Quarterly Report (10-q)

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 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 MARCH 31, 2023

 

☐

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 or Other Jurisdiction of Incorporation or Organization)		(I.R.S. Employer Identification No.)

 

16501 Ventura Blvd., Suite 400, Encino, CA		91436
(Address of Principal Executive Offices)		(Zip Code)

 

[phone]

(Registrant’s Telephone Number, Including Area Code)

 

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	None	None

 

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 ☒

 

As of May 12, 2023, there were 113,432,500 shares of the registrant’s common stock, $0.0001 par value per share, issued and outstanding.

 

 

 

Okmin Resources Inc.

 

 

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	18
Item 4.	Controls and Procedures	18
	PART II – OTHER INFORMATION
Item 1.	Legal Proceedings	20
Item 1A.	Risk Factors	20
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	20
Item 3.	Defaults Upon Senior Securities	20
Item 4.	Mine Safety Disclosures	20
Item 5.	Other Information	20
Item 6.	Exhibits	21

 

SIGNATURES

22

 

 

 

PART 1 – FINANCIAL INFORMATION

 

Item 1. Financial Statements.

 

OKMIN RESOURCES INC AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

  

		March 31				June 30
		2023				2022
			(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents		$	292,853			$	214,307
Production revenue receivable			—				29,430
Prepaid expenses			96				—
Total current assets			307,838				243,737
Oil and gas properties, net			543,961				528,622
Black Rock Joint Venture			142,401				127,455
Other assets and restricted cash			1,480				96
Total noncurrent assets			687,842				656,173
TOTAL ASSETS		$	995,680			$	899,910
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable		$	1,271			$	1,306
Accrued liabilities			117,250				54,000
Total current liabilities			118,521				55,305
Long term liabilities:
Accrued interest payable			28,442				13,385
Note payable			181,635				219,260
Total liabilities			328,598				287,951
Stockholders’ Equity:
Preferred Stock, $0.0001 par value, 50,000,000 shares authorized, 5,000,000 and 0 shares issued and outstanding at March 31, 2023 and June 30,2022			500				500
Common stock, $0.0001 par value, 750,000,000 shares authorized, 113,432,500 and 100,430,000, respectively, issued and outstanding at March 31, 2023 and June 30, 2022			11,343				10,043
Additional paid-in capital			1,393,007				907,707
Accumulated deficit			(737,768	)			(306,290	)
Total stockholders’ equity			667,082				611,960
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY		$	995,680			$	899,911

  

See accompanying notes to the unaudited consolidated financial statements.

 

  

1

 

OKMIN RESOURCES INC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

 

		Three Months				Three Months				Nine Months				Nine Months
		Ended				Ended				Ended				Ended
		March 31, 2023				March 31, 2022				March 31, 2023				March 31, 2022
Revenue
Oil and gas sales		$	30,228			$	29,497			$	98,466			$	51,421
Cost of revenue			100,019				25,906				223,517				27,481
Gross profit			(69,791	)			3,591				(125,051	)			23,940
Operating expenses:
General and administrative expense			68,830				92,991				306,068				173,672
Depreciation, depletion & amortization			1,220				—				2,732				—
Total operating expenses			70,050				92,991				308,800				173,672
Loss from operations			(139,841	)			(89,400	)			(433,851	)			(149,732	)
Other Income
Interest Income			1,123				—				2,373				—
Loss before taxes			(138,718	)			(89,400	)			(431,478	)			(149,732	)
Provision for income taxes			—				—				—				—
Net loss		$	(138,718	)		$	(89,400	)		$	(431,478	)		$	(149,732	)
Net income (loss) per share
Basic		$	(0.00	)		$	(0.00	)		$	(0.00	)		$	(0.00	)
Diluted		$	(0.00	)		$	(0.00	)		$	(0.00	)		$	(0.00	)
Weighted average number of shares outstanding
Basic			113,129,722				95,164,222				107,753,628				92,301,541
Diluted			170,197,189				152,864,222				164,809,228				129,414,190

 

   

See accompanying notes to the unaudited consolidated financial statements.

