UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON D.C. 20549
FORM
For
the Quarterly Period Ended
OR
For the transition period from _______ to ________.
Commission
file number:
(Exact name of Registrant as specified in its charter)
| (State or other jurisdiction of | (I.R.S. Employer | |
| incorporation or organization) | Identification No.) |
| (Address of principal executive offices) | (Zip Code) |
Registrant’s
telephone number, including area code:
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol(s) | Name of each exchange on which registered | ||
Indicate
by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange
Act of 1934 during the preceding 12 months (or for such shorter period that the Registrant was required to file such reports), and (2)
has been subject to such filing requirements for the past 90 days. ☒
Indicate
by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule
405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant
was required to submit such files). ☒
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of large accelerated filer, accelerated filer, smaller reporting company, and emerging growth company in Rule 12b-2 of the Exchange Act.
| Large Accelerated Filer | ☐ | Accelerated Filer | ☐ | |
| ☒ | Smaller Reporting Company | |||
| Emerging Growth Company |
If
an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying
with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
Indicate
by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ☐ Yes
As of June 9, 2025, there were shares of the registrant’s common stock outstanding.
TRIO PETROLEUM CORP.
FORM 10-Q
For the Three and Six Months Ended April 30, 2025
| 2 |
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
TRIO PETROLEUM CORP.
CONDENSED CONSOLIDATED BALANCE SHEETS
| April 30, | October 31, | |||||||
| 2025 | 2024 | |||||||
| (unaudited) | ||||||||
| ASSETS | ||||||||
| Current assets: | ||||||||
| Cash | $ | $ | ||||||
| Prepaid expenses | ||||||||
| Accounts receivable | ||||||||
| Total current assets | ||||||||
| Oil and gas properties - not subject to amortization | ||||||||
| Total assets | $ | $ | ||||||
| LIABILITIES AND STOCKHOLDERS’ EQUITY | ||||||||
| Current liabilities: | ||||||||
| Accounts payable and accrued liabilities | ||||||||
| Asset retirement obligations - current | ||||||||
| Convertible note, net of discounts | ||||||||
| Due to operators | ||||||||
| Promissory notes, net of discounts | ||||||||
| Payable - related party | ||||||||
| Note payable - related party | ||||||||
| Deferred consideration payable | ||||||||
| Other current liabilities | ||||||||
| Total current liabilities | ||||||||
| Long-term liabilities: | ||||||||
| Asset retirement obligations, net of current portion | ||||||||
| Total liabilities | ||||||||
| Commitments and Contingencies(Note 8) | ||||||||
| Stockholders’ Equity: | ||||||||
| Preferred stock, $ par value; shares authorized; -- shares issued and outstanding at April 30, 2025 and October 31, 2024, respectively | ||||||||
| Common stock, $ par value; shares authorized; and shares issued and outstanding as of April 30, 2025 and October 31, 2024, respectively | ||||||||
| Stock subscription receivable | ( | ) | ( | ) | ||||
| Additional paid-in capital | ||||||||
| Accumulated other comprehensive income | ||||||||
| Accumulated deficit | ( | ) | ( | ) | ||||
| Total stockholders’ equity | ||||||||
| Total liabilities and stockholders’ equity | $ | $ | ||||||
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
| 3 |
TRIO PETROLEUM CORP.
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
| For the Three Months Ended April 30, | For the Six Months Ended April 30, | |||||||||||||||
| 2025 | 2024 | 2025 | 2024 | |||||||||||||
| Revenues, net | $ | $ | $ | $ | ||||||||||||
| Cost of goods sold | ||||||||||||||||
| Gross profit | ||||||||||||||||
| Operating expenses: | ||||||||||||||||
| Exploration expense | ||||||||||||||||
| General and administrative expense | ||||||||||||||||
| Stock-based compensation expense | ||||||||||||||||
| Accretion expense | ||||||||||||||||
| Total operating expenses | ||||||||||||||||
| Loss from operations | ( | ) | ( | ) | ( | ) | ( | ) | ||||||||
| Other expenses: | ||||||||||||||||
| Interest expense | ||||||||||||||||
| Settlement fees | ||||||||||||||||
| Loss on abandonment of oil and gas properties | ||||||||||||||||
| Loss on extinguishment | ||||||||||||||||
| Loss on conversion | ||||||||||||||||
| Total other expenses | ||||||||||||||||
| Loss before income taxes | ( | ) | ( | ) | ( | ) | ( | ) | ||||||||
| Provision for income taxes | ||||||||||||||||
| Net loss | $ | ( | ) | $ | ( | ) | $ | ( | ) | $ | ( | ) | ||||
| Basic and Diluted Net Loss per Common Share | ||||||||||||||||
| Basic | $ | ( | ) | $ | ( | ) | $ | ( | ) | $ | ( | ) | ||||
| Diluted | $ | ( | ) | $ | ( | ) | $ | ( | ) | $ | ( | ) | ||||
| Weighted Average Number of Common Shares Outstanding | ||||||||||||||||
| Basic | ||||||||||||||||
| Diluted | ||||||||||||||||
| Comprehensive loss: | ||||||||||||||||
| Net loss | ( | ) | ( | ) | ( | ) | ( | ) | ||||||||
| Foreign currency translation adjustment | ||||||||||||||||
| Comprehensive loss | $ | ( | ) | $ | ( | ) | $ | ( | ) | $ | ( | ) | ||||
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
| 4 |
TRIO PETROLEUM CORP.
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY
FOR THE THREE AND SIX MONTHS ENDED APRIL 30, 2025 AND 2024
(Unaudited)
| Accumulated | ||||||||||||||||||||||||||||
| Stock | Additional | Other | Total | |||||||||||||||||||||||||
| Common Stock | Subscription | Paid-in | Comprehensive | Accumulated | Stockholders’ | |||||||||||||||||||||||
| Shares | Amount | Receivable | Capital | Income | Deficit | Equity | ||||||||||||||||||||||
| Balance at October 31, 2023 | $ | $ | ( | ) | $ | $ | $ | ( | ) | $ | ||||||||||||||||||
| Issuance of common shares in lieu of cash payments on convertible note | ||||||||||||||||||||||||||||
| Issuance of common shares to consultants | ||||||||||||||||||||||||||||
| Issuance of equity warrants in connection with convertible note | - | |||||||||||||||||||||||||||
| Stock-based compensation | - | |||||||||||||||||||||||||||
| Net loss | - | ( | ) | ( | ) | |||||||||||||||||||||||
| Balance at January 31, 2024 | $ | $ | ( | ) | $ | $ | $ | ( | ) | $ | ||||||||||||||||||
| Issuance of common shares in lieu of cash payments on convertible note | ||||||||||||||||||||||||||||
| Issuance of commitment shares in connection with the April 2024 Financings | ||||||||||||||||||||||||||||
| Issuance of common shares to consultants | ||||||||||||||||||||||||||||
| Adjustment to common stock for warrants related to the Resale S-1/A | ( | ) | ( | ) | ||||||||||||||||||||||||
| Stock-based compensation | - | |||||||||||||||||||||||||||
| Net loss | - | ( | ) | ( | ) | |||||||||||||||||||||||
| Balance at April 30, 2024 | $ | $ | ( | ) | $ | $ | $ | ( | ) | $ | ||||||||||||||||||
| Balance at October 31, 2024 | $ | $ | ( | ) | $ | $ | $ | ( | ) | $ | ||||||||||||||||||
| Issuance of common shares to executives and board members | ( | ) | ||||||||||||||||||||||||||
| Issuance of common shares in connection with ATM agreement, net | ||||||||||||||||||||||||||||
| Issuance of common shares in lieu of cash payments on promissory notes | ||||||||||||||||||||||||||||
| Issuance of beneficial ownership round-up shares for participants | ( | ) | ||||||||||||||||||||||||||
| Stock-based compensation | - | |||||||||||||||||||||||||||
| Net loss | - | ( | ) | ( | ) | |||||||||||||||||||||||
| Balance at January 31, 2025 | $ | $ | ( | ) | $ | $ | $ | ( | ) | $ | ||||||||||||||||||
| Issuance of common shares in connection with asset acquisition | ||||||||||||||||||||||||||||
| Issuance of common shares in connection with Note Exchange Agreement | ||||||||||||||||||||||||||||
| Issuance of common shares to a consultant | ||||||||||||||||||||||||||||
| Reduction in shares due to option forfeitures | ( | ) | ||||||||||||||||||||||||||
| Stock-based compensation | - | |||||||||||||||||||||||||||
| Net loss | - | ( | ) | ( | ) | |||||||||||||||||||||||
| Other comprehensive income | - | |||||||||||||||||||||||||||
| Balance at April 30, 2025 | $ | $ | ( | ) | $ | $ | $ | ( | ) | $ | ||||||||||||||||||
The accompanying notes are an integral part of these unaudited condensed financial statements.
| 5 |
TRIO PETROLEUM CORP.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
| For the Six Months Ended April 30, | ||||||||
| 2025 | 2024 | |||||||
| CASH FLOWS FROM OPERATING ACTIVITIES: | ||||||||
| Net loss | $ | ( | ) | $ | ( | ) | ||
| Adjustments to reconcile net loss to net cash (used in)/provided by operating activities: | ||||||||
| Issuance of common shares for services | ||||||||
| Issuance of equity warrants in connection with convertible note | ||||||||
| Conversion of convertible note payments into common shares | ||||||||
| Accretion expense | ||||||||
| Amortization of debt discounts | ||||||||
| Payable to related party | ||||||||
| Bad debt expense | ||||||||
| Stock-based compensation | ||||||||
| Debt discounts - convertible note | ( | ) | ||||||
| Loss on issuance of common shares in lieu of cash principal payments on debt | ||||||||
| Loss on abandonment of oil and gas properties | ||||||||
| Loss on debt extinguishment | ||||||||
| Changes in operating assets and liabilities: | ||||||||
| Accounts receivable | ( | ) | ||||||
| Prepaid expenses and other receivables | ( | ) | ||||||
| Accounts payable and accrued liabilities | ||||||||
| Other liabilities | ( | ) | ||||||
| Net cash (used in)/provided by operating activities | ( | ) | ||||||
| CASH FLOWS FROM INVESTING ACTIVITIES: | ||||||||
| Capital expenditures for unproved oil and gas properties | ( | ) | ( | ) | ||||
| Due to operators | ( | ) | ||||||
| Advances to operators | ||||||||
| Net cash used in investing activities | ( | ) | ( | ) | ||||
| CASH FLOWS FROM FINANCING ACTIVITIES: | ||||||||
| Proceeds from issuance of common shares in connection with ATM agreement | ||||||||
| Payment of convertible note payable | ( | ) | ||||||
| Proceeds from promissory notes | ||||||||
| Proceeds from note payable - related party | ||||||||
| Payment for debt issuance costs | ( | ) | ( | ) | ||||
| Payment of related party debt | ( | ) | ||||||
| Proceeds from issuance of convertible debt | ||||||||
| Payment of promissory notes | ( | ) | ||||||
| Net cash provided by/(used in) financing activities | ( | ) | ||||||
| Effect of foreign currency exchange | ||||||||
| NET CHANGE IN CASH | ( | ) | ||||||
| Cash - Beginning of period | ||||||||
| Cash - End of period | $ | $ | ||||||
| Supplemental disclosures of cash flow information: | ||||||||
| Cash paid for interest | $ | $ | ||||||
| Cash paid for income taxes | $ | $ | ||||||
| SUPPLEMENTAL CASH FLOW INFORMATION: | ||||||||
| Non-cash investing and financing activities: | ||||||||
| Issuance of shares to executives and directors | $ | $ | ||||||
| Issuance of warrants | $ | $ | ||||||
| Issuance of commitment shares | $ | $ | ||||||
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
| 6 |
TRIO PETROLEUM CORP.
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
FOR THE THREE AND SIX MONTHS ENDED APRIL 30, 2025
NOTE 1 – NATURE OF THE ORGANIZATION AND BUSINESS
Company Organization
Trio Petroleum Corp. (“Trio Petroleum”, the “Company” or “TPET”) is a California-based oil and gas exploration and development company headquartered in Malibu, California, with its principal executive offices located at 23823 Malibu Road, Suite 304, Malibu, California 90265, and with operations in Monterey County, California, Uintah County, Utah and Lloydminster, Saskatchewan. The Company was incorporated on July 19, 2021, under the laws of Delaware to acquire, fund, and operate oil and gas exploration, development and production projects, initially focusing on one major asset in California, the South Salinas Project (“South Salinas Project”). The Company has since acquired interests in the McCool Ranch Oil Field in Monterey County, California, in the Asphalt Ridge Project in Uintah County, Utah and in the heavy oil region of Saskatchewan, Canada. The Company has had revenue-generating operations since the McCool Ranch Oil Field was restarted on February 22, 2024, and recognized its first revenues in the fiscal quarter ended April 30, 2024, and received the proceeds from these operations in June 2024. Most recently, it has recognized initial revenues from its Saskatchewan assets during the quarter ended April 30, 2025.
