LRDC Laredo Oil Inc (PK)

UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

Form 10-K

For the fiscal year ended May 31, 2022

or

For the transition period from __________ to _________

Commission file number: 333-153168

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes o No x

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes o No x

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 x No o

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 (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No o

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

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. o

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

On November 30, 2021, the last business day of the registrant’s most recently completed second fiscal quarter, the aggregate market value of the registrant’s outstanding shares of common equity held by non-affiliates of the registrant was $1.46 million, based upon the closing price of the common stock on that date on the OTC Bulletin Board.

As of August 29, 2022, there were 55,787,339 shares of the registrant’s common stock outstanding.

Documents Incorporated by Reference: None.

LAREDO OIL, INC.

TABLE OF CONTENTS

Except as otherwise required by the context, references to “Laredo Oil,” “Laredo Oil, Inc.,” “the Company,” “we,” “us” and “our” are to Laredo Oil, Inc., a Delaware corporation, and its subsidiaries.

Forward-Looking Statements

From time to time, we may provide information, whether orally or in writing, including certain statements in this Annual Report on Form 10-K, which are deemed to be “forward-looking” within the meaning of the Private Securities Litigation Reform Act of 1995 (the “Litigation Reform Act”). These forward- looking statements and other information are based on our beliefs as well as assumptions made by us using information currently available.

The words “believe,” “plan,” “expect,” “intend,” “anticipate,” “estimate,” “may,” “will,” “should” and similar expressions are intended to identify forward-looking statements. Such statements reflect our current views with respect to future events and are subject to certain risks, uncertainties and assumptions. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those described herein as anticipated, believed, estimated, expected or intended or using other similar expressions. We do not intend to update these forward-looking statements, except as required by law.

In accordance with the provisions of the Litigation Reform Act, we are making investors aware that such forward-looking statements, because they relate to future events, are by their very nature subject to many important factors that could cause actual results to differ materially from those contemplated by the forward-looking statements contained in this Annual Report on Form 10-K, any exhibits to this Annual Report on Form 10-K and other public statements we make. Such factors are discussed in the “Risk Factors” section of this Annual Report on Form 10-K.

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

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

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

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

NOTE 1 - ORGANIZATION AND DESCRIPTION OF BUSINESS

The accompanying consolidated financial statements have been prepared by management of Laredo Oil, Inc. (“the Company”). In the opinion of management, all adjustments (which include only normal recurring adjustments) necessary to present fairly the financial position, results of operations and cash flows as of and for the years ended May 31, 2022 and 2021 presented have been made.

The Company was incorporated under the laws of the State of Delaware on March 31, 2008 under the name of “Laredo Mining, Inc.” with authorized common stock of 90,000,000 shares at $0.0001 par value and authorized preferred stock of 10,000,000 shares at $0.0001 par value. On October 21, 2009 the name was changed to “Laredo Oil, Inc.”

Laredo Oil, Inc. (“the Company”) is an oil exploration and production (“E&P”) company primarily engaged in acquisition and exploration efforts for mineral properties. From June 14, 2011 to December 31, 2020, the Company was a management services company managing the acquisition and conventional operation of mature oil fields and the further recovery of stranded oil from those fields using enhanced oil recovery (“EOR”) methods for its sole customer, Stranded Oil Resources Corporation (“SORC”), a wholly owned subsidiary of Alleghany Corporation (“Alleghany”).

From its inception through October 2009, the Company was primarily engaged in acquisition and exploration efforts for mineral properties. After a change in control in October 2009, the Company shifted its focus to locating mature oil fields with the intention of acquiring those oil fields and recovering stranded oil using EOR methods. The Company was unable to raise the capital required to purchase any suitable oil fields. On June 14, 2011, the Company entered into several agreements with SORC to seek recovery of stranded crude oil from mature, declining oil fields by using the EOR method known as Underground Gravity Drainage (“UGD”). Such agreements consisted of a license agreement between the Company and SORC (the “SORC License Agreement”), a license agreement between the Company and Mark See, the Company’s Chairman and Chief Executive Officer (“CEO”) (the “MS-Company License Agreement”), an Additional Interests Grant Agreement between the Company and SORC, a Management Services Agreement between the Company and SORC (the “MSA”), a Finder’s Fee Agreement between the Company and SORC (the “Finder’s Fee Agreement”), and a Stockholders Agreement (the “Stockholders Agreement”) among the Company, SORC and Alleghany Capital Corporation, a subsidiary of Alleghany (“Alleghany Capital”), each of which were dated June 14, 2011 (collectively, the “2011 SORC Agreements”).

The 2011 SORC Agreements stipulated that the Company and Mark See, the Company’s Chairman and Chief Executive Officer (“CEO”), will provide to SORC, management services and expertise through exclusive, perpetual license agreements and a management services agreement (the “Management Service Agreement”) with SORC. As consideration for the licenses to SORC, the Company will receive an interest in SORC’s net profits as defined in the Agreements (the “Royalty”). The Management Service Agreement (“MSA”) outlines that the Company will provide the services of various employees (“Service Employees”), including Mark See, in exchange for monthly and quarterly management service fees. The monthly management service fees provide funding for the salaries, benefit costs, and FICA taxes for the Service Employees identified in the MSA. SORC remits payment for the monthly management fees in advance and is payable on the first day of each calendar month. The quarterly management fee totals $137,500 and is paid on the first day of each calendar quarter, with the last payment being received October 1, 2020. In addition, prior to December 31, 2020, SORC reimbursed the Company for monthly expenses incurred by Service Employees in connection with their rendition of services under the MSA. The Company could also submit written requests to SORC for additional funding for payment of the Company’s operating costs and expenses, which SORC, in its sole and absolute discretion, determined whether or not to fund.