 

  

2

 

OKMIN RESOURCES INC AND SUBSIDIARIES

STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY

For the Three and Nine Months Ended March 31, 2023 and 2022

(Unaudited)

 

																		Additional								Stockholders'
		Preferred Stock								Common Stock								Paid-In				Accumulated				Equity/
		Shares				Amount				Shares				Amount				Capital				Deficit				(Deficit)
Balance, June 30, 2021			—			$	—				82,280,000			$	8,228			$	451,272			$	(71,921	)		$	387,579
Shares issued for cash			—				—				11,540,000				1,154				287,346								288,500
Shares issued for services			5,000,000				500				1,360,000				136				38,364				—				39,000
Shares used for financing (Note 9)											1,250,000				125				31,125				—				31,250
Net loss			—				—				—				—				—				(149,732	)			(149,732	)
Balance March 31, 2022			5,000,000				500				96,430,000				9,643				808,107				(221,653	)			596,597
Shares issued for cash			—				—				4,000,000				400				99,600				—				100,000
Net loss			—				—				—				—				—				(84,637	)			(84,637	)
Balance June 30, 2022			5,000,000				500				100,430,000				10,043				907,707				(306,290	)			611,960
Shares issued for cash			—				—				10,037,500				1,004				400,496				—				401,500
Shares issued for services			—				—				2,965,000				297				84,803				—				85,100
Net loss			—				—				—				—				—				(431,478	)			(431,478	)
Balance March 31, 2023			5,000,000			$	500				113,432,500			$	11,344			$	1,393,006			$	(737,768	)		$	667,082

 

See accompanying notes to the unaudited consolidated financial statements 

  

 

3

 

OKMIN RESOURCES INC AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

 

		Nine Months				Nine Months
		Ended				Ended
		March 31, 2023				March 31, 2022
Cash Flows From Operating Activities
Net loss		$	(431,478	)		$	(149,732	)
Adjustments to reconcile net loss to net cash from operations:
Accrued Product Sale (O&G)			(1,480	)			(1,560	)
Prepaid Deposit			—				25,000
Accrued Interest Payable			15,057				—
Production revenue receivable			14,542				(9,597	)
Accounts payable and accrued liabilities			63,216				30,191
Net cash from operating activities			(340,143	)			(105,698	)
Cash Flows From Investing Activities
Investment in Oil & Gas properties			(30,285	)			(524,213	)
Net cash from investing activities			(30,285	)			(524,213	)
Cash Flows From Financing Activities
Note Payable			(37,625	)			231,000
Additional Paid in Capital			485,300				356,835
Common and Preferred Stock Issued			1,300				1,915
Net cash from financing activities			448,975				589,750
Net change in cash			78,547				(40,161	)
Cash - beginning of period			214,307				275,572
Cash - end of period		$	292,854			$	235,411

 

 

See accompanying notes to the unaudited consolidated financial statements.

 

4

 

OKMIN RESOURCES INC AND SUBSIDIARIES

NOTES TO THE CONDENSED FINANCIAL STATEMENTS

As of March 31, 2023

(Unaudited)

  

 

1. ORGANIZATION AND BUSINESS

 

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.

 

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 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
	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.

 

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 accompanying condensed unaudited financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America and the rules and regulations of the Securities and Exchange Commission (“SEC”) for interim financial information. Accordingly, they do not include all the information necessary for a comprehensive presentation of financial position and results of operations.

 

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. The results for the interim period are not necessarily indicative of the results to be expected for the year.

  

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.

  

 

 

5

 

OKMIN RESOURCES INC AND SUBSIDIARIES

NOTES TO THE CONDENSED FINANCIAL STATEMENTS

As of March 31, 2023

(Unaudited)

 

 

Cash and cash Equivalents

 

The Company considers all highly liquid temporary cash investments with an original maturity of three months or less to be cash equivalents. At March 31, 2023 and June 30, 2022, the Company cash equivalents totaled $292,853 and $214,307 respectively.

 

Revenue recognition

 

The Company recognizes oil and gas revenues when production is sold at a fixed or determinable price, persuasive evidence of an arrangement exists, delivery has occurred and title has transferred, and collectability is reasonably assured.

 

Oil and gas properties

 

The Company uses the full cost method of accounting for exploration and development activities as defined by the 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.

 

 

 

6

OKMIN RESOURCES INC AND SUBSIDIARIES

NOTES TO THE CONDENSED FINANCIAL STATEMENTS

As of March 31, 2023

(Unaudited)

 

3. GOING CONCERN

 

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 $431,478 for the nine months ended March 31, 2023 and an accumulated deficit of $737,768 as of March 31, 2023. These factors, among others, raise doubt about the Company’s ability to continue as a going concern.

