White River Energy Corp. - Quarter Report: 2023 June (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

For the quarterly period ended: June 30, 2023

For the transition period from:

Commission file number 333-192060

White River Energy Corp

(Exact name of registrant as specified in its charter)

Issuer’s telephone number: (800) 203-5610

Securities registered pursuant to Section 12(b) of the Act: None

Indicate by checkmark 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 (§229.405 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 checkmark 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”, “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 standard 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 Act). Yes ☐ No ☒

As of August 9, 2023, the issuer had 10,833,800 shares of common stock, $0.0001 par value per share, outstanding.

TABLE OF CONTENTS

TABLE OF CONTENTS

WHITE RIVER ENERGY CORP

(FORMERLY FORTIUM HOLDINGS CORP.)

CONDENSED CONSOLIDATED BALANCE SHEETS

JUNE 30, 2023 (UNAUDITED) AND MARCH 31, 2023

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

WHITE RIVER ENERGY CORP

(FORMERLY FORTIUM HOLDINGS CORP.)

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (UNAUDITED)

FOR THE THREE MONTHS ENDED JUNE 30, 2023 AND 2022

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

WHITE RIVER ENERGY CORP

(FORMERLY FORTIUM HOLDINGS CORP.)

CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY (DEFICIT) (UNAUDITED)

FOR THE THREE MONTHS ENDED JUNE 30, 2023 AND 2022

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

WHITE RIVER ENERGY CORP

(FORMERLY FORTIUM HOLDINGS CORP.)

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

FOR THE THREE MONTHS ENDED JUNE 30, 2023 AND 2022

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

WHITE RIVER ENERGY CORP

(FORMERLY FORTIUM HOLDINGS CORP.)

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

JUNE 30, 2023

NOTE 1: DESCRIPTION OF BUSINESS, BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Description of Business

The terms “we,” “us,” “our,” and the “Company” refer to White River Energy Corp.

On September 19, 2022, the Company changed its name from Fortium Holdings Corp. to White River Energy Corp. On September 28, 2022, the Board of Directors and holders of the majority outstanding voting power approved the changing of the fiscal year of the Company from December 31 to March 31, and approved increasing the authorized capital to 505,000,000 shares consisting of 500,000,000 shares of common stock (from 200,000,000) and 5,000,000 shares of preferred stock. The Company filed a Certificate of Amendment to the Articles of Incorporation with the Nevada Secretary of State on September 29, 2022, and the changes became effective upon filing.

The Company executed a Share Exchange Agreement (the “Exchange Agreement”) on July 25, 2022 and pursuant to the Exchange Agreement that day acquired 100% of the outstanding shares of capital stock of White River Holdings Corp, a Delaware corporation (“Holdings”) from BitNile Metaverse, Inc. (formerly Ecoark Holdings, Inc. (“Ecoark”)), Holding’s sole stockholder. In exchange the Company issued Ecoark 1,200 shares of the newly designated non-voting Series A Convertible Preferred Stock (the “Series A”). The Series A will become convertible into approximately 42,253,521 shares of the Company’s common stock upon such time as (A) the Company has filed a Form S-1, with the Securities and Exchange Commission (the “SEC”) and such Form S-1 has been declared effective, and (B) Ecoark elects to distribute shares of the Company’s common stock to Ecoark’s stockholders. The Company filed the Form S-1 in December 2022 (File No. 333-268707) which is currently under review by the SEC Staff. The Series A has a stated value of $30 million and has a liquidation preference over the common stock and any subsequent series of junior preferred stock equal to the stated value, plus any accrued but unpaid dividends; the Series A, however, does not have any of the voting rights of common stockholders. The transaction was accounted for as a share exchange, whereby Holdings is considered the accounting acquirer. Since the share exchange occurred with a non-shell public company, the transaction included the purchase of the non-controlling interest of Fortium Holdings Corp. Except as expressly indicated in these footnotes to the contrary or where the context clearly dictates otherwise, references to “Fortium Holdings Corp.” refers to the predecessor of the Company before the Holdings share exchange was effected in July 2022.

Holdings has operations in oil and gas, including exploration, production and drilling operations on over 30,000 cumulative acres of active mineral leases Louisiana, and Mississippi.

Pursuant to the Exchange Agreement Mr. Randy May, Ecoark’s Chief Executive Officer, was appointed as Executive Chairman and as a director of the Company, and Mr. Jay Puchir, Ecoark’s Chief Financial Officer, was appointed as Chief Executive Officer and Principal Financial Officer of the Company. Effective July 28, 2022, the number of directors of the Company was fixed at five, and Danny Hames, James Cahill, Greg Landis, and Alisa Horgan were appointed as directors. Alisa Horgan is the daughter of Randy May, and wife of Richard Horgan, who was the Company’s Chief Executive Officer and sole director until after the closing of the Holdings acquisition. See Note 16. Subsequent Events for changes to our senior management.

On July 29, 2022, the Company filed a Certificate of Designation with the Nevada Secretary of State designating a new series of preferred stock as Series B Preferred Stock (the “Series B”). The single authorized share of Series B is entitled to vote with the Company’s common stock as a single class on any matter brought before the stockholders, and the Series B is entitled to a number of votes equal to the greater of (A) 100,000,000 votes, or (B) 50.1% of the Company’s voting power as of the applicable date of determination. Any outstanding Series B will be automatically cancelled upon the Company applying to have its common stock listed on a national securities exchange. As of the date of this Report, the Series B is unissued. The Series B is intended to enable the Board of Directors to act quickly to react to any potential hostile takeover. The auto-cancellation provision was included because the super-voting rights contained in the Series B would violate the rules of a prospective national securities exchange.

On October 25, 2022, the Company filed a Certificate of Designation of the Rights, Preferences and Limitations (the “Series C Certificate of Designation”) of Series C Convertible Preferred Stock (the “Series C”) with the Nevada Secretary of State. The Series C Certificate of Designation provides for the issuance of up to 1,000 shares of Series C. From October 25, 2022 through March 31, 2023, the Company sold 205.8726308 Units for $5,146,816. In April 2023, the Company sold 45.64 Units for $1,141,000, with each Unit comprised of one share of Series C and one Warrant to purchase 200% of the shares of common stock underlying such share of Series C (the “Units”) at a purchase price of $25,000 per Unit. In addition, the Company sold another 11.6 units ($290,000) to investors, for which the deposit has not been made yet. The Warrants may be separately sold by the holders rather than exercised into shares of common stock, and the Company has submitted an application for the Warrants to be traded on the OTCQB under their own unique ticker symbol.

On March 18, 2021, the Company formed Norr LLC (“Norr”), a Nevada limited liability company and wholly-owned subsidiary of the Company, and commenced operations as a sports equipment and apparel manufacturer and retailer.

On September 9, 2021, the Company formed Elysian, a Colorado corporation and wholly-owned subsidiary, for the purpose of engaging in cannabis operations.

In September 2022, the Company sold both Norr and Elysian pursuant to a Membership Interest Purchase Agreement (“MIPA”) for Norr, and a Stock Purchase Agreement for Elysian. These entities were sold to non-related third parties for $1 for Elysian and $3 for Norr. The purpose of the sale of these entities was for the Company to divest themselves of their non-core assets and focus exclusively on the oil and gas production business of Holdings.

On September 16, 2022, the Board of Directors and stockholders approved the name change of the Company from Fortium Holdings Corp. to White River Energy Corp. All paperwork were submitted to both the State of Nevada and to the Financial Industry Regulatory Authority (“FINRA”) on September 20, 2022 and subsequently approved.

The Company has reflected the operations of both Norr and Elysian post-combination in discontinued operations and have reflected the loss on disposal of these companies in the Statements of Operations.

Basis of Presentation

The Company’s unaudited condensed consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States (GAAP). Any reference in these notes to applicable guidance is meant to refer to the authoritative GAAP as found in the Accounting Standards Codification (ASC) and Accounting Standards Update (ASU) of the Financial Accounting Standards Board (FASB).

All adjustments considered necessary for a fair presentation have been included. These adjustments consist of normal and recurring accruals, as well as non-recurring charges.

As the acquisition of Holdings resulted in the owner of Holdings gaining control over the combined entity after the transaction, and the stockholders of the Company continuing only as passive investors, the transaction was not considered a business combination under the ASC. Instead, this transaction was considered to be a capital transaction of the legal acquiree (Holdings) and was equivalent to the issuance of shares by Holdings for the net monetary assets of the Company, except for the purchase of the 8,400,000 shares of issued and outstanding common shares of Fortium Holdings Corp., which were considered as purchase consideration resulting in $5,917,843 of goodwill that was impaired immediately. As a result, the historical balances represent Holdings. See the Annual Report on Form 10-K filed with the SEC on June 29, 2023 and Note 2 for further details on this transaction.

The condensed consolidated financial statements, and the accompanying notes, are prepared in accordance with GAAP and do not contain certain information included in the Company’s Annual Report on Form 10-K for the year ended March 31, 2023. Therefore, the interim condensed consolidated financial statements should be read in conjunction with those reports. Operating results for the periods presented are not necessarily indicative of the results that may be expected for the year due to various factors.

All adjustments considered necessary for a fair presentation have been included. These adjustments consist of normal and recurring accruals, as well as non-recurring charges.

Principles of Consolidation

The Company prepares its consolidated financial statements on the accrual basis of accounting. The accompanying consolidated financial statements include the accounts of the Company and its wholly owned subsidiaries. All intercompany accounts, balances and transactions have been eliminated in the consolidation.

The Company applies the guidance of Topic 810 Consolidation of the FASB ASC to determine whether and how to consolidate another entity. Pursuant to ASC Paragraph 810-10-15-10 all majority-owned subsidiaries—all entities in which a parent has a controlling financial interest—are consolidated except when control does not rest with the parent.

Pursuant to ASC Paragraph 810-10-15-8, the usual condition for a controlling financial interest is ownership of a majority voting interest, and, therefore, as a general rule ownership by one reporting entity, directly or indirectly, of more than 50 percent of the outstanding voting shares of another entity is a condition pointing toward consolidation. The power to control may also exist with a lesser percentage of ownership, for example, by contract, lease, agreement with other stockholders, or by court decree.

The Company’s wholly-owned subsidiary, White River Energy Partners Management I, LLC (formerly White River E&P Management 1, LLC) is the general partner and the only managing partner of the White River Energy Partners I, LP (formerly White River E&P 1, LP) (“WR Fund”) has control over the WR Fund, and has the power to deploy the investments from WR Fund into the Company for the various drilling projects they undertake. The name changes became effective May 30, 2023. The original Limited Partnership Agreement dated August 29, 2022 was amended by the Amended and Restated Limited Partnership Agreement dated July 12, 2023. The Company’s subsidiary is the managing partner of the WR Fund pursuant to the Amended and Restated Limited Partnership Agreement. The Company’s subsidiary, the managing general partner contributed $100 as a capital contribution, and the remaining ownership held by the limited partners are reflected as non-controlling interest in the consolidated financial statements.

All distributions from the WR Fund should be made only from revenues of the WR Fund and not from capital contributions or borrowed funds, unless otherwise determined by the Company’s subsidiary, the managing general partner. The managing general partner shall have the discretion to determine on a monthly basis whether any additional distribution shall be made and the amount, if any, of such distribution. The distributions shall be paid: (a) first, to each partner (other than the managing partner which is our subsidiary), as defined in the Amended and Restated Limited Partnership Agreement, in accordance with partner’s capital contribution percentage, until the distributions paid to each partner are equal to their total capital contributions; and (b) (i) if the distributions paid to each partner during the term of the WR Fund (the “Term”) were equal to or greater than such member’s total capital contribution, then ninety percent (90%) of the return of capital amount will be paid to each partner (other than the managing partner) and ten percent (10%) of the return of capital amount will be paid to the managing partner, (ii) if the distributions paid to each partner during the Term were less than such partner’s total capital contribution, then one hundred percent (100%) of the return of capital amount will be paid to the partners until the sum of the partners’s distributions during the Term and return of capital equal the unit holder’s total capital contribution, and (iii) if there are any return of capital amounts in excess of the partners’ total capital contribution, then ninety percent (90%) of the return of capital amount will be paid to partners and ten percent (10%) of the return of capital amount will be paid to the managing partner.

Any profit or loss in the WR Fund shall be allocated to the partners in such amounts as may be necessary or appropriate to cause the capital balance of each partner to equal, (a) the amounts such partners would receive if all assets on hand at the end of such year were sold for the gross asset value reflected for such assets on the books of the WR Fund, any partner that was obligated to contribute any amount to the WR Fund, or otherwise contributed such amount to the WR Fund, all liabilities of the WR Fund were satisfied in cash in accordance with their terms, and any remaining cash was distributed to the partners in accordance with the provisions for distributions; minus (b) an amount equal to such partner’s allocable share of the partnership minimum gain and nonrecourse debt minimum gain as computed on the last day of such fiscal year or other period in accordance with the applicable regulations, subject to allocations for organization and offering expenses, lease acquisition costs, depletion deductions with respect to oil and gas properties, all intangible drilling costs deductible under Section 263(c) of the Internal Revenue Code, and profits resulting from operations as determined by the managing general partner. Losses allocated to any unit holder for any taxable year shall not exceed the maximum amount of losses that may be allocated to such unit holder without causing such partner to have an adjusted capital account deficit at the end of such taxable year. All losses in excess of the limitation shall be allocated solely to the other partners. If no other partners may receive an additional allocation of losses, such additional losses shall be allocated solely to the general partners as determined by the managing partner. The managing partner shall have the discretion to allocate and reallocate profit and loss so as to conform each partner’s capital account to such unit holder’s rights to distributions, insofar as reasonably possible.