Formation of a Canadian Wholly-Owned Subsidiary
On March 28, 2025, the Company formed Trio Petroleum Canada, Corp., an Alberta, Canada corporation and its wholly owned subsidiary (“Trio Canada”). The Company’s Chief Executive Officer, Robin Ross, is also the Chief Executive Officer of Trio Canada and also serves as Secretary/Treasurer. The Company’s Chief Financial Officer, Greg Overholtzer, is also the Chief Financial Officer of Trio Canada. Robin Ross also serves as the sole director of Trio Canada.
Acquisition of South Salinas Project
The
Company was initially formed to acquire from Trio LLC (“Trio LLC”) an approximate
There
are two contiguous areas of notable oil/gas accumulations in the South Salinas Project; the first is the Humpback Area that occurs in
the northern part of the project and the second is the Presidents Area (“Presidents Oil Field”) that occurs in the southern
part of the project. As of April 30, 2025 and October 31, 2024, there were no proved reserves attributable to the approximate
Additional Acquisitions - Novacor Acquisition
As of April 4, 2025, the Company entered into an Asset Purchase Agreement (the “APA”) with Trio Petroleum Canada, Corp., an Alberta, Canada corporation and a wholly owned subsidiary of the Company (“Trio Canada”), and Novacor Exploration Ltd., a corporation incorporated under the Canada Business Corporations Act (“Novacor”), pursuant to which, subject to the terms and conditions set forth in the APA, Trio Canada agreed to acquire certain assets of Novacor relating its oil and gas business, including certain contracts, leases and permits for working interests in petroleum and natural gas and mineral rights located in the Lloydminster, Saskatchewan heavy oil region in Canada (see Note 5 and Note 10 for further information).
Emerging Growth Company
The Company is an “emerging growth company,” as defined in Section 2(a)(19) of the Securities Act, as modified by the Jumpstart Our Business Startups Act of 2012 (the “JOBS Act”), and it may take advantage of certain exemptions from various reporting requirements that are applicable to other public companies that are not emerging growth companies including, but not limited to, not being required to comply with the auditor attestation requirements of Section 404(b) of the Sarbanes-Oxley Act of 2002, reduced disclosure obligations regarding executive compensation in its periodic reports and proxy statements, and exemptions from the requirements of holding a nonbinding advisory vote on executive compensation and approval of any golden parachute payments not previously approved. Further, Section 102(b)(1) of the JOBS Act exempts emerging growth companies from being required to comply with new or revised financial accounting standards until private companies (that is, those that have not had a Securities Act registration statement declared effective or do not have a class of securities registered under the Exchange Act) are required to comply with the new or revised financial accounting standards. The JOBS Act provides that a company can elect to opt out of the extended transition period and comply with the requirements that apply to non-emerging growth companies but any such election to opt out is irrevocable. The Company has elected not to opt out of such extended transition period which means that when a standard is issued or revised and it has different application dates for public or private companies, the Company, as an emerging growth company, can adopt the new or revised standard at the time private companies adopt the new or revised standard. This may make a comparison of the Company’s condensed consolidated financial statements with another public company which is neither an emerging growth company nor an emerging growth company which has opted out of using the extended transition period difficult or impossible because of the potential differences in accounting standards used.
| 7 |
NOTE 2 –SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Consolidation
The condensed consolidated financial statements of Trio Petroleum, Corp. include the accounts of TPET and our wholly owned Canadian subsidiary Trio Canada. All significant intercompany profits, losses, transactions and balances have been eliminated in consolidation in the condensed consolidated financial statements.
Basis of Presentation
The accompanying condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”). Amounts presented in the balance sheet as of October 31, 2024 are derived from our audited financial statements as of that date. The unaudited condensed consolidated financial statements as of and for the three and six month periods ended April 30, 2025 and 2024 have been prepared in accordance U.S. GAAP and the interim reporting rules of the Securities and Exchange Commission (“SEC”) and should be read in conjunction with the audited financial statements and notes thereto contained in the Company’s annual report on Form 10-K/A filed with the SEC on February 27, 2025. In the opinion of management, all adjustments, consisting of normal recurring adjustments (unless otherwise indicated), necessary for a fair presentation of the financial position and the results of operations for the interim periods presented have been reflected herein. The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year.
Use of Estimates
The preparation of condensed consolidated financial statements in accordance with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, equity-based transactions and disclosure of contingent assets and liabilities at the date of the condensed consolidated financial statements, and the revenue and expenses during the reporting period.
Making estimates requires management to exercise significant judgment. It is at least reasonably possible that the estimate of the effect of a condition, situation or set of circumstances that existed at the date of the financial statement, which management considered in formulating its estimate, could change in the near term due to one or more future confirming events. Some of the more significant estimates required to be made by management include estimates of oil and natural gas reserves (when and if assigned) and related present value estimates of future net cash flows therefrom, the carrying value of oil and natural gas properties, accounts receivable, bad debt expense, ARO and the valuation of equity-based transactions. Accordingly, actual results could differ significantly from those estimates.
Foreign Currency Translation
The
Company’s reporting currency is the United States dollar. The functional currency of the Company’s Canadian subsidiary
is the Canadian Dollar (“CAD”) for balance sheet accounts (
Comprehensive
income is defined as the change in equity of an entity from all sources other than investments by owners or distributions to owners and
includes foreign currency translation adjustments as described above. During the three and six months ended April 30, 2025, the Company
recorded $
Foreign currency gains and losses resulting from transactions denominated in foreign currencies, including intercompany transactions, are included in results of operations. The Company recognized no foreign currency transaction gains or losses for the three and six months ended April 30, 2025 and 2024. Such amounts are classified within general and administrative expenses in the accompanying condensed consolidated statements of operations and comprehensive income (loss).
Cash and cash equivalents
The
Company considers all short-term investments with an original maturity of three months or less when purchased to be cash equivalents.
The Company had
Prepaid Expenses
Prepaid
expenses consist primarily of prepaid services which will be expensed as the services are provided within twelve months. As of April
30, 2025 and October 31, 2024, the balances of the prepaids account were $
Loan Receivables
Loan receivables are recorded at their outstanding principal balance, net of any allowance for credit losses. The Company evaluates the collectability of loan receivables based on historical experience, current economic conditions, and the creditworthiness of borrowers. The Company maintains an allowance for credit losses to cover estimated losses; the allowance is determined based on historical loss experience, current economic conditions and specific borrower risk assessments. Adjustments to the allowance are recorded through provision for credit losses in the statement of operations. Interest income on loan receivables is recognized using the effective interest method. Loans are placed on nonaccrual status when collection of principal or interest is uncertain. Loan receivables are reviewed periodically for impairment. If a loan is deemed uncollectible, the Company records a charge-off against the allowance for credit losses.
Debt Issuance Costs
Costs
incurred in connection with the issuance of the Company’s debt have been recorded as a direct reduction against the debt and amortized
over the life of the associated debt as a component of interest expense. As of April 30, 2025 and October 31, 2024, the Company recorded
$
| 8 |
Oil and Gas Assets and Exploration Costs – Successful Efforts
The Company’s projects are in exploration and/or early production stages and the Company began generating revenue from its operations during the quarterly period ended April 30, 2024. It applies the successful efforts method of accounting for crude oil and natural gas properties. Under this method, exploration costs such as exploratory, geological, and geophysical costs, delay rentals and exploratory overhead are expensed as incurred. If an exploratory property provides evidence to justify potential development of reserves, drilling costs associated with the property are initially capitalized, or suspended, pending a determination as to whether a commercially sufficient quantity of proved reserves can be attributed to the area as a result of drilling. At the end of each quarter, management reviews the status of all suspended exploratory property costs considering ongoing exploration activities; in particular, whether the Company is making sufficient progress in its ongoing exploration and appraisal efforts. If management determines that future appraisal drilling or development activities are unlikely to occur, associated exploratory well costs are expensed.
Costs to acquire mineral interests in crude oil and/or natural gas properties, drill and equip exploratory wells that find proved reserves and drill and equip development wells are capitalized. Acquisition costs of unproved leaseholds are assessed for impairment during the holding period and transferred to proven crude oil and/or natural gas properties to the extent associated with successful exploration activities. Significant undeveloped leases are assessed individually for impairment, based on the Company’s current exploration plans, and a valuation allowance is provided if impairment is indicated. Capitalized costs from successful exploration and development activities associated with producing crude oil and/or natural gas leases, along with capitalized costs for support equipment and facilities, are amortized to expense using the unit-of-production method based on proved crude oil and/or natural gas reserves on a field-by-field basis, as estimated by qualified petroleum engineers.
As of April 30, 2025, the Company had five wells that are producing, all of which are located in the newly acquired Saskatchewan property, plus two workovers. The Company expects to add the reserve value of such fields to the Company’s reserve report after a further period of observation and review of the oil production; once this has been determined, it will estimate the necessary depreciation, depletion and amortization (“DD&A”) for such wells.
Proved and unproved oil and natural gas properties
Unproved oil and natural gas properties have unproved lease acquisition costs, which are capitalized until the lease expires or otherwise until the Company specifically identifies a lease that will revert to the lessor, at which time the Company charges the associated unproved lease acquisition costs to exploration costs.
Unproved oil and natural gas properties are not subject to amortization and are assessed periodically for impairment on a property-by-property basis based on remaining lease terms, drilling results or future development plans. As of April 30, 2025 and October 31, 2024, such oil and gas properties were classified as unproved properties and were not subject to DD&A.
Proved oil and natural gas properties include developed and undeveloped reserves that have been confirmed through drilling and production activities. These properties are subject to DD&A, which is calculated using the unit-of-production method based on total proved reserves.
| ● | Proved developed reserves are amortized over the expected production life of the wells. | |
| ● | Proved undeveloped reserves remain capitalized until development activities commence. | |
| ● | The Company assesses impairment of proved properties periodically based on commodity prices, production forecasts, and reserve estimates. |
As of April 30, 2025, the Company has proved reserves in the newly acquired Saskatchewan properties and expects to add the reserves values of such fields to the Company’s reserve report; once this has been done, it will estimate the necessary DD&A for such wells.
Impairment of Other Long-lived Assets
The Company reviews the carrying value of its long-lived assets annually or whenever events or changes in circumstances indicate that the historical cost-carrying value of an asset may no longer be appropriate. The Company assesses the recoverability of the carrying value of the asset by estimating the future net undiscounted cash flows expected to result from the asset, including eventual disposition. If the future net undiscounted cash flows are less than the carrying value of the asset, an impairment loss is recorded equal to the difference between the asset’s carrying value and estimated fair value. With regards to oil and gas properties, this assessment applies to proved properties.
Asset Retirement Obligations
ARO consists of future plugging and abandonment expenses on oil and natural gas properties. In connection with the South Salinas Project (“SSP”) acquisition described above, the Company acquired the plugging and abandonment liabilities associated with six non-producing wells. The fair value of the ARO was recorded as a liability in the period in which the wells were acquired with a corresponding increase in the carrying amount of oil and natural gas properties not subject to impairment. The Company plans to utilize the six wellbores acquired in the SSP acquisition in future exploration, production and/or disposal (i.e., disposal of produced water or CO2 by injection) activities. The liability is accreted for the change in its present value each period based on the expected dates that the wellbores will be required to be plugged and abandoned. The capitalized cost of ARO is included in oil and gas properties and is a component of oil and gas property costs for purposes of impairment and, if proved reserves are found, such capitalized costs will be depreciated using the units-of-production method. The asset and liability are adjusted for changes resulting from revisions to the timing or the amount of the original estimate when deemed necessary. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized.
| 9 |
Components of the changes in ARO are shown below:
| ARO, ending balance – October 31, 2024 | $ | |||
| Accretion expense | ||||
| ARO, ending balance – April 30, 2025 | ||||
| Less: ARO – current | ||||
| ARO, net of current portion – April 30, 2025 | $ |
Revenue Recognition
ASU 2014-09, “Revenue from Contracts with Customers” (“Topic 606”) requires an entity to recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration the entity expects to be entitled to in exchange for those goods or services; refer to Note 4 – Revenue from Contracts with Customers for additional information.
The Company’s revenue is comprised of revenue from exploration and production activities to produce oil. The Company’s oil is sold to one customer who is a marketer, and payment is received in the month following delivery.
The Company recognizes sales revenues from oil when control transfers to the customer at the time of delivery. Revenue is measured based on the contract price, which may include adjustments for market differentials and downstream costs incurred by the customer, including gathering, transportation or short load fees.
Revenues are recognized for the sale of the Company’s percentage of working interest, adjusted for any incoming and outstanding expenses and oil and gas assessments.
