The wells were inactive since 2019 due to line leaks and lower gas prices, though in April 2021 some wells were put back online and have at various intervals produced between 100 - 300 thousand cubic feet per day (MCFD).

The existing seven wells show additional behind-pipe zones and the joint venture partners assessed recompleting a new zone in one of the wells called the KDC. The operator had a rig out on site at KDC in late January 2023 and commenced some work on the well and were planning to conduct a recompletion, though weather conditions made it too dangerous to proceed. Plans were also underway for the operator to commence repairing or possibly replacing the plunger lift systems of some of the wells, with the goal of dewatering the wells to enable the gas to flow freely. The joint venture partners have temporarily deferred pursuing this active rework activity during the current downturn in natural gas pricing or until additional capital is available.

A hydrocarbon survey was conducted in July 2022 across these leases utilizing a third party patented remote sensing technology. The survey has provided the operator with valuable data in charting the potential for the future development of this project. There is also space to drill new gas wells on the 3,840-acre leasehold, using the hydrocarbon mapping as a tool to locate the optimal drilling locations in these reservoirs.

In the three months ended September 30, 2024, the Company’s lease operating expenditures on the project were $3,538 with additional gas fees, transportation and taxes aggregating $717. For the three months ended September 30, 2024 the Company recorded $1,242 in revenues from the project compared to revenues for the three months ended September 30, 2023 of $6,149.

The operator believes with additional capital expenditures for reworking and recompletion efforts it can further optimize the production potential of this field. The application of newer technologies could also have an important impact on the economics for this asset.

-----------------------------------------------

Management is actively evaluating various new strategic investment and acquisition opportunities in the resources sector, including opportunities to potentially broaden our activities beyond the development of conventional oil and gas projects.

No agreements to acquire new assets or interests have been reached, and any future agreements would be subject to the Company being able to secure adequate additional financing.

RESULTS OF OPERATIONS

For the Three months ended September 30, 2024, as compared to the Three months ended September 30, 2023

Revenue

We generated $5,991 in revenue from oil and gas sales for the three months ended September 30, 2024, as compared to $22,677 in revenues generated in the three months ended September 30, 2024. The decrease in revenue is predominantly attributable to lower natural gas prices. These lower prices not only reduced the sales price we received for each MCF sold, but also led to the curtailment of operations on certain of our properties until prices improve which resulted in a decrease of our production volumes. We also received $507 in interest income from our cash balances for three months ended September 30, 2024.

General and Administrative Expense

General and administrative expenses decreased to $59,379 for the three months ended September 30, 2024 compared to $104,928 for the three months ended September 30, 2024. This decrease is attributable to a decrease in legal and professional fees and the Company’s curtailment of some operations. Expenses related to compensation, interest, rent, accounting and professional fees and other general and administrative expenses necessary for our operations.

Net Loss

The net loss for the three months ended September 30, 2024 was $67,785 compared to a net loss of $111,835 for the three months ended September 30, 2023. The expenses during the three month period ended September 30, 2024, included: $9,717 in lease operating expenses (including taxes and royalties), $40,500 in deferred and unpaid compensation, $4,320 in interest expense and financing costs, $8,400 in compliance listing related fees, $9,599 in accounting and professional fees and other general and administrative expenses necessary for our operations. Expenses during the comparative three month period ended September 30, 2023, including lease operating expenses, were higher and included: $33,485 in lease operating expenses (including taxes and royalties), $40,500 in compensation, a non-cash amount of $25,300 in connection with the services of outside consultants with stock issued in lieu of services, $4,278 in interest expense, legal and professional fees and other general and administrative expenses necessary for our operations.

Net cash (used) from financing

Net cash used in financing activities in the three months ended September 30, 2024 totaled $6,000 which was entirely for repayment of debt. Net cash from financing activities in the corresponding period ended September 30, 2023 totaled $108,325, which was predominantly comprised of stock issued in lieu of services during the period

LIQUIDITY AND CAPITAL RESOURCES

Current Financial Condition

As of September 30, 2024, we had total assets of $366,615, comprised primarily of cash and cash equivalents of $73,602, oil and gas properties $292,877 and prepaid expenses of $136. As at March 31, 2024, we had total liabilities of $600,938, primarily comprised of convertible debt and related interest payable of $202,506, accounts payable of $36,480 and accrued liabilities of $317,250 which is predominantly deferred compensation expense as the CEO is currently deferring salary in an effort to conserve cash.

Our business plan calls for substantial capital resource requirements and we have incurred significant losses since inception. The Company had a net loss of $67,785 for the three months ended September 30, 2024 and an accumulated deficit of $1,776,303 as of September 30, 2024. The Company had a working capital deficit of $527,336 as at September 30, 2024. For the 2025 fiscal year we anticipate cash needs of approximately $300,000 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. A portion of the required cash will be obtained from oil and gas sales. The Company plans to obtain the remainder of the required capital through private sales of securities or debt financing.

To date, we have funded our operations primarily through the issuance of equity and/or convertible securities for cash. We depend upon debt and/or equity financing and revenues to fund our ongoing operations and to execute our current business plan. In the current 2024 fiscal year, such capital requirements will be in excess of what we have in available cash for planned ongoing activities.

We will be required to obtain alternative or additional financing from financial institutions, investors or otherwise, in order to maintain and expand our existing operations. The failure by us to obtain such financing would have a material adverse effect upon our business, financial condition and results of operations, and adversely affecting our ability to complete ongoing activities.

Critical Accounting Estimates

This management’s discussion and analysis of financial condition and results of operations is based on our financial statements, which have been prepared in accordance with U.S. GAAP. Preparation of financial statements requires management to make assumptions, estimates and judgments that affect the reported amounts of assets, liabilities, revenues, costs and expenses, and the related disclosures of contingencies. Management bases its estimates on various assumptions and historical experience, which are believed to be reasonable; however, due to the inherent nature of estimates, actual results may differ significantly due to changed conditions or assumptions. On a regular basis, management reviews the accounting policies, assumptions, estimates and judgments to ensure that our financial statements are fairly presented in accordance with U.S. GAAP. However, because future events and their effects cannot be determined with certainty, actual results could differ from our assumptions and estimates, and such differences could be material.

Recently Issued Accounting Pronouncements

Management does not believe any recently issued but not yet effective accounting pronouncements, if adopted, would have a material effect on the Company’s present or future financial statements.

Going Concern Qualification

The Company’s 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 financial statements, the Company had a net loss of $67,785 for the three months ended September 30, 2024 and an accumulated deficit of $1,776,303 as of September 30, 2024. 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 $527,336 as at September 30, 2024 and for the 2025 fiscal year we anticipate cash needs of approximately $300,000 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. A portion of the required cash will be obtained from oil and gas sales. The Company plans to obtain the remainder of the required capital through private sales of securities or debt financing.

Off-Balance Sheet Arrangements

We do not have any off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources.

Inflation

The effect of inflation on our revenue and operating results was not significant.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

As a smaller reporting company, as defined in Rule 12b-2 of the Exchange Act, we are not required to provide the information required by this Item.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Our management is responsible for establishing and maintaining disclosure controls and procedures (as such term is defined in Rule 13a-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”) that are designed to reasonably ensure that information required to be disclosed in our reports under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC, and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure based closely on the definition of “disclosure controls and procedures” in Rule 15d-15(e) under the Exchange Act. In designing and evaluating the disclosure controls and procedures, our management recognized that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives, and management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

At the end of the period covered by this Quarterly Report, we conducted an evaluation (the “Evaluation”), under the supervision and with the participation of our Chief Executive Officer and Chief Financial Officer of the effectiveness of the design and operation of our disclosure controls and procedures. Based upon the foregoing, our Chief Executive Officer and Chief Financial Officer concluded that, as of September 30, 2024, the disclosure controls and procedures of our Company were not effective to ensure that the information required to be disclosed in our Exchange Act reports was recorded, processed, summarized and reported on a timely basis because of the material weaknesses in internal control over financial reporting described below.

Material Weaknesses and Corrective Actions

In connection with the audits of our financial statements for the fiscal years ended June 30, 2024 and 2023, we identified certain deficiencies relating to our internal control over financial reporting that constitute a material weakness under standards established by the Public Company Accounting Oversight Board (the “PCAOB”). The PCAOB defines a material weakness as a deficiency, or a combination of deficiencies, in internal control over financial reporting such that there is a reasonable possibility that a material misstatement of the company’s annual or interim financial statements will not be prevented or detected on a timely basis. A deficiency in internal control exists when the design or operation of a control does not allow management or employees, in the normal course of performing their assigned functions, to prevent or detect misstatements on a timely basis.

The following material weaknesses in our internal control over financial reporting continued to exist at September 30, 2024:

	●	We do not have written documentation of our internal control policies and procedures. Written documentation of key internal controls over financial reporting is a requirement of Section 404 of the Sarbanes-Oxley Act of 2002 (the “Sarbanes-Oxley Act”);

	●	We do not have sufficient segregation of duties within accounting functions, which is a basic internal control. Due to our limited size and early-stage nature of operations, segregation of all conflicting duties may not always be possible and may not be economically feasible; however, to the extent possible, the initiation of transactions, the custody of assets and the recording of transactions should be performed by separate individuals;

	●	We lack an audit committee of our board of directors; and

	●	We have insufficient monitoring and review of controls over the financial reporting closing process, including the lack of individuals with current knowledge of U.S. GAAP.

We believe that these material weaknesses primarily relate, in part, to our lack of sufficient staff with appropriate training in U.S. GAAP and SEC rules and regulations with respect to financial reporting functions, and the lack of robust accounting systems, as well as the lack of sufficient resources to hire such staff and implement these accounting systems.