The consolidated financial statements include the results of the WR Fund and the Company has eliminated all intercompany transactions. The WR Fund will incur direct expenses related to both the annual management fee and oil production from the working interests it owns in oil and gas wells; the managing partner, however, does not plan to charge any indirect costs such as audit, tax, legal, or fund administration to the WR Fund. These costs will be offset by the annual management fee, and if excess costs are incurred by the WR Fund over the proceeds from the annual management fee, then the Company will subsidize these expenses to enable the WR Fund to make greater distributions to partners.

Reclassifications

The Company has reclassified certain amounts in the June 30, 2022 condensed consolidated financial statements to be consistent with the June 30, 2023 presentation. These changes had no impact on the Company’s financial position or result of operations for the periods presented.

Cash and Cash Equivalents

Cash equivalents include demand deposits with banks and all highly liquid investments with original maturities of three months or less. The Company has in the past maintained balances in financial institutions where deposits may exceed the federally insured deposit limit of $250,000. The Company has not experienced any losses from such accounts and does not believe it is exposed to any significant credit risk on cash.

The Company’s restricted cash is in the form of certificates of deposit that secure our oil and gas properties.

Use of Estimates

The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and reported amounts of revenues and expenses during the reporting period. These estimates include, but are not limited to, management’s estimate of provisions required for uncollectible accounts receivable, cost allocation percentages, impaired value of equipment and intangible assets, including goodwill, asset retirement obligations, estimates of discount rates in lease, liabilities to accrue, fair value of derivative liabilities associated with warrants and conversion options, cost incurred in the satisfaction of performance obligations, permanent and temporary differences related to income taxes and determination of the fair value of stock awards.

Actual results could differ from those estimates.

The estimates of proved, probable and possible oil and gas reserves are used as significant inputs in determining the depletion of oil and gas properties and the impairment of proved and unproved oil and gas properties. There are numerous uncertainties inherent in the estimation of quantities of proven, probable and possible reserves and in the projection of future rates of production and the timing of development expenditures. Similarly, evaluations for impairment of proved and unproved oil and gas properties are subject to numerous uncertainties including, among others, estimates of future recoverable reserves and commodity price outlooks. Actual results could differ from the estimates and assumptions utilized.

Oil and Gas Properties

The Company uses the full cost method of accounting for its investment in oil and natural gas properties. Under the full cost method of accounting, all costs associated with acquisition, exploration and development of oil and gas reserves, including directly related overhead costs are capitalized. General and administrative costs related to production and general overhead are expensed as incurred.

All capitalized costs of oil and gas properties, including the estimated future costs to develop proved reserves, are amortized on the unit of production method using estimates of proved reserves. Disposition of oil and gas properties are accounted for as a reduction of capitalized costs, with no gain or loss recognized unless such adjustment would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in operations. Costs associated with unevaluated properties are excluded from the full-cost pool until the Company has made a determination as to the existence of proved reserves. The Company reviews its unevaluated properties at the end of each quarter to determine whether the costs incurred should be transferred to the full-cost pool and thereby subject to amortization. Additionally, the Company assesses all properties classified as unevaluated properties on a quarterly basis for possible impairment. During any period in which these factors indicate impairment, the cumulative drilling costs incurred to date for such properties are transferred to the full-cost pool and are then subject to depletion and the full-cost ceiling test limitation.

There was $57,811 and $102,223 in depletion expense of reserves for the Company’s oil and gas properties for the three months ended June 30, 2023 and 2022, respectively. In addition, the Company impaired $141,965 and $28,265 during the three months ended June 30, 2023 and 2022, respectively.

Limitation on Capitalized Costs

Under the full-cost method of accounting, we are required, at the end of each reporting period, to perform a test to determine the limit on the book value of our oil and gas properties (the “Ceiling” test). If the capitalized costs of our oil and natural gas properties, net of accumulated amortization and related deferred income taxes, exceed the Ceiling, the excess or impairment is charged to expense. The expense may not be reversed in future periods, even though higher oil and gas prices may subsequently increase the Ceiling.

The Ceiling is defined as the sum of: (a) the present value, discounted at 10% and assuming continuation of existing economic conditions, of (1) estimated future gross revenues from proved reserves, which is computed using oil and gas prices determined as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month hedging arrangements pursuant to Staff Accounting Bulletin (“SAB”) 103, less (2) estimated future expenditures (based on current costs) to be incurred in developing and producing the proved reserves; plus, (b) the cost of properties being amortized; plus, (c) the lower of cost or estimated fair value of unproven properties included in the costs being amortized; net of (d) the related tax effects related to the difference between the book and tax basis of our oil and natural gas properties. A ceiling test was performed as of June 30, 2023. The Company recognized impairment of $141,965 and $28,265 for the three months ended June 30, 2023 and 2022, respectively.

Oil and Gas Reserves

Reserve engineering is a subjective process that is dependent upon the quality of available data and interpretation thereof, including evaluations and extrapolations of well flow rates and reservoir pressure. Estimates by different engineers often vary sometimes significantly. In addition, physical factors such as results of drilling, testing and production subsequent to the date of an estimate, as well as economic factors such as changes in product prices, may justify revision of such estimates. Because proved reserves are required to be estimated using recent prices of the evaluation, estimated reserve quantities can be significantly impacted by changes in product prices.

Joint Interest Activities

Certain of our exploration, development and production activities are conducted jointly with other entities and, accordingly, the consolidated financial statements reflect only our proportionate interest in such activities.

Inventories

Crude oil is carried at the lower of cost (last-in-first-out (LIFO)) or net realizable value. Inventory costs include expenditures and other charges directly and indirectly incurred in bringing the inventory to its existing condition and location.

Accounting for Asset Retirement Obligation

The Company follows the provisions of ASC Topic 410, “Asset Retirement and Environmental Obligations” which addresses financial accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs. The standard requires that the Company recognize the fair value of a liability for an asset retirement obligation (“ARO”) in the period in which it is incurred. The ARO is capitalized as part of the carrying value of the assets to which it is associated and depreciated over the useful life of the asset. The ARO and the related asset retirement cost are recorded when an asset is first drilled, constructed or purchased. The asset retirement cost is determined and discounted to present value using a credit-adjusted risk-free rate over the estimated economic life of the oil and gas properties. After initial recording, the liability is periodically adjusted to reflect (1) new liabilities incurred, (2) liabilities settled during the period, (3) accretion expense, and (4) revisions to estimated future cash flow requirements resulting from changes in the estimated future costs or the estimated economic useful lives of the oil and gas properties. Subsequent adjustments in the cost estimate are reflected in the ARO liability and the amounts continue to be amortized over the useful life of the related long-lived assets.

Accounts Receivable and Concentration of Credit Risk

When the Company records an allowance for doubtful accounts it is based on management’s estimate of the overall collectability of accounts receivable, considering historical losses, credit insurance and economic conditions. Based on these same factors, individual accounts are charged off against the allowance when management determines those individual accounts are uncollectible. Credit extended to customers is generally uncollateralized. Past-due status is based on contractual terms. Substantially all of the Company’s accounts receivable result from joint interest billings to its working interest partners. As of June 30, 2023 and March 31, 2023, the Company had established $1,325,678 and $650,562 in allowances for doubtful accounts. The Company has also established a reserve in the amount of $1,380,627 during the three months ended June 30, 2023, related to a receivable due under participation agreements entered into during the year ended March 31, 2023.

Impairment of Long-lived Assets and Goodwill

ASC 360 requires that long-lived assets and certain identifiable intangibles held and used by an entity be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. The Company has adopted Accounting Standard Update (“ASU”) 2017-04 Intangibles – Goodwill and Other (Topic 350), Simplifying the Test for Goodwill Impairment.

The Company reviews recoverability of long-lived assets on a periodic basis whenever events and changes in circumstances have occurred which may indicate a possible impairment. The assessment for potential impairment is based primarily on the Company’s ability to recover the carrying value of its long-lived assets from expected future cash flows from its operations on an undiscounted basis. If such assets are determined to be impaired, the impairment recognized is the amount by which the carrying value of the assets exceeds the fair value of the assets.

Fixed assets and intangible assets with finite useful lives are stated at cost less accumulated amortization and impairment.

The Company assesses the impairment of identifiable intangibles whenever events or changes in circumstances indicate that the carrying value may not be recoverable. Factors the Company considers to be important which could trigger an impairment review include the following:

1. Significant underperformance relative to expected historical or projected future operating results;

2. Significant changes in the manner of use of the acquired assets or the strategy for the overall business; and

3. Significant negative industry or economic trends.

When the Company determines that the carrying value of intangibles may not be recoverable based upon the existence of one or more of the above indicators of impairment and the carrying value of the asset cannot be recovered from projected undiscounted cash flows, the Company records an impairment charge. The Company measures any impairment based on a projected discounted cash flow method using a discount rate determined by management to be commensurate with the risk inherent in the current business model. Significant management judgment is required in determining whether an indicator of impairment exists and in projecting cash flows. The Company impaired all of their goodwill in the year ended March 31, 2023.

Property and Equipment and Long-Lived Assets

Property and equipment is stated at cost. Depreciation on property and equipment is computed using the straight-line method over the estimated useful lives of the assets.

Fair Value Measurements

The accounting guidance defines fair value, establishes a consistent framework for measuring fair value and expands disclosure for each major asset and liability category measured at fair value on either a recurring or non-recurring basis. Fair value is defined as an exit price, representing the amount that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. As such, fair value is a market-based measurement that should be determined based on assumptions that market participants would use in pricing an asset or liability. As a basis for considering such assumptions, the accounting guidance establishes a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value as follows:

Level 1: Observable inputs such as quoted prices in active markets.

Level 2: Inputs, other than the quoted prices in active markets that are observable either directly or indirectly.

Level 3: Unobservable inputs in which there is little or no market data, which require the reporting entity to develop its own assumptions.

The carrying values of the Company’s financial instruments such as cash, accounts receivable, prepaid expenses, accounts payable, and accrued expenses approximate their respective fair values because of the short-term nature of those financial instruments.

Revenue Recognition

The Company accounts for revenue in accordance with ASC Topic 606, Revenue from Contracts with Customers.

The core principle of the revenue standard is that a company should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. The following five steps are applied to achieve that core principle:

● Step 1: Identify the contract with the customer  

● Step 2: Identify the performance obligations in the contract  

● Step 3: Determine the transaction price  

● Step 4: Allocate the transaction price to the performance obligations in the contract  

● Step 5: Recognize revenue when the Company satisfies a performance obligation   

In order to identify the performance obligations in a contract with a customer, a company must assess the promised goods or services in the contract and identify each promised good or service that is distinct. A performance obligation meets ASC 606’s definition of a “distinct” good or service (or bundle of goods or services) if both of the following criteria are met: The customer can benefit from the good or service either on its own or together with other resources that are readily available to the customer (i.e., the good or service is capable of being distinct), and the entity’s promise to transfer the good or service to the customer is separately identifiable from other promises in the contract (i.e., the promise to transfer the good or service is distinct within the context of the contract).

If a good or service is not distinct, the good or service is combined with other promised goods or services until a bundle of goods or services is identified that is distinct.

The transaction price is the amount of consideration to which an entity expects to be entitled in exchange for transferring promised goods or services to a customer. The consideration promised in a contract with a customer may include fixed amounts, variable amounts, or both. When determining the transaction price, an entity must consider the effects of all of the following:

● Variable consideration  

● Constraining estimates of variable consideration  

● The existence of a significant financing component in the contract  

● Noncash consideration  

● Consideration payable to a customer  

Variable consideration is included in the transaction price only to the extent that it is probable that a significant reversal in the amount of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is subsequently resolved. The transaction price is allocated to each performance obligation on a relative standalone selling price basis. The transaction price allocated to each performance obligation is recognized when that performance obligation is satisfied, at a point in time or over time as appropriate.

The Company accounts for contract costs in accordance with ASC Topic 340-40, Contracts with Customers. The Company recognizes the cost of sales of a contract as expense when incurred or at the time a performance obligation is satisfied. The Company recognizes an asset from the costs to fulfil a contract only if the costs relate directly to a contract, the costs generate or enhance resources that will be used in satisfying a performance obligation in the future and the costs are expected to be recovered. The incremental costs of obtaining a contract are capitalized unless the costs would have been incurred regardless of whether the contract was obtained.

All revenue is recorded at a point in time.

In continuing operations, the Company only recognizes revenue from one source, oil and gas production and services.

The Company recognizes revenue for their proportionate share of revenue when: (i) the Company receives notification of the successful sale of a load of crude oil to a buyer; and (ii) the buyer will provide a price based on the average monthly price of crude oil in the most recent month.