As consideration for the licenses to SORC, the Company was to receive an interest in SORC net profits as defined in the SORC License Agreement (the “SORC License Agreement”). Under the SORC License Agreement, the Company agreed that a portion of the Royalty equal to at least 2.25% of the net profits (“Incentive Royalty”) be used to fund a long-term incentive plan for the benefit of its employees, as determined by the Company’s board of directors. On October 11, 2012, the Laredo Royalty Incentive Plan (the “Plan”) was approved and adopted by the Board and the Incentive Royalty was assigned to the Plan. As a result of the Securities Purchase Agreement dated December 31, 2020, (the “SORC Purchase Agreement”), there are no longer any Incentive Royalties payable pursuant to the Plan and no Royalties will be paid to the Company by SORC in the future.

NOTE 1 - ORGANIZATION AND DESCRIPTION OF BUSINESS - continued

Pursuant to the SORC Purchase Agreement, by and among the Company, Alleghany, SORC, and SORC Holdings LLC, a wholly-owned subsidiary of the Company (“SORC Holdings”), SORC Holdings purchased all of the issued and outstanding shares of SORC stock (the “SORC Shares”) in a transaction that closed on December 31, 2020 (the “SORC Purchase Transaction”). As consideration for the SORC Shares, SORC Holdings paid Alleghany $72,678 (comprised of $55,000 purchase price plus a $17,678 working capital adjustment calculated in accordance with the SORC Purchase Agreement), and the Company agreed to pay Alleghany a revenue royalty of 5.0% of the Company’s future revenues and net profits relating to oil, gas, gas liquids and all other hydrocarbons, subject to certain adjustments, for a period of seven years after the closing. The SORC Purchase Agreement provides for customary adjustments to the purchase price based on the effective date of December 31, 2020. In connection with the SORC Purchase Transaction, the 2011 SORC Agreements were terminated effective as of December 31, 2020.

Further, pursuant to the SORC Purchase Agreement, the Company and Alleghany entered into a Consulting Agreement dated as of December 31, 2020 (the “Alleghany Consulting Agreement”), pursuant to which Alleghany agreed to pay an aggregate of approximately $1.245 million during calendar year 2021 in consideration of the Company causing certain individuals, including Mark See, the Company’s Chief Executive Officer and Chairman, and Chris Lindsey, the Company’s General Counsel and Secretary, to provide consulting services to Alleghany (for a period of three years for Mr. See and one year for Mr. Lindsey).

The Company believes that the SORC Purchase Transaction was advantageous as it simplified in a timely manner the unwinding of the 2011 SORC Agreements and allowed the Company to acquire vehicles and oil field assets that can be utilized in future oil recovery projects.

As the Company now owns SORC and the 2011 SORC Agreements have been terminated, the Company no longer receives any payments from SORC (including any Royalty payable by SORC to the Company) outlined in the 2011 SORC Agreements. As a result, except for the payments to be made in calendar year 2021 to the Company under the Alleghany Consulting Agreement, the Company will no longer receive management fee revenue from Alleghany or reimbursement from Alleghany for the monthly expenses of its employees, which fees and reimbursements were effectively all of the Company’s revenues prior to the closing of the SORC Purchase Transaction.

During the period from June 14, 2011 through December 31, 2020, Company management gained specialized know-how and operational experience in evaluating, acquiring, operating and developing oil and gas properties while implementing UGD projects, as well as gaining expertise designing, drilling and producing conventional oil wells. Based upon the knowledge gained, the Company has identified and acquired 45,246 gross acres and 37,932 net acres of mineral property interests in Montana. The Company has begun drilling one exploratory well during May 2022 and, if that well yields anticipated results, the Company plans to continue to develop the field thereafter. Each well is planned to have an 80-acre footprint, so the first 10 wells would affect approximately 800 acres, or less than 2 percent of the leased acreage. The success of the first development well and the ability to secure further funding will drive future plans and at this point there is nothing concrete that can be planned out.

In connection with securing this acreage in Montana, Lustre Oil Company LLC, a wholly-owned subsidiary of the Company (“Lustre”), entered into an Acquisition and Participation Agreement (“Erehwon APA”) with Erehwon Oil & Gas, LLC (“Erehwon”) to acquire oil and gas interests and drill, complete, re-enter, re-complete, sidetrack, and equip wells in Valley County, Daniels County and Roosevelt County, Montana. The Erehwon APA specifies calculations for royalty interests and working interests for the first 10 well completions and first 10 well recompletions and for all additional wells and recompletions thereafter. Lustre will acquire initial mineral leases and pay 100% of the costs with a cap of $500,000. When the cap is exceeded, Erehwon will have the option to acquire a 10% working interest (“WI”) in a lease by paying 10% of any lease acquisition cost, resulting in Lustre paying 90% of the lease costs, on a lease by lease basis. Until amounts paid to complete the first 10 new wells and first 10 recompletions are repaid (“Payback”), the WI split between Erehwon and Lustre is 10%/90%. Thereafter, the split between Erehwon and Lustre is 20%/80%. Additional wells and recompletions will have a WI split equal to their respective working interest in the leases. This will be 10% Erehwon and 90% Lustre unless Erehwon exercises its option to increase its WI by 10 percent points to 20%/80%, as described above. Under the Erehwon APA, Lustre will fund 100% of the construction costs of the first 10 wells and first 10 completions. Additional wells will be funded 80% by Lustre and 20% by Erehwon; provided, that Erehwon has the option to pay 10% of the cost to increase its WI to 20%. Royalty expense will consist of the sum of royalty interest to the land owner and an overriding royalty interest to two individuals (“Prospect Generators”) not to exceed 6% nor be less than 3%. For the first 10 new wells and first 10 recompletions, the Prospect Generators will receive an amount equal to 5% of the cost of each completed producing well.