Related Parties
Related
parties are directly or indirectly related to the Company, through one or more intermediaries and are in control, controlled by, or under
common control with the Company. Related parties also include principal owners of the Company, its management, members of the immediate
families of principal owners of the Company and its management and other parties with which the Company may deal if one party controls
or can significantly influence the management or operating policies of the other to an extent that one of the transacting parties might
be prevented from fully pursuing its own separate interests. The Company discloses all related party transactions. On September 14, 2021,
the Company acquired an
Income Taxes
Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets, including tax loss and credit carry forwards, and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.
The Company utilizes ASC 740, Income Taxes, which requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the condensed consolidated financial statements or tax returns. The Company accounts for income taxes using the asset and liability method to compute the differences between the tax basis of assets and liabilities and the related financial amounts, using currently enacted tax rates. A valuation allowance is recorded when it is “more likely than not” that a deferred tax asset will not be realized. At April 30, 2025 and October 31, 2024, the Company’s net deferred tax asset has been fully reserved.
For uncertain tax positions that meet a “more likely than not” threshold, the Company recognizes the benefit of uncertain tax positions in the condensed consolidated financial statements. The Company’s practice is to recognize interest and penalties, if any, related to uncertain tax positions in income tax expense in the statements of operations when a determination is made that such expense is likely. The Company is subject to income tax examinations by major taxing authorities since inception.
The Company’s wholly owned Canadian subsidiary is subject to taxation under Canadian federal and provincial tax laws. The subsidiary’s income tax provision is calculated based on applicable Canadian tax rates, and any differences between U.S. and Canadian tax treatments are considered in the condensed consolidated financial statements. The Company also considers the impact of the U.S.-Canada Tax Treaty in determining its tax obligations, including withholding taxes on intercompany transactions.
Fair Value Measurements
The carrying values of financial instruments comprising cash and cash equivalents, payables, and notes payable-related party approximate fair values due to the short-term maturities of these instruments. The notes payable- related party is considered a level 3 measurement. As defined in ASC 820, Fair Value Measurements and Disclosures, fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). The Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. ASC 820 establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). This fair value measurement framework applies to both initial and subsequent measurement.
| 10 |
| Level 1: | Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. |
| Level 2: | Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reported date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. |
| Level 3: | Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. The significant unobservable inputs used in the fair value measurement for nonrecurring fair value measurements of long-lived assets include pricing models, discounted cash flow methodologies and similar techniques. |
There are no assets or liabilities measured at fair value on a recurring basis. Assets and liabilities accounted for at fair value on a non-recurring basis in accordance with the fair value hierarchy include the initial allocation of the asset acquisition purchase price, including asset retirement obligations, the fair value of oil and natural gas properties and the assessment of impairment.
The fair value measurements and allocation of assets acquired are measured on a nonrecurring basis on the acquisition date using an income valuation technique based on inputs that are not observable in the market and therefore represent Level 3 inputs. Significant inputs used to determine the fair value include estimates of: (i) reserves; (ii) future commodity prices; (iii) operating and development costs; and (iv) a market-based weighted average cost of capital rate. The underlying commodity prices embedded in the Company’s estimated cash flows are the product of a process that begins with NYMEX forward curve pricing, adjusted for estimated location and quality differentials, as well as other factors that the Company’s management believes will impact realizable prices. These inputs require significant judgments and estimates by the Company’s management at the time of the valuation.
The fair value of additions to the asset retirement obligation liabilities is measured using valuation techniques consistent with the income approach, which converts future cash flows to a single discounted amount. Significant inputs to the valuation include: (i) estimated plug and abandonment cost per well for all oil and natural gas wells and for all disposal wells; (ii) estimated remaining life per well; (iii) future inflation factors; and (iv) the Company’s average credit-adjusted risk-free rate. These assumptions represent Level 3 inputs.
If the carrying amount of its proved oil and natural gas properties, which are assessed for impairment under ASC 360 – Property, Plant and Equipment, exceeds the estimated undiscounted future cash flows, the Company will adjust the carrying amount of the oil and natural gas properties to fair value. The fair value of its oil and natural gas properties is determined using valuation techniques consistent with the income and market approach. The factors used to determine fair value are subject to management’s judgment and expertise and include, but are not limited to, recent sales prices of comparable properties, the present value of future cash flows, net of estimated operating and development costs using estimates of proved reserves, future commodity pricing, future production estimates, anticipated capital expenditures, and various discount rates commensurate with the risk and current market conditions associated with the expected cash flow projected. These assumptions represent Level 3 inputs.
Basic and diluted net loss per share is computed by dividing net loss by the weighted average number of common shares outstanding during the reporting period. Diluted earnings per share is computed similar to basic loss per share, except the weighted average number of common shares outstanding are increased to include additional shares from the assumed exercise of share options, warrants and convertible notes, if dilutive.
Six Months Ended April 30, 2025 | Six Months Ended April 30, 2024 | |||||||
| Warrants | (1) | (1) | ||||||
| Total potentially dilutive securities | ||||||||
| (1) |
Environmental Expenditures
The operations of the Company have been, and may in the future be, affected from time to time to varying degrees by changes in environmental regulations, including those for future reclamation and site restoration costs. Both the likelihood of new regulations and their overall effect upon the Company vary greatly and are not predictable. The Company’s policy is to meet or, if possible, surpass standards set by relevant legislation by application of technically proven and economically feasible measures.
Environmental expenditures that relate to ongoing environmental and reclamation programs are charged against earnings as incurred or capitalized and amortized depending on their future economic benefits. All of these types of expenditures incurred since inception have been charged against earnings due to the uncertainty of their future recoverability. Estimated future reclamation and site restoration costs, when the ultimate liability is reasonably determinable, are charged against earnings over the estimated remaining life of the related business operation, net of expected recoveries.
Recent Accounting Pronouncements
All recently issued but not yet effective accounting pronouncements have been deemed to be not applicable or immaterial to the Company.
Reclassification of Expenses
Certain amounts in the prior periods presented have been reclassified to a current period financial statement presentation. This reclassification has no effect on previously reported net income.
Subsequent Events
The Company evaluated all events and transactions that occurred after April 30, 2025 through the date of the filing of this report. See Note 10 for such events and transactions.
| 11 |
NOTE 3 – GOING CONCERN AND MANAGEMENT’S LIQUIDITY PLANS
As
of April 30, 2025, the Company had $
The
accompanying condensed consolidated financial statements have been prepared on the basis that the Company will continue as a going concern
over the next twelve months from the date of issuance of these condensed consolidated financial statements, which assumes the realization
of assets and the satisfaction of liabilities in the normal course of business. As of April 30, 2025, the Company has an accumulated
deficit of $
Accordingly, the accompanying condensed consolidated financial statements have been prepared in conformity with U.S. GAAP, which contemplates continuation of the Company as a going concern and the realization of assets and the satisfaction of liabilities in the normal course of business. The condensed consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.
NOTE 4 – REVENUE FROM CONTRACTS WITH CUSTOMERS
Disaggregation of Revenue from Contracts with Customers
The following table disaggregates revenue by significant product type for the periods below:
Three Months Ended April 30, 2025 | Three Months Ended April 30, 2024 | Six Months Ended April 30, 2025 | Six Months Ended April 30, 2024 | |||||||||||||
| Oil sales | $ | $ | $ | $ | ||||||||||||
| Total revenue from customers | $ | $ | $ | $ | ||||||||||||
There
were
Significant concentrations of credit risk
The
Company’s revenue is primarily generated from oil and gas sales in California, United States, and Saskatchewan, Canada. As of April
30, 2025,
NOTE 5 – OIL AND NATURAL GAS PROPERTIES
The following tables summarize the Company’s oil and gas activities.
As of April 30, 2025 | As of October 31, 2024 | |||||||
| Oil and gas properties – not subject to amortization | $ | $ | ||||||
| Accumulated impairment | ||||||||
| Oil and gas properties – not subject to amortization, net | $ | $ | ||||||
During
the three and six months ended April 30, 2025, the Company incurred aggregated exploration costs of $
For
capitalized costs, the Company incurred approximately $
Leases
South Salinas Project
As
of April 30, 2025, the Company holds interests in various leases related to the unproved properties of the South Salinas Project (see
Note 7); two of the leases are held with the same lessor. The first lease, which covers
| 12 |
The
second lease covers
During
February and March of 2023, the Company entered into additional leases related to the unproved properties of the South Salinas Project
with two groups of lessors. The first group of leases covers
During
the current reporting period, the Company made the strategic decision to abandon the additional oil and gas leases. As a result, all
associated costs related to exploration and development activities, including any capitalized costs for support equipment and facilities,
have been expensed in accordance with applicable accounting standards. This decision was based on a comprehensive evaluation of the economic
viability and future potential of the leases, considering market conditions, regulatory factors, and operational constraints. The total
expense recognized in connection with this abandonment totals $
McCool Ranch Oil Field
In
October 2023, the Company entered into the McCool Ranch Purchase Agreement with Trio LLC for the purchase of a
On May 27, 2025, the Company made the decision to
abandon the McCool Ranch Oil Field leases. Because the conditions leading to this decision existed as of April 30, 2025, this event qualifies
as a recognized subsequent event under ASC 855-10-25-1 and has been reflected in the financial statements for the period ended April 30,
2025. Accordingly, all capitalized costs related to the acquisition, refurbishment, and production restart—including costs for support
equipment and facilities—totaling $
The Company will not make any further payments under the McCool Ranch Purchase Agreement, and all previously recorded liabilities associated with the project have been recognized as an expense. The Company no longer holds any interests in the McCool Ranch Oil Field, and the abandonment decision will be reflected in the financial statements.
Optioned Assets – Asphalt Ridge Leasehold Acquisition & Development Option Agreement
On
November 10, 2023, the Company entered into the ARLO Agreement with HSO for a term of nine months which gives the Company the exclusive
right to acquire up to a
On
December 29, 2023, the Company entered into an amendment to the ARLO Agreement, whereby the Company funded $
Per
the most recent amendment to the ARLO Agreement signed in April 2025, the Company had until May 10, 2025 to pay HSO an additional $
Novacor Acquisition
As
of April 4, 2025, the Company entered into an Asset Purchase Agreement (the “APA”) with Trio Petroleum Canada, Corp., an
Alberta, Canada corporation and a wholly owned subsidiary of the Company (“Trio Canada”), and Novacor Exploration Ltd., a
corporation incorporated under the Canada Business Corporations Act (“Novacor”), pursuant to which, subject to the terms
and conditions set forth in the APA, Trio Canada agreed to acquire certain assets of Novacor relating its oil and gas business, including
certain contracts, leases and permits for working interests in petroleum and natural gas and mineral rights located in the Lloydminster,
Saskatchewan heavy oil region in Canada (collectively, the “Novacor Assets”), free and clear of any liens other than certain
specified liabilities of Novacor that are being assumed (collectively, the “Liabilities” and such acquisition of the Novacor
Assets and assumption of the Liabilities together, the “Novacor Acquisition”) for a total purchase price of (i) US$
The
APA provides for the Novacor Acquisition to be closed in two closings. The first closing of the Novacor Acquisition was consummated on
April 8, 2025 (the “First Closing”). At the First Closing, title to certain of the Novacor Assets was delivered to Trio Canada
and the Company delivered to Novacor (i) US$
The
Company has accounted for this transaction as an asset acquisition in accordance with ASC 805 – Business Combinations. As a result,
an asset has been recorded on the balance sheet totaling $
Following the closings, (i) operating costs for the Novacor Assets will for a period of two (2) years, be held at the levels detailed in the auditor’s report over the eighteen (18) month period prior to the closings, unless otherwise mutually agreed to by the parties (ii) after such two-year period, operating costs will remain competitive with other operators in the area; and (iii) Trio Canada may terminate the Novacor’s post-closings actions at any time on 30 days’ prior written notice to Novacor. After the closings, Novacor will act as the on-site operator of the Novacor Assets and perform all work and services as provided in the APA.