Share-Based Payment Arrangements

The Company has accounted for stock-based compensation arrangements in accordance with Accounting Standards Codification subtopic 718-10, Compensation (“ASC 718”). This guidance addresses all forms of share-based payment awards including shares issued under employee stock purchase plans, stock options, restricted stock and stock appreciation rights, as well as share grants and other awards issued to employees and non-employees under free-standing arrangements. These awards are recorded at costs that are measured at fair value on the awards’ grant dates, based on the estimated number of awards that are expected to vest and will result in charges to operations.

Derivative Financial Instruments

The Company does not use derivative instruments to hedge exposures to cash flow, market, or foreign currency risks. Management evaluates all of the Company’s financial instruments, including warrants, to determine if such instruments are derivatives or contain features that qualify as embedded derivatives. The Company generally uses a Black-Scholes model, as applicable, to value the derivative instruments at inception and subsequent valuation dates when needed. The classification of derivative instruments, including whether such instruments should be recorded as liabilities or as equity, is re-measured at the end of each reporting period. The Black-Scholes model is used to estimate the fair value of the derivative liabilities.

Earnings (Loss) Per Share of Common Stock

Basic net income (loss) per common share is computed using the weighted average number of common shares outstanding. Diluted earnings per share (“EPS”) include additional dilution from common stock equivalents, such as stock issuable pursuant to the exercise of stock options and warrants and conversions of preferred stock into common stock. Common stock equivalents are not included in the computation of diluted earnings per share when the Company reports a loss because to do so would be anti-dilutive for periods presented, so only basic weighted average number of common shares are used in the computations.

Recently Issued Accounting Pronouncements

In May 2021, the Financial Accounting Standards Board (“FASB”) issued ASU 2021-04 “Earnings Per Share (Topic 260), Debt—Modifications and Extinguishments (Subtopic 470-50), Compensation— Stock Compensation (Topic 718), and Derivatives and Hedging—Contracts in Entity’s Own Equity (Subtopic 815- 40) Issuer’s Accounting for Certain Modifications or Exchanges of Freestanding Equity-Classified Written Call Options” which clarifies and reduces diversity in an issuer’s accounting for modifications or exchanges of freestanding equity-classified written call options (for example, warrants) that remain equity classified after modification or exchange. An entity should measure the effect of a modification or an exchange of a freestanding equity-classified written call option that remains equity classified after modification or exchange as follows: i) for a modification or an exchange that is a part of or directly related to a modification or an exchange of an existing debt instrument or line-of-credit or revolving-debt arrangements (hereinafter, referred to as a “debt” or “debt instrument”), as the difference between the fair value of the modified or exchanged written call option and the fair value of that written call option immediately before it is modified or exchanged; ii) for all other modifications or exchanges, as the excess, if any, of the fair value of the modified or exchanged written call option over the fair value of that written call option immediately before it is modified or exchanged.

The amendments in this Update are effective for all entities for fiscal years beginning after December 15, 2021, including interim periods within those fiscal years. An entity should apply the amendments prospectively to modifications or exchanges occurring on or after the effective date of the amendments. The Company has determined this new guidance will not have a material impact on its consolidated financial statements.

In August 2020, the FASB issued ASU No. 2020-06, Debt-Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging-Contracts in Entity’s Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity (“ASU 2020-06”), which simplifies the accounting for convertible instruments by removing the separation models for (1) convertible debt with a cash conversion feature and (2) convertible instruments with a beneficial conversion feature. ASU 2020-06 also requires the application of the if-converted method for calculating diluted earnings per share and the treasury stock method will be no longer available. This standard will be effective for smaller reporting companies in fiscal years beginning after December 15, 2023, with early adoption permitted. The Company early adopted the new standard beginning April 1, 2023 and the adoption did not have a material impact on our consolidated financial statements.

In June 2016, the Financial Accounting Standards Board (FASB) issued ASU No. 2016-13, Financial Instruments - Credit Losses (Topic 326) Measurement of Credit Losses on Financial Instruments (ASU 2016-13), which requires an entity to utilize a new impairment model known as the current expected credit loss (CECL) model to estimate its lifetime “expected credit loss” for financial assets held. ASU 2016-13 requires a cumulative effect adjustment to the balance sheet as of the beginning of the first reporting period in which the guidance is effective. In November 2019, the FASB issued ASU 2019-10, Financial Instruments—Credit Losses (Topic 326), Derivatives and Hedging (Topic 815) and Leases (Topic 842): Effective Dates, which defers the effective date of ASU 2016-13 to fiscal years beginning after December 15, 2022 for all entities except SEC reporting companies that are not smaller reporting companies. The Company adopted this new accounting guidance effective April 1, 2023 and the adoption did not have a material impact on our consolidated financial statements.

The Company does not discuss recent pronouncements that are not anticipated to have an impact on or are unrelated to its financial condition, results of operations, cash flows or disclosures.

Going Concern and Liquidity

The Company raised capital through a private investment in a public equity (PIPE) and raised approximately $6,288,000 through the end of April 2023 from this PIPE offering, together with approximately $2,811,609 received from Participation Agreements to provide the funds necessary for the Company’s drilling program. The Company also began receiving drilling capital from the limited partners of the WR Fund during the year ended March 31, 2023. The Company has incurred a net loss from operations and has a net capital deficiency that raises substantial doubt about its ability to continue as a going concern.

The accompanying financial statements for the three months ended June 30, 2023 have been prepared assuming the Company will continue as a going concern, but the ability of the Company to continue as a going concern is dependent on the Company obtaining adequate capital to fund operating losses until it establishes a revenue stream and becomes profitable. Management’s plans to continue as a going concern include raising additional capital through sales of equity securities and borrowing. However, management cannot provide any assurances that the Company will be successful in accomplishing any of its plans. If the Company is not able to obtain the necessary additional financing on a timely basis, the Company will be required to delay, and reduce the scope of the Company’s development and operations. Continuing as a going concern is dependent upon its ability to successfully secure other sources of financing and attain profitable operations. The accompanying consolidated financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.

NOTE 2: MERGER

The acquisition of Holdings was considered a reverse merger. In accordance with ASC 805-40-45-1, the consolidated financial statements prepared following a reverse acquisition are issued under the name of the legal parent (White River Energy Corp) but described in the notes to the financial statements as a continuation of the financial statements of the legal subsidiary (Holdings), with one adjustment, which is to retroactively adjust the accounting acquirer’s legal capital to reflect the legal capital of the accounting acquiree (White River Energy Corp). That adjustment is required to reflect the capital of the legal parent. Comparative information presented in the consolidated financial statements also is retroactively adjusted to reflect the legal capital of the legal parent.

Under ASC 805-40-45-2, the consolidated financial statements represent the continuation of the legal subsidiary except for the capital structure, as follows:

Fortium Holdings Corp. issued Ecoark 1,200 shares of Series A valued at $30,000,000 in the share exchange transaction. On an as converted basis, the 1,200 Series A shares convert to 42,253,521 shares of common stock which represents approximately 80% of the total issued and outstanding shares on a fully diluted basis at the time of the merger.

On July 25, 2022, the Company completed the share exchange transaction with Holdings. As a result of this transaction, which is accounted for as a share exchange, Holdings is a wholly owned subsidiary of the Company (the “Merger”). In accordance with the terms of the Merger, at the effective time of the Merger, the outstanding shares of the common stock of Holdings were exchanged for the 1,200 shares of Series A of the Company. This exchange of shares and the resulting controlling ownership of the Company constitutes a reverse acquisition and purchase accounting being applied to the net assets acquired from Fortium Holdings Corp. under ASC 805 due to Holdings being the accounting acquirer and Fortium Holdings Corp., being deemed an acquired business as they were not a shell corporation. This requires financial reporting from the Merger close date forward to reflect only the historic consolidated results of Holdings and to include the consolidated results for the Company and subsidiaries from July 25, 2022 forward.

The previously existing businesses of the Company at the time of the Merger, consisting of Norr and Elysian, were sold within 60 days of the Merger taking place.

The estimated allocation of the purchase price of the assets acquired and liabilities assumed for the acquisition by Holdings of Fortium Holdings Corp. via the reverse acquisition are set forth below in accordance with the guidance under ASC 805:

 SCHEDULE OF PURCHASE PRICE ALLOCATION

This allocation is based on management’s estimated fair value of the Fortium Holdings Corp assets and liabilities as of July 25, 2022 utilizing the guidance in ASC 820-10-35 which included the measurement based on a known level one input regarding the applicable share price as well as the level of activity in the Company and the fact that the value was driven off of a business no longer included in the Company’s current operations. Fortium Holdings Corp. assets were derived from a total value of $5,964,000, based on 8,400,000 shares of common stock outstanding on July 25, 2022 and the closing price that day of $0.71 per share. The Company impaired the goodwill effective with the Merger on July 25, 2022, as they had decided at that time to sell the Norr and Elysian businesses, although the sales were effected later in September 2022. The Company sold these two entities for a total of $4 in September 2022. The loss on the sale is reflected as a loss on disposal in the consolidated statements of operations.

The following table shows the unaudited pro-forma results for the three months ended June 30, 2022, as if the acquisitions had occurred on April 1, 2022.

 SCHEDULE OF BUSINESS ACQUISITION

The condensed consolidated statements of operations and cash flows represent the operations of Holdings for the three months ended June 30, 2022 include cost allocations from Holding’s former parent Ecoark as discussed below.

Cost Allocations

The consolidated financial statements of Holdings have been prepared in connection with the expected separation and have been derived from the consolidated financial statements and accounting records of Ecoark operated on a standalone basis during the periods presented and were prepared in accordance with GAAP.

The consolidated financial statements reflect allocations of certain Ecoark corporate, infrastructure and shared services expenses, including centralized research, legal, human resources, payroll, finance and accounting, employee benefits, real estate, insurance, information technology, telecommunications, treasury, and other income and expenses for interest expense on debt that portions were used for Holdings, changes in derivative liabilities on the books of Ecoark for Warrants granted in offerings of which proceeds went towards the operations of Holdings, and conversions of debt. Where possible, these charges were allocated based on direct usage, with the remainder allocated on a pro rata basis of headcount, asset, or other allocation methodologies that are considered to be a reasonable reflection of the utilization of services provided or the benefit received by the Company during the periods presented pursuant to SAB Topic 1.B.1. The allocations may not, however, reflect the expense the Company would have incurred as a standalone company for the periods presented. These costs also may not be indicative of the expenses that the Company will incur in the future or would have incurred if the Company had obtained these services from a third party.

Management believes the assumptions underlying our financial statements, including the assumptions regarding the allocation of general corporate expenses from the former parent company are reasonable. Nevertheless, our financial statements may not include all of the actual expenses and income that would have been incurred had we operated as a standalone company during the periods presented and may not reflect our results of operations, financial position and cash flows had we operated as a standalone company during the periods presented.

Actual costs that would have been incurred if we had operated as a standalone company would depend on multiple factors, including organizational structure and strategic decisions made in various areas, including information technology and infrastructure.

NOTE 3: PROPERTY AND EQUIPMENT

Property and equipment consisted of the following as of June 30, 2023 (unaudited) and March 31, 2023:

SCHEDULE OF PROPERTY AND EQUIPMENT

Depreciation expense for the three months ended June 30, 2023 and 2022 was $86,775 and $20,030, respectively. Depreciation does not include items in fixed assets that are not in service.

NOTE 4: OIL AND GAS PROPERTIES

Activity in the year ended March 31, 2023 consist of the following:

For the three months ended June 30, 2022, the Company received proceeds of $999,999 from a related party for the sale of wells which were recorded in the full-cost pool.

The WR Fund received limited partnership interests during the year ended March 31, 2023 in the amount of $3,244,653 for two drilling projects in Louisiana and Mississippi which funds were spent by the Company. There were no amounts collected during the three months ended June 30, 2023. The amounts received in the year ended March 31, 2023 are reflected in our unevaluated wells in progress as of June 30, 2023. These projects were not completed during the three months ended June 30, 2023.

The following table summarizes the Company’s oil and gas activities by classification as of June 30, 2023 (unaudited) and March 31, 2023.

SCHEDULE OF OIL AND GAS ACTIVITIES

There was $57,811 and $102,223 in depletion expense of reserves for the Company’s oil and gas properties for the three months ended June 30, 2023 and 2022, respectively. In addition, the Company impaired $141,965 and $28,265 during the three months ended June 30, 2023 and 2022, respectively.

Unevaluated Wells in Progress

The following table summarizes the Company’s unevaluated wells in progress for the periods ended June 30, 2023 and 2022.

SUMMARY OF UNEVALUATED WELLS IN PROGROSS

During the three months ended June 30, 2023, the Company conducted two drilling projects (a) Peabody AMI 12 #18, and (b) Denmiss #1. The Company anticipates completion of these projects in their second fiscal quarter ending September 30, 2023. The exploration costs above represent the costs incurred for the three months ended June 30, 2023 on those two projects. The Company reviews its unevaluated properties at the end of each quarter to determine whether the costs incurred should be transferred to the full-cost pool and thereby subject to amortization.