 

The Company had working capital of $189,317 as at March 31, 2023 and management believes that the Company will have sufficient working capital for the remaining last quarter of the 2023 fiscal year. For the 2024 fiscal year starting in July, the Company anticipates cash needs of a minimum of $600,000, of which approximately $300,000 is for general corporate overhead and $300,000 for continued work on existing properties. The Company anticipates receiving limited revenue from oil and gas sales and intends to obtain the remaining capital through private sales of securities.

 

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.

 

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 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, Okmin’s Joint Venture partner 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 1500 acres. In the nine months ended March 31, 2023, equipment and capital expenditures were $15,761 and lease operating expenses across the now extended Joint Venture totaled $117,021. Our share of revenues attributable to the Joint Venture totaled $37,912.

 

 

 

7

OKMIN RESOURCES INC AND SUBSIDIARIES

NOTES TO THE CONDENSED FINANCIAL STATEMENTS

As of March 31, 2023

(Unaudited)

 

Pursuant to the 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 our last fiscal year end on June 30, 2022, additional expenditures beyond the purchase totaled $89,878. During the nine months ended March 31, 2023, the Company’s commitments and expenditures at the Vitt totaled $11,500. For the nine months ended March 31, 2023 the Company received $5,209 in revenues from the project compared to revenues for the nine months ending March 31, 2022 of $1,863.

 

 

8

OKMIN RESOURCES INC AND SUBSIDIARIES

NOTES TO THE CONDENSED FINANCIAL STATEMENTS

As of March 31, 2023

(Unaudited)

 

 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 and made payments approximating an additional $21,000 in the fiscal year ended June 30, 2022 on project expenses and equipment purchases. In the nine months ended March 31, 2023, the Company’s commitments and expenditures at West Sheppard Pool were $19,542. For the nine months ended March 31, 2023 the Company received $1,948 in revenues from the project.

 

During the quarter ended March 31, 2023, 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.

 

Prior to the compressor outage, only 6 of the 24 wells on the property were selling into the pipeline. 4 additional wells were connected in late 2022, so in total the operator has now connected 10 of the 24 wells at West Sheppard Pool, which will be ready to sell gas upon the resumption of the necessary throughput via the pipeline. Additionally further trenching work was conducted to lay flow lines with associated valve requirements.

 

The property operator was preparing to conduct the necessary 72-hour flow test which would include production from additional wells to meet the pipeline owner’s requirements to reactivate the operation of the compressor station so that gas sales may resume, however, in view of more recently depressed natural gas prices and ongoing discussions with the adjacent lease holder exploring ways to achieve an optimal result; the operator has deferred proceeding at this stage.

 

The 24 existing wells on the leases range from 850 feet to 1950 feet in depth with gas production from several zones as their main objective.

 

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 and made payments of an additional $22,900 during the fiscal year ended June 30, 2022 on project expenses and equipment purchases.

 

In the nine months ended March 31, 2023, the Company’s capital expenditures on the project were $21,256 and lease operating expenses were approximately $57,310. For the nine months ended March 31, 2023 the Company recorded $53,397 in revenues from the project.

 

 

 

9

OKMIN RESOURCES INC AND SUBSIDIARIES

NOTES TO THE CONDENSED FINANCIAL STATEMENTS

As of March 31, 2023

(Unaudited)

 

For the nine months ended March 31, 2023, the Company had production revenues of $98,466. Refer to the table below of production and revenue through March 31, 2023. For the nine months ended March 31, 2023, our cost of revenue, consisting of lease operating expenses and production and excise taxes was $223,517, reflecting the fact that production costs are expected to be higher during the reworking phases of the projects as these are older leases that require rehabilitation and ongoing reworks to re-establish production activity.

 

The Company’s work program will require further additional lease operating expenditures that are likely to exceed production revenues for the foreseeable future, as it seeks to improve infrastructure on the leases and optimize the production potential of the existing oil and gas wells on site.

