DAYBREAK OIL & GAS, INC. - Quarter Report: 2022 August (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended August 31, 2022

OR

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

For the transition period from ______________ to _______________

Commission File Number: 000-50107

DAYBREAK OIL AND GAS, INC.

(Exact name of registrant as specified in its charter)

(509) 232-7674

(Registrant’s telephone number, including area code)

(Former name, former address and former fiscal year, if changed since last report)

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

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. þ Yes ¨ No

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

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

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

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

At October 25, 2022 the registrant had 384,735,402 outstanding shares of $0.001 par value common stock.

TABLE OF CONTENTS

PART I

FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DAYBREAK OIL AND GAS, INC.

Balance Sheets – Unaudited

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

DAYBREAK OIL AND GAS, INC.

Statements of Operations – Unaudited

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

DAYBREAK OIL AND GAS, INC.

Consolidated Statements of Changes in Stockholders' Deficit

For the Three and Six Months Ended August 31, 2022 August 2021

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

 Common Stock

Additional Paid-In Capital

Accumulated Deficit

DAYBREAK OIL AND GAS, INC.

Statements of Cash Flows – Unaudited

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

DAYBREAK OIL AND GAS, INC.

NOTES TO UNAUDITED FINANCIAL STATEMENTS

NOTE 1 — ORGANIZATION AND BASIS OF PRESENTATION:

Organization

Originally incorporated as Daybreak Uranium, Inc., (“Daybreak Uranium”) on March 11, 1955, under the laws of the State of Washington, Daybreak Uranium was organized to explore for, acquire, and develop mineral properties in the Western United States. In August 1955, the assets of Morning Sun Uranium, Inc. were acquired by Daybreak Uranium. In May 1964, Daybreak Uranium changed its name to Daybreak Mines, Inc. During 2005, management of the Company decided to enter the crude oil and natural gas exploration, development and production industry. On October 25, 2005, the Company shareholders approved a name change from Daybreak Mines, Inc. to Daybreak Oil and Gas, Inc. (referred to herein as “Daybreak” or the “Company”) to better reflect the business of the Company.

All of the Company’s crude oil production is sold under contracts which are market-sensitive. Accordingly, the Company’s financial condition, results of operations, and capital resources are highly dependent upon prevailing market prices of, and demand for, crude oil. These commodity prices are subject to wide fluctuations and market uncertainties due to a variety of factors that are beyond the control of the Company. These factors may include the level of global demand for petroleum (hydrocarbon) products; foreign supply of crude oil and natural gas; the establishment of and compliance with production quotas by crude oil-exporting countries; the relative strength of the U.S. dollar; weather conditions; the price and availability of alternative fuels; overall economic conditions, both foreign and domestic; crude oil price disputes between OPEC and non-OPEC members; and national and international pandemics like the coronavirus outbreak.

Basis of Presentation

The accompanying unaudited interim financial statements and notes for the Company have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial information and with the instructions to Form 10-Q for quarterly reports under Section 13 or 15(d) of the Securities Exchange Act of 1934 (the “Exchange Act”). Accordingly, they do not include all of the information and footnote disclosures normally required by accounting principles generally accepted in the United States of America for complete financial statements.

In the opinion of management, all adjustments considered necessary for a fair presentation of the financial statements have been included and such adjustments are of a normal recurring nature. Operating results for the six months ended August 31, 2022 are not necessarily indicative of the results that may be expected for the fiscal year ending February 28, 2023.

These financial statements should be read in conjunction with the audited financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the fiscal year ended February 28, 2022.

Use of Estimates

In preparing financial statements in conformity with accounting principles generally accepted in the United States of America, management is required to make estimates and assumptions. These estimates and assumptions may affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, and revenues and expenses during the reporting period. Actual results could differ materially from those estimates. The accounting policies most affected by management’s estimates and assumptions are as follows:

Earnings per Share

The Company follows ASC Topic 260, Earnings per Share, to account for the earnings per share. Basic earnings per common share (“EPS”) calculations are determined by dividing net income (loss) by the weighted average number of shares of common stock outstanding during the period. Diluted earnings per common share calculations are determined by dividing net income (loss) by the weighted average number of common shares and dilutive common share equivalents outstanding. During periods when common stock equivalents, if any, are anti-dilutive they are not considered in the computation.