See Note 10 for additional information.
| 13 |
NOTE 6 – RELATED PARTY TRANSACTIONS
South Salinas Project – Related Party
Upon
its formation, the Company acquired from Trio LLC a majority working interest in the South Salinas Project and engaged the services of
certain members of Trio LLC to manage the Company’s assets (see Note 1 and Note 5). Trio LLC operates the South Salinas Project
on behalf of the Company, and as operator, conducts and has full control of the operations within the constraints of the Joint Operating
Agreement, and acts in the capacity of an independent contractor. Trio LLC currently holds a
McCool Ranch Oil Field Asset Purchase – Related Party
On
October 16, 2023, the Company entered into the McCool Ranch Purchase Agreement with Trio LLC for purchase of a
On May 27, 2025, the Company made the decision to abandon the McCool Ranch
Oil Field leases. Because the conditions leading to this decision existed as of April 30, 2025, this event qualifies as a recognized subsequent
event under ASC 855-10-25-1 and has been reflected in the financial statements for the period ended April 30, 2025. Accordingly, all capitalized
costs related to the acquisition, refurbishment, and production restart—including costs for support equipment and facilities—totaling
$
Restricted Stock Units (“RSUs”) issued to Directors
On
June 19, 2024, the Company agreed to award restricted stock units to a newly appointed director under the Plan; as there were
only shares remaining for issuance under the Plan at that time, RSUs were awarded immediately with a fair value of $
per share for a grant date value of $
On
October 21, 2024, the Company agreed to award restricted stock units to a newly appointed director under the Plan; the RSUs vest
at a rate of % upon the six month anniversary of the commencement date and were recorded at a fair value of $ per share for a
grant date value of $
Restricted Shares issued to Executives and Employees
In
May 2023, the Company entered into six employee agreements which, among other things, provided for the grant of an aggregate of
restricted shares pursuant to the Plan. Per the terms of the employee agreements, subject to continued employment, the restricted shares
vest as follows: % of the shares vested five months after the issuance date, after which the remainder vest in equal tranches every
six months until fully vested. The shares were recorded on the date of issuance at a fair value of $ per share for an aggregate
fair value of $
On
July 11, 2024, the Company and Mr. Peterson (the Company’s former Chief Executive Officer) entered into a three-month consulting
agreement, which includes a monthly cash fee of $
On
July 11, 2024, the Company entered into an employment agreement with Mr. Robin Ross, pursuant to which Mr. Ross will serve as Chief Executive
Officer of the Company, replacing Mr. Peterson. Pursuant to the Ross Employment Agreement, Mr. Ross will be paid an annual base salary
of $
On
October 21, 2024, the Company agreed to award restricted stock units to its CFO under the Plan; the RSUs vest at a rate of %
upon the six month anniversary of the commencement date and were recorded at a fair value of $ per share for a grant date value of
$
| 14 |
Note Payable – Related Party
On
March 26, 2024, the Company borrowed $
On
September 26, 2024 and October 28, 2024, the Company entered into the first and second amendments, respectively, to the Peterson Note;
each amendment extended the maturity dates to October 28, 2024 and November 30, 2024, respectively, and added a $
Consulting Agreement
On
December 31, 2024, the employment agreement between the Company and Mr. Overholtzer ended, and on January 1, 2025, the Company entered
into an independent contractor agreement with Mr. Overholtzer, under which he continues to serve as the Chief Financial Officer of the
Company and is paid a monthly fee of $
Loan to Trio Canada
As
of April 4, 2025, the Company entered into a Loan and Note Purchase Agreement (the “Loan Agreement”) with Trio Canada, whereby
it made a loan (the “Subsidiary Loan”) to Trio Canada in the amount of $
Under
the terms of the Loan Agreement, $
| 15 |
NOTE 7 – COMMITMENTS AND CONTINGENCIES
From time to time, the Company is subject to various claims that arise in the ordinary course of business. Management believes that any liability of the Company that may arise out of or with respect to these matters will not materially adversely affect the financial position, results of operations, or cash flows of the Company.
Unproved Property Leases
The
Company holds various leases related to the unproved properties of the South Salinas Project; two of the leases are held with the same
lessor. The first lease, which covers
The
second lease covers
During
February and March of 2023, the Company entered into additional leases related to the unproved properties of the South Salinas Project
with two groups of lessors. The first group of leases covers
The
Company holds interests in various leases related to the unproved properties of the McCool Ranch Oil Field. These leases occur in two
parcels, “Parcel 1” and “Parcel 2”. Parcel 1 comprises ten leases and approximately
On
November 10, 2023, the Company entered into the ARLO Agreement with HSO for a term of nine months which allows us the exclusive right
to acquire up to a
On
December 29, 2023, the Company entered into an amendment to the ARLO Agreement, whereby the Company funded $
| 16 |
Per
the most recent amendment to the ARLO Agreement signed in April 2025, the Company had until May 10, 2025 to pay HSO an additional $
Proved Property Leases
In
April 2025, the Company acquired oil and gas lease rights for four leases related to the proved properties located in Saskatchewan, Canada
(see Note 5); the sum total of all four leases is
Board of Directors Compensation
On
July 11, 2022, the Company’s Board of Directors approved compensation for each of the non-employee directors of the Company, which
would be effective upon the consummation of the IPO. Such compensation is structured as follows: an annual retainer of $ cash plus
an additional $ for each Board committee upon which the Director serves, each paid quarterly in arrears. Payment for this approved
compensation commenced upon successful completion of the Company’s IPO in April 2023, and for the three and six months ended April
30, 2025, the Company recognized $
Agreements with Advisors
On
July 28, 2022, the Company entered into a placement agent agreement with the Placement Agent with Spartan Capital Securities, LLC (“Spartan”),
whereby Spartan agreed to serve as the exclusive agent, advisor or underwriter in any offering of securities of the Company for a one-year
term. The agreement provided for a $
On
October 4, 2023 and December 29, 2023, the Company entered into additional placement agent agreements with Spartan, whereby Spartan would
serve as the exclusive placement agent in connection with the closing of private placements. The agreements provided the agent with
Notice of Delisting or Failure to Satisfy a Continued Listing Rule or Standard from the NYSE American
On November 5, 2024, the Company received notice from NYSE American that NYSE American had halted trading in the shares of the Common Stock until the effectiveness of the reverse stock split the Company intended to effect because its common stock was consistently selling at a low selling price per share in violation of Section 1003(f)(v) of the NYSE American Company Guide. NYSE American informed the Company that it would attempt to reopen trading in the Common Stock on November 15, 2024, which is when the common stock is expected to begin trading on a post-split basis, provided that NYSE American no longer deems the selling price of the Common Stock to be too low.
| 17 |
NOTE 8 – NOTES PAYABLE
Notes payable as of April 30, 2025 and October 31, 2024 consisted of the following:
As of April 30, 2025 | As of October 31, 2024 | |||||||
| Promissory notes, net of discounts | ||||||||
| Payable – related party | ||||||||
| Convertible note, net of discounts | ||||||||
| Note Payable, related party | ||||||||
| Total Notes payable | $ | $ | ||||||
Payable – related party
See Note 6 - McCool Ranch Oil Field Asset Purchase – Related Party for further information.
March 2024 Debt Financing
The
Company executed a Securities Purchase Agreement, dated March 27, 2024 (the “SPA”) with an institutional investor (the “March
2024 Investor”), which March 2024 Investor signed and funded on April 5, 2024, and pursuant to which the Company raised gross proceeds
of $
In
connection with the March 2024 Debt Financing, the Company issued an unsecured promissory note to the March 2024 Investor, dated March
27, 2024, in the principal amount of $
On
September 30, 2024, October 30, 2024 and November 30, 2024, the Company made cash payments in the amounts of $
Note Payable – Related Party
On
March 26, 2024, the Company borrowed $
On
September 26, 2024 and October 28, 2024, the Company entered into the first and second amendments, respectively, to the Peterson Note;
each amendment extended the maturity dates to October 28, 2024 and November 30, 2024, respectively, and added a $
June 2024 Convertible Debt Financings
On
June 27, 2024, the Company entered into a securities purchase agreement (the “June 2024 SPA”) with the same April 2024 Investors
(the “June 2024 Investors”). Pursuant to the terms and conditions of the June 2024 SPA, each June 2024 Investor provided
financing of $
| 18 |
Commencing
on the 90th day following the original issue date of the June 2024 Notes, the Company is required to pay to the June 2024
Investors the outstanding principal balance under the June 2024 Notes in monthly installments, on such date and each one (1) month anniversary
thereof, in an amount equal to
The
Company may repay all or any portion of the outstanding principal amount of the June 2024 Notes, subject to a
On
September 26, 2024, October 1, 2024, and October 30, 2024, the Company made principal payments towards the June 2024 Notes in the amounts
of $
On
December 2, 2024, December 20, 2024 and January 7, 2025, the Company made principal payments in the amounts of $
August 1, 2024 Financing
On
August 1, 2024, the Company entered into a Securities Purchase Agreement (the “August 1st SPA”) with an investor,
pursuant to which the Company raised gross proceeds of $
| 19 |
On
January 30, 2025, the Company made a principal payment of $
August 6, 2024 Financing
On
August 6, 2024, the Company entered into a Securities Purchase Agreement (the “August 6th SPA”) with an investor,
pursuant to which the Company raised gross proceeds of $
Additionally,
in conjunction with two prior investors and the April 2024 Debt Financing, the Company will make two payments of $
On
January 28, 2025, the Company entered into a Note Exchange Agreement, whereby it and the investor agreed to exchange the outstanding
balance of $
As
of April 30, 2025, the balance of the August 6, 2024 Financing was $
April 2025 Financing
On
April 11, 2025, we issued an Unsecured Original Discount Convertible Promissory Note (the “Note”) to an institutional investor
(the “Convertible Note Investor”) in a principal amount of $
On
April 17, 2025, we issued an amended and restated Unsecured Original Discount Convertible Promissory Note (the “Amended and Restated
Note”), in an aggregate principal amount, with the principal amount of the Note, of $
The Amended and Restated Note provides for both voluntary conversion by the Convertible Note Investor and a right for TPET to require conversion, subject to certain conditions into shares of common stock. The Amended and Restated Note also contains “piggyback” registration rights and the shares issuable upon conversion of the Amended and Restated Note are being registered in the registration statement of which this prospectus forms a part in order to comply with such registration obligations.
As
of April 30, 2025, the balance of the April 2025 Financing was $
| 20 |
NOTE 9 – STOCKHOLDERS’ EQUITY
Common Shares
On
January 1, 2025, the Company entered into an agreement with a consulting firm to provide investor communications and public relations
services. As part of the compensation payable, the Company issued common shares at a fair value per share of $ for a total
value of $
On
January 28, 2025, the Company entered into a Note Exchange Agreement with the investor from the August 6th Financing, pursuant to which
the outstanding balance of $
On
April 11, 2025, the Company issued common shares at a fair value of $ per share for a total value of $
Series 1 Preferred Shares
Trio
Canada holds an unlimited number of Series 1 Preferred Shares; under the terms of the shares, (i) holders of such shares may require
the entity to purchase their shares upon submission of a retraction notice, (ii) Trio Canada is obligated to redeem the shares within
30 days of receiving a retraction notice and (iii) Trio Canada may redeem the shares at its discretion at any time. On April 4, 2025,
Trio Canada issued Series 1 Preferred shares (which are redeemable at CAD$) at a value of US$
Warrants
A summary of the warrant activity during the six months ended April 30, 2025 is presented below:
| Weighted | ||||||||||||||||
| Weighted | Average | |||||||||||||||
|
Average | Remaining | |||||||||||||||
Number of Warrants | Exercise Price | Life in Years | Intrinsic Value | |||||||||||||
| Outstanding, November 1, 2024 | $ | $ | ||||||||||||||
| Expired | ( | ) | - | - | ||||||||||||
| Outstanding, April 30, 2025 | $ | $ | ||||||||||||||
| Exercisable, April 30, 2025 | $ | $ | ||||||||||||||
A summary of the warrant activity during the three and six months ended April 30, 2024 is presented below:
| Weighted | ||||||||||||||||
| Weighted | Average | |||||||||||||||
| Average | Remaining | |||||||||||||||
Number of Warrants | Exercise Price | Life in Years | Intrinsic Value | |||||||||||||
| Outstanding, November 1, 2023 | $ | $ | ||||||||||||||
| Issued | - | |||||||||||||||
| Outstanding, April 30, 2024 | $ | $ | ||||||||||||||
| Exercisable, April 30, 2024 | $ | $ | ||||||||||||||
| 21 |
A summary of outstanding and exercisable warrants as of April 30, 2025 is presented below:
| Warrants Outstanding | Warrants Exercisable | |||||||||||||
Exercise Price | Number of Shares | Weighted Average Remaining Life in Years | Number of Shares | |||||||||||
| $ | ||||||||||||||
| $ | ||||||||||||||
| $ | ||||||||||||||
| $ | ||||||||||||||
| $ | ||||||||||||||
| $ | ||||||||||||||
| $ | ||||||||||||||
Stock Options
Number of Options | Weighted Average Exercise Price | Weighted Average Remaining Life in Years | Intrinsic Value | |||||||||||||
| Outstanding, November 1, 2024 | $ | $ | ||||||||||||||
| Issued | - | |||||||||||||||
| Outstanding, April 30, 2025 | $ | $ | ||||||||||||||
| Exercisable, April 30, 2025 | $ | $ | ||||||||||||||
A summary of the option activity during the six months ended April 30, 2024 is presented below:
Number of Options | Weighted Average Exercise Price | Weighted Average Remaining Life in Years | Intrinsic Value | |||||||||||||
| Outstanding, November 1, 2023 | $ | $ | ||||||||||||||
| Issued | - | |||||||||||||||
| Outstanding, April 30, 2024 | $ | $ | ||||||||||||||
| Exercisable, April 30, 2024 | $ | $ | ||||||||||||||
| 22 |
| Options Outstanding | Options Exercisable | |||||||||||
Exercise Price | Number of Shares | Weighted Average Remaining Life in Years | Number of Shares | |||||||||
| $ | ||||||||||||
On August 15, 2023, the Company issued five-year options to purchase shares of the Company’s common stock to a consultant of the Company, pursuant to the Plan. The options have an exercise price of $ per share and vest monthly over a period of months, beginning on the vesting commencement date. The options have a grant date fair value of $, which will be recognized over the vesting term.
| Risk free interest rate | % | |||
| Expected term (years) | ||||
| Expected volatility | % | |||
| Expected dividends rate | % |
NOTE 10 – SUBSEQUENT EVENTS
In accordance with ASC 855 – Subsequent Events, which establishes general standards of accounting for and disclosure of events that occur after the balance sheet date but before condensed consolidated financial statements are issued, the Company has evaluated all events and transactions that occurred after April 30, 2025, through the date the condensed consolidated financial statements were issued. Except for the following, there are no subsequent events identified that would require disclosure in the condensed consolidated financial statements.