 

		Oil												Natural Gas
		Production				Avg. Cost				Avg. Sales Price				Production				Avg. Cost				Avg. Sales Price				Total Revenue
Project		(BBLS)				($)				($)				(MCF)				($)				($)				($)
Black Rock JV			507				219				72.62				2,736				4				1.46				37,912
Pushmataha			—				—				—				11,798				5				4.64				53,397
West Sheppard			—				—				—				572				34				2.70				1,948
Vitt Lease			56.6				203				92.03				—				—				—				5,209

 

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.

 

5. 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 of March 31, 2023, 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. The Series A Preferred Stock upon liquidation, winding-up or dissolution of the Corporation, ranks on a parity, in all respects, with all the Common Stock.

 

Common stock

 

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

 

As of March 31, 2023, the Company had 113,432,500 shares of its common stock issued and outstanding.

 

During the period ended March 31, 2023, the Company completed the private placement of 10,037,500 equity units at a price of $0.04 per unit. Each unit consists of one common share and 0.5 of a warrant. Each full warrant is exercisable to buy one additional share of common stock at a price of $0.05 until December 2024. A total of 10,037,500 common shares and 5,018,750 were issued in this placement for gross proceeds of $401,500. These equity units were issued pursuant to an exemption from registration under Section 4(a)(2) of the Securities Act of 1933 (the “Securities Act”) and Regulation D promulgated thereunder.

 

 

10

OKMIN RESOURCES INC AND SUBSIDIARIES

NOTES TO THE CONDENSED FINANCIAL STATEMENTS

As of March 31, 2023

(Unaudited)

 

In the Company’s efforts to conserve limited liquidity, the Company issued the following shares of common stock during the nine months ending March 31, 2023 in lieu of cash for services:

 

On September 30, 2022, the board of directors approved the issuance of an aggregate of 65,000 shares of common stock in lieu of cash payments of $2,600 in consideration of: accounting, secretarial and public relations related services.

 

On September 30, 2022, the board of directors approved the issuance of 250,000 shares of common stock in connection with a consulting services agreement for services in connection with the Company’s filing preparation, compliance matters and business activities.

 

On December 29, 2022, the board of directors approved the issuance of 2,400,000 shares of common stock in connection with ongoing services of a corporate consultant covering a twelve-month period. 

 

On February 11, 2023, the board of directors approved the issuance of 250,000 shares of common stock in connection with the signing of an ongoing services agreement with Sierra Land Resources, LLC, in connection with Land and Resource Development work. 

 

6. NET INCOME PER COMMON SHARE

 

A reconciliation of the components of basic and diluted net income per common share for the three and nine months ended March 31, 2023 is presented below:

 

		Three Months Ended March 31, 2023
		Net Loss				Weighted Average Shares				Per Share
Basic Earnings per Share:
Net loss attributable to common stock basic		$	(138,718	)			113,129,722			$	(0.00	)
Net loss attributable to common stock fully diluted		$	(138,718	)			170,197,189			$	(0.00	)
		Nine Months Ended March 31, 2023
		Net Loss				Weighted Average Shares				Per Share
Basic Earnings per Share:
Net loss attributable to common stock basic		$	(431,478	)			107,753,628			$	(0.00	)
Net loss attributable to common stock fully diluted		$	(431,478	)			164,809,228			$	(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.

 

7. INCOME TAXES

 

Net operating loss carry forwards of approximately $737,768 at March 31, 2023 are available to offset future taxable income. This results in a net deferred tax asset, assuming an effective tax rate of 21% of approximately $154,931 at March 31, 2023.

 

 

 

11

OKMIN RESOURCES INC AND SUBSIDIARIES

NOTES TO THE CONDENSED FINANCIAL STATEMENTS

As of March 31, 2023

(Unaudited)

 

8. CONVERTIBLE LOAN

 

In November 2021, the Company entered into a convertible loan agreement pursuant to which it raised $231,000 in financing. The note has a 10% annual interest rate, with repayments of a minimum of $3,500 per month commencing as of May 2022 and any open balance is convertible at the Lender’s discretion into shares of the Company’s common stock at $0.03 per share with warrant coverage at the same price on the basis of one warrant per every three shares issued under the loan. As of March 31, 2023, the Company had an outstanding balance of $181,635 and accrued interest of $28,442 payable on the convertible loan. 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 Lender’s ability to convert the loan to only that portion of the outstanding loan amount that would result in the Lender being the beneficial owner of not more than 9.99% of the Company’s class of common stock.