NOTE 5: ASSET RETIREMENT OBLIGATIONS

In conjunction with the approval permitting the Company to resume drilling in the existing fields, the Company has recorded an asset retirement obligation (“ARO”) based upon the plan submitted in connection with the permit. The ARO results from the Company’s responsibility to abandon and reclaim their net share of all working interest properties and facilities.

The following table summarizes activity in the Company’s ARO for the three months ended June 30, 2023 and 2022 (unaudited):

SCHEDULE OF ASSET RETIREMENT OBLIGATIONS

Total ARO at June 30, 2023 and 2022 shown in the table above consists of amounts for future plugging and abandonment liabilities on our wellbores and facilities based on third-party estimates of such costs, adjusted for inflation for the three months ended June 30, 2023 and 2022, respectively. These values are discounted to present value at 8% per annum for the three months ended June 30, 2023 and 2022.

NOTE 6: LONG-TERM DEBT

Long-term debt consisted of the following as of June 30, 2023 (unaudited) and March 31, 2023.

SCHEDULE OF LONG-TERM DEBT 

The following is a list of maturities as of June 30:

 SCHEDULE OF MATURITIES

Interest expense on long-term debt during the three months ended June 30, 2023 and 2022 are $10,042 and $2,421, respectively.

NOTE 7: SENIOR SECURED CONVERTIBLE PROMISSORY NOTE

Convertible Note Transaction

On December 20, 2022, the Company entered into a Securities Purchase Agreement (“SPA”) with an accredited investor (the “Purchaser”) whereby the Purchaser lent the Company an aggregate of $1,500,000 in gross proceeds and the Company issued the Purchaser a 10% Original Issue Discount Senior Secured Convertible Promissory Note in the principal amount of $1,666,666.67 (the “Note”). The proceeds are being used for working capital and growth capital.

Pursuant to the SPA, the Company, its direct and indirect subsidiaries, and Jay Puchir and Randy May, executive officers of the Company, entered into Guarantee Agreements (the “Guarantee”) with the Purchaser pursuant to which each subsidiary and Messrs. Puchir and May personally guaranteed to the Purchaser the payment of the Note. In addition, Messrs. Puchir and May pledged the shares of the Company’s common stock they hold or have the right to acquire in the anticipated distribution of the Company’s common stock by Ecoark as collateral to secure the Company’s obligations under the Note, and each individual also executed affidavits of confession to that effect. The affidavits of confession signed by Messrs. Puchir and May in connection with their Guarantees will permit the Purchaser to obtain a judgment against them personally upon the occurrence of an event of default without having to file a lawsuit.

The Note was due September 16, 2023. The Note bears interest at a rate of 12% per annum, payable monthly, subject to an increase to 18% per annum in case of an event of default as provided for therein. In addition, all overdue accrued and unpaid principal and interest is subject to a late fee at an interest rate equal to the lesser of 18% per annum or the maximum rate permitted by applicable law which if applicable accrues daily from the date such principal and interest is due.

The Note is convertible into shares of the Company’s common stock at any time following the issuance date at the Purchaser’s option at a conversion price equal to the lesser of (i) $1.00 per share and (ii) the average of the five-closing prices of the common stock immediately prior to the date of conversion, subject to certain adjustments (including based on the issuance of lower priced securities) and beneficial ownership limitations. Upon an event of default, the Purchaser may convert the Note at a reduced conversion price equal to 70% of the lowest closing price of the common stock for the 10 prior trading days.

Under the Note, beginning on April 16, 2023 the Company was required to pay monthly installments equal to one-fourth of the original principal amount at 120% of such principal amount, plus accrued but unpaid interest and any other amounts outstanding under the Note, with each payment resulting in a reduction in the principal of the Note at 100% (as compared to 120%). Furthermore, at any time after the issuance date of the Note, the Company may, after written notice to the Purchaser, prepay the Note in an amount equal to 120% of the then outstanding principal amount, plus accrued but unpaid interest and any other amounts outstanding under the Note. The Company will also be required to offer to pay the Note at 120% of the principal amount plus any unpaid accrued interest, upon the occurrence of certain events including (i) a change of control or sale of assets, (ii) a sale by the Company of equity or debt securities for gross proceeds to the Company of at least $5 million, and (iii) upon the maturity of the Note. The Company paid $625,000 in April through June 2023, and the Note is currently in good standing.

The Note is secured by the assets of the Company and its subsidiaries. The Note provides for certain events of default, including failure to pay amounts owing on the Note when due, failure to observe other covenants or obligations under the Note, default under any other indebtedness or material contract, a bankruptcy event with respect to the Company or a significant subsidiary, failure to maintain listing or quotation of the common stock on a trading market, failure to maintain the current public information requirement under Rule 144, and a judgment or similar process against the Company or any of its subsidiaries or assets in excess of $100,000. Upon an event of default, the Purchaser may cause the Note to become immediately due and payable and require the Company to pay 125% of the then outstanding principal amount, plus accrued but unpaid interest and any other amounts outstanding under the Note.

Further, pursuant to the Note the Company is subject to certain restrictive covenants, including covenants against incurring new indebtedness or liens on its assets, paying cash dividends or distributions on any equity securities, or entering into transactions with affiliates, subject to certain exceptions. In addition, under the Note the Company agreed to at all times reserve three times the number of shares of common stock into which the Note is convertible. The Company is in compliance with the covenants as of June 30, 2023.

In addition, pursuant to the SPA, the Company entered into a Registration Rights Agreement with each Purchaser in which the Purchasers are entitled to “piggyback” registration rights, pursuant to which the Company has agreed to include the underlying shares of common stock from the conversion of the Note in a registration statement, if the Company files a registration statement for another purpose, subject to certain terms and conditions.

On May 10, 2023, the Company entered into an amendment with the holder of the 10% Original Issue Discount Secured Convertible Note dated December 16, 2022 (see Note 7), and the designated counterparty under that certain Letter Agreement dated December 16, 2022 pursuant to which the Note and Consulting Agreement were amended as follows: (A) with respect to the Note, (i) the monthly redemption payment obligation was eliminated, (ii) the mandatory prepayment amount with respect to principal was increased from 120% to 127.5%, or $2,125,000, (iii) the mandatory default amount with respect to principal was increased from 125% to 132.5%, or $2,208,333.34; and (iv) the optional redemption amount with respect to principal was increased from 120% to 127.5%, or $2,125,000; and (B) with respect to the Consulting Agreement, an additional clause was added providing that the consultant shall receive on the date ending 180 days after the date a registration statement filed by the company registering the sale of the shares issuable thereunder is declared effective by the SEC, an additional number of shares of common stock if necessary such that the consultant shall have received a number of shares equal to $1,666,666.67 divided by the price per share of the common stock as of such date.

The conversion terms of the Note required the Company to bifurcate the conversion option from the host and classify the conversion option as a derivative liability under ASC 815. The value of the derivative liability at inception was $923,956.

During the three months ended June 30, 2023, the Company incurred interest expense of $39,584, amortization of original issue discount on the convertible note of $56,354, and amortization of debt discount of $358,194. The Company repaid $625,000 of the convertible note payable. The value of the derivative liability related to the convertible note at June 30, 2023 is $305,073. The convertible note is valued at $762,379, net of discounts. See Note 16. - Subsequent Events for information on certain amendments and a subsequent loan to the Company.

Consulting Agreement

On December 20, 2022, the Company entered into a Consulting Agreement with an affiliate of the Purchaser described above (the “Consultant”), pursuant to which the Company agreed to issue shares 1,666,667 shares of common stock, subject to upward adjustment to the extent the closing price per share of the Company’s common stock is below $1.00 as of (i) the date a registration statement registering the resale by the Consultant of its shares of common stock is declared effective by the SEC (the “Effective Date”), and/or (ii) 90 days after the Effective Date. In such event, the number of shares will be increased to the quotient obtained by dividing $1,666,666.67 by the closing price of the common stock. The value of $1,666,667 was expensed as stock-based compensation under this agreement. The Company also agreed to indemnify the Consultant pursuant to indemnification provisions attached to the Consulting Agreement.

NOTE 8: DERIVATIVE LIABILITIES

The Company issued Units consisting of Series C Preferred Stock and Warrants in a PIPE financing (see Note 9) and a Note payable (see Note 7) in two transactions (“Derivative Instruments”). The Series C Warrants as well as the conversion option on the Note payable contained characteristics that required the Company to classify them as derivative liabilities. The Derivative Instruments have been accounted for utilizing ASC 815 “Derivatives and Hedging.”

The Company identified embedded features in some of the agreements which were classified as liabilities. These embedded features included a variable conversion price that would convert those instruments into a variable number of common shares. The accounting treatment of derivative financial instruments requires that the Company treat the instrument as liability and record the fair value of the instrument as derivatives as of the inception date of the instrument and to adjust the fair value of the instrument as of each subsequent balance sheet date.

The Company determined the derivative liabilities to be a Level 3 fair value measurement and used the Black-Scholes pricing model to calculate the fair value. The Black-Scholes model requires six basic data inputs: the exercise or strike price, expected term, the risk-free interest rate, the current stock price, the estimated volatility of the stock price in the future, and the dividend rate.

Changes to these inputs could produce a significantly higher or lower fair value measurement. The fair value of each derivative instrument is estimated using the Black-Scholes valuation model. The following assumptions were used during the three months ended June 30, 2023 and 2022:

SCHEDULE OF FAIR VALUE OF EACH WARRANTS 

Derivative liabilities as of June 30, 2023 (unaudited) and March 31, 2023 are as follows.

SCHEDULE OF REMAINING DERIVATIVE LIABILITIES 

Activity related to the derivative liabilities for the three months ended June 30, 2023 is as follows:

 SCHEDULE OF ACTIVITY RELATED TO THE DERIVATIVE LIABILITIES

The change in fair value of the derivative liability for the three months ended June 30, 2023 was $2,343,320.

There were no derivative liabilities in the three months ended June 30, 2022.

NOTE 9: STOCKHOLDERS’ EQUITY (DEFICIT)

On September 28, 2022, the Company increased its authorized capital to 505,000,000 shares consisting of 500,000,000 shares of common stock (from 200,000,000) and 5,000,000 shares of preferred stock. See Note 1.

The Company executed the Exchange Agreement on July 25, 2022 and pursuant to the Exchange Agreement that day acquired 100% of the outstanding shares of capital stock of Holdings from Ecoark, Holding’s sole stockholder. In exchange the Company issued Ecoark 1,200 shares of the newly designated Series A. See Note 1 under “Description of Business” for more details on the Series A.

The Series A has a stated value of $30 million and has a liquidation preference over the common stock and any subsequent series of junior preferred stock equal to the stated value, plus any accrued but unpaid dividends.

On July 29, 2022, the Company filed a Certificate of Designation with the Nevada Secretary of State designating a new series of preferred stock, the Series B. See Note 1 under “Description of Business” for more details on the Series B.

On October 25, 2022, the Company filed a Certificate of Designation of the Rights, Preferences and Limitations of Series C Convertible Preferred Stock (the “Series C Certificate of Designation”) with the Nevada Secretary of State. The Series C Certificate of Designation provides for the issuance of up to 1,000 shares of Series C. See Note 1 under “Description of Business” and the below section in Note 9 “Series C Convertible Preferred Stock” for more details on the Series C.

From October 19, 2022 through June 30, 2023, the Company entered into a Securities Purchase Agreement (“SPA”) pursuant to which the Company sold 251.5126308 Units to accredited investors, with each Unit consisting of one share of Series C and five-year Warrants to purchase up to 200% of the shares of common stock issuable upon conversion of the Series C, at a purchase price of $25,000 per Unit for a total purchase price of $6,287,816 in the PIPE Offering. In addition, the Company sold another 11.6 units ($290,000) to investors, for which the deposit has not been made yet. The Warrants may be separately sold by the holders rather than exercised into shares of common stock, and the Company has submitted an application for the Warrants to be traded on the OTCQB under their own unique ticker symbol.

The net proceeds from the PIPE Offering, after offering expenses and related costs, have been used for working capital and general corporate purposes including oil and gas drilling on the Company’s working interests in Louisiana and Mississippi. The shares of the Series C are expected to be converted upon the effective registration of the Registration Statement filed by the Company.

In June 2023, the Company issued 167,133 shares to its three non-employee directors that were earned through March 31, 2023.

Restricted Stock Units

From July 25, 2022 through August 15, 2022, the Company entered into advisor agreements with directors, management and consultants pursuant to which the Company agreed to issue a total of 17,450,000 restricted shares of common stock at prices ranging from $0.71 to $1.25 per share (combined value of $12,604,500). These issuances represented 11,950,000 shares that are service-based grants ($8,699,500 value) and 5,500,000 shares that are performance-based grants ($3,905,000 value). The performance criteria are based on the average number of gross barrels of oil produced per day (BOPD) ranging from 1,000 to 5,000 BOPD. The service-based grants vest through July 31, 2032. None of the 17,450,000 restricted shares of common stock have been issued by the transfer agent as of November 30, 2022, and on November 15, 2022, 25,000 of these service-based shares were cancelled as the employee terminated their employment prior to any issuance or vesting of those shares. None of the shares have vested. On December 1, 2022, the remaining 17,425,000 restricted stock grants were cancelled. The Company then entered into new restricted stock unit “RSU” agreements on December 1, 2022 with these individuals, that represented 5,500,000 performance-based RSUs valued at $5,005,000, and 11,925,000 service-based RSUs valued at $10,851,750. The performance-based grants are based on the average number of gross barrels of oil produced per day (BOPD) ranging from 1,000 to 5,000 BOPD; and the service-based grants vest through November 30, 2032.