Letter of Intent with HSO
On
May 15, 2025, the Company entered into a non-binding Letter of Intent (LOI) with HSO for the potential acquisition of
Asphalt Ridge Leasehold Option Not Exercised
Effective
as of May 10, 2025, the Company’s option to acquire the remaining
Second Closing of Novacor Acquisition
On
May 21, 2025, the Second Closing of the Novacor Acquisition was consummated; title to certain of the assets was delivered to the Buyer,
and the Buyer delivered to the Seller $
Abandonment of McCool Ranch Properties
As
of May 27, 2025, the Company and Trio LLC executed a Termination Agreement, pursuant to which the Company terminated all operations and
abandoned all leases at this location. Because the conditions leading to this decision existed as of April 30, 2025, this event qualifies
as a recognized subsequent event under ASC 855-10-25-1 and has been reflected in the financial statements for the period ended April
30, 2025. Accordingly, all capitalized costs related to the acquisition, refurbishment, and production restart—including costs
for support equipment and facilities—totaling $
| 23 |
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
You should read the following discussion and analysis of financial condition and operating results together with our condensed consolidated financial statements and the related notes and other financial information included elsewhere in this quarterly report on Form 10-Q, as well as our audited financial statements and related notes as disclosed in our Form 10-K/A for the year ended October 31, 2024, filed with the SEC on April 15, 2025 (“our Form 10-K/A”). This discussion contains forward-looking statements that involve risks and uncertainties. As a result of many factors, such as those in this Quarterly Report on Form 10-Q, as well as the risk factors set forth in the section titled “Risk Factors” included in our Form 10-K/A, our actual results may differ materially from those anticipated in these forward-looking statements. For convenience of presentation some of the numbers have been rounded in the text below.
Throughout this report, the terms “our,” “we,” “us,” and the “Company” refer to Trio Petroleum Corp.
CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS
This Quarterly Report on Form 10-Q contains forward-looking statements that can involve substantial risks and uncertainties. All statements other than statements of historical facts contained in this Quarterly Report, including statements regarding our future results of operations and financial position, business strategy, prospective products, product approvals, research and development costs, future revenue, timing and likelihood of success, plans and objectives of management for future operations, future results of anticipated products and prospects, plans and objectives of management are forward-looking statements. These statements involve known and unknown risks, uncertainties and other important factors that may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by the forward-looking statements.
In some cases, you can identify forward-looking statements by terms such as “anticipate,” “believe,” “contemplate,” “continue,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “potential,” “predict,” “project,” “should,” “target,” “will,” or “would” or the negative of these terms or other similar expressions, although not all forward-looking statements contain these words. Risks, risk factors and uncertainties involved in forward-looking statements contained in this Form 10-Q include, but are not limited to, the following:
| ● | our ability to find, acquire or gain access to other properties, discoveries and prospects and to successfully develop our current properties, discoveries and prospects; | |
| ● | uncertainties inherent in making estimates of our oil and natural gas resources; | |
| ● | the successful implementation of our prospective discovery, development and drilling plans with the South Salinas Project; | |
| ● | projected and targeted capital expenditures and other costs, commitments and revenues; | |
| ● | our dependence on our key management personnel and our ability to attract and retain qualified technical personnel; | |
| ● | the ability to obtain financing and the terms under which such financing may be available; | |
| ● | the volatility of oil and natural gas prices; | |
| ● | the availability and cost of developing appropriate infrastructure around and transportation to our discoveries and prospects; | |
| ● | the availability and cost of drilling rigs, production equipment, supplies, personnel and oilfield services; | |
| ● | other competitive pressures; |
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| ● | potential liabilities inherent in oil and natural gas operations, including drilling risks and other operational and environmental hazards; | |
| ● | current and future government regulation of the oil and gas industry; | |
| ● | cost of compliance with laws and regulations; | |
| ● | changes in environmental, health and safety or climate change laws, greenhouse gas regulation or the implementation of those laws and regulations; | |
| ● | environmental liabilities; | |
| ● | geological, technical, drilling and processing problems; | |
| ● | military operations, terrorist acts, wars or embargoes; | |
| ● | the cost and availability of adequate insurance coverage; | |
| ● | our vulnerability to severe weather events; and | |
| ● | other risk factors discussed in the “Risk Factors” section of this Quarterly Report and in our Form 10-K/A. |
We have based these forward-looking statements largely on our current expectations and projections about our business, the industry in which we operate and financial trends that we believe may affect our business, financial condition, results of operations and prospects, and these forward-looking statements are not guarantees of future performance or development. These forward-looking statements speak only as of the date of this Quarterly Report and are subject to a number of risks, uncertainties and assumptions described in the section titled “Risk Factors” and elsewhere in this Quarterly Report. Because forward-looking statements are inherently subject to risks and uncertainties, some of which cannot be predicted or quantified, you should not rely on these forward-looking statements as predictions of future events. The events and circumstances reflected in our forward-looking statements may not be achieved or occur and actual results could differ materially from those projected in the forward-looking statements. Except as required by applicable law, we do not plan to publicly update or revise any forward-looking statements contained herein until after we distribute this Quarterly Report, whether as a result of any new information, future events or otherwise.
In addition, statements that “we believe” and similar statements reflect our beliefs and opinions on the relevant subject. These statements are based upon information available to us as of the date of this Quarterly Report, and while we believe such information forms a reasonable basis for such statements, such information may be limited or incomplete, and our statements should not be read to indicate that we have conducted an exhaustive inquiry into, or review of, all potentially available relevant information. These statements are inherently uncertain, and you are cautioned not to unduly rely upon these statements.
Overview
We are a California-based oil and gas exploration and development company headquartered in Malibu, California, with our principal executive offices located at 23823 Malibu Road, Suite 304, Malibu, California 90265, with operations in Monterey County, California, Uintah County, Utah and Lloydminster, Saskatchewan.
We have had revenue-generating operations since the McCool Ranch Oil Field was restarted on February 22, 2024, and recognized our first revenues in our fiscal quarter ended April 30, 2024, and received the proceeds from these operations in June 2024. We have recently generated revenues during the period ended April 30, 2025 from our newly acquired properties in Saskatchewan, Canada.
Our Canadian project has the potential through workovers to double production which we immediately began planning following closing. Novacor, whom we acquired the project from, is one of the lowest cost operators with lift costs of $10 per barrel. Our focus remains on acquiring projects that generate immediate cash flow or offer transformative growth potential with strategic investment.
We were formed to initially acquire an approximate 82.75% working interest (which was subsequently increased to an approximate 85.775% working interest) from Trio LLC (“Trio LLC”) in the large, approximately 9,300-acre South Salinas Project that is located in Monterey County, California, and subsequently partner with certain members of Trio LLC’s management team to develop and operate those assets. We hold an approximate 68.62% interest after the application of royalties (“net revenue interest”) in the South Salinas Project. Trio LLC holds an approximate 3.8% working interest in the South Salinas Project. We and Trio LLC are separate and distinct companies.
Initially, California was a significant part of our geographic focus; however, due to rising drilling costs and the negative impact on potential profitability, we have strategically shifted our efforts beyond California to pursue more economically viable opportunities. This transition is reflected in our acquisition of an interest in the Asphalt Ridge Project in Uintah County, Utah, as well as our recent acquisition of additional oil and gas assets in the prolific Lloydminster, Saskatchewan heavy oil region.
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South Salinas Project
Efforts to obtain from Monterey County conditional use permits and a full field development permit for the South Salinas Project are progressing. Efforts to obtain from the California Geologic Energy Management Division (“CalGEM”) and from the California Water Boards a permit for a water disposal project at the South Salinas Project are also progressing. In the meantime, the Company recently determined that existing permits allow production testing to continue at the HV-3A discovery well at Presidents Field and, consequently, testing operations were restarted at this well on March 22, 2024. Oil production from this well has occurred and the Company is assessing steps to attempt to increase the well’s gross production rate, for example by adding up to 650 feet of additional perforations in the oil zone and/or acidizing the well for borehole cleanup. First oil sales from the HV-3A well occurred in the third calendar quarter of 2024 but is currently idled as we further discussions with local oil and gas companies to joint venture the project.
McCool Ranch Oil Field
On October 16, 2023, we entered into a Purchase and Sale Agreement with Trio LLC (the “McCool Ranch Purchase Agreement”) pertaining to the McCool Ranch Oil Field. Pursuant to this agreement, effective October 1, 2023, we entered into an agreement to acquire an approximate 22% working interest in and to certain oil and gas assets at the McCool Ranch Field, located in Monterey County, California, near our flagship South Salinas Project.
The acquired assets included six oil wells, a water-disposal well, a steam generator, boiler, storage tanks, and various operational infrastructure. While initial production was restarted on February 22, 2024, we have subsequently determined that under previously negotiated terms, natural gas prices and water disposal costs, particularly in California, makes it cost prohibitive for the Company to employ cyclic-steam operations to increase production and will not be economically feasible in the long run. On May 27, 2025, we executed a termination agreement with Trio LLC to end operations at the location and abandon all related leases. Capitalized costs totaling $500,614 have been written off and expensed in the statement of operations for the period ended April 30, 2025.
Asphalt Ridge Option Agreement and the Lafayette Energy Leasehold Acquisition and Development Option Agreement
On November 10, 2023, TPET entered into a Leasehold Acquisition and Development Option Agreement (the “Asphalt Ridge Option Agreement”) with Heavy Sweet Oil LLC (“HSO”). Pursuant to the Asphalt Ridge Option Agreement, the Company acquired an option to purchase up to a 20% working interest in certain leases at a long-recognized, major oil accumulation in northeastern Utah, including an initial 960 acres and a subsequent 1,920 acres, as well as a right-of-refusal option on approximately 30,000 acres.
On December 29, 2023, the Company and HSO entered into an Amendment to the Asphalt Ridge Option Agreement, under which the Company funded $200,000 in exchange for an immediate 2% working interest in the initial 960 acres. An additional $25,000 was funded in January 2024, increasing the Company’s working interest to 2.25%. While the Company had the option to acquire an additional 17.75% working interest, it has decided not to exercise this option and will instead retain its existing 2.25% working interest in the initial 960 acres.
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Novacor Asset Purchase Agreement
As of April 4, 2025, we entered into an Asset Purchase Agreement (the “APA”) with Trio Petroleum Canada, Corp., an Alberta, Canada corporation and a wholly owned subsidiary of the Company (“Trio Canada”), and Novacor Exploration Ltd., a corporation incorporated under the Canada Business Corporations Act (“Novacor”), pursuant to which, subject to the terms and conditions set forth in the APA, Trio Canada agreed to acquire certain assets of Novacor relating its oil and gas business, including certain contracts, leases and permits for working interests in petroleum and natural gas and mineral rights located in the Lloydminster, Saskatchewan heavy oil region in Canada (collectively, the “Novacor Assets”), free and clear of any liens other than certain specified liabilities of Novacor that are being assumed (collectively, the “Liabilities” and such acquisition of the Novacor Assets and assumption of the Liabilities together, the “Novacor Acquisition”) for a total purchase price of (i) US$650,000, in cash, US$65,000 of which was previously provided as a deposit to Novacor, and (ii) the issuance to Novacor of 526,536 shares of common stock of common stock (the “Novacor Shares”). The Novacor Acquisition was consummated in two closings, which was completed on May 22, 2025. All five of our currently active wells are in the newly acquired Novacor property
P.R. Spring Letter of Intent and Option
On May 15, 2025, the Company entered into a non-binding Letter of Intent (LOI) with Heavy Sweet Oil LLC (“HSO”) for the potential acquisition of 2,000 acres of oil and gas properties at P.R. Spring, Uintah Basin, Utah (“P.R. Spring”), which is adjacent to Asphalt Ridge. The LOI contemplates our issuance of 1,492,272 restricted shares of common stock and the payment of $850,000 at closing, subject to execution of definitive agreements. Upon signing the LOI, we made a non-refundable $150,000 payment to HSO in consideration for the option. The LOI requires evidence of a minimum sustained production rate of 40 barrels per day for a continuous 30-day period from two wells at Asphalt Ridge by May 15, 2026, or the LOI will expire unless extended by us. We are not under any obligation to enter into definitive agreements in connection with an acquisition.