 

9. SUBSEQUENT EVENTS

 

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

 

 

 

12

 

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 March 31, 2023 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 near the end of 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, 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.

 

Recent focus was directed to the Shanks lease, one of the newly acquired leases. Initially the operator was able to activate one of the four wells on the lease (Well 13C) and ran a 24 hour gas test on the well. The test results showed 198.5 MCFD potential. Upon being put on production, the 13C well flowed 140 MCFD through the meter for a short time from the lower Dutcher zone at 1683 to 1687 feet. However, due to blockages downhole, the flow rate subsequently dropped. Blockages and corrosion are typical since the well has been shut in for a number of years. The well was subsequently pulled and the operator attempted to recomplete the well utilizing a stimulation technique, though encountered continued issues with the well and was unable to resume immediate production. In April 2023, the lower zone was acidized to clean up the gypsum blockages, and an additional zone was perforated in the middle Dutcher at a depth of around 1672 feet which shows oil potential. The well resumed production at between 62 to 104 MCFD gas, which subsequently dropped to approximately 30 MCFD. It is also showing a small amount of oil. We are considering installing a small gas compressor on this well in an attempt to stabilize and increase gas production which may be fluctuating due to pipeline differential pressure changes. The compressor could also help enhance oil production by reducing back pressure in the wellbore.

 

 

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On the Shanks 12B well, we perforated a new Dutcher zone at a depth of 1608' to 1614' for natural gas production. Due to service delays and wet weather conditions, we have been unable to acidize this new zone but intend to complete this work as soon as practicable.

 

Two additional wells at Shanks, the Shanks 12A and Shanks Watson 3, initially produced a small amount of oil, but eventually changed to all water. Three different log analysts have examined the well logs and have concluded that the Shanks 12A has one possible methane coal bed gas zone at a depth of around 700 feet that could be pursued when natural gas prices improve. The Watson 3 well shows one very shallow methane coal bed gas zone at a depth of around 400 feet, but the potential of this zone may be too marginal to justify additional expenditures. 

 

In the most recent fiscal year ended June 30, 2022, our share of the overall joint venture recorded revenues of approximately $51,000 from oil and gas sales, predominantly oil. In the nine months ended March 31, 2023, our share of the joint venture recorded revenues of $33,924 from oil sales and $3,988 from the sale of natural gas.

 

Vitt

 

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 two active water injection wells, plus another two injection wells that require further assessment. At present, five of the nine oil wells are pumping. We are planning to pull some wells and perform additional work in an effort to improve the rate of production. In the nine months ended March 31, 2023, commitments and expenditures at the Vitt totaled $11,500 with revenue of $5,209 being derived during this period.

 

The Vitt lease has now become a small nominal producing lease, 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 lease, which may include involving a partner in its further development.

 

West Sheppard Pool

 

In November 2021, the Company entered into a definitive joint venture and operating 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 with an upfront cost of $150,000 plus some ancillary costs and an anticipated initial rework budgeted at $100,000. As of the last fiscal year end on June 30, 2022, approximately $21,000 of additional expenditures had been made on equipment and field work. The 24 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. Following the acquisition of the leases, the operator began to assess the inventory of wells and equipment on site. Initial work focused on improving the flow lines, water congestion issues and electronic metering. After some minor repairs, there was gas flow between 25 to 50 MCFD, and additional work continued until gas sales were temporarily suspended, as the gas pipeline company had an equipment failure at its compressor station three miles away and in order to justify the investment in upgraded equipment, the gas pipeline company is requiring local operators to provide additional production throughput, sending more gas into the system.

 

Prior to the compressor outage, only 6 of the 24 wells on the property were selling into the pipeline. 4 additional wells were connected in late 2022, so in total the operator has now connected 10 of the 24 wells at West Sheppard Pool, which will be ready to sell gas upon the resumption of the necessary throughput via the pipeline. Additionally, further trenching work was conducted to lay flow lines with associated valve requirements.

 

The operator had previously negotiated an arrangement with the adjacent lease operator, which had yet to be implemented, to gather and sell the gas from three of their wells situated in close proximity to our leases in exchange for 20% of the gas revenue. Subsequent to the end of the period ended March 31, 2023, the operator has commenced new negotiations with the adjacent lease operator, pursuant to which the gas production from several of our West Sheppard wells will be transmitted into the adjacent lease’s gas gathering system without a customary 20% fee. In exchange, when gas sales are able to resume through our master meter, we will no longer charge the adjacent lease holder the previously negotiated 20% of gas revenue in connection with our processing of the gas production from their three wells included in the earlier arrangement.