On June 30, 2020, the Company entered into the Limited Liability Company Agreement (the “LLC Agreement”) of Cat Creek Holdings LLC (“Cat Creek”), a Montana limited liability company formed as a joint venture with Lipson Investments LLC (“Lipson”) and Viper Oil & Gas, LLC (“Viper”) for the purchase of certain oil and gas properties in the Cat Creek Field in Petroleum and Garfield Counties in the State of Montana (the “Cat Creek Properties”). Cat Creek entered into an Asset Purchase and Sale Agreement (the “Cat Creek Purchase Agreement”) with Carrell Oil Company (“Carrell Oil”) on July 1, 2020 for the purchase of the Cat Creek Properties from Seller. Upon closing under the Cat Creek Purchase Agreement, Carrell received consideration of $400,000, subject to certain adjustments resulting from pre- and post-effective date revenue, expense and tax allocations. In accordance with the LLC Agreement, the Company invested $448,900 in Cat Creek for 50% of the ownership interests in Cat Creek using cash on hand. Each of Lipson Investments LLC and Viper Oil & Gas, LLC, the other two members of Cat Creek, have ownership interests in Cat Creek of 25% in consideration of their respective investments of $224,450. Cat Creek will be managed by a Board of Directors consisting of four directors, two of which shall be designated by the Company.

NOTE 1 - ORGANIZATION AND DESCRIPTION OF BUSINESS - continued

In January 2022, the Company and Lustre executed a Net Profits Interest Agreement effective as of October 2021 (“NPI Agreement”) with Erehwon and Olfert No. 11-4 Holdings, LLC (“Olfert Holdings”) for the purpose of funding the first well, Olfert #11-4, (the “Well”) under the Erehwon Acquisition and Participation Agreement (“APA”). In connection with the NPI Agreement, the Company was credited a contribution totaling $59,935 of well development costs as determined per agreement with Olfert on behalf of Olfert Holding representing a 5.5% interest in the entity as of May 31, 2022 based on the carrying value of assets contributed to Olfert. The total investment recorded by Laredo was $19,435 as of May 31, 2022. The difference between the $59,935 contribution recorded at the Olfert level and the investment recorded by Laredo is due to the investment at Laredo being recorded at the carrying value of the assets contributed. As Laredo also currently serves as the manager of Olfert, the Company exercises significant influence. Accordingly, the amount paid is recorded as an equity method investment as of May 31, 2022. See further disclosures in Note 9.

Basic and Diluted Loss per Share

The Company’s basic earnings per share (“EPS”) amounts have been computed based on the weighted-average number of shares of common stock outstanding for the period. For the years ended May 31, 2022 and 2021, all options and warrants potentially convertible into common equivalent shares are considered antidilutive and have been excluded in the calculation of diluted earnings per share.

NOTE 2 – GOING CONCERN

These consolidated financial statements have been prepared on a going concern basis. The Company has routinely incurred losses since inception, resulting in an accumulated deficit, and historically has been dependent on one customer for its revenue. The Company entered into the Agreements with SORC to fund operations and to provide working capital. However, as a result of the SORC Purchase Transaction, except for payments to be made in calendar year 2021 to Laredo under the Consulting Agreement, Alleghany will no longer fund operations or provide working capital to the Company or SORC. There is no assurance that in the future such financing will be available to meet the Company’s needs. This situation raises substantial doubt about the Company’s ability to continue as a going concern within one year of the issuance date of the consolidated financial statements.

Management has undertaken steps as part of a plan to improve operations with the goal of sustaining operations for the next twelve months and beyond. These steps include an ongoing effort to (a) controlling overhead and expenses; (b) raising funds connected with specific well development; and (b) raising funds through notes payable and convertible debt to expand and fund property acquisitions exploration and development as well as maintaining operations. The Company has worked to attract and retain key personnel with significant experience in the industry. At the same time, in an effort to control costs, the Company has required a number of its personnel to multi-task and cover a wider range of responsibilities in an effort to restrict the growth of the Company’s headcount. There can be no assurance that the Company can successfully accomplish these steps and it is uncertain that the Company will achieve a profitable level of operations and obtain additional financing. There can be no assurance that any additional financing will be available to the Company on satisfactory terms and conditions, if at all.

The accompanying consolidated financial statements do not include any adjustments to reflect the possible future effects on the recoverability and classification of assets or the amounts and classifications of liabilities that may result from the possible inability of the Company to continue as a going concern.

NOTE 3 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

USE OF ESTIMATES

Management uses estimates and assumptions in preparing these consolidated financial statements in accordance with generally accepted accounting principles. Those estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities, and the reported revenues and expenses. Actual results could differ from those estimates.

PRINCIPLES OF CONSOLIDATION

The accompanying consolidated financial statements include the accounts of Laredo Oil and its subsidiaries after elimination of intercompany balances and transactions.

EQUITY METHOD INVESTMENT

Investments classified as equity method consist of investments in companies in which the Company is able to exercise significant influence but not control. Under the equity method of accounting, the investment is initially recorded at cost, then the Company’s proportional share of investee’s underlying net income or loss is recorded as a component of “other income” with a corresponding increase or decrease to the carrying value of the investment. Distributions received from the investee reduce the Company’s carrying value of the investment. These investments are evaluated for impairment if events or circumstances arise that indicate that the carrying amount of such assets may not be recoverable. The Company has elected to record its portion of the equity method income with a two-month lag. Accordingly, the financial results for the equity investment are reported through March 31, 2022. No impairments were recognized for the Company’s equity method investment during the year ended May 31, 2022. See Note 16.