Carbon Capture and Storage Project as part of Company’s South Salinas Project
We are committed to attempting to reduce our own carbon footprint and, where possible, that of others. For this reason, we are taking initial steps to launch a Carbon Capture and Storage (“CCS”) project as part of the South Salinas Project, which appears ideal for such a task. The South Salinas Project covers a vast area and is uniquely situated at a deep depocenter where there are thick geologic zones (e.g., Vaqueros Sand, up to approximately 500’ thick) about two miles deep, which could accommodate and permanently store vast volumes of CO2. Four existing deep wells in the South Salinas Project (i.e., the HV 1-35, BM 2-2, BM 1-2-RD1 and HV 3-6 wells) are excellent candidates for use as CO2 injection wells. A CCS project in the future may help reduce our carbon footprint by sequestering and permanently storing CO2 deep underground at one or more deep wells, away from drinking water sources. Furthermore, three of the aforementioned deep wells are directly located on three idle oil and gas pipelines that could be used to import CO2 to our CCS Project. We have opened discussions with third parties who wish to reduce their own greenhouse gas emissions and who may be interested in participating in our CCS project. We believe it is feasible to develop the major oil and gas resources of the South Salinas Project and to concurrently establish a substantial CCS project and potentially a CO2 storage hub and/or Direct Air Capture (DAC) hub.
Going Concern Considerations
We have only begun to generate revenues in the prior fiscal year and have incurred significant losses since inception. As of April 30, 2025, we have an accumulated deficit of $23,252,956 and a working capital deficit of $531,983, and for the three and six months ended April 30, 2025, net losses of $1,563,752 and $3,179,277, respectively, and cash used in operating activities of $1,660,469. To date, we have been funding operations through proceeds from the issuance of common stock, financing through certain investors, the consummation of our initial public offering (“IPO”) in April 2023, and convertible note financing under two tranches in October 2023 and December 2023, pursuant to which the Company raised total gross proceeds of $2,371,500. Additionally, in 2024 the Company received funds in the amount of $125,000 from an unsecured promissory note from its former CEO, gross proceeds of $543,500 from promissory notes with investors, gross proceeds of $1,440,000 from convertible debt financing with investors and net proceeds of approximately $4,650,000 in connection with an “at-the-market” agreement entered into in September 2024. In April 2025, the Company received gross proceeds in the amount of $606,000 from a convertible debt financing provided by one investor.
There is substantial doubt regarding our ability to continue as a going concern as a result of our accumulated deficit. Our current source of revenue is insufficient to cover our operating costs and we are dependent on private equity and external financing to sustain operations.
The accompanying condensed consolidated financial statements have been prepared assuming we will continue as a going concern. As we have only begun to generate revenues, we need to raise a significant amount of capital to pay for our development, exploration, drilling and operating costs. While we raised capital in April 2023 in our IPO, in October 2023, December 2023, April 2024, June 2024 and April 2025 with convertible debt financing, in March 2024 and August 2024 with promissory notes, September 2024 with an ATM agreement, we expect to require additional funding in the future and there is no assurance that we will be able to raise additional needed capital or that such capital will be available under favorable terms or at all. We are subject to all the substantial risks inherent in the development of a new business enterprise within an extremely competitive industry. Due to the absence of a long-standing operating history and the emerging nature of the markets in which we compete, we anticipate operating losses until we can successfully implement our business strategy, which includes all associated revenue streams. We may never achieve profitable operations or generate significant revenues.
We will require additional capital funding in order to drill additional planned wells at the South Salinas and Asphalt Ridge assets and to pay for additional development costs and other payment obligations and operating costs until our planned revenue streams are fully implemented and begin to offset our operating costs, if ever.
Since our inception, we have funded our operations with the proceeds from equity and debt financing. We have experienced liquidity issues due to, among other reasons, our limited ability to raise adequate capital on acceptable terms. We have historically relied upon the issuance of equity and promissory notes that are convertible into shares of our common stock to fund our operations and have devoted significant efforts to reduce that exposure. We anticipate that we will need to issue equity to fund our operations for the foreseeable future. If we are unable to achieve operational profitability or are not successful in securing other forms of financing, we will have to evaluate alternative actions to reduce our operating expenses and conserve cash.
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The accompanying condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America on a going concern basis, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business. Accordingly, the condensed consolidated financial statements do not include any adjustments relating to the recoverability of assets and classification of liabilities that might be necessary should we be unable to continue as a going concern. The condensed consolidated financial statements included in this report also include a going concern footnote (see Note 3).
Factors and Trends Affecting Our Business and Results of Operations
We are mindful of global economic trends and their potential influence on commodity prices. Recent fluctuations in global oil prices, political considerations and tariffs can impact cash flow and ultimately profitability. Mitigating factors include our relatively low lift costs and a continued commitment to cost management and efficient production techniques. Our ability to continue to grow our business will in large part depend on continued access to receptive capital markets.
Emerging Growth Company Status
We are an “emerging growth company,” as defined in Section 2(a) of the Securities Act, as modified by the JOBS Act, and it may take advantage of certain exemptions from various reporting requirements that are applicable to other public companies that are not emerging growth companies including, but not limited to, not being required to comply with the auditor attestation requirements of Section 404(b) of the Sarbanes-Oxley Act of 2002, reduced disclosure obligations regarding executive compensation in periodic reports and proxy statements, and exemptions from the requirements of holding a nonbinding advisory vote on executive compensation and stockholder approval of any golden parachute payments not previously approved. Further, Section 102(b)(1) of the JOBS Act exempts emerging growth companies from being required to comply with new or revised financial accounting standards until private companies (that is, those that have not had a Securities Act registration statement declared effective or do not have a class of securities registered under the Exchange Act) are required to comply with the new or revised financial accounting standards. The JOBS Act provides that a company can elect to opt out of the extended transition period and comply with the requirements that apply to non-emerging growth companies but any such election to opt out is irrevocable. We have elected not to opt out of such extended transition period which means that when a standard is issued or revised and it has different application dates for public or private companies, we, as an emerging growth company, can adopt the new or revised standard at the time private companies adopt the new or revised standard. This may make comparison of our condensed consolidated financial statements with another public company which is neither an emerging growth company nor an emerging growth company which has opted out of using the extended transition period difficult or impossible because of the potential differences in accounting standards used.
Results of Operations
Three Months Ended April 30, 2025 compared to the Three Months Ended April 30, 2024 (unaudited)
Our financial results for the three months ended April 30, 2025 and 2024 are summarized as follows:
For the Three Months Ended April 30, | ||||||||||||||||
| 2025 | 2024 | Change | % Change | |||||||||||||
| Revenues, net | $ | 23,271 | $ | 72,923 | $ | (49,652 | ) | (68.1 | )% | |||||||
| Cost of goods sold | 9,262 | - | 9,262 | 100.0 | % | |||||||||||
| Gross profit | 14,009 | 72,923 | (58,914 | ) | (80.8 | )% | ||||||||||
| Operating expenses: | ||||||||||||||||
| Exploration expenses | $ | 11,161 | $ | 40,223 | $ | (29,062 | ) | (72.3 | )% | |||||||
| General and administrative expenses | 755,481 | 1,475,685 | (720,204 | ) | (48.8 | )% | ||||||||||
| Stock-based compensation expense | 115,652 | 504,912 | (389,260 | ) | (77.1 | )% | ||||||||||
| Accretion expenses | 694 | 694 | - | 0.0 | % | |||||||||||
| Total operating expenses | 882,988 | 2,021,514 | (1,138,526 | ) | (56.3 | )% | ||||||||||
| Loss from Operations | (868,979 | ) | (1,948,591 | ) | 1,079,612 | (55.4 | )% | |||||||||
| Other expenses: | ||||||||||||||||
| Interest expenses | 30,154 | 982,691 | (952,537 | ) | (96.9 | )% | ||||||||||
| Settlement fees | - | 10,500 | (10,500 | ) | (100.0 | )% | ||||||||||
| Loss on abandonment of oil and gas properties | 574,419 | - | 574,419 | 100.0 | % | |||||||||||
| Loss on extinguishment | 90,200 | - | 90,200 | 100.0 | % | |||||||||||
| Loss on note conversion | - | 1,104,153 | (1,104,153 | ) | (100.0 | )% | ||||||||||
| Total other expenses | 694,773 | 2,097,344 | (1,402,571 | ) | (66.9 | )% | ||||||||||
| Loss before income taxes | (1,563,752 | ) | (4,045,935 | ) | 2,482,183 | (61.4 | )% | |||||||||
| Income tax benefit | - | - | - | - | ||||||||||||
| Net loss | $ | (1,563,752 | ) | $ | (4,045,935 | ) | $ | 2,482,183 | (61.4 | )% | ||||||
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Revenues, net
Revenues, net decreased for the three months ended April 30, 2025 by approximately $50,000 as compared to the prior period; revenues from the prior period were from the sale of approximately 2,100 barrels of oil from our McCool Ranch field, which operations were terminated in May 2025. Current revenues are the sale of approximately 550 barrels of oil from our recently acquired assets in the Lloydminster, Saskatchewan region.
Exploration expenses
Under the successful efforts method of accounting for crude oil and natural gas properties, exploration expenses consist primarily of exploratory, geological and geophysical costs, delay rentals and exploratory overhead, and are expensed as incurred. Exploration expenses decreased by approximately $0.1 million as compared to the prior year period due to a decrease in exploratory, geological, and geophysical costs incurred during the period.
General and administrative expenses
General and administrative expenses consist primarily of personnel expenses, including salaries, benefits and stock-based compensation expense for employees and consultants in executive, finance and accounting, legal, operations support, information technology and human resource functions. General and administrative expenses also include corporate facility costs including rent, utilities, depreciation, amortization and maintenance, as well as legal fees related to intellectual property and corporate matters and fees for accounting and consulting services.
General and administrative expenses decreased for the three months ended April 30, 2025 by approximately $0.7 million as compared to the prior period due to (i) a decrease in advertising and marketing fees of approximately $235,000, (ii) decreased legal fees of approximately $165,000 and (iii) decreased salaries and wages of approximately $245,000, respectively.
Stock-based compensation expense
We record stock-based compensation expenses for costs associated with options and restricted shares granted in connection with the Plan, as well as for shares issued as payment for services. Stock-based compensation expense decreased by approximately $0.4 million for the three months ended April 30, 2025 due to the amortization of approximately 30,000 more options in the prior three month period than in the current period.
Accretion expenses
We have an Asset Retirement Obligation (“ARO”) recorded that is associated with its oil and natural gas properties in the SSP; the fair value of the ARO was recorded as a liability and is accreted over time until the date the ARO is to be paid. For the three months ended April 30, 2025, accretion expenses remained consistent with that of the prior year period.
Other expenses, net
For the three months ended April 30, 2025, other expenses, net decreased by approximately $1.4 million when compared to the prior year period. This decline was primarily driven by (i) an approximate $1.0 million reduction in non-cash interest expense resulting from lower debt levels in the current period (non-cash interest expense is recognized as debt discounts on financings are amortized), as well as (ii) an approximate $1.1 million loss on a note conversion recorded in the prior period, which stemmed from principal payments made via conversion shares under the October 2023 Securities Purchase Agreement. These reductions were partially offset by a $0.6 million loss incurred in the current period due to the abandonment of oil and gas properties.