 

Additionally, the plan would provide for the adjacent operator utilizing its knowledge and expertise of the area, to conduct further work at our West Sheppard Pool leases to reactivate additional wells that can eventually add additional gas production through our master meter as part of the current effort to  provide the requisite production throughput to justify the gas pipeline company’s upgrading of the compressor equipment which will restore service to the rest of the property.  Such an agreement is expected to enable us to resume generating some revenue from gas sales while the work required to reactivate the other wells at West Sheppard is being performed.

 

Beyond this, in terms of further developing the project, the operator believes that there is room to drill additional wells and additional behind-pipe opportunities within the existing 24 wells. In the nine months ended March 31, 2023, we had lease operating expenditures of $19,542 as we continued to conduct some additional work at the project. We recorded minimal revenues of $1,948 prior to the suspension at West Sheppard Pool, which continued through this quarter.

 

14

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 land owner 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 7 existing gas wells ranging in depth from 10,000-12,300 feet. The wells were temporarily 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 MCFD. Through the fiscal year ended June 30, 2022, we recorded $28,110 in revenues from gas sales at the project. Earlier this fiscal year, the wells were shut in, as the operator awaited repairs to a gas leak by the pipeline owner to the pipeline gathering system. The operator developed its plan to resume and improve production on the leases and the Company committed to further expend an unspecified additional amount of capital toward reworking the field as it reasonably determines. In the nine months ended March 31, 2023 lease operating expenditures totaling $57,310 were largely offset with revenues of $53,397, though there was some additional capital expenditures of $21,256 on the project, including a hydrocarbon survey. The operator believes with additional 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. In July 2022, a hydrocarbon survey was conducted across these leases utilizing a third party patented remote sensing technology, which has provided the operator with valuable data in charting the potential for the future development of this project.

 

The existing seven wells show additional behind-pipe zones and the joint venture partners have 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 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.

 

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. 

  

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.

 

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.

 

 

15

 

Results of Operations

 

For the Three months ended March 31, 2023, as compared to the Three months ended March 31, 2022

 

Revenue

 

We generated $30,228 in revenue from oil and gas sales for the three months ended March 31, 2023, as compared to $29,497 in revenues generated in the three months ended March 31, 2022. Revenues in the corresponding quarters were fairly steady, though the current quarter was lower than anticipated due to the suspension of gas sales at West Sheppard Pool and generally lower natural gas prices worldwide, impacting Pushmataha in particular. We also received $1,123 in interest income from our cash balances for three months ended March 31, 2023.

 

General and Administrative Expense

 

General and administrative expenses decreased to $68,830 for the three months ended March 31, 2023 as compared to $92,991 for the three months ended March 31, 2022, including $12,500 in non-cash items, where stock was issued in lieu of cash for services. This decrease is attributable to the Company recording $30,000 non-cash fees in the previous corresponding quarter versus only $12,500 in the current quarter ended March 31, 2023. Additionally, legal fees were lower during the current quarter. Other 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 March 31, 2023 was $138,718 compared to a net loss of $89,400 for the three months ended March 31, 2022. The Expenses during the three month period ended March 31, 2023, included: $100,019 in lease operating expenses (including taxes and royalties), $40,500 in compensation (of which only half is being paid out at the present time, with the remainder being accrued as a payable), $4,658 in interest expense, $12,500 in connection with our manager of land and resource development, $9,206 in professional fees and other general and administrative expenses necessary for our operations. These amounts included $12,500 of non-cash items with stock issued in lieu of services. Expenses during the comparative three month period ended March 31, 2022, including lease operating expenses, were lower as the Company had not fully established operations.

 

For the Nine months ended March 31, 2023, as compared to the Nine months ended March 31, 2022

 

Revenue

 

We generated $98,466 in revenue from oil and gas sales for the nine months ended March 31, 2023, as compared to $51,421 in revenues generated in the nine months ended March 31, 2022. The increase in revenue is attributable to ongoing rework operations over the past twelve months and the fact that some of the properties had only been acquired toward the end of our 2022 fiscal year, including West Sheppard Pool and Pushmataha, Therefore, revenues in fiscal 2023 included additional properties that were not included during all of the previous period. We also received $2,373 in interest income from our cash balances for nine months ended March 31, 2023.