In the three months ended June 30, 2023, the Company granted 6,150,000 RSUs to advisors and management that are service-based grants that expire at various times through March 31, 2033.

The Company has expensed $3,720,054 (including $75,000 to non-employee directors) in stock-based compensation for the three months ended June 30, 2023 related to all of the Company’s grants. The Company has unrecognized stock-based compensation of $18,181,337 as of June 30, 2023 that will be expensed through March 31, 2033.

 SCHEDULE OF RESTRICTED STOCK UNITS

Series C Convertible Preferred Stock

The Company on October 25, 2022, filed the Series C Certificate of Designation. The Company provides for the issuance of up to 1,000 shares of Series C.

The Company evaluated ASC 480-10-25-14 and determined that the Series C is a financial instrument that embodies an unconditional obligation that the issuer must or may settle by issuing a variable number of its equity shares and shall be classified as a liability.

The Company evaluated ASC 480-10-55-22 and determined the Series C offering is considered a “share settled debt” and is measured at amortized cost and has been expensed immediately.

Details of the Series C:

Dividends: If declared by the Board of Directors.

Conversion: Upon the earlier to occur of (i) the effectiveness of a registration statement on Form S-1 registering the sale by the Holders of the shares of common stock into which such Series C is convertible and (ii) December 31, 2023 (“Conversion Date”).

Conversion Price: The lower of (i) $1.00 and (ii) an amount equal to 80% of the 30-day VWAP of the common stock as reported on the Principal Market as of the 10^th Trading Day immediately preceding the Conversion Date as such price may be adjusted from time-to-time pursuant to the terms hereof, including, without limitation, Section 8 of the agreement.

Negative Covenants: Certain restrictions are imposed if more than 25% of the Series C is outstanding at any given point of time.

Anti-Dilution Clause: Present.

If, at any time while any share of Series C is outstanding, the Company shall issue any Common Stock, except for the Exempt Issuances, for a consideration per share or issues Common Stock Equivalents with an exercise, conversion or exchange price that is less than $0.80, then and thereafter successively upon each such issuance, the Conversion Price shall be reduced to such other lower price.

Fundamental Transaction Clause: Present, without the distribution of cash.

Voting Rights: Reserved on “as converted basis”.

The Company recognized amortization of the discount on the issuance of the Series C in the amount of $1,145,441 for the three months ended June 30, 2023. The value of the Series C liability as of June 30, 2023 is $8,774,619.

Stock Options

The Company’s Board of Directors approved the adoption of the 2016 Stock-Based Compensation Plan (the “2016 Plan”) on May 12, 2016.

There have been no stock options granted since 2018.

As summary of option activity under the 2016 Plan as of June 30, 2023 and changes during the periods then ended are presented below:

SCHEDULE OF STOCK OPTION ACTIVITY 

Warrants

As discussed herein, the Company issued 12,575,632 Warrants in the Series C Offering as of June 30, 2023. These Warrants have a five-year term and $1.00 exercise price. There were no warrants issued in the three months ended June 30, 2022.

The following table reflects Warrant activity:

 SCHEDULE OF WARRANTS ACTIVITY

NOTE 10: LEASES

The Company has adopted ASU No. 2016-02, Leases (Topic 842) and as such accounted for our leases in terms of the right of use assets and offsetting lease liability obligations under this pronouncement. The Company had had only short-term leases up through this acquisition. The Company recorded these amounts at present value, in accordance with the standard, using discount rates ranging between 0% and 18.13%. The right of use asset is composed of the sum of all lease payments, at present value, and is amortized straight line over the life of the expected lease term. For the expected term of the lease the Company used the initial terms ranging between 36 and 48 months. Upon the election by the Company to extend the lease for additional years, that election will be treated as a lease modification and the lease will be reviewed for re-measurement.

The Company has chosen to implement this standard using the modified retrospective model approach with a cumulative-effect adjustment, which does not require the Company to adjust the comparative periods presented when transitioning to the new guidance. The Company has also elected to utilize the transition related practical expedients permitted by the new standard. The modified retrospective approach provides a method for recording existing leases at adoption and in comparative periods that approximates the results of a modified retrospective approach. Adoption of the new standard did not result in an adjustment to retained earnings for the Company.

The Company’s portfolio of leases contains operating and financing leases. As of June 30, 2023, the value of the unamortized lease right of use asset was $224,438 ($165,674 in financing leases and $58,764 in operating leases) (through maturity at November 2026). As of June 30, 2023, the Company’s lease liability was $208,669 ($137,906 in financing leases and $70,763 in operating leases) (through maturity at November 2026).

SCHEDULE OF MATURITY OF OPERATING LEASE LIABILITY 

 SCHEDULE OF MATURITY OF FINANCE LEASE LIABILITY

SCHEDULE OF AMORTIZATION OF RIGHT OF USE ASSET 

Total Lease Cost

Individual components of the total lease cost incurred by the Company is as follows:

 SCHEDULE OF TOTAL LEASE COST

NOTE 11: RELATED PARTY TRANSACTIONS

On September 1, 2022, the Company assigned 10% working interests in a well to two related parties that are controlled by officers of the Company (Sky3D, LLC and Atikin Investments LLC) pursuant to the vesting of various performance conditions in the employment contracts of Randy May and Jay Puchir. In addition, two entities related to directors are working interest owners in wells the Company operates. As of June 30, 2023 and March 31, 2023, the Company is owed $791,011 and $683,043, respectively from these entities for their portion of the production expenses over the revenues received. These amounts are monitored closely and fluctuate each month. In addition at June 30, 2023 and March 31, 2023, the Company is owed $345,407 and $274,598 from another related party. Total related parties accounts receivable at June 30, 2023 and March 31, 2023 is $1,136,418 and $957,641.

The May Family Foundation controls 15.36% of the outstanding common stock of the Company as of June 30, 2023. Additionally, Atikin, an entity which is controlled by Jay Puchir, our Chief Executive Officer, controls 6.65% of the outstanding common stock. Alisa Horgan, the daughter of Randy May, our new Executive Chairman, became a director and officer of the Company following the Holdings acquisition. Her husband Richard Horgan was the Company’s former Chief Executive Officer and director. Mr. May is the Chief Executive Officer of Ecoark. Each of Messrs. May, Horgan and Puchir disclaim beneficial ownership of the securities held by The May Family Foundation except to the extent of any pecuniary interest therein.

All amounts due to Ecoark were exchanged for the 1,200 shares of Series A and classified as a capital transaction with the adjustment to additional paid in capital as they were from a related party. The historical cost basis as of the date of the merger with White River Holdings that have been reclassified to additional paid in capital was $28,953,510 which were deemed to be permanently contributed by Ecoark effective with the issuance of the 1,200 Series A. The Series A shares are reflected in the Company’s historical financial statements in place of the equity instruments held by Ecoark on a historical cost basis. There was no impact on the consolidated statements of operations.

Ecoark had previously entered into a written Participation Agreement with Ault Energy, LLC (“Ault Energy”), a subsidiary of Ault Alliance, Inc. (“Ault”). After we acquired Ecoark’s oil and gas exploration and drilling business, we orally agreed to provide Ault Energy with similar rights. In furtherance of this understanding, we entered into written Participation Agreements with Ault Energy. As a result of delays in Ault Energy meeting its payment obligations, on April 4, 2023 we entered into an agreement with Ecoark and with Ault (dated March 29, 2023) under which the parties agreed we were owed $3.25 million for the participation rights, and Ecoark agreed to pay us up to $3.25 million in exchange for Ault Energy agreeing to the redemption of shares of its preferred stock of Ecoark. As of August 8, 2023, the balance due the Company from Ecoark was $1,380,627 from under this agreement. The sums received were credited to the project on the Company’s mineral lease located in Concordia Parish, Louisiana. In addition, Ault Energy has a payable to the Company of $364,942 relating to other drilling obligations. The Company has reserved both the $1,380,627 and the $364,942 due from Ault Energy as of June 30, 2023.

Based upon Ecoark’s public filings with the SEC, Ecoark has no cash resources and we are uncertain if it will make any further payments although Ault’s Executive Chairman has assured us Ecoark will pay us. While we understand from public filings that Ault has recently raised capital, given their liquidity issues, we cannot predict with certainty if and when we will receive the remaining balance due or any portion thereof from Ault for these participation rights.

Due to Ault Energy’s failure to make timely payments of the full amounts, the Company has concluded that Ault Energy’s participation rights are no longer enforceable except for amounts previously paid and for which all other obligations of Ault Energy have been satisfied. The Company is under no obligation to offer Ault Energy participation rights in the future, although it may do so voluntarily. We are seeking a replacement source of capital for one or more investors to acquire Ault Energy’s interests in the affected wells. As another option, if we are unable to collect payment, we may seek to exercise creditors’ remedies for the unpaid amounts.

The April 4^th agreement was approved by the independent directors of the Company and Ecoark with Mr. May and his daughter abstaining as White River Energy Corp directors, and Mr. May also abstained as an Ecoark Holdings director.

On April 30, 2023, the Company purchased supplies to be used in the current drilling projects for $183,000 from Sky3D, LLC, an entity controlled by Randy May, our Chief Executive Officer. In lieu of payment to this entity, the Company issued a credit against an account receivable from the entity.

The Company from time to time will borrow amounts from related parties, principally Mr. May and to a lesser extent, its Chief Financial Officer. During the three months ended June 30, 2023 the Company borrowed $2,730,326 from related parties in non-interest bearing advances of which $115,199 was repaid, and incurred $229,635 in accrued salaries and expenses that the related parties paid on behalf of the Company that are due to these related parties. These are considered short-term advances. As of June 30, 2023, the Company owed $4,027,012 to the related parties.

NOTE 12: FAIR VALUE MEASUREMENTS

The Company measures and discloses the estimated fair value of financial assets and liabilities using the fair value hierarchy prescribed by U.S. generally accepted accounting principles. The fair value hierarchy has three levels, which are based on reliable available inputs of observable data. The hierarchy requires the use of observable market data when available. The three-level hierarchy is defined as follows:

Level 1 – quoted prices for identical instruments in active markets;

Level 2 – quoted prices for similar instruments in active markets; quoted prices for identical or similar instruments in markets that are not active; and model derived valuations in which significant inputs and significant value drivers are observable in active markets; and

Level 3 – fair value measurements derived from valuation techniques in which one or more significant inputs or significant value drivers are unobservable.

Financial instruments consist principally of cash, accounts receivable and other receivables, accounts payable and accrued liabilities, notes payable, and amounts due to related parties. The fair value of cash is determined based on Level 1 inputs. There were no transfers into or out of “Level 3” during the three months ended June 30, 2023 and 2022. The recorded values of all other financial instruments approximate their current fair values because of their nature and respective relatively short maturity dates or durations.

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

SCHEDULE OF FAIR VALUE ESTIMATES 

The table in Note 8 shows a reconciliation of the beginning and ending liabilities measured at fair value using significant unobservable inputs (Level 3) for the three months ended June 30, 2023.

NOTE 13: COMMITMENTS

Participation Agreements

The Company had entered into a number of Participation Agreements with third parties. We refer you to the Annual Report on Form 10-K for the year ended March 31, 2023 filed with the SEC on June 29, 2023 for all Participation Agreements entered into as of March 31, 2023. The Company has not executed any Participation Agreements during the three months ended June 30, 2023.

White River Fund

The WR Fund which is consolidated by the Company as the Company’s subsidiary is the general partner and managing partner of the WR Fund as discussed in Note 1 under “Principles of Consolidation” is a closed-end private fund where general partners and limited partners invest into WR Fund and the WR Fund then purchases direct working interests in various oil and gas drilling projects of the Company. Subject to available cash, the Company will offer to purchase all outstanding WR Fund partnership interests (other than its subsidiary) The Company has formally committed to purchasing these working interests at a PV20 valuation by an independent firm. The PV20 valuation would be the present value of the remaining net cash flows from the WR Fund’s pro rata share of each oil well it has invested in during the term, discounted by 20%. The managing partner of the WR Fund, which is a wholly-owned subsidiary of the Company, shall receive a ten percent (10%) carried interest, payable starting after all investor partners have received a return of capital. In addition to the offer to purchase, each partner will have the option to remain a partner or exchange the partnership unit for a new partnership in a new fund the Company is offering. The Company plans to make the offer within 90 days of 42 months after the termination of the offering, but no later than March 30, 2027.

The WR Fund invested in two drilling projects in the Company during the year ended March 31, 2023. The first drilling project, the Peabody AMI 12 No 18, hit oil in January 2023 and the second oil project, the Denmiss No 1 well is expected to be spudded in August 2023. The Company is still evaluating the economic viability of the Peabody AMI 12 No. 18 well.