Subject to raising sufficient additional capital, we plan to take a number of actions in the future to correct these material weaknesses including adding experienced accounting and financial personnel and retaining third-party consultants to review our internal controls and recommend improvements. We will need to take additional measures to fully mitigate these issues, and the measures we have taken, and expect to take, to improve our internal controls may not be sufficient to (1) address the issues identified, (2) ensure that our internal controls are effective or (3) ensure that the identified material weakness or other material weaknesses will not result in a material misstatement of our annual or interim financial statements. In addition, other material weaknesses may be identified in the future. If we are unable to correct deficiencies in internal controls in a timely manner, our ability to record, process, summarize and report financial information accurately and within the time periods specified in the rules and forms of the SEC will be adversely affected. This failure could negatively affect the market price and trading liquidity of our common stock, cause investors to lose confidence in our reported financial information, subject us to civil and criminal investigations and penalties, and generally materially and adversely impact our business and financial condition.

Limitations on Effectiveness of Controls and Procedures

In designing and evaluating the disclosure controls and procedures and internal control over financial reporting, management recognizes that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives. In addition, the design of disclosure controls and procedures and internal control over financial reporting must reflect the fact that there are resource constraints and that management is required to apply judgment in evaluating the benefits of possible controls and procedures relative to their costs.

Changes in Internal Controls over Financial Reporting

There were no changes (including corrective actions with regard to material weakness) in our internal controls over financial reporting that occurred during the period covered by this report that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II – OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

From time to time, we may be subject to ordinary routine litigation incidental to our normal business operations. We are not currently a party to any litigation the outcome of which, if determined adversely to us, would individually or in the aggregate be reasonably expected to have a material adverse effect on our business, operating results, cash flows or financial condition.

ITEM 1A. RISK FACTORS.

Risk factors describing the major risks to our business can be found under Item 1A, “Risk Factors”, in our Annual Report on Form 10-K for the year ended June 30, 2024. There has been no material change in our risk factors from those previously discussed in the Annual Report on Form 10-K.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

During the three month period ended September 30, 2024, the Company did not issue any securities.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

During the quarter ended September 30, 2024, no director or officer of the Company adopted or terminated a contract, instruction or written plan for the purchase or sale of securities of the Company intended to satisfy the affirmative defense conditions of Rule 10b5-1(c) and/or a non-Rule 10b5-1 trading arrangement.

ITEM 6. EXHIBITS

Exhibit Number		Description

31.1*		Certification of Principal Executive Officer and Principal Financial Officer pursuant to Rule 13a-14a or 15d-14(a) under the Securities Exchange Act of 1934, as amended, and adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1*		Certification of the Principal Executive Officer and Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS		XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH		Inline XBRL Taxonomy Extension Schema Document
101.CAL		Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF		Inline XBRL Taxonomy Extension Definition Linkbase Document
101.LAB		Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE		Inline XBRL Taxonomy Extension Presentation Linkbase Document
104*		Cover Page Interactive Data File - the cover page from the Registrant’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2023, is formatted in Inline XBRL.

* Filed herewith.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		OKMIN RESOURCES INC.

Date: November 13, 2024		/s/ Jonathan Herzog
		Jonathan Herzog, Chief Executive Officer and Chief Financial Officer (Principal Executive Officer, Principal Financial Officer and Principal Accounting Officer)

EX-31.1 2 ex31x1.htm EXHIBIT 31.1

EXHIBIT 31.1

Certification of Principal Executive Officer and Principal Financial Officer pursuant to Rule 13a-14a or 15d-14(a) under the Securities Exchange Act of 1934, as amended, and adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

I, Jonathan Herzog, certify that:

1. I have reviewed this Form 10-Q of Okmin Resources Inc. for the period ended September 30, 2024;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the small business issuer as of, and for, the periods presented in this report;

4. I am responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal controls over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

	a)	designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly for the period in which this quarterly report is being prepared;

	b)	designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

	c)	evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation;

	d)	disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting;

5. I have disclosed, based on our most recent evaluation, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent function):

	a)	all significant deficiencies in the design or operation of internal controls which could adversely affect the registrant’s ability to record, process, summarize and report financial data and have identified for the registrant’s auditors any material weaknesses in internal controls; and

	b)	any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal controls over financial reporting.

Date: November 13, 2024

By:

/s/ Jonathan Herzog

Jonathan Herzog

Chief Executive Officer and

Chief Financial Officer

(Principal Executive Officer and

Principal Financial Officer)

EX-32.1 3 ex32x1.htm EXHIBIT 31.2

EXHIBIT 32.1

Certification of the Principal Executive Officer and Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

In connection with the Quarterly Report on Form 10-Q of Okmin Resources Inc. (the “Company”) for the quarter ended September 30, 2024, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Jonathan Herzog, Chief Executive Officer and Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge:

	1.	The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

	2.	The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.

Date: November 13, 2024	/s/ Jonathan Herzog
	Jonathan Herzog
	Chief Executive Officer and Chief Financial Officer (Principal Executive Officer and Principal Financial Officer)

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[Member] Shmuel Naparstek [Member] Cover [Abstract] Document Type Amendment Flag Amendment Description Document Registration Statement Document Annual Report Document Quarterly Report Document Transition Report Document Shell Company Report Document Shell Company Event Date Document Period Start Date Document Period End Date Document Fiscal Period Focus Document Fiscal Year Focus Current Fiscal Year End Date Entity File Number Entity Registrant Name Entity Central Index Key Entity Primary SIC Number Entity Tax Identification Number Entity Incorporation, State or Country Code Entity Address, Address Line One Entity Address, Address Line Two Entity Address, Address Line Three Entity Address, City or Town Entity Address, State or Province Entity Address, Country Entity Address, Postal Zip Code Country Region City Area Code Local Phone Number Extension Written Communications Soliciting Material Pre-commencement Tender Offer Pre-commencement Issuer Tender Offer Title of 12(b) Security No Trading Symbol Flag Trading Symbol Security Exchange Name Title of 12(g) Security Security Reporting Obligation Annual Information Form Audited Annual Financial Statements Entity Well-known Seasoned Issuer Entity Voluntary Filers Entity Current Reporting Status Entity Interactive Data Current Entity Filer Category Entity Small Business Entity Emerging Growth Company Elected Not To Use the Extended Transition Period Document Accounting Standard Other Reporting Standard Item Number Entity Shell Company Entity Public Float Entity Bankruptcy Proceedings, Reporting Current Entity Common Stock, Shares Outstanding Documents Incorporated by Reference [Text Block] Statement of Financial Position [Abstract] ASSETS Current assets: Cash and cash equivalents Total current assets Oil and gas properties, net Black Rock Joint Venture Other assets and restricted cash Total noncurrent assets TOTAL ASSETS LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT) Current liabilities: Accounts payable Accrued liabilities – related party Accrued interest payable – current portion Note payable – current portion Other liabilities Total current liabilities Stockholders’ Equity (Deficit): Preferred Stock, $0.0001 par value, 50,000,000 shares authorized, 5,000,000 shares issued and outstanding at September 30, 2024 and June 30, 2024, respectively Common stock, $0.0001 par value, 750,000,000 shares authorized, 114,424,921 shares issued and outstanding at September 30, 2024 and June 30, 2024, respectively Additional paid-in capital Accumulated deficit Total stockholder’s equity (deficit) TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY (DEFICIT) Preferred stock, par value Preferred stock, shares authorized Preferred stock, share issued Preferred stock, share outstanding Common stock, par value Common stock, shares authorized Common stock, shares issued Common stock, shares outstanding Income Statement [Abstract] Revenue Oil and gas sales Cost of revenue Gross profit (loss) Operating expenses: General and administrative expense Depreciation, depletion and amortization Total operating expenses (Loss) income from operations Other Income (Expense) Interest (expense) income (Loss) income before taxes Provision for income taxes Total net loss Net income (loss) per share Basic Diluted Weighted average number of shares outstanding Basic Diluted Statement [Table] Statement [Line Items] Beginning balance, value Beginning balance, shares Shares issued for services Shares issued for services, shares Net loss Ending balance, value Ending balance, shares Statement of Cash Flows [Abstract] Cash Flows from Operating Activities Net loss Adjustments to reconcile net loss to net cash from operations: Depreciation and Amortization Accrued Product Sale (O&G) Deferred Expense Production revenue receivable Accounts receivable related party Accrued interest payable Accounts payable and accrued liabilities Net cash from operating activities Cash Flows from Investing Activities Investment in Oil and Gas 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Cover - shares	Sep. 30, 2024	Nov. 13, 2024
Cover [Abstract]
Document Type	10-Q
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Document Quarterly Report	true
Document Transition Report	false
Document Period End Date	Sep. 30, 2024
Document Fiscal Period Focus	Q1
Document Fiscal Year Focus	2025
Current Fiscal Year End Date	--06-30
Entity File Number	000-56381
Entity Registrant Name	OKMIN RESOURCES INC.
Entity Central Index Key	0001848334
Entity Tax Identification Number	85-4401166
Entity Incorporation, State or Country Code	NV
Entity Address, Address Line One	16501 Ventura Boulevard
Entity Address, Address Line Two	Suite 400
Entity Address, City or Town	Encino
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	91436
City Area Code	818
Local Phone Number	201-3727
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	true
Elected Not To Use the Extended Transition Period	false
Entity Shell Company	false
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CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($)	Sep. 30, 2024	Jun. 30, 2024
Current assets:
Cash and cash equivalents	$ 73,602	$ 72,281
Total current assets	73,602	72,281
Oil and gas properties, net	138,911	139,619
Black Rock Joint Venture	153,967	154,618
Other assets and restricted cash	136	103
Total noncurrent assets	293,014	294,340
TOTAL ASSETS	366,616	366,621
Current liabilities:
Accounts payable	36,480	32,698
Accrued liabilities – related party	317,250	276,750
Accrued interest payable – current portion	53,371	49,542
Note payable – current portion	149,135	155,135
Other liabilities	44,703	19,034
Total current liabilities	600,939	533,159
Stockholders’ Equity (Deficit):
Preferred Stock, $0.0001 par value, 50,000,000 shares authorized, 5,000,000 shares issued and outstanding at September 30, 2024 and June 30, 2024, respectively	500	500
Common stock, $0.0001 par value, 750,000,000 shares authorized, 114,424,921 shares issued and outstanding at September 30, 2024 and June 30, 2024, respectively	11,443	11,443
Additional paid-in capital	1,530,037	1,530,037
Accumulated deficit	(1,776,303)	(1,708,518)
Total stockholder’s equity (deficit)	(234,323)	(166,538)
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY (DEFICIT)	$ 366,616	$ 366,621