NOTE 2 — GOING CONCERN:

Financial Condition

The Company’s financial statements for the six months ended August 31, 2022 have been prepared on a going concern basis, which contemplates the realization of assets and the settlement of liabilities in the normal course of business. The Company has incurred net operating losses since entering the crude oil exploration industry and as of August 31, 2022 has an accumulated deficit of $30.95 million and a working capital deficit of $1.6 million which raises substantial doubt about the Company’s ability to continue as a going concern.

Management Plans to Continue as a Going Concern

The Company continues to implement plans to enhance its ability to continue as a going concern. Daybreak currently has a net revenue interest (“NRI”) in 20 producing crude oil wells in its East Slopes Project located in Kern County, California (the “East Slopes Project”). The revenue from these wells has created a steady and reliable source of income for the Company. The Company’s average working interest (“WI”) in these wells is 36.6% and the average net revenue interest (“NRI”) is 27.6% for these same wells.

Revenue

In May 2022, the Company acquired Reabold California, LLC (“Reabold”) from a third party. This property currently includes four producing wells, five shut-in wells and two potential disposal wells in the Monterey and Contra Costa counties of California. We have a 50% working interest with a 40% net revenue interest in this project.

In conjunction with our acquisition of Reabold, the Company was able to secure a capital raise of $2,500,000 through the issuances of the Company’s common stock.

The Company anticipates its revenue will continue to increase as the Company participates in the drilling of more wells in the East Slopes and the Reabold Projects in California. Daybreak’s sources of funds in the past have included the debt or equity markets and the sale of assets. It will be necessary for the Company to obtain additional funding from the private or public debt or equity markets in the future. However, the Company cannot offer any assurance that it will be successful in executing the aforementioned plans to continue as a going concern.

Daybreak’s financial statements as of August 31, 2022 do not include any adjustments that might result from the inability to implement or execute the Company’s plans to improve its ability to continue as a going concern.

NOTE 3 — CONCENTRATION RISK:

Substantially all of the Company’s trade accounts receivable consists of receivables from two sources: (1) the sale of crude oil and natural gas production from operations by the Company and (2) from receivables from the Company’s working interest partners in the East Slopes project where we are the Operator or from the Reabold project where we have one working interest partner. This concentration of customers and joint interest owners may impact the Company’s overall credit risk, as these entities could be affected by similar changes in economic conditions including lower crude oil prices as well as other related factors. Trade accounts receivable are generally not collateralized.

Customer Concentration 

At the Company’s East Slopes and Reabold projects in California, there is only one buyer for the purchase of crude oil production and one buyer for our natural gas production in the Reabold project. The Company has no natural gas production in the East Slopes project. At August 31, 2022 and February 28, 2022 these customers represented 100.0% of crude oil and natural gas sales receivable. If these buyers are unable to resell their products or if they lose a significant sales contract, the Company may incur difficulties in selling its crude oil and natural gas production.

Crude oil and natural gas sales receivables balances of $223,639 and $117,727 at August 31, 2022 and February 28, 2022, represent crude oil and natural gas sales that occurred in August and February 2022, respectively.

Joint interest participant receivables balances of $305,774 and $85,339 at August 31, 2022 and February 28, 2022, respectively, represent amounts due from our working interest partners in both the East Slopes and Reabold projects. There were no allowances for doubtful accounts for the Company’s trade accounts receivable at August 31, 2022 and February 28, 2022, as the joint interest owners have a history of paying their obligations.

NOTE 4 — CRUDE OIL PROPERTIES:

Crude oil property balances at August 31, 2022 and February 28, 2022 are set forth in the table below.

Crude Oil Properties - Schedule of Crude Oil Activities

On May 25, 2022, the Company finalized the acquisition of Reabold California, LLC (“Reabold”). This property includes producing wells in both the Monterey and Contra Costa counties of California. This project includes four producing wells, five shut-in wells and the potential for two disposal wells. The Company has a 50% working interest with a 40% net revenue interest in this project. The balances above include the Reabold acquisition.