NOTE 3 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - continued

REVENUE RECOGNITION

Monthly Management Fee

The Company generated monthly management revenues from fees for labor and benefit costs in accordance with the Agreements. The Company recognizes revenue for these services in the month the labor and benefits are received by the customer. As a result, the Company records deferred revenue for service that have not been provided. Monthly management fee revenues of $0 and $3,694,930, respectively, were recognized for the years ended May 31, 2022 and 2021. The last monthly management fee payment from SORC was paid in February 2021.

Quarterly Management Fee

While the Agreements were in place with Alleghany during calendar year 2021, the Company generated management fee revenue of $137,500 each quarter, payable in advance. The Company recognized that revenue over the applicable quarter on a straight-line basis. Quarterly management fees recognized for the years ended May 31, 2022 and 2021 were $0 and $320,833, respectively. The last quarterly management fee payment from SORC was paid October 1, 2020 in fiscal year 2021.

Other Revenue

The Company and Alleghany have entered into a Consulting agreement (see Note 1), where Alleghany is obligated to pay the Company a total of $1,144,471, in quarterly payments beginning January 1, 2021, in consideration for making certain individuals available for their advice, assistance and support in connection with the oil and gas industry and any questions, issues or matters arising from Alleghany’s previous ownership of SORC. Two individuals are committed for a one-year period ending December 31, 2021, and one individual is committed for a three-year period ending December 31, 2023. The Company’s management believes that any work necessary under this obligation will in fact be completed by December 31, 2021, and is recognizing revenue on a monthly basis over the year ended December 31, 2021. Unearned revenue related to amounts received but not yet earned under this contract at May 31, 2022 and 2021 totaled $0 and $95,373, respectively. Other revenue fees of $667,608 and $576,863, respectively, were recognized for the years ended May 31, 2022 and 2021.

CASH AND CASH EQUIVALENTS

All highly liquid investments with a maturity of three months or less are considered to be cash equivalents. There were no cash equivalents as of May 31, 2022 and 2021. At times, the Company maintains cash balances deposited at its financial institution that exceed FDIC insured limits.

RECEIVABLES

Receivables as of May 31, 2022 represent balances arising from employee expense reports.

As of May 31, 2021, receivables include amounts due from Alleghany pursuant to the SORC Purchase Transactions. Receivables represent related party balances arising from employee expense reports and estimated monthly license fees incurred in accordance with the Company’s revenue recognition policy, but not paid at May 31, 2021 period end.

PREPAID EXPENSES AND OTHER CURRENT ASSETS

Prepaid expenses and other current assets are primarily comprised of prepaid public relations fees which are recorded on a quarterly basis and amortized to expense over the 3-month contract life and prepaid directors’ and officers’ insurance which is recorded and amortized to expense over the 12-month contract life. During fiscal year 2021, the Company also had prepaids acquired in the acquisition of SORC and prepaid wages. Certain employees are paid wages on a quarterly basis. As a result, the Company recorded one month of prepaid wages as of May 31, 2021.

OIL AND GAS ACQUISITION AND DRILLING COSTS

Oil and gas acquisition and drilling costs include expenditures representing investments in unproved and unevaluated properties and include non-producing leasehold, leasehold or drilling interest costs, and costs to drill one exploratory well. Exploratory drilling costs are deferred until the outcome of the well is known. If an exploratory well finds proved reserves, the deferred costs are transferred to the company’s Wells and Related Equipment and Facilities accounts. Absent proved reserves, the deferred costs of the well, net of salvage, are charged to expense. All costs of wells drilled to develop proved reserves, along with all costs of equipment necessary to produce and handle the hydrocarbons, are capitalized even if a development well proves dry. Costs are reviewed to determine if impairment has occurred. The Company has incurred oil and gas acquisition and drilling costs totaling $2,702,715 and 389,480 during the years ended May 31, 2022 and 2021, respectively.

NOTE 3 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES – continued

PROPERTY AND EQUIPMENT

The carrying value of the Company’s property and equipment represents the cost incurred to acquire the property and equipment, net of any impairments. For business combinations, property and equipment cost is based on the fair values at the acquisition date. Property and equipment are stated at cost less accumulated depreciation and amortization. Depreciation and amortization is computed using the straight-line method over the estimated useful lives of the assets. Estimated useful lives of five to seven years are used for vehicles and machinery. Realization of the carrying value of property and equipment is reviewed for possible impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. Assets are determined to be impaired if a forecast of undiscounted estimated future net operating cash flows directly related to the asset, including disposal value, if any, is less than the carrying amount of the asset. If any asset is determined to be impaired, the loss is measured as the amount by which the carrying amount of the asset exceeds its fair value. Repairs and maintenance costs are expensed in the period incurred.

CONVERTIBLE NOTES

The Company accounts for convertible instruments (when it has determined that the embedded conversion options should not be bifurcated from their host instruments) in accordance ASC Topic 470, “Accounting for Convertible Securities with Beneficial Conversion Features”, as those professional standards pertain to “Certain Convertible Instruments”. Accordingly, the Company records, when necessary, discounts to convertible notes for the intrinsic value of conversion options embedded in debt instruments based upon the differences between the fair value of the underlying common stock at the commitment date of the note transaction and the effective conversion price embedded in the note. Debt discounts under these arrangements are amortized over the term of the related debt to their earliest date of redemption. The Company also records when necessary deemed dividends for the intrinsic value of conversion options embedded in preferred shares based upon the differences between the fair value of the underlying common stock at the commitment date of the note transaction and the effective conversion price embedded in the note. ASC Topic 815 provides that generally, if an event that is not within the entity’s control could or require net cash settlement, then the contract shall be classified as an asset or a liability. 