Broker Dealer Acquisition

On January 23, 2023 the Company entered into a Membership Interest Purchase Agreement (the “MIPA”) with an entity (the “Seller”), which Seller is the sole member of another entity (the “Commenda” or the “Broker”), pursuant to which the Company agreed to purchase from the Seller all membership interests in the Broker in exchange for (i) payment of $70,000 in cash, (ii) prepaid expenses incurred or to be incurred by the Broker not to exceed $30,000, and (iii) up to $20,000 in transaction expenses incurred by the Seller in connection with the MIPA. In connection with the execution of the MIPA, the Company paid a $10,000 non-refundable deposit, which will be applied against the cash portion of the purchase consideration at closing. In February 2023, we filed a change of control application, referred to as a Continuing Membership Application or CMA, with FINRA in February 2023. In April 2023, we incurred a conflict with our proposed principal assigned as a control person of the broker-dealer post-acquisition and engaged new principals as control persons of the broker-dealer acquisition post-acquisition as well as engaged an outside advisory firm experienced in filing CMA applications. Upon re-filing the CMA application with the new principals, FINRA extended the CMA application start date to April 25, 2023 which provided the Company with 180 additional days to complete the acquisition from that date. The Company paid the sellers an additional $20,000 non-refundable payment in late May 2023 towards the acquisition price to further reiterate that the Company is committed to consummating this broker-dealer acquisition.

On August 10, 2023 we entered into an Amendment with the Seller to modify the MIPA and extend our time to close as follows:

The Company entered into the MIPA to acquire the Broker for the purpose of enabling the Company to create and sell interests in oil and gas funds to assist the Company in continuing its oil and gas exploration and drilling activities.

Employment Agreements and RSUs

The Company’s Board of Directors approved Executive Employment Agreements pursuant to which our executive officers are entitled to the following compensation and other rights:

Randy May, our Chief Executive Officer, is receiving an annual base salary of $400,000, which has increased to $420,000 for the cost of living adjustment and was granted 5,000,000 shares of restricted common stock (since cancelled on December 1, 2022 and replaced with 5,000,000 RSUs with half of the RSUs vesting annually over a five-year period and the remainder vesting based on performance metrics set forth in the Agreement. Under his Agreement, Mr. May was also granted the following rights related to the Company’s oil and gas operations:

(A) an overriding royalty interest or carried working interest to be held in perpetuity from either the Company or its subsidiaries equal to 5% in any and all successfully drilled and completed oil and/or gas wells (an “ORRI”) during the term of his employment.

(B) a 15% participation right in the funding and ownership interest in any drilling or participation by the Company or any subsidiary in the drilling by the Company or a third party of an oil and gas well other than the WR Fund (a “Participation Right”).

Jay Puchir, our Chief Financial Officer, is receiving an annual base salary of $350,000, which has increased to $367,500 for the cost of living adjustment and was granted 5,000,000 shares of restricted common stock (since cancelled on December 1, 2022 and was granted 5,000,000 RSU) with half of the RSUs vesting annually over a five-year period and the remainder vesting based on performance metrics set forth in the agreement. Under his Agreement, Mr. Puchir was also granted the following rights related to the Company’s oil and gas operations:

(A) a 5% overriding royalty interest or carried working interest during the term of his employment.

(B) a 10% Participation Right otherwise identical to Mr. May’s.

Alisa Horgan, our Chief Administrative Officer and a member of our Board of Directors and Mr. May’s daughter, is receiving an annual base salary of $180,000, which has increased to $189,000 for the cost of living adjustment and was granted 2,000,000 shares of restricted common stock (since cancelled on December 1, 2022 and was granted 2,000,000 RSUs) with the RSUs vesting annually over a 10-year period.

Mrs. Horgan’s husband, Richard Horgan, Senior Vice President of M&A and our former Chief Executive Officer, is receiving an annual base salary of $200,000, which has increased to $210,000 for the cost of living adjustment and was granted 2,000,000 shares of restricted common stock (since cancelled on December 1, 2022 and was granted 2,000,000 RSUs) with the RSUs vesting annually over a 10-year period.

Each of the above Agreements are also subject to the following severance provisions:

In the event of termination by the Company without “cause” or resignation by the officer for “good reason,” each officer is entitled to receive 2.99 years’ base salary, immediate vesting of unvested equity awards and continued benefits for six months.

In case of termination or adverse change in title upon a change of control, each officer is entitled to receive 2.99 years’ base salary, immediate vesting of unvested equity awards, continued benefits for 18 months and 100% of the existing target bonus, if any, for that fiscal year when the change of control occurs.

Further, upon the officer’s death or disability, as defined, during the officer’s term of employment, the officer’s estate or the officer, as applicable, becomes entitled to, among other things, a $500,000 lump-sum payment and full vesting of all outstanding equity grants made to the officer.

In the event an officer’s employment is terminated at the end of the term upon the notice of non-renewal and the officer remains employed until the end of the term, the officer will be entitled to receive six months’ base salary and continued benefits for six months.

In addition, the Company agreed to the following compensation for each non-employee director:

(A) an annual grant of $100,000 in RSUs which will vest on the final business day of each quarter equal to one-fourth of the total stipend, or $25,000 per quarter, with the number of shares to be determined based on the volume weighted average price of the Company’s common stock as of each quarterly vesting (the “RSU Grant”).

(B) an annual cash fee of $50,000 which will vest on the final business day of each quarter equal to one-fourth of the total fee, or $12,500 per quarter (the “Cash Fees”).

The director compensation set forth above is subject to upward adjustment upon the successful uplisting of the Company to a national securities exchange, whereupon the RSU Grant will be increased to $200,000 per year and the Cash Fees will be increased to $100,000 per year.

In addition, the Company entered into indemnification agreements with each of its officers and directors.

The Company entered into five-year Employment Agreements effective May 2023 with Colin Cosgrove and Zackery Holley.

Mr. Cosgrove, as Chief Executive Officer of the WR Fund Manager, receives a monthly base salary of $85,000 which for the first two years operates as a draw against commissions. This means that if commissions for a given month are less than the draw, Mr. Cosgrove receives no commissions; if the commissions are higher than the draw in a given month, Mr. Cosgrove will receive the difference within five business days. After the first two years he will receive both his monthly base salary and monthly commissions, regardless of whether the commissions are more or less than the salary. The commissions will be 10% of capital raised by the WR Fund and will be paid by the Company’s broker-dealer subsidiary if it receives FINRA approval. Mr. Cosgrove has the power to allocate the 10% between himself, Mr. Holley and any other persons associated with the broker-dealer. Because it is possible FINRA will not approve the broker-dealer acquisition, and the commissions by a registered broker-dealer, there is a risk that Mr. Cosgrove may not be paid the commissions.

Mr. Holley, as Executive Vice President of the WR Fund Manager, receives a monthly base salary of $65,000 which for the first two years operates as a draw against commissions. This means that if commissions for a given month are less than the draw, Mr. Holley receives no commissions; if the commissions are higher than the draw in a given month, Mr. Holley will receive the difference within five business days. After the first two years he will receive both his monthly base salary and monthly commissions, regardless of whether the commissions are more or less than the salary. The commissions will be 10% of capital raised by the WR Fund (or any entities they raise money for) and will be paid by the Company’s broker-dealer subsidiary if it receives FINRA approval. Mr. Holley has the power to allocate the 10% between himself, Mr. Holley and any other persons associated with the broker-dealer. Because it is possible FINRA will not approve the broker-dealer acquisition, and the commissions by a registered broker-dealer, there is a risk that Mr. Holley may not be paid the commissions.

Each of Messrs. Cosgrove and Holley are eligible for quarterly bonuses as determined by Mr. Puchir with the approval of Mr. May. Each of Messrs. Cosgrove and Holley received a grant of 2,500,000 RSUs with 850,000 vested, 200,000 vesting each May for four years and the balance of 850,000 RSUs vesting on May 2028, subject in all cases to continued employment on each applicable vesting date. Messrs. Cosgrove and Holly each have 10% participation rights in future wells drilled by the Company except for the WR Fund, which rights apply to future investment partnerships the Company sponsors.

See Note 9 for applicable ASC 718 disclosures related to these grants.

Legal Matters

The Company is a party to two separate actions in the United States District Court, Western District of Louisiana (Alexandria Division) filed on December 30, 2021. In each complaint the plaintiffs namely, in one case Steve H. Crooks and Era Lea Crooks (Case No. 1:21-CV-04457) (“Louisiana Case 1”) and in the other case Ricky Shirley and Dana Shirley (Case No. 1:21-CV-04458) (“Louisiana Case 2”), as plaintiffs who own property in Louisiana filed complaint against multiple defendants, who are involved in oil and gas drilling and production, including White River Operating, LLC (the “Operator”). The other defendants in Louisiana Case 1 are Sanchez Oil & Gas Corporation and Day Town Operating LLC. The other defendants in Louisiana Case 2 are Sanchez Oil & Gas Corporation, Day Town Operating LLC, Pryme Energy, LLC, Belle Exploration, Inc. and Kepco Operating, Inc. The complaints allege that the Operator and the other defendants acted in bad faith in removing minerals from the plaintiffs’ property, and the plaintiffs seek to recover all proceeds from the Operator on the sale of production without deducting any costs. The two cases combined total $299,032 in estimated production. These cases are still in the early stages and management has concluded that there is a remote possibility of the plaintiff securing a favorable outcome and has not accrued for these amounts. The Operator maintains that their costs on the leases in question exceed the proceeds received from the sale of production.

The Company is the operator of leases that relate to a lawsuit filed in the 7^th Judicial District Court, Concordia Parish, Louisiana filed by Ravenwood Lands of Louisiana, L.L.C. et. al. v. Chevron U.S. Inc., et. al (Docket No. 54134; Div. “A,” 7th JDC; Parish of Concordia; State of Louisiana). The Company received a verbal demand to plug wells that have no future utility in Concordia Parish to avoid being named in a lawsuit. In August 2022, the plaintiff filed the lawsuit alleging an environmental tort for contamination of groundwater and soil on plaintiffs’ lands, which lawsuit did not name the Company as a defendant although the Company had performed certain work, including the plugging and abandonment of a well, removal of certain equipment and upgrades at one of its tank battery facilities on the property. Moreover, the Company executed a tolling agreement that suspended the statute of limitations, which has been amended twice and currently expires in October 2023.

NOTE 14: CONCENTRATIONS

Customer Concentration. Four and four customers accounted for more than 10% of the accounts receivable balance at June 30, 2023 and March 31, 2023 for a total of 96% and 97% of accounts receivable, of which two of the customers in each of the periods have been reserved in the allowance for doubtful accounts, respectively. In addition, one and two customers represent approximately 96% and 95% of total revenues for the Company for the three months ended June 30, 2023 and 2022, respectively.

Supplier Concentration. Certain of the raw materials, components and equipment used by the Company in the manufacture of its products are available from single-sourced vendors. Shortages could occur in these essential materials and components due to an interruption of supply or increased demand in the industry. If the Company were unable to procure certain materials, components or equipment at acceptable prices, it would be required to reduce its manufacturing operations, which could have a material adverse effect on its results of operations. In addition, the Company may make prepayments to certain suppliers or enter into minimum volume commitment agreements. Should these suppliers be unable to deliver on their obligations or experience financial difficulty, the Company may not be able to recover these prepayments.

The Company occasionally maintains cash balances in excess of the FDIC insured limit. The Company does not consider this risk to be material.

Commodity price risk

We are exposed to fluctuations in commodity prices for oil and natural gas. Commodity prices are affected by many factors, including but not limited to, supply and demand.

NOTE 15: DISCONTINUED OPERATIONS

In September 2022, the Company sold both Norr and Elysian. See Note 1 under “Description of Business” for more details on the sale of Norr and Elysian.

The Company accounted for these sales as a disposal of the business under ASC 205-20-50-1(a) on September 20, 2022 and September 21, 2022 respectively at which time a loss was recognized. As a result of the Merger with Holdings, the current assets of $68,360 at March 31, 2022 for the pre-combination reporting entity is not reflected on the condensed consolidated balance sheet.

The Company reclassified the following operations to discontinued operations for the three months ended June 30, 2022.

SCHEDULE OF DISCONTINUED OPERATIONS 

NOTE 16: SUBSEQUENT EVENTS

The following events occurred from July 1, 2023 up through the date of filing:

Effective July 1, 2023, Randy May was appointed Chief Executive Officer of the Company and Jay Puchir was appointed Chief Financial Officer of the Company.

On July 13, 2023, White River Private Capital Management (the “Manager”) and WR Fund, consolidated subsidiaries of the Company, entered into a Managing Broker-Dealer Agreement (the “Agreement”) with Emerson Equity LLC (the “Broker”), pursuant to which the Broker agreed to serve as the managing broker-dealer to assist in selling partnership units of the WR Fund in a private placement offering for gross proceeds of up to $50,000,000 on a “best efforts” basis. Under the Agreement, the Broker may enlist other broker-dealers which are members of the Financial Industry Regulatory Authority to assist in the selling efforts as part of the selling group for the offering. As compensation for its services, the Broker will be entitled to receive the following compensation: (i) a selling commission of up to 6% of the gross proceeds from units sold by the Broker in the offering (“Total Sales”), which may be allocated to other selling group members, (ii) a placement fee equal to 1.5% of Total Sales, and (iii) a wholesaler fee equal to up to 1.25% of the Total Sales, which may be allocated to other wholesalers in the offering (including potentially to affiliates of the Broker), and (iv) a marketing diligence allowance equal to up to 1% of the Total Sales, which may be allocated to other selling group members. Under the Agreement, the WR Fund reserves the right to accept or reject any investments in the offering, and to terminate the offering, in its discretion.