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CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - $ / shares	Sep. 30, 2024	Jun. 30, 2024
Statement of Financial Position [Abstract]
Preferred stock, par value	$ 0.0001	$ 0.0001
Preferred stock, shares authorized	50,000,000	50,000,000
Preferred stock, share issued	5,000,000	5,000,000
Preferred stock, share outstanding	5,000,000	5,000,000
Common stock, par value	$ 0.0001	$ 0.0001
Common stock, shares authorized	750,000,000	750,000,000
Common stock, shares issued	114,424,921	114,424,921
Common stock, shares outstanding	114,424,921	114,424,921

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($)	3 Months Ended
	Sep. 30, 2024	Sep. 30, 2023
Revenue
Oil and gas sales	$ 5,991	$ 22,677
Cost of revenue	(9,717)	(32,247)
Gross profit (loss)	(3,726)	(9,570)
Operating expenses:
General and administrative expense	59,379	104,928
Depreciation, depletion and amortization	1,359	1,238
Total operating expenses	60,738	106,166
(Loss) income from operations	(64,464)	(115,736)
Other Income (Expense)
Interest (expense) income	(3,321)	3,901
(Loss) income before taxes	(67,785)	(111,835)
Provision for income taxes
Total net loss	$ (67,785)	$ (111,835)
Net income (loss) per share
Basic	$ (0.00)	$ (0.00)
Diluted	$ (0.00)	$ (0.00)
Weighted average number of shares outstanding
Basic	114,424,921	113,759,443
Diluted	171,199,610	170,656,308

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CONDENSED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (DEFICIT) (Unaudited) - USD ($)	Preferred Stock [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Total
Beginning balance, value at Jun. 30, 2023	$ 500	$ 11,344	$ 1,393,006	$ (835,304)	$ 569,546
Beginning balance, shares at Jun. 30, 2023	5,000,000	113,432,500
Shares issued for services		$ 51	108,274		108,325
Shares issued for services, shares	519,375
Net loss				(111,835)	(111,835)
Ending balance, value at Sep. 30, 2023	$ 500	$ 11,395	1,501,280	(947,139)	566,036
Ending balance, shares at Sep. 30, 2023	5,000,000	113,951,875
Shares issued for services		$ 48	28,757		28,805
Shares issued for services, shares	473,046
Net loss				(761,379)	(761,379)
Ending balance, value at Jun. 30, 2024	$ 500	$ 11,443	1,530,037	(1,708,518)	(166,538)
Ending balance, shares at Jun. 30, 2024	5,000,000	114,424,921
Net loss				(67,785)	(67,785)
Ending balance, value at Sep. 30, 2024	$ 500	$ 11,443	$ 1,530,037	$ (1,776,303)	$ (234,323)
Ending balance, shares at Sep. 30, 2024	5,000,000	114,424,921

- Definition

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

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- Definition

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOW (Unaudited) - USD ($)	3 Months Ended
	Sep. 30, 2024	Sep. 30, 2023
Cash Flows from Operating Activities
Net loss	$ (67,785)	$ (111,835)
Adjustments to reconcile net loss to net cash from operations:
Depreciation and Amortization	1,359	1,238
Accrued Product Sale (O&G)	(33)
Deferred Expense		(75,912)
Production revenue receivable		(8,724)
Accounts receivable related party		(258)
Accrued interest payable	3,828
Accounts payable and accrued liabilities	69,951	17,745
Net cash from operating activities	7,320	(177,746)
Cash Flows from Investing Activities
Investment in Oil and Gas Properties
Net cash from investing activities
Cash Flows from Financing Activities
Note Payable	(6,000)
Issuance of Common Stock		108,325
Net cash (used) from financing activities	(6,000)	108,325
Net change in cash	1,320	(69,421)
Cash - beginning of period	72,281	214,316
Cash - end of period	$ 73,602	$ 144,895

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Pay vs Performance Disclosure - USD ($)	3 Months Ended		12 Months Ended
Pay vs Performance Disclosure - USD ($)	Sep. 30, 2024	Sep. 30, 2023	Jun. 30, 2024
Pay vs Performance Disclosure [Table]
Net Income (Loss)	$ (67,785)	$ (111,835)	$ (873,214)

- Definition

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

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Insider Trading Arrangements	3 Months Ended
Insider Trading Arrangements	Sep. 30, 2024
Insider Trading Arrangements [Line Items]
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

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ORGANIZATION AND NATURE OF OPERATIONS

3 Months Ended

Sep. 30, 2024

Accounting Policies [Abstract]

ORGANIZATION AND NATURE OF OPERATIONS

1. ORGANIZATION AND NATURE OF OPERATIONS

Business description

The Company has an interest in four separate projects:

	1)	The Blackrock Joint Venture encompassing 15 oil and gas leases in Oklahoma;
	2)	A 72.5% Net Revenue Interest in the Vitt oil lease located in Neosho County, Kansas;
	3)	A 50% Joint Venture interest in West Sheppard Pool, a natural gas project in North East Oklahoma; and
	4)	A 50% Joint Venture interest in Pushmataha, a natural gas project in Southeast Oklahoma.

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 fiscal year end is June 30.

XML 19 R10.htm IDEA: XBRL DOCUMENT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

3 Months Ended

Sep. 30, 2024

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation

Use of 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 September 30, 2024, the Company cash totaled $73,602.

Oil and gas properties

Depreciation, depletion, and amortization

Asset retirement obligations

Fair Value

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.

Revenue recognition

Stock-based compensation

Income taxes

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GOING CONCERN

3 Months Ended

Sep. 30, 2024

Going Concern

GOING CONCERN

3. GOING CONCERN

XML 21 R12.htm IDEA: XBRL DOCUMENT

OIL AND GAS PROPERTIES

3 Months Ended

Sep. 30, 2024

Extractive Industries [Abstract]

OIL AND GAS PROPERTIES

4. OIL AND GAS PROPERTIES

Blackrock Joint Venture - Oklahoma

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.

Vitt Project – Kansas

West Sheppard Pool Field in North East Oklahoma

Pushmataha in South East Oklahoma

XML 22 R13.htm IDEA: XBRL DOCUMENT

REVENUES AND COST OF REVENUES

3 Months Ended

Sep. 30, 2024

Revenue from Contract with Customer [Abstract]

REVENUES AND COST OF REVENUES

5. REVENUES AND COST OF REVENUES

Schedule of oil & gas revenue
	Oil						Natural Gas
Project	Production (BBLS)		Avg. Cost ($)		Avg. Sales Price ($)		Production (MCF)		Avg. Cost ($)		Avg. Sales Price ($)		Total Revenue ($)

Black Rock JV		75.69		65.90		63.52		-		-		-		4,808

Pushmataha		—		—		—		572		6.19		2.07		1,183

West Sheppard		—		—		—		—		—		—		—

Vitt Lease		—		—		—		—		—		—		—

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

- Definition

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

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-URI https://asc.fasb.org/1943274/2147479806/606-10-50-12

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-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (b)
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-URI https://asc.fasb.org/1943274/2147479806/606-10-50-12

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-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479806/606-10-50-12

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-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
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-Subparagraph (d)
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-URI https://asc.fasb.org/1943274/2147479806/606-10-50-12

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-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Subparagraph (e)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479806/606-10-50-12

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-Topic 606
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 13
-Subparagraph (b)(2)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479806/606-10-50-13

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-Name Accounting Standards Codification
-Topic 606
-Publisher FASB
-URI https://asc.fasb.org/606/tableOfContent

+ Details

XML 23 R14.htm IDEA: XBRL DOCUMENT

STOCKHOLDERS’ EQUITY

3 Months Ended

Sep. 30, 2024

Equity [Abstract]

STOCKHOLDERS’ EQUITY

6. STOCKHOLDERS’ EQUITY

Preferred 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 September 30, 2024, the Company had 114,424,921 shares of its common stock issued and outstanding.

- Definition

The entire disclosure for equity.