FAIR VALUE OF FINANCIAL INSTRUMENTS

Fair value is defined as the amount that would be received from the sale of an asset or paid for the transfer of a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are classified and disclosed in one of the following categories:

SHARE BASED COMPENSATION

FASB ASC 718, Compensation - Stock Compensation prescribes accounting and reporting standards for all stock-based payment awards to employees, including employee stock options, restricted stock, employee stock purchase plans and stock appreciation rights. Stock-based payment awards may be classified as either equity or liabilities. The Company should determine if a present obligation to settle the share-based payment transaction in cash or other assets exists. A present obligation to settle in cash or other assets exists if: (a) the option to settle by issuing equity instruments lacks commercial substance or (b) the present obligation is implied because of an entity’s past practices or stated policies. If a present obligation exists, the transaction should be recognized as a liability; otherwise, the transaction should be recognized as equity.

The Company accounts for stock-based compensation issued to non-employees and consultants in accordance with the provisions of FASB ASC 505-50, Equity - Based Payments to Non-Employees. Measurement of share-based payment transactions with non-employees shall be based on the fair value of whichever is more reliably measurable: (a) the goods or services received; or (b) the equity instruments issued. The fair value of the share-based payment transaction should be determined at the earlier of performance commitment date or performance completion date.

INCOME TAXES

The Company accounts for income taxes by the asset and liability method in accordance with FASB ASC 740, Income Taxes. Under this method, current income taxes are recognized for the estimated income taxes payable for the current year. Deferred income tax assets and liabilities are recognized in the current year for temporary differences between the tax and accounting bases of assets and liabilities as well as for the benefit of losses available to be carried forward to future years for tax purposes that are likely to be realized. In addition, a valuation allowance is established to reduce any deferred tax asset for which it is determined that it is more likely than not that some portion of the deferred tax asset will not be realized.

In addition, the Company utilizes the two-step approach to recognizing and measuring uncertain tax positions taken or expected to be taken in a tax return. The first step is to determine if the weight of available evidence indicates that it is more likely than not that the tax position will be sustained in an audit, including resolution of any related appeals or litigation processes. The second step is to measure the tax benefit as the largest amount that is more than 50% likely to be realized upon ultimate settlement. The Company recognizes interest and penalties accrued on unrecognized tax benefits within general and administrative expense. To the extent that accrued interest and penalties do not ultimately become payable, amounts accrued will be reduced and reflected as a reduction in general and administrative expenses in the period that such determination is made.

RECENTLY ISSUED ACCOUNTING PRONOUNCEMENTS

The Company has implemented all new accounting pronouncements that are in effect. These pronouncements did not have any material impact on the consolidated financial statements unless otherwise disclosed, and the Company does not believe that there are any other new accounting pronouncements that have been issued that might have a material impact on its financial position or results of operations.

NOTE 4 – ACQUISITION OF SORC

Purchase Price Allocation

Effective December 31, 2020, the Company acquired a 100% equity interest in SORC (see Note 1). We have accounted for the acquisition of SORC as a business combination using the acquisition method. The following table represents the allocation of the total purchase price of SORC to the identifiable assets acquired and the liabilities assumed based on the fair values as of the acquisition date, as updated for identified adjustments to current assets and liabilities. The preliminary allocations of the purchase price with less than a year of ownership are subject to revisions as additional information is obtained about the facts and circumstances that existed as of the acquisition date. The purchase price allocation was preliminary and was subject to revision through the end of the measurement period on December 31, 2021. The original purchase price is final and no further adjustments are necessary.

Financial Information

Pursuant to Topic 2, section 2010 of the SEC financial reporting manual, the Company evaluated the business combination. Prior to the acquisition by the Company, SORC sold all operating assets, terminated all employees and no longer maintained any of the business processes that previously existed. Accordingly, the Company has determined the transaction is considered an asset acquisition only. As a result, historical consolidated financial statements are not considered relevant to the ongoing operations and are not required.

In accordance with the Securities Purchase Agreement, Laredo agreed to pay to Alleghany a revenue royalty of 5.0% of the Company’s future revenues and net profits relating to oil, gas, gas liquids and all other hydrocarbons, subject to certain adjustments, for a period of seven years after the closing. The Company has not attributed a value to this potential liability in the preliminary purchase price allocation as eligible revenues or net profits do not currently exist and are not estimable.

In connection with the acquisition, the Company received tangible assets which had previously been written off by the Seller. This previous reduction in asset values in combination with the Seller’s desire to close the transaction on an accelerated basis enabled the Company to obtain the assets at a lower price resulting in the recognition of a bargain purchase gain.

For the years ended May 31, 2022 and 2021, respectively, SORC recognized no revenues and $17,629 and $12,439 interest expense recorded related to the debt discount amortization and $12,782 and $0 interest expense on the note payable, included in the Consolidated Statement of Operations.

NOTE 5—ACCOUNTING FOR ASSET RETIREMENT AND ENVIRONMENTAL OBLIGATIONS

We account for our asset retirement obligations in accordance with Accounting for Asset Retirement and Environmental Obligations. This requires that legal obligations associated with the retirement of long-lived assets be recognized at fair value when incurred and capitalized as part of the related long-lived asset. Over time, the liability is accreted to its present value each period, and the capitalized asset is depreciated over the useful life of the long-lived asset.