On July 27, 2023, the Company granted 500,000 shares of common stock to a business development advisor for services rendered. The shares were valued at $1.24 per share ($620,000).

On July 27, 2023, the Company purchased supplies to be used in the current drilling projects for $389,174 from Sky3D, LLC, an entity controlled by Randy May, our Chief Executive Officer. The related party agreed to payment for these items to be in the form of a credit to the related party payable the Company has with the related party.

See Note 7 related to the Company’s senior convertible debt. On August 10, 2023, the Company entered into a second amendment to the SPA and Note pursuant to which the maturity date of the Note was extended to December 16, 2023. In connection with this amendment, the Company also entered into a new SPA with the same lender and borrowed an additional $1 million and issued the lender, a private family trust, an additional Original Issue Discount Convertible Note of $1,111,111 (“Note 2”) and with identical terms as the December 2022 Note. The Company’s Chief Executive Officer and Chief Financial Officer personally guaranteed Note 2 similar to their guarantees of the Note. In addition, the Company agreed to provide the lender with a carried working interest in one or more productive oil wells in an amount to be mutually agreed by the parties, and that if such interest does not result in revenue to the lender of at least $1,111,111 within 24 months from the date of the amendment, to pay the lender the difference between such amount and the amount actually received by the lender pursuant to the carried working interest. Finally, the Company issued the lender participation rights equal to 15% of any future wells drilled.

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

Cautionary Note Regarding Forward Looking Statements

This Quarterly Report on Form 10-Q (this “Report”) contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995, including statements regarding the planned spin-off by BitNile Metaverse, Inc., formerly known as Ecoark Holdings, Inc. (“Ecoark”) of our common stock issuable upon conversion of its preferred stock, the expected results from and trends and developments in our oil drilling and related activities, future plans for and anticipated transactions and relationships with respect to our oil and gas portfolio and operations, our expectations with respect to the WR Fund, as defined below, our working capital needs and liquidity issues, expectations with respect to Ault Energy and the resale of working interests, potential financings through the sale of our common stock or other securities, the subsequent use and sufficiency of the proceeds from any capital raising methods we may undertake to fund our operations, and our planned acquisition of a broker-dealer to assist us in our fund raising efforts. All statements other than statements of historical facts contained in this Report, including statements regarding our future financial position, liquidity, business strategy and plans and objectives of management for future operations, are forward-looking statements. The words “believe,” “may,” “estimate,” “continue,” “anticipate,” “intend,” “should,” “plan,” “could,” “target,” “potential,” “is likely,” “will,” “expect” and similar expressions, as they relate to us, are intended to identify forward-looking statements. We have based these forward-looking statements largely on our current expectations and projections about future events and financial trends that we believe may affect our financial condition, results of operations, business strategy and financial needs.

The results anticipated by any or all of these forward-looking statements might not occur. Important factors, uncertainties and risks that may cause actual results to differ materially from these forward-looking statements include oil and gas price volatility and the continuation of high oil prices, the impact of the Securities and Exchange Commission’s (“SEC”) proposed climate change rules on us including enhanced regulatory compliance costs, the Russian invasion of the Ukraine, inflation and Federal Reserve interest rate increases in response thereto on the economy including a possible recession which could result, supply chain shortages, the future prices of, and demand for, oil and gas, our ability to efficiently develop our current oil reserves and economically find or acquire additional recoverable reserves, and general risks related to drilling operations, together with those risk factors contained in our Form 10-K for the year ended March 31, 2023, our Registration Statement filed with the SEC, as amended, and the risk factor contained in item 1A of this Report. We may also encounter regulatory delays in causing the Registration Statement to go effective with the SEC in connection with Ecoark’s planned spin-off of shares of our common stock and the PIPE offering. We undertake no obligation to publicly update or revise any forward-looking statements, whether as the result of new information, future events or otherwise.

Company Overview

White River Energy Corp (“White River” or the “Company”) operates in the oil and gas industry, with a focus on exploration, production and drilling operations on approximately 30,000 cumulative acres of active mineral leases in Louisiana and Mississippi through White River Holdings Corp. (“White River Holdings”). Prior to the White River Holdings acquisition, the Company was formerly in the early stages of operations in the online sporting goods space, and was planning to operate as a retail distributor of cannabis products in California. In September 2022, the Company sold each of these entities to focus exclusively on its core business in the energy sector through its oil and gas operations.

White River also manages White River Energy Partners I LP (the “WR Fund”), which is consolidated for accounting purposes by the Company as White River Energy Partners Management I LLC, the Company’s subsidiary (the “Manager”), is the only managing general partner of the WR Fund and has the power to deploy the investments from the WR Fund into the Company for the various drilling projects they undertake. A subsidiary of the Company is the managing partner of the WR Fund. The Company’s subsidiary, the managing general partner contributed $100 as a capital contribution, and the remaining ownership held by the limited partners are reflected as non-controlling interest. The WR Fund was formed to provide the Company with a non-dilutive source of capital to fund its oil and gas drilling ventures.

Oil and Gas Properties

As of June 30, 2023, our oil and gas acreage was comprised of approximately 30,000 cumulative acres of active mineral leases in Louisiana and Mississippi. During the three months ended June 30, 2023 (“FQ 2023”) period and continuing presently, we continue to focus on expanding our exploration and production footprint and capabilities by acquiring real property and working interests in oil and gas mineral leases and drilling exploratory wells.

The Company has received an analysis from an independent petroleum consulting company as of March 31, 2023 and 2022. We have impaired certain reserves on our oil and gas properties when necessary pursuant to our full cost ceiling test calculations.

The following is an overview of our oil and gas properties portfolio in Louisiana and Mississippi:

Louisiana properties

Mississippi properties:

Business Update

During the period covered by this Report, the Company has continued its efforts to grow its oil and gas exploration and drilling business. As of August 3, 2023, the Company has 11 productive wells in operation.

Key Terms and Metrics

In connection with the management of our businesses, we identify, measure and assess a variety of operating metrics. The principal metrics we use in managing our business are set forth below:

“Bbl” – Bbl means barrel of crude oil. Metric used by management to specify the unit of measure (“in barrels”) from which the Company’s midstream customers use to incrementally purchase oil from the Company. Barrels are used as a unit of measure universally across the oil industry so the Company’s adoption of barrels to measure units of oil is a standard practice.

“Mbbl” – Mbbl means a thousand barrels of oil. See comments on “Bbl” metric. “Mbbl” is a standard for measuring larger quantities of barrels of oil in thousands of units.

“Production (Gross)” – Production (Gross) is defined as barrels of oil produced before accounting for working interests from non-mineral owning parties. Metric used by management to specify the total number of barrels of oil produced from a given oil well. Gross production includes both the barrels owned by the oil and gas mineral owners as well as the drilling and investing group who funded and drilled the well which are considered the working interest owners. Gross production is a standard term used universally across the oil industry, so the Company’s adoption of this term is a standard practice.

“Production (Net)” – Production (Net) is defined as the net barrels of oil produced after deducting the ownership portion owned by the mineral owning parties. Unless otherwise specified, management assumes that the mineral ownership portion of a well is 25%, so a 100% working interest would result in a 75% Net Production or Net Revenue interest after accounting for the ownership portion of oil production owned by the mineral owners.

Oil and Natural Gas Reserves

As of June 30, 2023 all of our proved oil and natural gas reserves were located in the United States, specifically in Mississippi and Louisiana.

For more information on our oil and natural gas reserves, we refer you to our Annual Report on Form 10-K filed with the SEC on June 29, 2023.

Drilling and other exploratory activities

During the three months ended June 30, 2023 (“FQ 2023”) , we undertook three drilling programs in Holmes County, MS, Concordia Parish, LA and Rankin County. MS. 

Present activities

The Company is assessing all of its properties at the present time to determine any future drilling activities to commence.

Delivery commitments

The Company is not currently committed to provide a fixed and determinable quantity of oil and gas in the near future under existing contracts or agreements.

Results of Operations

Results of Operations for FQ 2023 compared to the three months ended June 30, 2022 (“FQ 2022”)

White River Holdings has included in their historical consolidated financial statements certain operating expenses and other income (expense) from Ecoark that have been allocated to them in the FQ 2022 which are part of the Condensed Consolidated Statements of Operations. The allocations represented charges incurred by Ecoark for certain corporate, infrastructure and shared services expenses, including legal, human resources, payroll, finance and accounting, employee benefits, insurance, information technology, telecommunications, treasury, and other expenses. Where possible, these charges were allocated based on direct usage, with the remainder allocated on a pro rata basis of headcount, asset, or other allocation methodologies that are considered to be a reasonable reflection of the utilization of services provided or the benefit received by the Company during the periods presented pursuant to SAB Topic 1.B.1. The allocations may not, however, reflect the expense White River Holdings would have incurred as a standalone company for the periods presented. These costs also may not be indicative of the expenses that White River Holdings will incur in the future or would have incurred if White River Holdings had obtained these services from a third party. There were no allocations in FQ 2023.

Revenues

Revenues for FQ 2023 of $195,937 compared to FQ 2022 of $116,461, with the increase primarily related the higher average oil prices compared to FQ 2022. Production was comparable FQ 2023 to FQ 2022 for the wells that were online.

We expect our revenues to continue to increase in this fiscal year as a result of the drilling projects we expect to complete in the remainder of this fiscal year ending March 31, 2024 as we complete the projects currently being drilled.

Costs and Expenses

The following table shows costs and expenses for FQ 2023 and FQ 2022:

Costs and expenses in FQ 2023 totaled $8,881,766 compared to $2,014,952 for FQ 2022. The significant increases from FQ 2022 to FQ 2023 were the result of stock-based compensation of $3,720,054 (included in salaries and salaries related costs), bad debt expense related to joint interest billing receivables and receivables under participation agreements, additional management salaries, and professional fees incurred in FQ 2023 related to our regulatory filings, including our registration statement on Form S-1 for Ecoark’s spin-off of our common stock and the PIPE offering.

The impairment charges were the result of the ceiling test calculations we perform every quarter. The depletion changes are the result of less wells producing from 2022 to 2023. The depreciation increase in 2023 is the result of the purchase of our own drilling and workover rigs that are being depreciated in 2023 that we did not have in 2022.

We expect our costs and expenses to continue increase in our current fiscal year ending March 31, 2024 as a result of increased drilling projects as well as anticipated increases in stock-based compensation related to the granted RSUs on December 2, 2022 as well more recent equity grants including those in FQ 2023 and the recent grant referred to in Note 16. Subsequent Events. The Company is currently incurring material start-up costs related to the roll-out of both its Fund and the acquisition of its broker-dealer which are expected to cost approximately $4,000,000 over the next 12 months on a cash basis and also include equity grants which could cost approximately $7,500,000 in non-cash equity compensation over the next five years due to stock grant vesting terms. The Company, however, expects to realize significantly more than that in allowable commission revenue over the next 12 months as these functions are expected to raise up to $50,000,000 in drilling capital for the Company prior to December 31, 2023 based on the offering of the WR Fund. The significant cost relates to salaries, benefits and equity grants to two new key securities salesmen the Company recently hired to spearhead capital raising for the WR Fund. The salaries and related share-based compensation to the two individuals are expected to add approximately $4,000,000 in the remainder of the year ending March 31, 2024.

Other Income (Expense)

The following table shows other income (expense) for FQ 2023 and FQ 2022:

Total other expense was ($6,481,039) in FQ 2023 compared to other expense of ($2,205) in FQ 2022. The increase was primarily the derivative expense related to the warrants issued in connection with the PIPE offering for ($2,427,596), the change in the fair value of the derivative liability of ($2,343,320), and the amortization of debt discount, non-cash original issue discount on the convertible note and amortization of discount related to the Series C preferred stock increased our other expenses in FQ 2023.

Net Loss

Net loss from continuing operations for FQ 2023 was $15,166,868 as compared to net loss from continuing operations of $1,900,696 for FQ 2022. The increase in net loss was primarily due to the items discussed above. Approximately 83% of loss from operations was from non-cash charges including bad debt, depreciation, amortization, impairment, depletion and accretion in FQ 2023, compared to approximately 9% in FQ 2022.

Liquidity and Capital Resources

Liquidity is the ability of a company to generate funds to support its current and future operations, satisfy its obligations, and otherwise operate on an ongoing basis. Significant factors in the management of liquidity are revenue generated from operations, levels of accounts receivable and accounts payable and capital expenditures.