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Six Months Ended April 30, 2025 compared to the Six Months Ended April 30, 2024 (unaudited)
Our financial results for the six months ended April 30, 2025 and 2024 are summarized as follows:
For the Six Months Ended April 30, | ||||||||||||||||
| 2025 | 2024 | Change | % Change | |||||||||||||
| Revenues, net | $ | 34,090 | $ | 72,923 | $ | (38,833 | ) | (53.3 | )% | |||||||
| Cost of goods sold | 9,262 | - | 9,262 | 100.0 | % | |||||||||||
| Gross profit | 24,828 | 72,923 | (48,095 | ) | (66.0 | )% | ||||||||||
| Operating expenses: | ||||||||||||||||
| Exploration expenses | $ | 35,882 | $ | 124,817 | $ | (88,935 | ) | (71.3 | )% | |||||||
| General and administrative expenses | 1,467,027 | 2,433,375 | (966,348 | ) | (39.7 | )% | ||||||||||
| Stock-based compensation expense | 605,966 | 912,530 | (306,564 | ) | (33.6 | )% | ||||||||||
| Accretion expenses | 1,389 | 1,389 | - | 0.0 | % | |||||||||||
| Total operating expenses | 2,110,264 | 3,472,111 | (1,361,847 | ) | (39.2 | )% | ||||||||||
| Loss from Operations | (2,085,436 | ) | (3,399,188 | ) | 1,313,752 | (38.6 | )% | |||||||||
| Other expenses: | ||||||||||||||||
| Interest expenses | 348,520 | 1,141,989 | (793,469 | ) | (69.59 | )% | ||||||||||
| Settlement fees | - | 10,500 | (10,500 | ) | (100.0 | )% | ||||||||||
| Loss on abandonment of oil and gas properties | 574,419 | - | 574,419 | 100.0 | % | |||||||||||
| Loss on extinguishment | 90,200 | - | 90,200 | 100.0 | % | |||||||||||
| Loss on note conversion | 80,702 | 1,196,306 | (1,115,604 | ) | (93.3 | )% | ||||||||||
| Total other expenses | 1,093,841 | 2,348,795 | (1,254,954 | ) | (53.4 | )% | ||||||||||
| Loss before income taxes | (3,179,277 | ) | (5,747,983 | ) | 2,568,706 | (44.7 | )% | |||||||||
| Income tax benefit | - | - | - | - | ||||||||||||
| Net loss | $ | (3,179,277 | ) | $ | (5,747,983 | ) | $ | 2,568,706 | (44.7 | )% | ||||||
Revenues, net
Revenues, net decreased for the six months ended April 30, 2025 by approximately $0.1 million as compared to the prior period; revenues from the six months ended April 30, 2024 were from the sale of approximately 2,100 barrels of oil from our McCool Ranch field, versus the sale of only (i) approximately 200 barrels of oil from our McCool Ranch location and (ii) approximately 550 barrels of oil produced from our recently acquired oil and gas assets in the Lloydminster, Saskatchewan region for the six months ended April 30, 2025.
Exploration expenses
Under the successful efforts method of accounting for crude oil and natural gas properties, exploration expenses consist primarily of exploratory, geological and geophysical costs, delay rentals and exploratory overhead, and are expensed as incurred. Exploration expenses decreased by approximately $0.1 million as compared to the prior year period due to a decrease in exploratory, geological, and geophysical costs incurred during the period.
General and administrative expenses
General and administrative expenses consist primarily of personnel expenses, including salaries, benefits and stock-based compensation expense for employees and consultants in executive, finance and accounting, legal, operations support, information technology and human resource functions. General and administrative expenses also include corporate facility costs including rent, utilities, depreciation, amortization and maintenance, as well as legal fees related to intellectual property and corporate matters and fees for accounting and consulting services.
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General and administrative expenses decreased for the six months ended April 30, 2025 by approximately $1.0 million as compared to the prior period due to decreases in salary expenses, advertising and marketing fees, filing fees and legal fees of approximately $330,000, $235,000, $160,000 and $200,000, respectively.
Stock-based compensation expense
We record stock-based compensation expenses for costs associated with options and restricted shares granted in connection with the Plan, as well as for shares issued as payment for services. For the six months ended April 30, 2025, stock-based compensation expense decreased by approximately $0.3 million compared to the prior period. This decrease was primarily due to the final vesting of certain restricted shares in the previous quarter, which resulted in a lower expense allocation for the current six-month period.
Accretion expenses
We have an Asset Retirement Obligation (“ARO”) recorded that is associated with its oil and natural gas properties in the SSP; the fair value of the ARO was recorded as a liability and is accreted over time until the date the ARO is to be paid. For the six months ended April 30, 2025, accretion expenses remained consistent with that of the prior year period.
Other expenses, net
For the six months ended April 30, 2025, other expenses, net decreased by approximately $1.3 million when compared to the prior year period. This decline was primarily driven by (i) an approximate $0.8 million reduction in non-cash interest expense resulting from lower debt levels in the current period (non-cash interest expense is recognized as debt discounts on financings are amortized), as well as (ii) an approximate $1.1 million loss on a note conversion recorded in the prior period, which stemmed from principal payments made via conversion shares under the October 2023 Securities Purchase Agreement. These reductions were partially offset by a $0.6 million loss incurred in the current period due to the abandonment of oil and gas properties.
Liquidity and Capital Resources
Working Capital/(Deficiency)
Our working capital deficiency as of April 30, 2025, in comparison to our working capital deficiency as of October 31, 2024, can be summarized as follows:
| April 30, 2025 | October 31, 2024 | |||||||
| Current assets | $ | 1,738,678 | $ | 565,219 | ||||
| Current liabilities | 2,270,661 | 2,590,699 | ||||||
| Working capital (deficiency) | $ | (531,983 | ) | $ | (2,025,480 | ) | ||
Current assets increased because of i) an increase to the cash account of approximately $3.4 million due to cash proceeds from the sale of shares related to the ATM agreement. Current liabilities decreased because of (i) a decrease in promissory notes of approximately $0.7 million, (ii) a decrease in notes payable-related parties of $0.2 million and (iii) a decrease in other current liabilities of approximately $0.3 million, offset by increases of approximately $0.6 million and $0.3 million in convertible note debt and deferred consideration payable, respectively.
Cash Flows
Our cash flows for the six months ended April 30, 2025, in comparison to our cash flows for the six months ended April 30, 2024, can be summarized as follows:
| Six months ended April 30, | ||||||||
| 2025 | 2024 | |||||||
| Net cash (used in)/provided by operating activities | $ | (1,660,469 | ) | $ | 682,525 | |||
| Net cash used in investing activities | (453,616 | ) | (1,018,704 | ) | ||||
| Net cash provided by/(used in) financing activities | 3,250,350 | (1,005,098 | ) | |||||
| Effect of foreign currency exchange | 34,846 | - | ||||||
| Net change in cash | $ | 1,171,111 | $ | (1,341,277 | ) | |||
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Cash Flows from Operating Activities
For the six months ended April 30, 2025 and 2024, cash (used in)/provided by operating activities was ($1,660,469) and $682,525, respectively. The cash used in operations for the six months ended April 30, 2025 was primarily attributable to our net loss of $3,179,277, adjusted for non-cash expenses in the aggregate amount of $1,725,452, as well as $206,644 of net cash used to fund changes in the levels of operating assets and liabilities. The cash provided by operations for the six months ended April 30, 2024 was primarily attributable to our net loss of $5,747,983, adjusted for non-cash expenses in the aggregate amount of $6,086,949, as well as $343,559 of net cash provided to fund changes in the levels of operating assets and liabilities.
Cash Flows from Investing Activities
For the six months ended April 30, 2025 and 2024, cash used in investing activities was $453,616 and $1,018,704, respectively. The cash used in investing activities during the six months ended April 30, 2025 is attributable to approximately $0.4 million for assets acquired at the Lloydminster, Saskatchewan properties. The cash used for the six months ended April 30, 2024 is attributable to approximately $1.1 million related to costs for capital expenditures, which were capitalized and are reflected in the balance of the oil and gas property as of April 30, 2024. These amounts were offset by approximately $50,000 in amounts due to operators for costs for the South Salinas Project and the McCool Ranch Option.
Cash Flows from Financing Activities
For the six months ended April 30, 2025 and 2024, cash provided by/(used in) financing activities was $3,250,350 and ($1,005,098), respectively. Cash provided by financing activities during the six months ended April 30, 2025 was primarily attributable to (i) proceeds from the issuance of common shares in connection with an ATM agreement, (ii) proceeds from the issuance of convertible debt of approximately $0.6 million, offset by repayments of related party debt and promissory notes of approximately $0.2 million and $0.6 million, respectively. Cash provided by financing activities during the six months ended April 30, 2024 was primarily attributable to approximately $0.6 million in net proceeds from the issuance of convertible debt and approximately $1.0 million from the issuance of promissory notes and related party notes, offset by payments for the convertible debt in the amount of approximately $2.6 million and debt issuance costs of $0.2 million.
Capital Resources
Since our inception, we have funded our operations with the proceeds from equity and debt financing. We have experienced liquidity issues due to, among other reasons, our limited ability to raise adequate capital on acceptable terms. We have historically relied upon the issuance of equity and promissory notes that are convertible into shares of our common stock to fund our operations and have devoted significant efforts to reduce that exposure. Unless we are able to raise additional capital through equity and/or debt financing, we believe our existing cash and cash flow from operations will be sufficient to meet our working capital and capital expenditure needs for not more than six months from the date of this report. Future capital requirements will depend on many factors, including the time period in which we are able to ramp up the operation of wells and the acquisition of additional properties. To the extent that existing capital and revenue growth are not sufficient to fund future activities, we will need to raise capital through additional equity or debt financings. Additional funds may not be available on terms favorable to us or at all. Failure to raise additional capital, if needed, could have a material adverse effect on our financial position, results of operations and cash flows.
Contractual Obligations and Commitments
Unproved Property Leases
We hold various leases related to the unproved properties of the South Salinas Project; two of the leases are held with the same lessor. The first lease, which covers 8,417 acres, was amended on May 27, 2022 to provide for an extension of then-current force majeure status for an additional, uncontested twelve months, during which we would be released from having to evidence to the lessor the existence of force majeure conditions. As consideration for the granting of the lease extension, we paid the lessor a one-time, non-refundable payment of $252,512; this amount was capitalized and reflected in the balance of the oil and gas property as of October 31, 2022. The extension period commenced on June 19, 2022 and currently, the “force majeure” status has been extinguished by the drilling of the HV-1 well. The ongoing operation and oil production at the HV-3A well maintain the validity of the lease.
The second lease covers 160 acres of the South Salinas Project; it is currently held by delay rental and is renewed every three years. Until drilling commences, we are required to make delay rental payments of $30/acre per year. We are currently in compliance with this requirement and have paid in advance the delay rental payment for the period from October 2024 through October 2025.
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During February and March of 2023, we entered into additional leases related to the unproved properties of the South Salinas Project with two groups of lessors. The first group of leases covers 360 acres and has a term of 20 years; we are required to make rental payments of $25/acre per year. The second group of leases covers 307.75 acres and has a term of 20 years; we are required to make rental payments of $30/acre per year. During the current reporting period, we made the strategic decision to abandon the additional oil and gas leases. As a result, all associated costs related to exploration and development activities, including any capitalized costs for support equipment and facilities, have been expensed in accordance with applicable accounting standards. This decision was based on a comprehensive evaluation of the economic viability and future potential of the leases, considering market conditions, regulatory factors, and operational constraints.
We hold interests in various leases related to the unproved properties of the McCool Ranch Oil Field. These leases occur in two parcels, “Parcel 1” and “Parcel 2”. Parcel 1 comprises ten leases and approximately 480 acres, which are held by delay rental payments that are paid-up and current. Parcel 2 comprises one lease and approximately 320 acres, which is held by production. The total leasehold comprises approximately 800 gross and net acres. As of April 30, 2025, we made the decision to abandon all McCool Ranch leases. Accordingly, these leases have been written off and have been expensed on the statement of operations as of April 30, 2025. No further rental payments or development activities will be pursued.
On November 10, 2023, we entered into the ARLO Agreement with HSO for a term of nine months which allows us the exclusive right to acquire up to a 20% interest in a 960 acre drilling and production program in the Asphalt Ridge leases for $2,000,000, which may be invested in tranches, with an initial tranche closing for an amount no less than $500,000 and paid within seven days subsequent to HSO providing certain required items to us.
On December 29, 2023, we entered into an amendment to the ARLO Agreement, whereby we funded $200,000 of the $500,000 payable by us to HSO at the Initial Closing, in advance of HSO satisfying certain required items for a 2% interest in the leases; such funds are to be used by HSO solely for the building of roads and related infrastructure in furtherance of the development of the leases. As of April 30, 2025, we have paid a total of $225,000 to HSO in costs related to infrastructure and have obtained a 2.25% interest in the leases; such costs are capitalized costs and are reflected in the balance of the oil and gas property as of April 30, 2025.
Per the most recent amendment to the ARLO Agreement signed in April 2025, we had until May 10, 2025 to pay HSO an additional $1,775,000 to exercise an option for the remaining 17.75% working interest in the initial 960 acres of the Asphalt Ridge Leases. The option expired after the reporting period on May 10, 2025 due to our failure to exercise it before the expiration date. As a result, we forfeited any further right to acquire the additional 17.75% working interest but will retain our existing 2.25% interest in the leases.
Proved Property Leases
In April 2025, the Company acquired oil and gas lease rights for four leases related to the proved properties located in Saskatchewan, Canada (see Note 5); the sum total of all four leases is 320 net acres and all are held by production.