In the absence of quoted market prices, we estimate the fair value of our asset retirement obligations using present value techniques, in which estimates of future cash flows associated with retirement activities are discounted using a credit-adjusted risk-free rate. Our estimated liability could change significantly if actual costs vary from assumptions or if governmental regulations change significantly.

Our asset retirement obligation was established in May 2022 when we commenced drilling the Olfert#11-4 well in the Lustre oil field. At May 31, 2022 the asset retirement obligation totaled $61,762.

The cash flow estimate for the asset retirement obligation is based upon the assumption of a 25-year expected life of the well, discounted using a credit-adjusted risk free interest rate of 10%.

As drilling commenced in May 2022, no accretion expense has been recorded as of May 31, 2022.

NOTE 6 – FAIR VALUE MEASUREMENTS

Fair Value of Financial Instruments

The carrying values of cash and cash equivalents, accounts and other receivables, accounts payable and accrued current liabilities approximate their fair values due to the short-term nature of the instruments.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

The estimated fair value of oil and gas properties and the asset retirement obligation incurred in the drilling of oil and gas wells or assumed in the acquisitions of additional oil and gas working interests are based on an estimated discount cash flow model and market assumptions. The significant Level 3 assumptions used in the calculation of estimated discounted cash flow model include future commodity prices, projections of estimated quantities of oil and gas reserves, expectations for timing and amount of future development, operating and asset retirement costs, projections of future rates of production, expected recovery rates and risk adjusted discount rates. See Note 3 for additional information regarding oil and gas property acquisitions.

Laredo estimates the fair value of asset retirement obligations based on the projected discounted future cash outflows required to settle abandonment and restoration liabilities. Such an estimate requires assumptions and judgments regarding the existence of liabilities, the amount and timing of cash outflows required to settle the liability, what constitutes adequate restoration, inflation factors, credit adjusted discount rates, and consideration of changes in legal, regulatory, environmental and political environments. Abandonment and restoration cost estimates are determined in conjunction with Laredo’s reserve engineers based on historical information regarding costs incurred to abandon and restore similar well sites, information regarding current market conditions and costs, and knowledge of subject well sites and properties. Asset retirement obligation fair value measurements in the current period were Level 3 fair value measurements. As further described in Note 5, the Company recognizes the fair value of a liability for an asset retirement obligation in the period in which it is incurred if a reasonable estimate of fair value can be made. Asset retirement obligations are not measured at fair value subsequent to initial recognition.

NOTE 7 – EARNINGS/(LOSS) PER SHARE

Basic and diluted earnings/(loss) per share is computed by dividing net income/(loss) available to common shareholders by the weighted average number of common shares outstanding during the period. Diluted earnings/(loss) per share gives effect to all dilutive potential common shares outstanding during the period. Dilutive earnings/(loss) per share excludes all potential common shares if their effect is anti-dilutive. For the years ended May 31, 2022 and 2021, respectively, warrants to purchase 0 and 5,374,501 shares of common stock, options to purchase 5,275,000 and 4,300,000 shares of common stock , and 928,333 and 0 shares convertible into shares of common stock in connection with the convertible debt, were not included in the computation of diluted earnings/(loss) per share because they were anti-dilutive.

NOTE 8 - RELATED PARTY TRANSACTIONS

Transactions between related parties are considered to be related party transactions even though they may not be given accounting recognition. FASB ASC 850, Related Party Disclosures (“FASB ASC 850”) requires that transactions with related parties that would make a difference in decision making shall be disclosed so that users of the consolidated financial statements can evaluate their significance. Related party transactions typically occur within the context of the following relationships:

Prior to the SORC Purchase Acquisition on December 31, 2020, SORC and Alleghany were considered related parties under FASB ASC 850. See Note 1. All management fee revenue reported by the Company for the period through December 31, 2020 is generated from charges to SORC.

Subsequent to the Company’s purchase of 100% of SORC’s stock on December 31, 2020, Alleghany and its subsidiaries are no longer a related party. See Note 9.

Cat Creek, the Company’s equity investment, loaned Laredo $136,479 at a market rate of interest on April 4, 2022. The note and accrued interest was repaid on August 30, 2022 in exchange for property, plant and equipment.

In accordance with the NPI Agreement, Olfert #11-4 Holdings transferred funds totaling $1,000,000 to Laredo’s wholly owned subsidiary, Lustre for purposes of providing a loan for drilling expenses incurred with respect to the development of one well.

NOTE 9- STOCKHOLDERS’ DEFICIT

Share Based Compensation

Effective November 6, 2011, the holders of a majority of the shares of common stock approved the Plan to reserve 10,000,000 shares of common stock for issuance to eligible recipients. Effective December 2014, an additional 5,000,000 shares of common stock were reserved for issuance to eligible recipients under the Plan. Shares under the plan can be issued in the form of options, restricted stock, and other forms of equity securities. The Company’s board of directors has the discretion to set the amount and vesting period of award grants. As of May 31, 2022, 8,149,000 shares remain available for issuance under the Plan.

The fair value of stock options granted was calculated using the Black-Scholes option pricing model using the following weighted average assumptions during the year ended May 31,2022. There were no options granted in the year ended May 31, 2021.

The risk-free interest rate is based on the U.S. Treasury yield curve in effect at the time of grant for a bond with a similar term. The Company does not anticipate declaring dividends in the foreseeable future. Volatility is estimated based on the historical share prices over the same period as the expected life of the option. The Company uses the simplified method for determining the expected term of its stock options.