 

General and Administrative Expense

 

General and administrative expenses increased to $306,068 for the nine months ended March 31, 2023 as compared to $173,672 for the nine months ended March 31, 2022. A portion of these expenses included $85,100 in non-cash items, where stock was issued in lieu of cash for services. This increase is attributable to the Company moving into the development stage, with operations at its oil and gas properties and greater expenses of the Company as it has transitioned to a more advanced operating Company for the full reporting period, therefore incurring increased expenses related to compensation, lease operating, interest, consultants, legal and professional fees. Additionally, this incorporates fees and expenses related to the efforts in becoming a publicly traded company.

 

Net Loss

 

The net loss for the nine months ended March 31, 2023 was $431,478 compared to a net loss of $149,732 for the nine months ended March 31, 2022.  The Expenses during the nine month period ended March 31, 2023, included: $223,517 in lease operating expenses (including taxes and royalties), $121,500 in compensation (of which only half is being paid out at the present time, with the remainder being accrued as a payable), $15,057 in interest expense, $61,721 in connection with corporate and investor relations consultants and $63,561 in legal and professional fees, $26,912 in listing related fees, and other general and administrative expenses necessary for our operations. These amounts included $85,100 of non-cash items with stock issued in lieu of services. The Expenses during the comparative nine month period ended March 31, 2022 were lower as the Company had still not fully established its operations. These included $67,500 in compensation, $31,250 in finance costs, $30,464 in legal and professional fees and other general and administrative expenses necessary for our operations.

 

 

16

Net cash used in investing activities

 

In the nine months ended March 31, 2023, net cash expended on investing activities was $30,285 versus $524,213 in the previous corresponding nine months ended March 31, 2022. The difference is attributable to the fact that a significant amount was invested into acquiring three of our oil and gas projects during the nine months ended March 31, 2022.

 

Net cash from financing 

 

Net cash from financing activities in the nine months ended March 31, 2023 totaled $448,975, which was predominantly comprised of private placements of equity securities during the period. Net cash from financing activities in the corresponding nine months ended March 31, 2022 totaled $589,750, which was higher, attributable to an earlier private placement of equity securities and the addition of some debt financing via a convertible note during that period.

 

LIQUIDITY AND CAPITAL RESOURCES

 

Current Financial Condition

 

The potential profitability of the Company’s operations is highly dependent upon the commodity prices of oil and natural gas. Natural gas prices tend to be seasonal and have declined substantially from the highs achieved in calendar 2022, although prices are expected to rebound somewhat later in the year as colder weather arrives in North America. In response to the current commodity prices, we have slowed our capital expenditures and are focusing our efforts on marginal improvements that can be conducted our projects which have the greatest potential returns on investment. These expenditures include the reworking of existing wells, and infrastructure investments on certain of our leases which are intended to increase production and cash flow without major capital expenditures.

 

As of March 31, 2023, we had total assets of $995,680, comprised primarily of cash and cash equivalents of $292,853, production revenue receivable of $14,889, oil and gas properties $686,362 and other assets of $1,576. As at March 31, 2023, we had total liabilities of $328,598, primarily comprised of convertible debt and related interest payable of $210,077, accounts payable of $1,271 and accrued liabilities of $117,250 in deferred compensation expense.

 

We have substantial capital resource requirements and have incurred significant losses since inception. The Company had a net loss of $431,478 for the nine months ended March 31, 2023 and an accumulated deficit of $737,768 as of March 31, 2023. The Company had working capital of $189,317 as at March 31, 2023 and management believes that the Company will have sufficient working capital for the remaining last quarter of the 2023 fiscal year. For the 2024 fiscal year starting in July, the Company anticipates cash needs of a minimum of $600,000, of which approximately $300,000 is for general corporate overhead and $300,000 for continued work on existing properties. The Company anticipates receiving limited revenue from oil and gas sales and intends to obtain the remaining capital through private sales of securities.