Board of Directors Compensation
On July 11, 2022, our Board of Directors approved compensation for each of the non-employee directors of the Company, which would be effective upon the consummation of the IPO. Such compensation is structured as follows: an annual retainer of $50,000 cash plus an additional $10,000 for each Board committee upon which the Director serves, each paid quarterly in arrears. Payment for this approved compensation commenced upon successful completion of the Company’s IPO in April 2023, and for the three and six months ended April 30, 2025, we recognized $102,508 and $161,675, respectively, in directors’ fees. For the three and six months ended April 30, 2024, we recognized $54,000 and $110,685, respectively, in directors’ fees.
Agreements with Advisors
On October 4, 2023 and December 29, 2023, we entered into placement agent agreements with Spartan Capital Securities, LLC (“Spartan”), whereby Spartan has served as the exclusive placement agent in connection with the closing of private placements. The agreements provide the agent with i) a cash fee 7.5% of the aggregate proceeds raised in the sale and ii) warrants to purchase a number of common shares equal to 5% of the number of common shares initially issuable upon conversion of each note tranche; warrants to purchase 4,167 and 2,750 common shares with exercise prices of $26.40 and $11.00 for the first and second tranches, respectively, were issued to Spartan as of January 31, 2024. Such warrants may be exercised beginning 6 months after issuance until four and one-half years thereafter.
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Critical Accounting Policies and Estimates
Basis of Presentation
We prepare our condensed consolidated financial statements in conformity with GAAP, which requires management to make certain estimates and assumptions and apply judgments. We base our estimates and judgments on historical experience, current trends and other factors that management believes to be important at the time the condensed consolidated financial statements are prepared, and actual results could differ from our estimates and such differences could be material. Due to the need to make estimates about the effect of matters that are inherently uncertain, materially different amounts could be reported under different conditions or using different assumptions. On a regular basis, we review our critical accounting policies and how they are applied in the preparation of our condensed consolidated financial statements, as well as the sufficiency of the disclosures pertaining to our accounting policies in the footnotes accompanying our condensed consolidated financial statements. Described below are the most significant policies we apply in preparing our condensed consolidated financial statements, some of which are subject to alternative treatments under GAAP. We also describe the most significant estimates and assumptions we make in applying these policies. See “Note 2 - Summary of Significant Accounting Policies” to our condensed consolidated financial statements.
Oil and Gas Assets and Exploration Costs – Successful Efforts
Our projects are in exploration and/or early production stages and we began generating revenue from its operations during the quarterly period ended April 30, 2024. We apply the successful efforts method of accounting for crude oil and natural gas properties. Under this method, exploration costs such as exploratory, geological, and geophysical costs, delay rentals and exploratory overhead are expensed as incurred. If an exploratory property provides evidence to justify potential development of reserves, drilling costs associated with the property are initially capitalized, or suspended, pending a determination as to whether a commercially sufficient quantity of proved reserves can be attributed to the area as a result of drilling. At the end of each quarter, management reviews the status of all suspended exploratory property costs considering ongoing exploration activities; in particular, whether we are making sufficient progress in our ongoing exploration and appraisal efforts. If management determines that future appraisal drilling or development activities are unlikely to occur, associated exploratory well costs are expensed.
Costs to acquire mineral interests in crude oil and/or natural gas properties, drill and equip exploratory wells that find proved reserves and drill and equip development wells are capitalized. Acquisition costs of unproved leaseholds are assessed for impairment during the holding period and transferred to proven crude oil and/or natural gas properties to the extent associated with successful exploration activities. Significant undeveloped leases are assessed individually for impairment, based on our current exploration plans, and a valuation allowance is provided if impairment is indicated. Capitalized costs from successful exploration and development activities associated with producing crude oil and/or natural gas leases, along with capitalized costs for support equipment and facilities, are amortized to expense using the unit-of-production method based on proved crude oil and/or natural gas reserves on a field-by-field basis, as estimated by qualified petroleum engineers.
As of April 30, 2025, we had five wells that are producing, all of which are located in the newly acquired Saskatchewan property, plus two workovers. We expect to add the reserve value of such fields to our reserve report after a further period of observation and review of the oil production; once this has been determined, we will estimate the necessary depreciation, depletion and amortization (“DD&A”) for such wells.
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Proved and unproved oil and natural gas properties
Unproved oil and natural gas properties have unproved lease acquisition costs, which are capitalized until the lease expires or otherwise until we specifically identify a lease that will revert to the lessor, at which time we charge the associated unproved lease acquisition costs to exploration costs.
Unproved oil and natural gas properties are not subject to amortization and are assessed periodically for impairment on a property-by-property basis based on remaining lease terms, drilling results or future plans to develop acreage. As of April 30, 2025 and October 31, 2024, such oil and gas properties were classified as unproved properties and were not subject to depreciation, depletion and amortization.
Proved oil and natural gas properties include developed and undeveloped reserves that have been confirmed through drilling and production activities. These properties are subject to DD&A, which is calculated using the unit-of-production method based on total proved reserves.
| ● | Proved developed reserves are amortized over the expected production life of the wells. | |
| ● | Proved undeveloped reserves remain capitalized until development activities commence. | |
| ● | The Company assesses impairment of proved properties periodically based on commodity prices, production forecasts, and reserve estimates. |
As of April 30, 2025, we have proved reserves in the newly acquired Saskatchewan properties and expect to add the reserves values of such fields to our reserve report; once this has been done, we will estimate the necessary DD&A for such wells.
Impairment of Other Long-lived Assets
We review the carrying value of our long-lived assets annually or whenever events or changes in circumstances indicate that the historical cost-carrying value of an asset may no longer be appropriate. We assess the recoverability of the carrying value of the asset by estimating the future net undiscounted cash flows expected to result from the asset, including eventual disposition. If the future net undiscounted cash flows are less than the carrying value of the asset, an impairment loss is recorded equal to the difference between the asset’s carrying value and estimated fair value. With regards to oil and gas properties, this assessment applies to proved properties; unproved properties are assessed for impairment either at an individual property basis or a group basis.
Asset Retirement Obligations
ARO consists of future plugging and abandonment expenses on oil and natural gas properties. In connection with the South Salinas Project acquisition described above, we acquired the plugging and abandonment liabilities associated with six temporarily shut-in, idle wells. The fair value of the ARO was recorded as a liability in the period in which the wells were acquired with a corresponding increase in the carrying amount of oil and natural gas properties. We plan to utilize the six wellbores acquired in the South Salinas Project acquisition in future production, development and/or exploration activities. The liability is accreted for the change in its present value each period based on the expected dates that the wellbores will be required to be plugged and abandoned. The capitalized cost of ARO is included in oil and gas properties and is a component of oil and gas property costs for purposes of impairment and, if proved reserves are found, such capitalized costs will be depreciated using the units-of-production method. The asset and liability are adjusted for changes resulting from revisions to the timing or the amount of the original estimate when deemed necessary. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized.
Fair Value Measurements
The carrying values of financial instruments comprising cash and cash equivalents, payables, and notes payable-related party approximate fair values due to the short-term maturities of these instruments. The notes payable- related party is considered a level 3 measurement. As defined in ASC 820, Fair Value Measurements and Disclosures, fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). The Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. ASC 820 establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). This fair value measurement framework applies to both initial and subsequent measurement.
| Level 1: | Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. |
| Level 2: | Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reported date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. |
| Level 3: | Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. The significant unobservable inputs used in the fair value measurement for nonrecurring fair value measurements of long-lived assets include pricing models, discounted cash flow methodologies and similar techniques. |
There are no assets or liabilities measured at fair value on a recurring basis. Assets and liabilities accounted for at fair value on a non-recurring basis in accordance with the fair value hierarchy include the initial allocation of the asset acquisition purchase price, including asset retirement obligations, the fair value of oil and natural gas properties and the assessment of impairment.
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The fair value measurements and allocation of assets acquired are measured on a nonrecurring basis on the acquisition date using an income valuation technique based on inputs that are not observable in the market and therefore represent Level 3 inputs. Significant inputs used to determine the fair value include estimates of: (i) reserves; (ii) future commodity prices; (iii) operating and development costs; and (iv) a market-based weighted average cost of capital rate. The underlying commodity prices embedded in the Company’s estimated cash flows are the product of a process that begins with NYMEX forward curve pricing, adjusted for estimated location and quality differentials, as well as other factors that the Company’s management believes will impact realizable prices. These inputs require significant judgments and estimates by the Company’s management at the time of the valuation.
The fair value of additions to the asset retirement obligation liabilities is measured using valuation techniques consistent with the income approach, which converts future cash flows to a single discounted amount. Significant inputs to the valuation include: (i) estimated plug and abandonment cost per well for all oil and natural gas wells and for all disposal wells; (ii) estimated remaining life per well; (iii) future inflation factors; and (iv) the Company’s average credit-adjusted risk-free rate. These assumptions represent Level 3 inputs.
If the carrying amount of its proved oil and natural gas properties, which are assessed for impairment under ASC 360 – Property, Plant and Equipment, exceeds the estimated undiscounted future cash flows, the Company will adjust the carrying amount of the oil and natural gas properties to fair value. The fair value of its oil and natural gas properties is determined using valuation techniques consistent with the income and market approach. The factors used to determine fair value are subject to management’s judgment and expertise and include, but are not limited to, recent sales prices of comparable properties, the present value of future cash flows, net of estimated operating and development costs using estimates of proved reserves, future commodity pricing, future production estimates, anticipated capital expenditures, and various discount rates commensurate with the risk and current market conditions associated with the expected cash flow projected. These assumptions represent Level 3 inputs.
Recent Accounting Pronouncements
All recently issued but not yet effective accounting pronouncements have been deemed to be not applicable or immaterial to us.
Item 3. Quantitative and Qualitative Disclosures about Market Risk
Not Applicable. As a smaller reporting company, we are not required to provide the information required by this Item.
Item 4. Controls and Procedures
Evaluation of Disclosure Controls and Procedures
Our management, with the participation and supervision of our Chief Executive Officer and our Chief Financial Officer, have evaluated our disclosure controls and procedures as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act as of the end of the period covered by this Quarterly Report on Form 10-Q. Based on that evaluation, our Chief Executive Officer and our Chief Financial Officer have concluded that, as of the end of the period covered by this Quarterly Report on Form 10-Q, our disclosure controls and procedures were effective to provide reasonable assurance that information we are required to disclose in reports that we file or submit under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in SEC rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.
Changes in Internal Control over Financial Reporting
There were no changes in our internal control over financial reporting that occurred during our second fiscal quarter ended April 30, 2025 that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
PART II. OTHER INFORMATION
Item 1. Legal Proceedings
We are not currently subject to any legal proceedings.
Item 1A. Risk Factors
There have been no other material changes to the risk factors set forth in the section titled “Risk Factors” included in our Amendment No. 3 to our Annual Report on Form 10-K/A for the year ended October 31, 2024, which was filed with the SEC on April 15, 2025 (“2024 Annual Report”). Our business involves significant risks. You should carefully consider the risks and uncertainties described in our 2024 Annual Report, together with all of the other information in our 2024 Annual Report and in this Quarterly Report on Form 10-Q, as well as our audited financial statements and related notes as disclosed in our 2024 Annual Report.
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Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
None, except as reported on Current Reports on Form 8-K filed by the Company during the quarterly period covered by this report.
Item 3. Defaults Upon Senior Securities
None.
Item 4. Mine Safety Disclosures
Not applicable.
Item 5. Other Information
None.
Item 6. Exhibits
| Exhibit No. | Description | |
| 31.1* | Certification of the Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. | |
| 31.2* | Certification of the Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. | |
| 32.1** | Certification of the Chief Executive Officer and Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. | |
| 101.INS* | Inline XBRL Instance Document. | |
| 101.SCH* | Inline XBRL Taxonomy Extension Schema Document | |
| 101.CAL* | Inline XBRL Taxonomy Extension Calculation Linkbase Document | |
| 101.LAB* | Inline XBRL Taxonomy Extension Label Linkbase Document | |
| 101.PRE* | Inline XBRL Taxonomy Extension Presentation Linkbase Document | |
| 101.DEF* | Inline XBRL Taxonomy Extension Definition Linkbase Document | |
| 104 | Cover Page Interactive Data File (formatted as inline XBRL and contained in Exhibit 101) |
| * | Filed herewith. |
| ** | Furnished, not filed |
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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
| TRIO PETROLEUM CORP. | ||
| By: | /s/ Robin Ross | |
| Robin Ross | ||
| Chief
Executive Officer (Principal Executive Officer) |
||
| Date: June 10, 2025 | ||
| By: | /s/ Greg Overholtzer | |
| Greg Overholtzer | ||
| Chief
Financial Officer (Principal Financial Officer and Principal Accounting Officer) |
||
| Date: June 10, 2025 |
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