+ References

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-Subparagraph (b)
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-Topic 946
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-Name Accounting Standards Codification
-Section 50
-Paragraph 6
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-Topic 815
-SubTopic 40
-Name Accounting Standards Codification
-Section 50
-Paragraph 6
-Subparagraph (a)
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-URI https://asc.fasb.org/1943274/2147480237/815-40-50-6

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-Topic 505
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.3-04)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147480008/505-10-S99-1

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-Name Accounting Standards Codification
-Section S99
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-Subparagraph (SX 210.4-08(e)(1))
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-Topic 505
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-Section 50
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-Subparagraph (g)
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-Topic 505
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-Subparagraph (a)
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-Publisher FASB
-URI https://asc.fasb.org/1943274/2147481112/505-10-50-18

+ Details

XML 24 R15.htm IDEA: XBRL DOCUMENT

INCOME (LOSS) PER COMMON SHARE

3 Months Ended

Sep. 30, 2024

Net income (loss) per share

INCOME (LOSS) PER COMMON SHARE

7. INCOME (LOSS) PER COMMON SHARE

A reconciliation of the components of basic and diluted net loss per common share for the three months ended September 30, 2024 is presented below:


	Three Months Ended September 30, 2024
	Net Loss			Weighted Average Shares		Per Share

Basic Earnings per Share:

Net loss attributable to common stock basic	$	(67,785	)		114,424,921	$	(0.00	)
Net loss attributable to common stock fully diluted	$	(67,785	)		171,199,610	$	(0.00	)

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.

XML 25 R16.htm IDEA: XBRL DOCUMENT

INCOME TAXES

3 Months Ended

Sep. 30, 2024

Income Tax Disclosure [Abstract]

INCOME TAXES

8. INCOME TAXES

Net operating loss carry forwards of approximately $1,776,303 at September 30, 2024 are available to offset future taxable income.

- Definition

The entire disclosure for income tax.

+ References

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-Topic 740
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 12
-Publisher FASB
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-Topic 740
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-Section 55
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-Topic 740
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-Section 50
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-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SAB Topic 6.I.5.Q1)
-Publisher FASB
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-Topic 946
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-Section 50
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-Topic 235
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(h)(2))
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-Section 50
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-Topic 740
-SubTopic 10
-Name Accounting Standards Codification
-Section 50
-Paragraph 17
-Subparagraph (b)
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-URI https://asc.fasb.org/1943274/2147482685/740-10-50-17

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-Topic 740
-SubTopic 10
-Name Accounting Standards Codification
-Section S99
-Paragraph 2
-Subparagraph (SAB Topic 11.C)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147479360/740-10-S99-2

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-Topic 740
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-Name Accounting Standards Codification
-Section 50
-Paragraph 2
-Subparagraph (a)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482603/740-30-50-2

+ Details

XML 26 R17.htm IDEA: XBRL DOCUMENT

RELATED PARTY TRANSACTIONS

3 Months Ended

Sep. 30, 2024

RELATED PARTY TRANSACTIONS

9. RELATED PARTY TRANSACTIONS

- Definition

The entire disclosure for related party transactions. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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-Topic 850
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-Section 50
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-Subparagraph (a)
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-Section 50
-Paragraph 1
-Subparagraph (b)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483326/850-10-50-1

+ Details

XML 27 R18.htm IDEA: XBRL DOCUMENT

CONVERTIBLE LOAN

3 Months Ended

Sep. 30, 2024

Convertible Loan

CONVERTIBLE LOAN

10. CONVERTIBLE LOAN

XML 28 R19.htm IDEA: XBRL DOCUMENT

SUBSEQUENT EVENTS

3 Months Ended

Sep. 30, 2024

Subsequent Events [Abstract]

SUBSEQUENT EVENTS

11. SUBSEQUENT EVENTS

XML 29 R20.htm IDEA: XBRL DOCUMENT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	3 Months Ended
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	Sep. 30, 2024
Accounting Policies [Abstract]
Basis of Presentation	*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	*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	*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 September 30, 2024, the Company cash totaled $73,602.
Oil and gas properties	*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	*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	*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	*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.
Revenue recognition	*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	*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* 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.

XML 30 R21.htm IDEA: XBRL DOCUMENT

REVENUES AND COST OF REVENUES (Tables)

3 Months Ended

Sep. 30, 2024

Revenue from Contract with Customer [Abstract]

Schedule of oil & gas revenue

Schedule of oil & gas revenue
	Oil						Natural Gas
Project	Production (BBLS)		Avg. Cost ($)		Avg. Sales Price ($)		Production (MCF)		Avg. Cost ($)		Avg. Sales Price ($)		Total Revenue ($)

Black Rock JV		75.69		65.90		63.52		-		-		-		4,808

Pushmataha		—		—		—		572		6.19		2.07		1,183

West Sheppard		—		—		—		—		—		—		—

Vitt Lease		—		—		—		—		—		—		—

XML 31 R22.htm IDEA: XBRL DOCUMENT

INCOME (LOSS) PER COMMON SHARE (Tables)

3 Months Ended

Sep. 30, 2024

Net income (loss) per share

Schedule of components of net loss per common share


	Three Months Ended September 30, 2024
	Net Loss			Weighted Average Shares		Per Share

Basic Earnings per Share:

Net loss attributable to common stock basic	$	(67,785	)		114,424,921	$	(0.00	)
Net loss attributable to common stock fully diluted	$	(67,785	)		171,199,610	$	(0.00	)

XML 32 R23.htm IDEA: XBRL DOCUMENT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details Narrative)	Sep. 30, 2024 USD ($)
Accounting Policies [Abstract]
Cash equivalents	$ 73,602

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GOING CONCERN (Details Narrative) - USD ($)	3 Months Ended		12 Months Ended
GOING CONCERN (Details Narrative) - USD ($)	Sep. 30, 2024	Sep. 30, 2023	Jun. 30, 2024
Going Concern
Net loss	$ 67,785	$ 111,835	$ 873,214
Accumulated deficit	1,776,303		1,708,518
Working capital deficit	$ 527,337		$ 460,878
Future need amount, description	for the 2025 fiscal year which started in July, we anticipate cash needs of approximately $300,000 for general corporate overhead and for operations on our existing lease properties.

- Definition

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

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+ Details

- Definition

Amount of accumulated undistributed earnings (deficit).

+ References + Details

XML 34 R25.htm IDEA: XBRL DOCUMENT

OIL AND GAS PROPERTIES (Details Narrative) - USD ($)	1 Months Ended			3 Months Ended		12 Months Ended
OIL AND GAS PROPERTIES (Details Narrative) - USD ($)	Nov. 30, 2021	Jul. 31, 2021	Feb. 28, 2021	Sep. 30, 2024	Sep. 30, 2023	Dec. 31, 2021	Aug. 31, 2021
Total revenue				$ 5,991	$ 22,677
Sheppard Pool Operating L L C [Member] \| West Sheppard Blackrock [Member]
Expenditures				0
Vitt Project [Member]
Investment in working interests		$ 50,000		108,250
Share of expense attributable to the joint venture				250
Total revenue				0
Working interest		72.50%
Investment in working interests		$ 25,000
West Sheppard Blackrock [Member] \| Option Agreement [Member]
Investment in working interests	$ 150,000
Working interest							50.00%
Pushmataha Blackrock [Member] \| Option Agreement [Member]
Investment in working interests						$ 252,526
Working interest						50.00%
Blackrock [Member]
Investment in working interests			$ 100,000
Share of expense attributable to the joint venture				5,334
Total revenue				4,808
Pushmataha Blackrock [Member]
Total revenue				1,242
Pushmataha Blackrock [Member] \| Oil and Gas Service [Member]
Share of expense attributable to the joint venture				$ 3,538

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REVENUES AND COST OF REVENUES (Details)	3 Months Ended
REVENUES AND COST OF REVENUES (Details)	Sep. 30, 2024 USD ($) $ / Mcf $ / bbl Mcf bbl	Sep. 30, 2023 USD ($)
Oil and Gas, Proved Reserve, Quantity [Line Items]
Total revenue \| $	$ 5,991	$ 22,677
Oil BBLS [Member] \| Black Rock JV [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| bbl	75.69
Average cost \| $ / bbl	65.90
Average price \| $ / bbl	63.52
Oil BBLS [Member] \| Pushmataha [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| bbl
Average cost \| $ / bbl
Average price \| $ / bbl
Oil BBLS [Member] \| West Sheppard Pool [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| bbl
Average cost \| $ / bbl
Average price \| $ / bbl
Oil BBLS [Member] \| Vitt Lease [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| bbl
Average cost \| $ / bbl
Average price \| $ / bbl
Natural Gas MCF [Member] \| Black Rock JV [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| Mcf
Average cost \| $ / Mcf
Average price \| $ / Mcf
Natural Gas MCF [Member] \| Pushmataha [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| Mcf	572
Average cost \| $ / Mcf	6.19
Average price \| $ / Mcf	2.07
Natural Gas MCF [Member] \| West Sheppard Pool [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| Mcf
Average cost \| $ / Mcf
Average price \| $ / Mcf
Natural Gas MCF [Member] \| Vitt Lease [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| Mcf
Average cost \| $ / Mcf
Average price \| $ / Mcf
Oil and Natural Gas Revenue [Member] \| Black Rock JV [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Total revenue \| $	$ 4,808
Oil and Natural Gas Revenue [Member] \| Pushmataha [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Total revenue \| $	1,183
Oil and Natural Gas Revenue [Member] \| West Sheppard Pool [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Total revenue \| $
Oil and Natural Gas Revenue [Member] \| Vitt Lease [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Total revenue \| $

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REVENUES AND COST OF REVENUES (Details Narrative) - USD ($)	3 Months Ended
	Sep. 30, 2024	Sep. 30, 2023
Revenue from Contract with Customer [Abstract]
Revenue	$ 5,991	$ 22,677
Cost of revenue	$ 9,717	$ 32,247

- Definition

The aggregate cost of goods produced and sold and services rendered during the reporting period.