FQ 2023 and FQ 2022

Net cash (used in) operating activities was $(2,774,637) for FQ 2023, as compared to net cash (used in) operating activities of ($699,938) for FQ 2022. Cash used in operating activities for FQ 2022 was primarily caused by White River Holdings net loss partially offset by adjustments including depreciation, amortization, depletion and accretion, share-based compensation, bad debt expenses and losses on the sale of fixed assets and disposal or abandonment of oil and gas properties as well as amounts allocated from Ecoark and changes in amounts due to Ecoark. In FQ 2023, the net cash used in operating activities was caused by the net loss offset by non-cash items such as depreciation, depletion, impairment, stock-based compensation, derivative expense and the change in fair value of the derivative liability as well as the net changes in our assets and liabilities that yielded an offset to the loss of approximately $12.4 million.

Net cash (used in) investing activities for FQ 2023 was $(898,986) compared to net cash provided for investing activities of $394,399 for FQ 2022. In FQ 2023, the cash used in investing activities primarily related to purchases of oil and gas properties, net of asset retirement obligations, and purchases of fixed assets. Net cash provided by investing activities in FQ 2022 were comprised of proceeds from the sale of oil and gas properties as we sold various leases that had large plugging liabilities, partially offset by purchases of oil and gas properties, net of asset retirement obligations.

In FQ 2023, net cash provided by financing activities was $3,098,464 related to proceeds received from related party advances and our Series C Preferred Stock offset by repayment of long-term debt. Net cash provided by financing activities for FQ 2022 was $255,539 arising from an increase in cash overdraft and from proceeds received from long-term debt.

Available Cash

As of August 10, 2023, the Company has approximately $1,312,280 in cash and cash equivalents.

The Company does not have available cash resources to meet its working capital needs for the next 12 months. We are relying upon the future results of our two new key executives in selling WR Fund units which in turn will, if successful, raise substantial capital for the WR Fund and at some point eliminate our need to pay their salaries since the commissions payable to them will eliminate the Company’s obligation. We have relied upon related party loans, principally from our Chief Executive Officer.

Ecoark had previously entered into a written Participation Agreement with Ault Energy, LLC (“Ault Energy”), a subsidiary of Ault Alliance, Inc. (“Ault”). After we acquired Ecoark’s oil and gas exploration and drilling business, we orally agreed to provide Ault Energy with similar rights. In furtherance of this understanding, we entered into written Participation Agreements with Ault Energy. As a result of delays in Ault Energy meeting its payment obligations, on April 4, 2023 we entered into an agreement with Ecoark and with Ault (dated March 29, 2023) under which the parties agreed we were owed $3.25 million for the participation rights, and Ecoark agreed to pay us up to $3.25 million in exchange for Ault Energy agreeing to the redemption of shares of its preferred stock of Ecoark. As of August 8, 2023, the balance due the Company from Ecoark was $1,380,627 from under this agreement. The sums received were credited to the project on the Company’s mineral lease located in Concordia Parish, Louisiana. In addition, Ault Energy has a payable to the Company of $364,942 relating to other drilling obligations. The Company has reserved both the $1,380,627 and the $364,942 due from Ault Energy as of June 30, 2023.

Based upon Ecoark’s public filings with the SEC, Ecoark has no cash resources and we are uncertain if it will make any further payments although Ault’s Executive Chairman has assured us Ecoark will pay us. While we understand from public filings that Ault has recently raised capital, given their liquidity issues, we cannot predict with certainty if and when we will receive the remaining balance due or any portion thereof from Ault for these participation rights.

Due to Ault Energy’s failure to make timely payments of the full amounts, the Company has concluded that Ault Energy’s participation rights are no longer enforceable except for amounts previously paid and for which all other obligations of Ault Energy have been satisfied. The Company is under no obligation to offer Ault Energy participation rights in the future, although it may do so voluntarily. We are seeking a replacement source of capital for one or more investors to acquire Ault Energy’s interests in the affected wells. As another option, if we are unable to collect payment, we may seek to exercise creditors’ remedies for the unpaid amounts.

On July 13, 2023, the Manager and the WR Fund entered into a Managing Broker-Dealer Agreement with Emerson Equity LLC (the “Broker”), pursuant to which the Broker agreed to serve as the managing broker-dealer to assist in selling partnership units of the WR Fund in a private placement offering for gross proceeds of up to $50,000,000 on a “best efforts” basis, which it may undertake with the efforts of other broker-dealers, in exchange for compensation consisting of (i) a selling commission of up to 6% of the gross proceeds from units sold by the Broker in the offering (“Total Sales”), (ii) a placement fee equal to 1.5% of Total Sales, (iii) a wholesaler fee equal to up to 1.25% of the Total Sales, and (iv) a marketing diligence allowance equal to up to 1% of the Total Sales. The Broker is currently seeking to raise capital using other broker-dealers it with which has a relationship. Our two senior executives we recently hired are associated persons with the Broker.

As disclosed under “Unregistered Sales of Equity Securities and Use of Proceeds,” on August 10, 2023, the Company extended the maturity date of the 10% Senior Secured Promissory Note (the “Note”) originally issued on December 20, 2022 to December 16, 2023. It also entered into a new Securities Purchase Agreement with the same lender, borrowed $1,000,000 and issued an additional Note having a principal amount of $1,111,111 and with identical terms as the December 2022 Note as amended, and agreed to provide the lender with a carried working interest in one or more productive oil wells in an amount to be mutually agreed by the parties, and that if such interest does not result in revenue to the lender of at least $1,111,111 within 24 months from the date of the amendment, to pay the lender the difference between such amount and the amount actually received by the lender pursuant to the carried working interest.

Finally, the Company is exploring various forms of financing which could serve as a bridge financing to help White River sustain operations until the broker-dealer or investment bank are able to raise capital for the Company.

The Company will continue to require additional capital from either the WR Fund or from other sources to assist in their operations and drilling projects. The raising of additional funds may be on terms that continue to dilute the current shareholders.

Critical Accounting Policies, Estimates and Assumptions

Our discussion and analysis of our financial condition and results of operations are based upon our consolidated financial statements, which have been prepared in accordance with generally accepted accounting principles in the United States. The preparation of these consolidated financial statements requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, net sales and expenses. We evaluate our estimates and assumptions on an ongoing basis and base our estimates on historical experience and on various other assumptions that we believe to be reasonable under the circumstances, the results of which form the basis for the judgments we make about the carrying value of assets and liabilities that are not readily apparent from other sources. Because these estimates can vary depending on the situation, actual results may differ from these estimates. Making estimates and judgments about future events is inherently unpredictable and is subject to significant uncertainties.

There have been no material changes to our critical accounting policies and estimates as compared to those disclosed in our Form 10-K. For a description of our critical accounting policies and estimates, see Part I, Item 1, Note 1, “Description of Business, Basis of Presentation and Summary of Significant Accounting Policies” in our notes to the consolidated financial statements in this Report.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Not applicable.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures.

We are required to maintain “disclosure controls and procedures” as such term is defined in Rule 13a-15(e) under the Exchange Act. Based on their evaluation as of the end of the period covered by this Report, Mr. Randy May, our Chief Executive Officer and Mr. Jay Puchir, our Chief Financial Officer have concluded that our disclosure controls and procedures were not effective to ensure that the information relating to our company, required to be disclosed in our SEC reports (i) is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms, and (ii) is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, to allow timely decisions regarding required disclosure as a result of material weaknesses in our internal control over financial reporting.

Changes in Internal Control over Financial Reporting.

There have been no changes in our internal control over financial reporting during our last fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II: OTHER INFORMATION

ITEM 1 - LEGAL PROCEEDINGS

From time-to-time, we may be involved in litigation relating to claims arising out of our operations in the normal course of business. As of the date of this Report, other than the following paragraphs, we are not aware of any pending or threatened lawsuits that could reasonably be expected to have a material effect on the results of our operations.

The Company is a party to two separate actions in the United States District Court, Western District of Louisiana (Alexandria Division) filed on December 30, 2021. In each complaint the plaintiffs namely, in one case Steve H. Crooks and Era Lea Crooks (Case No. 1:21-CV-04457) (“Louisiana Case 1”) and in the other case Ricky Shirley and Dana Shirley (Case No. 1:21-CV-04458) (“Louisiana Case 2”), as plaintiffs who own property in Louisiana filed complaint against multiple defendants, who are involved in oil and gas drilling and production, including White River Operating, LLC (the “Operator”). The other defendants in Louisiana Case 1 are Sanchez Oil & Gas Corporation and Day Town Operating LLC. The other defendants in Louisiana Case 2 are Sanchez Oil & Gas Corporation, Day Town Operating LLC, Pryme Energy, LLC, Belle Exploration, Inc. and Kepco Operating, Inc. The complaints allege that the Operator and the other defendants acted in bad faith in removing minerals from the plaintiffs’ property, and the plaintiffs seek to recover all proceeds from the Operator on the sale of production without deducting any costs. The two cases combined total $299,032 in estimated production. These cases are still in the early stages and management has concluded that there is a remote possibility of the plaintiff securing a favorable outcome and has not accrued for these amounts. The Operator maintains that their costs on the leases in question exceed the proceeds received from the sale of production.

The Company is the operator of leases that relate to a lawsuit filed in the 7^th Judicial District Court, Concordia Parish, Louisiana filed by Ravenwood Lands of Louisiana, L.L.C. et. al. v. Chevron U.S. Inc., et. al (Docket No. 54134; Div. “A,” 7th JDC; Parish of Concordia; State of Louisiana). The Company received a verbal demand to plug wells that have no future utility in Concordia Parish to avoid being named in a lawsuit. In August 2022, the plaintiff filed the lawsuit alleging an environmental tort for contamination of groundwater and soil on plaintiffs’ lands, which lawsuit did not name the Company as a defendant although the Company had performed certain work, including the plugging and abandonment of a well, removal of certain equipment and upgrades at one of its tank battery facilities on the property. Moreover, the Company executed a tolling agreement that suspended the statute of limitations, which has been amended twice and currently expires in October 2023.

ITEM 1A – RISK FACTORS

In addition to the below Risk Factor, see also the Company’s Annual Report on Form 10-K for the fiscal year ended March 31, 2023 and Registration Statement on Form S-1 (File No. 333-268707) for the Risk Factors applicable to the Company and its securities.

If we are unable to collect sums due to us for certain participation rights, we could experience material adverse consequences on our business and financial condition.

As described elsewhere in this Report, in connection with its participation rights in various drilling projects, as of August 4, 2023 Ault Energy, a subsidiary of Ault, owes us $1,745,569 in obligations related to various drilling projects. We entered into an agreement on April 4, 2023 with Ecoark and Ault (dated March 29, 2023) with the goal of permitting Ecoark to pay us the sums due on behalf of Ault. However, due to Ecoark’s lack of cash resources, we may not receive any further amounts. Further, the Company also has very limited cash resources as of the date of this Report in part due to the failure of Ault Energy and Ecoark to pay these obligations. As a result, as a practical matter, the Company’s most realistic option is to provide notice to Ault Energy that it will terminate Ault’s rights under the Participation Agreement and either find other investors or if the well begins production use the production that Ault would have received to fund the Company’s operations. The failure to receive the sums due has exacerbated the Company’s liquidity problems. The failure to receive the payments could have a material adverse effect on our business and financial condition, and your investment in us. The Company has reserved the sums due from Ault Energy as of June 30, 2023.

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

On August 10, 2023, the Company borrowed $1,000,000 from Smithline Family Trust I, an accredited investor, and issued it a 10% Original Issue Discount Convertible Promissory Note due December 16, 2023. The foregoing transaction was were not registered under the Securities Act of 1933 and was exempt from registration pursuant to Section 4(a)(2) thereof and Rule 506(b) promulgated thereunder.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5 - OTHER INFORMATION

Secured Loan Amendment and Financing

As disclosed under “Part I – Item 2. – Management’s Discussion and Analysis of Financial Condition and Results of Operations - Liquidity and Capital Resources,” on August 10, 2023, the Company extended the maturity date of the 10% Senior Secured Promissory Note (the “Note”) originally issued on December 20, 2022 to December 16, 2023. The Company also entered into a new Securities Purchase Agreement with the same lender, borrowed $1,000,000 and issued an additional Note having a principal amount of $1,111,111 and with identical terms as the December 2022 Note as amended, and agreed to provide the lender with a carried working interest in one or more productive oil wells in an amount to be mutually agreed by the parties, and that if such interest does not result in revenue to the lender of at least $1,111,111 within 24 months from the date of the amendment, to pay the lender the difference between such amount and the amount actually received by the lender pursuant to the carried working interest. Finally, the Company issued the lender participation rights equal to 15% of any future wells drilled.

In connection with the foregoing, the Company’s Chief Executive Officer and Chief Financial Officer personally guaranteed the August 2023 similar to their guarantees of the December 2022 Note. The terms of the December 2022 Note and related agreements were previously disclosed on the Company’s Current Report on Form 8-K filed on December 21, 2022.

MIPA Amendment

As disclosed under Note 2 to the financial statements contained in this Report, on August 10, 2023 we entered into an Amendment with the Seller to modify the MIPA and extend our time to close as follows:

The foregoing descriptions do not purport to be complete and is qualified in its entirety by the full text of the agreements related thereto, copies of which are filed as exhibits to this Report.

ITEM 6 – EXHIBITS