Stock Options

As of May 31, 2022 and 2021, there were 1,143,761 and 0 unvested and unrecognized shares. As of May 31, 2022, unrecognized compensation cost related to nonvested stock options amounted to $84,282 which is expected to be recognized over the next three years.

The following table summarizes information about options granted during the years ended May 31, 2022 and 2021:

All stock options are exercisable upon vesting.

As of May 31, 2022 and 2021, 5,275,000 and 4,300,000 options are outstanding at a weighted average exercise price of $0.16 and $0.94, respectively.

Restricted Stock

During fiscal years ending May 31, 2022 and 2021, no restricted stock has been granted and accordingly, no expense has been recorded for restricted stock. The Company granted 1.55 million shares of restricted stock, net of forfeitures during fiscal year 2014. As of May 31, 2022, all 1,550,000 granted shares have been issued.

Warrants

As of May 31, 2021, there were 5,374,501 warrants remaining to be exercised at a price of $0.70 per share to Sunrise Securities Corporation to satisfy the finders’ fee obligation associated with the Alleghany transaction. The warrants expired June 14, 2021.

No warrants are outstanding at May 31, 2022.

NOTE 10 - NET PROFITS INTEREST AGREEMENT

In January 2022, the Company and Lustre executed a Net Profits Interest Agreement effective as of October 2021 (“NPI Agreement”) with Erehwon and Olfert No. 11-4 Holdings, LLC (“Olfert Holdings”) for the purpose of funding the first well, Olfert #11-4, (the “Well”) under the Erehwon Acquisition and Participation Agreement (“APA”). The NPI Agreement grants Olfert Holdings a flow of an Applicable Percentage of available funds from the Well in exchange for Olfert Holdings funding its development. The “Applicable Percentage” under the NPI Agreement is 90% prior to Payout and 50% after Payout, where “Payout” means the point in time when the aggregate of all Net Profits Interest payments made to Olfert Holdings under the NPI Agreement equals 105% of the well development costs. In January 2022, the Company entered into an Amended and Restated Limited Liability Company Operating Agreement of Olfert Holdings dated effective as of November 2021 (the “Olfert Holdings Operating Agreement”). Pursuant to the Olfert Holdings Operating Agreement, the Company has agreed to make a capital contribution to Olfert Holdings in the amount of $500,000 out of the aggregate $1,500,000 of capital raised by Olfert Holdings. During October and November 2021, through the Company’s wholly owned subsidiary, Lustre Holdings, Laredo received advance payments totaling $1.0 million from four investors pursuant to the NPI agreement. Pursuant to the Olfert Holdings Operating Agreement, the Company was credited an amount equal to $59,935 of well development costs as part of its capital contribution. The Company has not yet determined the source of its funds for the balance of its capital contribution, and it is possible that another investor may invest all or a part of such funds instead of the Company. The Company has also been appointed as the Manager of Olfert Holdings. Through February 28, 2022, the Company has incurred approximately $220,000 related to the development of the first well. The expected well development cost for the first well to be developed under the NPI Agreement is $1.5 million.

In connection with the NPI Agreement, the Company was credited a contribution totaling $59,935 of well development costs as determined per agreement with Olfert on behalf of Olfert Holding representing a 5.5% interest in the entity as of May 31, 2022 based on the carrying value of assets contributed to Olfert. The total investment recorded by Laredo was $19,435 as of May 31, 2022. The difference between the $59,935 contribution recorded at the Olfert level and the investment recorded by Laredo is due to the investment at Laredo being recorded at the carrying value of the assets contributed. As Laredo also currently serves as the manager of Olfert, the Company exercises significant influence. Accordingly, the amount paid is recorded as an equity method investment as of May 31, 2022.

NOTE 11 – NOTES PAYABLE

Convertible Debt

In October, November, December 2021, March, April and May 2022, Laredo entered into Securities Purchase Agreements with three accredited investors, pursuant to which the Company issued six convertible promissory notes in the principal amount of $608,575, receiving $527,500 in net cash proceeds (the “Convertible Notes”). The Convertible Notes had an original issue discount of $58,575. Further $22,500 debt issue costs were deducted from the gross proceeds. The total of $81,075 recorded as debt discount are being amortized using the effective interest method through the maturity dates of the Convertible Notes. The Convertible Notes are due in one year from the date of issuance, accrue interest at 8% per annum (22% upon the occurrence of an event of default) and are convertible after 180 days into shares of the Company’s common stock at a discount of 25% of the average of the three lowest trading prices during the 15 trading days immediately preceding the conversion. The Company has determined the value associated with the beneficial conversion feature in connection with the notes resulting in a further increase in the debt discount totaling $55,918. The additional debt discount is amortized using the effective interest method through the date the notes are initially convertible. 

The Company has the right to prepay the Convertible Notes at any time during the first six months the note is outstanding at the rate of (a) 110% of the unpaid principal amount of the note plus interest, during the first 120 days the note is outstanding, and (b) 115% of the unpaid principal amount of the note plus interest between days 121 and 180 after the issuance date of the note. The Convertible Notes may not be prepaid after the 180^th day following the issuance date, unless the note holders agree to such repayment and such terms.

The Company agreed to reserve a number of shares of its common stock which may be issuable upon conversion of the Convertible Notes at all times.

The Convertible Notes provide for standard and customary events of default such as failing to timely make payments under the Convertible Notes when due, the failure of the Company to timely comply with the Securities Exchange Act of 1934, as amended, reporting requirements and the failure to maintain a listing on the OTC Markets. The Convertible Notes also contains customary positive and negative covenants. The Convertible Notes include penalties and damages payable to the noteholders in the event we do not comply with the terms of such note, including in the event we do not issue shares of common stock to the noteholders upon conversion of the notes within the time periods set forth therein. Additionally, upon the occurrence of certain defaults, as described in the Convertible Notes, we are required to pay the noteholders liquidated damages in addition to the amount owed under the Convertible Notes (including in some cases up to 300% of the amount of the note).