+ References

+ Details

- Definition

Amount of revenue recognized from goods sold, services rendered, insurance premiums, or other activities that constitute an earning process. Includes, but is not limited to, investment and interest income before deduction of interest expense when recognized as a component of revenue, and sales and trading gain (loss).

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-Subparagraph (SX 210.5-03(1))
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147483621/220-10-S99-2

+ Details

XML 37 R28.htm IDEA: XBRL DOCUMENT

STOCKHOLDERS’ EQUITY (Details Narrative) - $ / shares		3 Months Ended
STOCKHOLDERS’ EQUITY (Details Narrative) - $ / shares	Oct. 01, 2024	Sep. 30, 2024	Jun. 30, 2024
Class of Stock [Line Items]
Preferred stock, shares authorized		50,000,000	50,000,000
Preferred stock, par value per share		$ 0.0001	$ 0.0001
Preferred stock, share issued		5,000,000	5,000,000
Preferred stock, share outstanding		5,000,000	5,000,000
Voting rights, description		Each share of Series A Preferred Stock has voting rights of ten votes per share, though is not entitled to receive dividends.
Conversion stock, description		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.
Common stock, shares authorized		750,000,000	750,000,000
Common stock, par value per share		$ 0.0001	$ 0.0001
Common stock, shares issued		114,424,921	114,424,921
Common stock, shares outstanding		114,424,921	114,424,921
Advisory Board Member Agreement [Member] \| Dr O Brien [Member] \| Restricted Stock [Member]
Class of Stock [Line Items]
Number of shares issued	200,000
Mr. Herzog [Member]
Class of Stock [Line Items]
Voting rights, description		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.

XML 38 R29.htm IDEA: XBRL DOCUMENT

NET INCOME PER COMMON SHARE (Details) - USD ($)	3 Months Ended
NET INCOME PER COMMON SHARE (Details) - USD ($)	Sep. 30, 2024	Sep. 30, 2023
Net income (loss) per share
Net loss attributable to common stock basic	$ (67,785)	$ (111,835)
Basic weighted average number of common shares outstanding	114,424,921	113,759,443
Basic loss per common share	$ (0.00)	$ (0.00)
Net loss attributable to common stock fully diluted	$ (67,785)
Diluted weighted average number of common shares outstanding	171,199,610	170,656,308
Diluted loss per common share	$ (0.00)	$ (0.00)

- Definition

The amount of net income (loss) for the period per each share of common stock or unit outstanding during the reporting period.

+ References

+ Details

- Definition

The amount of net income (loss) for the period available to each share of common stock or common unit outstanding during the reporting period and to each share or unit that would have been outstanding assuming the issuance of common shares or units for all dilutive potential common shares or units outstanding during the reporting period.

+ References

+ Details

- Definition

Amount, after deduction of tax, noncontrolling interests, dividends on preferred stock and participating securities; of income (loss) available to common shareholders.

+ References

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Topic 805
-SubTopic 60
-Name Accounting Standards Codification
-Section 65
-Paragraph 1
-Subparagraph (g)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147476176/805-60-65-1

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
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-Name Accounting Standards Codification
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
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-Name Accounting Standards Codification
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Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Topic 250
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-Name Accounting Standards Codification
-Section 50
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Reference 5: http://www.xbrl.org/2003/role/disclosureRef
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Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Topic 220
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-Section S99
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Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Topic 260
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Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Topic 260
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Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Topic 260
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-Name Accounting Standards Codification
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-URI https://asc.fasb.org/1943274/2147482689/260-10-45-11

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Topic 260
-SubTopic 10
-Name Accounting Standards Codification
-Section 45
-Paragraph 60B
-Subparagraph (c)
-Publisher FASB
-URI https://asc.fasb.org/1943274/2147482689/260-10-45-60B

+ Details

- Definition

Amount, after deduction of tax, noncontrolling interests, dividends on preferred stock and participating securities, and addition from assumption of issuance of common shares for dilutive potential common shares; of income (loss) available to common shareholders.

+ References + Details

XML 39 R30.htm IDEA: XBRL DOCUMENT

INCOME TAXES (Details Narrative)	Sep. 30, 2024 USD ($)
Income Tax Disclosure [Abstract]
Net operating loss carry forwards	$ 1,776,303

XML 40 R31.htm IDEA: XBRL DOCUMENT

RELATED PARTY TRANSACTIONS (Details Narrative) - USD ($)	Sep. 30, 2024	Jun. 30, 2024
Related Party Transactions [Abstract]
Accrued liabilities related party	$ 317,250	$ 276,750

XML 41 R32.htm IDEA: XBRL DOCUMENT

CONVERTIBLE LOAN (Details Narrative) - USD ($)	1 Months Ended	3 Months Ended
CONVERTIBLE LOAN (Details Narrative) - USD ($)	Nov. 30, 2021	Sep. 30, 2024	Jun. 30, 2024
Offsetting Assets [Line Items]
Interest payable, current		$ 53,371	$ 49,542
Convertible Note Agreement [Member]
Offsetting Assets [Line Items]
Debt amount	$ 231,000
Interest rate	10.00%
Repayments of debt	$ 3,500
Convertible notes payable		149,135
Interest payable, current		53,371
Net revenue received		$ 125,000

XML 42 R33.htm IDEA: XBRL DOCUMENT

SUBSEQUENT EVENTS (Details Narrative) - Consulting [Member]	Nov. 12, 2024 $ / shares shares
Stock issued for services \| shares	250,000
Share Price \| $ / shares	$ 0.04
Shmuel Naparstek [Member]
Stock issued for services \| shares	2,500,000
Share Price \| $ / shares	$ 0.04