 

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 upcoming 2024 fiscal year, such capital requirements will be in excess of what we have in available cash for planned ongoing activities. On October 4, 2022, the Company filed a Form D in connection with a private placement of securities in the Company, total gross proceeds of the private placement are an aggregate of $401,500 as of March 31, 2023. These securities were issued pursuant to an exemption from registration under Section 4(a)(2) of the Securities Act of 1933 (the “Securities Act”) and Regulation D promulgated thereunder. Proceeds from the placement will be used for general corporate purposes. 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.

 

 

17

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 $431,478 for the nine months ended March 31, 2023 and an accumulated deficit of $737,768 as of March 31, 2023. These factors, among others, raise doubt about the Company’s ability to continue as a going concern.

 

The Company had working capital of $189,317 as at March 31, 2023 and management believes that the Company will have sufficient working capital for the remaining last quarter of the 2023 fiscal year. For the 2024 fiscal year starting in July, the Company anticipates cash needs of a minimum of $600,000, of which approximately $300,000 is for general corporate overhead and $300,000 for continued work on existing properties. The Company anticipates receiving limited revenue from oil and gas sales and intends to obtain the remaining capital through private sales of securities.

 

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.

 

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.

 

Item 3. Quantitative and Qualitative Disclosures about Market Risk

 

Not applicable to smaller reporting companies.

 

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 March 31, 2023, 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, 2021 and 2022, 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. 

 

 

18

The following material weaknesses in our internal control over financial reporting continued to exist at March 31, 2023:

 

	●	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 in our internal controls over financial reporting that occurred during the quarter ended March 31, 2023 that have materially affected, or are reasonably likely to materially affect, our internal controls over financial reporting.

  

 

19

 

Part II – OTHER INFORMATION

 

Item 1. Legal Proceedings

 

We are not currently involved in any litigation that we believe could have a material adverse effect on our financial condition or results of operations.

 

Item 1A. Risk Factors.

 

We are not required to provide this information as we are a smaller reporting company.

 

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

 

On September 29, 2022, the Company completed the initial placement of 6,375,000 equity units in a private placement. Subsequently, through March 31, 2023, the Company placed an additional 3,662,500 equity units in the private placement. Each unit consists of 1 common share and 0.5 of a warrant. The units were priced at $0.04 per unit and each full warrant will be exercisable to buy one share of the Company’s common stock at a price of $0.05 until December 31, 2024. Pursuant to the terms of the placement the Company issued an aggregate of 10,037,500 common shares and 5,018,750 warrants for gross proceeds of $401,500. These equity units were issued pursuant to an exemption from registration under Section 4(a)(2) of the Securities Act of 1933 (the “Securities Act”) and Regulation D promulgated thereunder.

 

On September 30, 2022, the Company issued an aggregate of 65,000 shares of common stock in lieu of cash in connection with accounting, secretarial and public relations related services.

 

Additionally on September 30, 2022, the Company issued 250,000 shares of common stock in lieu of cash in connection with a compliance consulting services agreement.

 

On December 29, 2022, the Company issued 2,400,000 shares of common stock in lieu of cash in connection with ongoing services of a corporate consultant covering a twelve month period. 

 

On February 11, 2023, the board of directors approved the issuance of 250,000 shares of common stock in connection with the signing of an ongoing services agreement with Sierra Land Resources, LLC, in connection with Land and Resource Development work. 

 

Except as otherwise noted, the securities in the transactions described above were sold in reliance on the exemption from registration provided in Section 4(a)(2) of the Securities Act and/or Rule 506(b) of Regulation D for transactions not involving any public offering. All certificates evidencing the shares sold bore a restrictive legend. No underwriter participated in the offer and sale of these securities, and no commission or other remuneration was paid or given directly or indirectly in connection therewith. The cash proceeds from these sales will be used for general corporate purposes.

 

Item 3. Defaults Upon Senior Securities

 

None

 

Item 4. Mine Safety Disclosures

 

Not applicable.

 

Item 5. Other Information

 

There is no other information required to be disclosed under this item which has not been previously disclosed.

 

 

 

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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 March 31, 2022, is formatted in Inline XBRL.

 

* Filed herewith.

 

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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:  May 12, 2023		/s/ Jonathan Herzog
		Jonathan Herzog, Chief Executive Officer and Chief Financial Officer (Principal Executive Officer, Principal Financial Officer and Principal Accounting Officer)

 

 

 

 

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