NOTE 11 – NOTES PAYABLE - continued

At no time may the Convertible Notes be converted into shares of Laredo common stock if such conversion would result in the note holders and their affiliates owning an aggregate of in excess of 4.99% of the then outstanding shares of Laredo common stock.

The proceeds from the Convertible Notes can be used by the Company for general corporate purposes.

During April and May 2022, the Company repaid the Convertible Notes entered in October and November 2021. The October 2021 repayment totaled $136,479 comprised of $114,125 principal and $22,354 related accrued interest and prepayment penalty interest. The Company borrowed $136,479 from Cat Creek to repay the Convertible Note.

The November 2021 note repayment totaled $85,469 comprised of $71,500 principal and $13,969 related accrued interest and prepayment penalty interest.

Upon repayment of the October and November 2021 notes, the related remaining outstanding debt discount and debt issue costs totaling $12,388 were amortized and recorded as interest expense.

See Note 17 – Subsequent Events for convertible debt activity after period end.

Revolving Note

The Company entered into a Revolving Credit Note (the “Revolving Note”) with AEI Management, Inc. (“AEI”) with a maximum draw amount of $1,500,000.00. In May 2022, the Company borrowed $62,858 under the Revolving Note. The Note is dated May 25, 2022, to be effective May 12, 2022. The Note has a maturity date of May 1, 2023 or such later date as requested by the Company and agreed in writing by the Lender in its sole discretion. Under the Note, the Lender may, at its sole discretion, make advances to the Company upon the Company’s request in amounts not to exceed an aggregate amount of $150,000 in any 30-day period and not to exceed the full principal amount of the Note in the aggregate. The Note will accrue interest on the outstanding principal sum at the rate of 8.75% per annum, and is payable by the Company every 90 days following the date of the first drawdown. All unpaid principal, accrued interest and any other amounts will be due and payable on the maturity date.

In accordance with the Note, the Lender is entitled, at its option and upon its issuance of a conversion notice to the Company, to convert all or any part of the outstanding and unpaid principal and accrued interest amount under the Note into fully paid and non-assessable shares of common stock of the Company, at a conversion price that shall equal:

if the Company’s common stock is not listed for trading on an exchange or quoted for trading on the OTC Bulletin Board or the Pink Sheets, the lesser of (i) par value of the Company’s common stock or (ii) the cost basis of the most recent, non-affiliate issuance of common stock, or

if the Company’s common stock is listed for trading on an exchange or quoted for trading on the OTC Bulletin Board or the OTC Markets Group, a 20% discount to the closing price of the common stock as reported by the Company’s primary market on the trading day immediately preceding the issuance of the conversion notice by the Lender to the Company.

Notwithstanding anything to the contrary, in no event shall the Note be converted into shares of common stock or other securities of the Company to the extent that such conversion would result in the Lender and its affiliates together beneficially owning more than 4.99% of the outstanding shares of the Company’s common stock.

The Company did not provide any collateral or guarantees for the loan, nor did the Company pay any facility charge to obtain the loan. The Note provides for certain consent rights of the Lender for the Company to take certain actions, including, among others, any redemption, repurchase, acquisition or declaration or payment of any cash dividend or distribution on any capital stock of the Company, increase of the par value of the Company’s common stock, issuance of debt or sale of substantially all assets or stock, as well as customary events of default, including, among others, those relating to failure to make payment, bankruptcy, breaches of representations and termination or impairment of the Company’s business in any material respect. The Company may prepay the Note at any time without payment of any penalty or premium.

During the fiscal year ended May 31, 2011, the Company entered into two Loan Agreements with Alleghany Capital for a combined available borrowing limit of $350,000. The notes accrued interest on the outstanding principal of $350,000 at the rate of 6% per annum, with an amended due date of December 31, 2020.

In connection with the SORC Purchase Transaction, the notes were amended, restated and consolidated into one note including all accrued interest through December 31, 2020, for a total of $631,434 (the “Senior Consolidated Note”) with a maturity date of June 30, 2022. The Senior Consolidated Note requires any stock issuances for cash be utilized to pay down the outstanding loan balance unless written consent is obtained from Alleghany. As part of the SORC Purchase Agreement, the Company agreed to secure repayment of the Senior Consolidated Note with certain equipment and to reduce the note balance with any proceeds received from any sales of such equipment. During the five months ending May 31, 2021, the Company repaid $13,500 of the Senior Consolidated Note upon the sale of certain equipment. The note bears no interest until January 1, 2022 whereupon the interest rate increases to 5% per annum through maturity. Principal with all accrued and unpaid interest is due at maturity. In connection with the SORC acquisition purchase price allocation, the Company recorded a debt discount totaling $30,068 in recognition of imputed interest on the Senior Consolidated Note, to be amortized over the first year of the note term. The Senior Consolidated Note is recorded as a Note payable – Alleghany, net of debt discount as of May 31, 2022. The debt discount has been fully amortized as of December 31, 2021. In August 2022, the Company entered an amendment to the Senior Consolidated Note whereby the maturity date of the loan was extended to December 31, 2023 in exchange for an interest rate to 8% per annum commencing July 1, 2022. Further, if the loan is not paid prior to December 31, 2022, the revenue royalty as defined in the Purchase Agreement will be increased from 5% to 6%.