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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: <table cellpadding="0" cellspacing="0" style="font: 11pt Arial, Helvetica, Sans-Serif; width: 100%; border-collapse: collapse"> <tr style="vertical-align: top"> <td style="width: 24px"> </td> <td style="width: 24px; text-align: justify">1)</td> <td style="text-align: justify">The Blackrock Joint Venture encompassing 15 oil and gas leases in Oklahoma;</td></tr> <tr style="vertical-align: top"> <td> </td> <td style="text-align: justify">2)</td> <td style="text-align: justify">A 72.5% Net Revenue Interest in the Vitt oil lease located in Neosho County, Kansas;</td></tr> <tr style="vertical-align: top"> <td> </td> <td style="text-align: justify">3)</td> <td style="text-align: justify">A 50% Joint Venture interest in West Sheppard Pool, a natural gas project in North East Oklahoma; and</td></tr> <tr style="vertical-align: top"> <td> </td> <td style="text-align: justify">4)</td> <td style="text-align: justify">A 50% Joint Venture interest in Pushmataha, a natural gas project in Southeast Oklahoma.</td></tr> </table> 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 September 30, 2024, the Company cash totaled $73,602. 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. 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. 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 September 30, 2024, the Company cash totaled $73,602. 73602 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. 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 $67,785 for the three months ended September 30, 2024 (year ended June 30, 2024 - $873,214) and an accumulated deficit of $1,776,303 as of September 30, 2024 (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 $527,337 as at September 30, 2024 (as of June 30, 2024 – deficit of $460,878) and for the 2025 fiscal year which started in July, we anticipate cash needs of approximately $300,000 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 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. -67785 -873214 -1776303 -1708518 527337 460878 for the 2025 fiscal year which started in July, we anticipate cash needs of approximately $300,000 for general corporate overhead and for operations on our existing lease properties. 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 three months ended September 30, 2024, lease operating expenses including taxes across the extended Joint Venture totaled $<span id="xdx_903_eus-gaap--ResultsOfOperationsExpenseFromOilAndGasProducingActivities_c20240701__20240930__us-gaap--BusinessAcquisitionAxis__custom--BlackrockMember_pp0p0" title="Share of expense attributable to the joint venture">5,334. Our share of revenues attributable to the Joint Venture totaled $4,808. 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. 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 $<span id="xdx_902_eus-gaap--BusinessCombinationConsiderationTransferred1_c20210701__20210731__srt--ScheduleOfEquityMethodInvestmentEquityMethodInvesteeNameAxis__custom--VittProjectMember_pp0p0" title="Investment in working interests">25,000 together with a commitment to make additional expenditures, initially of at least $<span id="xdx_90E_eus-gaap--BusinessCombinationAcquisitionRelatedCosts_c20210701__20210731__srt--ScheduleOfEquityMethodInvestmentEquityMethodInvesteeNameAxis__custom--VittProjectMember_pp0p0" title="Investment in working interests">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 September 30, 2024, aggregate additional expenditures beyond the purchase totaled $<span id="xdx_906_eus-gaap--BusinessCombinationAcquisitionRelatedCosts_c20240701__20240930__srt--ScheduleOfEquityMethodInvestmentEquityMethodInvesteeNameAxis__custom--VittProjectMember_pp0p0" title="Investment in working interests">108,250. During the three months ended September 30, 2024, the Company’s expenditures at the Vitt Lease totaled $<span id="xdx_90D_eus-gaap--ResultsOfOperationsExpenseFromOilAndGasProducingActivities_c20240701__20240930__srt--ScheduleOfEquityMethodInvestmentEquityMethodInvesteeNameAxis__custom--VittProjectMember_pp0p0" title="Share of expense attributable to the joint venture">250, and the Company received $Nil <span id="xdx_90F_eus-gaap--ResultsOfOperationsRevenueFromOilAndGasProducingActivities_c20240701__20240930__srt--ScheduleOfEquityMethodInvestmentEquityMethodInvesteeNameAxis__custom--VittProjectMember_pp0p0" style="display: none" title="Total revenue">0 in revenues from the project. West Sheppard Pool Field in North East Oklahoma In August 2021, the Company entered into an option agreement with Blackrock to acquire a <span id="xdx_90B_eus-gaap--EquityMethodInvestmentOwnershipPercentage_c20210831__srt--ScheduleOfEquityMethodInvestmentEquityMethodInvesteeNameAxis__custom--WestSheppardBlackrockMember__us-gaap--TransactionTypeAxis__custom--OptionAgreementMember_pdd" title="Working interest">50% joint venture interest in the West Sheppard Pool Field, a series of leases totaling 1,930 acres located in Okmulgee County, Oklahoma. In November 2021, the Company exercised its option and entered into a definitive joint venture and operating agreement with Blackrock at a cost of $<span id="xdx_90E_eus-gaap--BusinessCombinationAcquisitionRelatedCosts_c20211101__20211130__srt--ScheduleOfEquityMethodInvestmentEquityMethodInvesteeNameAxis__custom--WestSheppardBlackrockMember__us-gaap--TransactionTypeAxis__custom--OptionAgreementMember_pp0p0" title="Investment in working interests">150,000 in cash. 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. During the year ended June 30, 2024, gas sales continued to be suspended on the property due the failure of equipment owned by the gas pipeline company at its compressor station. In order to replace the failed equipment, the gas pipeline company is requiring additional gas throughput to justify the investment. As a result of this, in quarter ending September 30, 2024, the Company recorded no revenues from the project. During the second half of calendar 2023, our partner and operator, Blackrock Energy, LLC agreed to a farmout agreement of its working interests in West Sheppard Pool (with the exception of a 2% overriding royalty interest maintained by Blackrock). Blackrock’s interests were transferred to Sheppard Pool Operating, LLC (hereinafter referred to as “SPO”), the owner of the adjacent East Sheppard Pool leases. SPO also became the Operator of record on the project. This transaction does not change the Company’s working interests in the project. The Company and SPO had already previously entered into a gas gathering agreement in June 2023 in an effort to restore and ultimately improve gas flows into the gas transit pipeline system. SPO has completed some work to upgrade the West Sheppard Pool leases, though to date gas sales have not resumed. In the three months ended September 30, 2024, the Company recorded expenditures at West Sheppard Pool of $Nil <span id="xdx_90B_eus-gaap--LeaseholdImprovementsGross_c20240930__srt--CounterpartyNameAxis__custom--SheppardPoolOperatingLLCMember__srt--OwnershipAxis__custom--WestSheppardBlackrockMember_pp0p0" style="display: none" title="Expenditures">0. Pushmataha in South East Oklahoma In December 2021, the Company exercised its option and entered into definitive agreements with Blackrock to acquire a <span id="xdx_90C_eus-gaap--EquityMethodInvestmentOwnershipPercentage_iI_c20211231__srt--ScheduleOfEquityMethodInvestmentEquityMethodInvesteeNameAxis__custom--PushmatahaBlackrockMember__us-gaap--TransactionTypeAxis__custom--OptionAgreementMember_zv162ljwRsw6" title="Working interest">50% joint venture interest 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 $<span id="xdx_90D_eus-gaap--BusinessCombinationAcquisitionRelatedCosts_pp0p0_c20210101__20211231__srt--ScheduleOfEquityMethodInvestmentEquityMethodInvesteeNameAxis__custom--PushmatahaBlackrockMember__us-gaap--TransactionTypeAxis__custom--OptionAgreementMember_zSWxXVInfpN2" title="Investment in working interests">252,526 in cash. In the three months ended September 30, 2024, lease operating expenditures at Pushmataha were $<span id="xdx_901_eus-gaap--ResultsOfOperationsExpenseFromOilAndGasProducingActivities_c20240701__20240930__us-gaap--BusinessAcquisitionAxis__custom--PushmatahaBlackrockMember__srt--ProductOrServiceAxis__us-gaap--OilAndGasServiceMember_pp0p0" title="Share of expense attributable to the joint venture">3,538, and production revenues received were $1,242. 100000 5334 4808 0.725 25000 50000 108250 250 0 0.50 150000 0 0.50 252526 3538 1242 5. REVENUES AND COST OF REVENUES For the three months ended September 30, 2024, the Company had production revenue of $5,991 compared to revenue of $22,677 for the three months ended September 30, 2023. Refer to the table below of production and revenue for the period ended September 30, 2024. For the three months ended September 30, 2024 and September 30, 2023 our cost of revenue, consisting of lease operating expenses and production and excise taxes was $9,717 and $32,247 respectively. <table cellpadding="0" cellspacing="0" id="xdx_88F_esrt--ScheduleOfProductiveWellsTextBlock_z01huhUqXRa4" style="font: 11pt Arial, Helvetica, Sans-Serif; width: 100%; border-collapse: collapse" summary="xdx: Disclosure - REVENUES AND COST OF REVENUES (Details)"> <tr style="vertical-align: bottom; background-color: white"> <td>Schedule of oil & gas revenue</td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify"> </td> <td> </td> <td colspan="10" style="border-bottom: black 1pt solid; text-align: center">Oil</td> <td> </td> <td> </td> <td colspan="10" style="border-bottom: black 1pt solid; text-align: center">Natural Gas</td> <td> </td> <td> </td> <td colspan="2" style="text-align: center"> </td> <td> </td></tr> <tr style="vertical-align: bottom"> <td style="border-bottom: black 1pt solid; text-align: justify">Project</td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Production (BBLS)</td> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Avg. Cost ($)</td> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Avg. Sales Price ($)</td> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Production (MCF)</td> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Avg. Cost ($)</td> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Avg. Sales Price ($)</td> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Total Revenue ($)</td> <td> </td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify"> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td style="width: 23%; text-align: justify">Black Rock JV</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_983_ecustom--ProductionOilAndGas_pdp0_uBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_zUTBpnSkP0s7" style="width: 8%; text-align: right" title="Production">75.69</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_980_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_zmfA3akJhtLi" style="width: 8%; text-align: right" title="Average cost">65.90</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_985_esrt--AverageSalesPrices_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_zl3sbvw4LKtl" style="width: 8%; text-align: right" title="Average price">63.52</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_98B_ecustom--ProductionOilAndGas_uMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_z3MYRvOChbCl" style="width: 8%; text-align: right" title="Production">-</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_98C_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_zQSOqvczqBwj" style="width: 8%; text-align: right" title="Average cost">-</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_98B_esrt--AverageSalesPrices_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_zWntqRGPcGz2" style="width: 8%; text-align: right" title="Average price">-</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_98B_eus-gaap--ResultsOfOperationsRevenueFromOilAndGasProducingActivities_pp0p0_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilAndNaturalGasRevenueMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_zklz4Jts6GGc" style="width: 8%; text-align: right" title="Total revenue">4,808</td> <td style="width: 1%"> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td style="text-align: justify"> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td style="text-align: justify">Pushmataha</td> <td> </td> <td> </td> <td id="xdx_98F_ecustom--ProductionOilAndGas_uBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zv2mqWRfKgj" style="text-align: right" title="Production">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_984_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zN0boW56W3k1" style="text-align: right" title="Average cost">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_980_esrt--AverageSalesPrices_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zgz7EV1A4c23" style="text-align: right" title="Average price">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_98B_ecustom--ProductionOilAndGas_uMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zGGXwY5sSavh" style="text-align: right" title="Production">572</td> <td> </td> <td> </td> <td> </td> <td id="xdx_98C_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zgwfL1ZJ0zbb" style="text-align: right" title="Average cost">6.19</td> <td> </td> <td> </td> <td> </td> <td id="xdx_984_esrt--AverageSalesPrices_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zYvgb3f7WHz3" style="text-align: right" title="Average price">2.07</td> <td> </td> <td> </td> <td> </td> <td id="xdx_983_eus-gaap--ResultsOfOperationsRevenueFromOilAndGasProducingActivities_pp0p0_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilAndNaturalGasRevenueMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zXa2XrppN1U9" style="text-align: right" title="Total revenue">1,183</td> <td> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td style="text-align: justify"> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td style="text-align: justify">West Sheppard</td> <td> </td> <td> </td> <td id="xdx_98E_ecustom--ProductionOilAndGas_uBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_zHpU2RMHF875" style="text-align: right" title="Production">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_984_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_zbs11J71tmCl" style="text-align: right" title="Average cost">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_98E_esrt--AverageSalesPrices_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_zGXF1okmdB3b" style="text-align: right" title="Average price">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_980_ecustom--ProductionOilAndGas_uMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_zQdRH5RYLpeb" style="text-align: right" title="Production">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_986_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_z6xl7TNLWZp1" style="text-align: right" title="Average cost">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_98F_esrt--AverageSalesPrices_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_zdhPtwtiUdF6" style="text-align: right" title="Average price">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_987_eus-gaap--ResultsOfOperationsRevenueFromOilAndGasProducingActivities_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilAndNaturalGasRevenueMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_pp0p0" style="text-align: right" title="Total revenue">—</td> <td> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td style="text-align: justify"> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td style="text-align: justify">Vitt Lease</td> <td> </td> <td> </td> <td id="xdx_986_ecustom--ProductionOilAndGas_uBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_zjHOX0JgETG8" style="text-align: right" title="Production">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_98E_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_zbXfdcxNlpr8" style="text-align: right" title="Average cost">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_984_esrt--AverageSalesPrices_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_zRfWMCiDanNb" style="text-align: right" title="Average price">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_985_ecustom--ProductionOilAndGas_uMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_zZjHpjTjbbn6" style="text-align: right" title="Production">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_98B_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_za11a8i6cTFe" style="text-align: right" title="Average cost">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_984_esrt--AverageSalesPrices_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_zTvTIgdsQYla" style="text-align: right" title="Average price">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_982_eus-gaap--ResultsOfOperationsRevenueFromOilAndGasProducingActivities_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilAndNaturalGasRevenueMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_pp0p0" style="text-align: right" title="Total revenue">—</td> <td> </td></tr> </table> 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. 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. 5991 22677 9717 32247 <table cellpadding="0" cellspacing="0" id="xdx_88F_esrt--ScheduleOfProductiveWellsTextBlock_z01huhUqXRa4" style="font: 11pt Arial, Helvetica, Sans-Serif; width: 100%; border-collapse: collapse" summary="xdx: Disclosure - REVENUES AND COST OF REVENUES (Details)"> <tr style="vertical-align: bottom; background-color: white"> <td>Schedule of oil & gas revenue</td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify"> </td> <td> </td> <td colspan="10" style="border-bottom: black 1pt solid; text-align: center">Oil</td> <td> </td> <td> </td> <td colspan="10" style="border-bottom: black 1pt solid; text-align: center">Natural Gas</td> <td> </td> <td> </td> <td colspan="2" style="text-align: center"> </td> <td> </td></tr> <tr style="vertical-align: bottom"> <td style="border-bottom: black 1pt solid; text-align: justify">Project</td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Production (BBLS)</td> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Avg. Cost ($)</td> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Avg. Sales Price ($)</td> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Production (MCF)</td> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Avg. Cost ($)</td> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Avg. Sales Price ($)</td> <td> </td> <td> </td> <td colspan="2" style="border-bottom: black 1pt solid"> Total Revenue ($)</td> <td> </td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify"> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td> <td> </td> <td colspan="2" style="text-align: right"> </td> <td> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td style="width: 23%; text-align: justify">Black Rock JV</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_983_ecustom--ProductionOilAndGas_pdp0_uBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_zUTBpnSkP0s7" style="width: 8%; text-align: right" title="Production">75.69</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_980_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_zmfA3akJhtLi" style="width: 8%; text-align: right" title="Average cost">65.90</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_985_esrt--AverageSalesPrices_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_zl3sbvw4LKtl" style="width: 8%; text-align: right" title="Average price">63.52</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_98B_ecustom--ProductionOilAndGas_uMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_z3MYRvOChbCl" style="width: 8%; text-align: right" title="Production">-</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_98C_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_zQSOqvczqBwj" style="width: 8%; text-align: right" title="Average cost">-</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_98B_esrt--AverageSalesPrices_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_zWntqRGPcGz2" style="width: 8%; text-align: right" title="Average price">-</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td id="xdx_98B_eus-gaap--ResultsOfOperationsRevenueFromOilAndGasProducingActivities_pp0p0_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilAndNaturalGasRevenueMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--BlackRockJVMember_zklz4Jts6GGc" style="width: 8%; text-align: right" title="Total revenue">4,808</td> <td style="width: 1%"> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td style="text-align: justify"> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td style="text-align: justify">Pushmataha</td> <td> </td> <td> </td> <td id="xdx_98F_ecustom--ProductionOilAndGas_uBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zv2mqWRfKgj" style="text-align: right" title="Production">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_984_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zN0boW56W3k1" style="text-align: right" title="Average cost">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_980_esrt--AverageSalesPrices_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zgz7EV1A4c23" style="text-align: right" title="Average price">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_98B_ecustom--ProductionOilAndGas_uMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zGGXwY5sSavh" style="text-align: right" title="Production">572</td> <td> </td> <td> </td> <td> </td> <td id="xdx_98C_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zgwfL1ZJ0zbb" style="text-align: right" title="Average cost">6.19</td> <td> </td> <td> </td> <td> </td> <td id="xdx_984_esrt--AverageSalesPrices_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zYvgb3f7WHz3" style="text-align: right" title="Average price">2.07</td> <td> </td> <td> </td> <td> </td> <td id="xdx_983_eus-gaap--ResultsOfOperationsRevenueFromOilAndGasProducingActivities_pp0p0_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilAndNaturalGasRevenueMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--PushmatahaMember_zXa2XrppN1U9" style="text-align: right" title="Total revenue">1,183</td> <td> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td style="text-align: justify"> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td style="text-align: justify">West Sheppard</td> <td> </td> <td> </td> <td id="xdx_98E_ecustom--ProductionOilAndGas_uBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_zHpU2RMHF875" style="text-align: right" title="Production">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_984_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_zbs11J71tmCl" style="text-align: right" title="Average cost">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_98E_esrt--AverageSalesPrices_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_zGXF1okmdB3b" style="text-align: right" title="Average price">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_980_ecustom--ProductionOilAndGas_uMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_zQdRH5RYLpeb" style="text-align: right" title="Production">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_986_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_z6xl7TNLWZp1" style="text-align: right" title="Average cost">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_98F_esrt--AverageSalesPrices_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_zdhPtwtiUdF6" style="text-align: right" title="Average price">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_987_eus-gaap--ResultsOfOperationsRevenueFromOilAndGasProducingActivities_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilAndNaturalGasRevenueMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--WestSheppardPoolMember_pp0p0" style="text-align: right" title="Total revenue">—</td> <td> </td></tr> <tr style="vertical-align: bottom; background-color: white"> <td style="text-align: justify"> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td> <td> </td> <td> </td> <td style="text-align: right"> </td> <td> </td></tr> <tr style="vertical-align: bottom; background-color: #CCEEFF"> <td style="text-align: justify">Vitt Lease</td> <td> </td> <td> </td> <td id="xdx_986_ecustom--ProductionOilAndGas_uBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_zjHOX0JgETG8" style="text-align: right" title="Production">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_98E_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_zbXfdcxNlpr8" style="text-align: right" title="Average cost">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_984_esrt--AverageSalesPrices_uUSDPBarrels_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilBBLSMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_zRfWMCiDanNb" style="text-align: right" title="Average price">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_985_ecustom--ProductionOilAndGas_uMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_zZjHpjTjbbn6" style="text-align: right" title="Production">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_98B_esrt--ConsolidatedOilAndGasProductionCostsPerUnitOfProduction_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_za11a8i6cTFe" style="text-align: right" title="Average cost">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_984_esrt--AverageSalesPrices_uUSDPMCF_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--NaturalGasMCFMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_zTvTIgdsQYla" style="text-align: right" title="Average price">—</td> <td> </td> <td> </td> <td> </td> <td id="xdx_982_eus-gaap--ResultsOfOperationsRevenueFromOilAndGasProducingActivities_c20240701__20240930__srt--ReserveQuantitiesByTypeOfReserveAxis__custom--OilAndNaturalGasRevenueMember__us-gaap--CapitalizedCostsOfUnprovedPropertiesExcludedFromAmortizationByPropertyOrProjectAxis__custom--VittLeaseMember_pp0p0" style="text-align: right" title="Total revenue">—</td> <td> </td></tr> </table> 75.69 65.90 63.52 4808 572 6.19 2.07 1183 6. 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 September 30, 2024, 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 September 30, 2024, the Company had 114,424,921 shares of its common stock issued and outstanding. On October 1, 2023, the Company established an Advisory Board to include seasoned professionals and industry experts to assist in the development of the Company. On October 1, 2023, the Company entered into an Advisory Board Member Agreement with Dr. John N. O’Brien pursuant to which Dr. O’Brien was appointed by the Company as Senior Advisory Board Member to its Board of Advisors. In consideration of Dr. O’Brien’s appointment to the Company’s Board of Advisors, the Company agreed to issue Dr. O’Brien an aggregate of <span id="xdx_90B_eus-gaap--StockIssuedDuringPeriodSharesNewIssues_c20240928__20241001__us-gaap--TypeOfArrangementAxis__custom--AdvisoryBoardMemberAgreementMember__srt--CounterpartyNameAxis__custom--DrOBrienMember__us-gaap--StatementClassOfStockAxis__us-gaap--RestrictedStockMember_zlm6NSFxmMZa" title="Number of shares issued">200,000 restricted shares of its common stock (the “Shares”), subject to a vesting schedule. No Shares have been issued to Dr. O’Brien as of September 30, 2024. 50000000 0.0001 5000000 5000000 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. 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. 750000000 0.0001 114424921 114424921 200000 7. INCOME (LOSS) PER COMMON SHARE A reconciliation of the components of basic and diluted net loss per common share for the three months ended September 30, 2024 is presented below: <table cellpadding="0" cellspacing="0" id="xdx_88E_eus-gaap--ScheduleOfEarningsPerShareBasicAndDilutedTableTextBlock_zQk763n8gqA3" style="font: 11pt Arial, Helvetica, Sans-Serif; border-collapse: collapse; width: 100%" summary="xdx: Disclosure - NET INCOME PER COMMON SHARE (Details)"> <tr style="vertical-align: bottom"> <td>Schedule of components of net loss per common share</td><td> </td> <td colspan="2" style="text-align: center"> </td><td> </td><td> </td> <td colspan="2" style="text-align: center"> </td><td> </td><td> </td> <td colspan="2" style="text-align: center"> </td><td> </td></tr> <tr style="vertical-align: bottom"> <td style="text-align: center"> </td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td> <td colspan="10" style="border-bottom: Black 1pt solid; font: bold 8pt Times New Roman, Times, Serif; text-align: center">Three Months Ended September 30, 2024</td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom"> <td style="text-align: center"> </td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td> <td colspan="2" style="border-bottom: Black 1pt solid; font: bold 8pt Times New Roman, Times, Serif; text-align: center">Net Loss</td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td> <td colspan="2" style="border-bottom: Black 1pt solid; font: bold 8pt Times New Roman, Times, Serif; text-align: center">Weighted Average Shares</td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td> <td colspan="2" style="border-bottom: Black 1pt solid; font: bold 8pt Times New Roman, Times, Serif; text-align: center">Per Share</td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom"> <td style="text-align: center"> </td><td> </td> <td colspan="2" style="text-align: center"> </td><td> </td><td> </td> <td colspan="2" style="text-align: center"> </td><td> </td><td> </td> <td colspan="2" style="text-align: center"> </td><td> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="font: 10pt Times New Roman, Times, Serif; width: 55%; text-align: justify">Basic Earnings per Share:</td><td style="width: 1%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right"> </td><td style="width: 1%; text-align: left"> </td><td style="width: 1%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right"> </td><td style="width: 1%; text-align: left"> </td><td style="width: 1%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right"> </td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="font: 10pt Times New Roman, Times, Serif; text-align: justify">Net loss attributable to common stock basic</td><td style="font: 10pt Times New Roman, Times, Serif"> </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: left">$</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: right">(67,785</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: left">)</td><td style="font: 10pt Times New Roman, Times, Serif"> </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: left"> </td><td style="font: 10pt Times New Roman, Times, Serif; text-align: right">114,424,921</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: left"> </td><td style="font: 10pt Times New Roman, Times, Serif"> </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: left">$</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: right">(0.00</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: left">)</td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="font: 10pt Times New Roman, Times, Serif; text-align: justify">Net loss attributable to common stock fully diluted</td><td style="font: 10pt Times New Roman, Times, Serif"> </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: left">$</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: right">(67,785</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: left">)</td><td style="font: 10pt Times New Roman, Times, Serif"> </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: left"> </td><td style="font: 10pt Times New Roman, Times, Serif; text-align: right">171,199,610</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: left"> </td><td style="font: 10pt Times New Roman, Times, Serif"> </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: left">$</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: right">(0.00</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: left">)</td></tr> </table> 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. 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. <table cellpadding="0" cellspacing="0" id="xdx_88E_eus-gaap--ScheduleOfEarningsPerShareBasicAndDilutedTableTextBlock_zQk763n8gqA3" style="font: 11pt Arial, Helvetica, Sans-Serif; border-collapse: collapse; width: 100%" summary="xdx: Disclosure - NET INCOME PER COMMON SHARE (Details)"> <tr style="vertical-align: bottom"> <td>Schedule of components of net loss per common share</td><td> </td> <td colspan="2" style="text-align: center"> </td><td> </td><td> </td> <td colspan="2" style="text-align: center"> </td><td> </td><td> </td> <td colspan="2" style="text-align: center"> </td><td> </td></tr> <tr style="vertical-align: bottom"> <td style="text-align: center"> </td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td> <td colspan="10" style="border-bottom: Black 1pt solid; font: bold 8pt Times New Roman, Times, Serif; text-align: center">Three Months Ended September 30, 2024</td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom"> <td style="text-align: center"> </td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td> <td colspan="2" style="border-bottom: Black 1pt solid; font: bold 8pt Times New Roman, Times, Serif; text-align: center">Net Loss</td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td> <td colspan="2" style="border-bottom: Black 1pt solid; font: bold 8pt Times New Roman, Times, Serif; text-align: center">Weighted Average Shares</td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td> <td colspan="2" style="border-bottom: Black 1pt solid; font: bold 8pt Times New Roman, Times, Serif; text-align: center">Per Share</td><td style="font: bold 8pt Times New Roman, Times, Serif; padding-bottom: 1pt"> </td></tr> <tr style="vertical-align: bottom"> <td style="text-align: center"> </td><td> </td> <td colspan="2" style="text-align: center"> </td><td> </td><td> </td> <td colspan="2" style="text-align: center"> </td><td> </td><td> </td> <td colspan="2" style="text-align: center"> </td><td> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="font: 10pt Times New Roman, Times, Serif; width: 55%; text-align: justify">Basic Earnings per Share:</td><td style="width: 1%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right"> </td><td style="width: 1%; text-align: left"> </td><td style="width: 1%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right"> </td><td style="width: 1%; text-align: left"> </td><td style="width: 1%"> </td> <td style="width: 1%; text-align: left"> </td><td style="width: 12%; text-align: right"> </td><td style="width: 1%; text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="text-align: justify"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td><td> </td> <td style="text-align: left"> </td><td style="text-align: right"> </td><td style="text-align: left"> </td></tr> <tr style="vertical-align: bottom; background-color: rgb(204,238,255)"> <td style="font: 10pt Times New Roman, Times, Serif; text-align: justify">Net loss attributable to common stock basic</td><td style="font: 10pt Times New Roman, Times, Serif"> </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: left">$</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: right">(67,785</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: left">)</td><td style="font: 10pt Times New Roman, Times, Serif"> </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: left"> </td><td style="font: 10pt Times New Roman, Times, Serif; text-align: right">114,424,921</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: left"> </td><td style="font: 10pt Times New Roman, Times, Serif"> </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: left">$</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: right">(0.00</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: left">)</td></tr> <tr style="vertical-align: bottom; background-color: White"> <td style="font: 10pt Times New Roman, Times, Serif; text-align: justify">Net loss attributable to common stock fully diluted</td><td style="font: 10pt Times New Roman, Times, Serif"> </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: left">$</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: right">(67,785</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: left">)</td><td style="font: 10pt Times New Roman, Times, Serif"> </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: left"> </td><td style="font: 10pt Times New Roman, Times, Serif; text-align: right">171,199,610</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: left"> </td><td style="font: 10pt Times New Roman, Times, Serif"> </td> <td style="font: 10pt Times New Roman, Times, Serif; text-align: left">$</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: right">(0.00</td><td style="font: 10pt Times New Roman, Times, Serif; text-align: left">)</td></tr> </table> -67785 114424921 -0.00 -67785 171199610 -0.00 8. INCOME TAXES Net operating loss carry forwards of approximately $1,776,303 at September 30, 2024 are available to offset future taxable income. 1776303 9. 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. As of September 30, 2024, the Company has accrued $317,250 as accrued liabilities – related party. 317250 10. 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 September 30, 2024, the Company had an outstanding balance of $149,135 and accrued interest of $53,371 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. In the quarter ended September 30, 2023, the Company, in agreement with the Investor, temporarily suspended monthly repayments. The loan continued to accrue interest during this period. 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. 231000 0.10 3500 149135 53371 125000 11. SUBSEQUENT EVENTS On November 12, 2024, the board of directors approved the issuance of 250,000 shares of common stock at $0.04 per share in connection with consulting services for the Company’s filings preparation, compliance matters and business activities. Additionally, in connection with ongoing services, the Company issued <span id="xdx_90A_eus-gaap--StockIssuedDuringPeriodSharesIssuedForServices_c20241101__20241112__srt--ProductOrServiceAxis__custom--ConsultingMember__srt--CounterpartyNameAxis__custom--ShmuelNaparstekMember_pdd" title="Stock issued for services">2,500,000 at $0.04 per share to Shmuel Naparstek, who has been a corporate consultant to the Company since 2021 and took up a position to join the Board of Directors as of July 31, 2024. Outside of this, 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. 250000 0.04 2500000 0.04 false false false false

REVENUES AND COST OF REVENUES (Details)	3 Months Ended
REVENUES AND COST OF REVENUES (Details)	Sep. 30, 2024 USD ($) $ / Mcf $ / bbl Mcf bbl	Sep. 30, 2023 USD ($)
Oil and Gas, Proved Reserve, Quantity [Line Items]
Total revenue \| $	$ 5,991	$ 22,677
Oil BBLS [Member] \| Black Rock JV [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| bbl	75.69
Average cost \| $ / bbl	65.90
Average price \| $ / bbl	63.52
Oil BBLS [Member] \| Pushmataha [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| bbl
Average cost \| $ / bbl
Average price \| $ / bbl
Oil BBLS [Member] \| West Sheppard Pool [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| bbl
Average cost \| $ / bbl
Average price \| $ / bbl
Oil BBLS [Member] \| Vitt Lease [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| bbl
Average cost \| $ / bbl
Average price \| $ / bbl
Natural Gas MCF [Member] \| Black Rock JV [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| Mcf
Average cost \| $ / Mcf
Average price \| $ / Mcf
Natural Gas MCF [Member] \| Pushmataha [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| Mcf	572
Average cost \| $ / Mcf	6.19
Average price \| $ / Mcf	2.07
Natural Gas MCF [Member] \| West Sheppard Pool [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| Mcf
Average cost \| $ / Mcf
Average price \| $ / Mcf
Natural Gas MCF [Member] \| Vitt Lease [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Production \| Mcf
Average cost \| $ / Mcf
Average price \| $ / Mcf
Oil and Natural Gas Revenue [Member] \| Black Rock JV [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Total revenue \| $	$ 4,808
Oil and Natural Gas Revenue [Member] \| Pushmataha [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Total revenue \| $	1,183
Oil and Natural Gas Revenue [Member] \| West Sheppard Pool [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Total revenue \| $
Oil and Natural Gas Revenue [Member] \| Vitt Lease [Member]
Oil and Gas, Proved Reserve, Quantity [Line Items]
Total revenue \| $