NOTE 5 – ACQUISITION

On May 25, 2022, the Company finalized the acquisition of Reabold from a third party for 160,964,489 shares of the Company’s common stock valued at $6,599,544. The transaction balance of $6,863,163 reflects the common stock valuation of the acquisition transaction and $263,619 in reimbursements to the seller as a purchase price adjustment relating to expenditures for workovers agreed to by the Company and the third party. The following table presents the estimated allocation of the purchase price of the assets acquired and liabilities assumed for the acquisition.

This preliminary allocation is based on management’s estimated fair value of the Reabold assets and liabilities at May 25, 2022, and is subject to adjustment when a third party valuation to determine the fair value of the assets for ASC 805, Business Combinations reporting purposes is received. Adjustments made to the Reabold assets are derived from a total value of $6,599,544, based on 160,964,489 shares of stock issued for the acquisition and the closing price that day of $0.041 per share. From that amount, total assets acquired of $4,694,563 was deducted, and total liabilities acquired of $555,955 were added back to arrive at the $1,876,264 of Goodwill recorded. The Company incurred approximately $95,120 in transaction costs related to the Acquisition.

NOTE 6 — ACCOUNTS PAYABLE:

On March 1, 2009, the Company became the operator for its East Slopes Project located in Kern County, California. Additionally, the Company then assumed certain original defaulting partners’ approximate $1.5 million liability representing a 25% working interest in the drilling and completion costs associated with the East Slopes Project four earning well program. The Company subsequently sold the same 25% working interest on June 11, 2009. Of the $1.5 million liability, $244,849 remains unpaid and is included in both the August 31, 2022 and February 28, 2022 accounts payable balances. Payment of this liability has been delayed until the Company’s cash flow situation improves. On October 17, 2018, a working interest partner in California filed a UCC financing statement in regards to payables owed to the partner by the Company. At August 31, 2022 and February 28, 2022, the balance owed this working interest partner was $67,799 and $76,268, respectively, and is included in the approximate $2.0 million and $1.65 million accounts payable balance at August 31, 2022 and February 28, 2022, respectively.

NOTE 7 — ACCOUNTS PAYABLE- RELATED PARTIES:

The August 31, 2022 and February 28, 2022 accounts payable – related party balances of approximately $23,307 and $49,228 respectively, were comprised primarily of expense reimbursements to employees.

In California at the East Slopes Project, two of the vendors that the Company uses for services are partially owned by a related party, the Company’s Chief Operating Officer. The Company’s Chief Operating Officer is 50% owner in both Great Earth Power and ABPlus Net Holdings. Great Earth Power began providing a portion of the solar power electrical service for production operations in July 2020. ABPlus Net Holdings began providing portable tank rentals to the Company as a part of its water treatment and disposal operations in September 2020. The services provided by Great Earth Power and ABPlus Net Holdings are competitive with other vendors and save the Company significant expense. For the six months ended August 31, 2022 and 2021, Great Earth Power was paid $9,716 and $10,675, respectively. For the six months ended August 31, 2022 and 2021, ABPlus Net holdings was paid $5,760 and $5,760, respectively.

NOTE 8 — SHORT-TERM AND LONG-TERM BORROWINGS:

Note Payable

In December 2018, the Company was able to settle an outstanding balance owed to one of its third-party vendors. This settlement resulted in a $120,000 note payable being issued to the vendor. Additionally, the Company agreed to issue 2,000,000 shares of the Company’s common stock as a part of the settlement agreement. Based on the closing price of the Company’s common stock on the date of the settlement agreement, the value of the common stock transaction was determined to be $6,000. The common stock shares were issued during the twelve months ended February 29, 2020. The note has a maturity date of January 1, 2022 and bears an interest rate of 10% rate per annum. Monthly interest is accrued and payable on January 1^st of each anniversary date until maturity of the note. At August 31, 2022, the accrued interest had not been paid and was outstanding. The accrued interest on the Note was $44,000 and $38,000 at August 31, 2022 and February 28, 2022, respectively.

Note Payable – Related Party

On December 22, 2020, the Company entered into a Secured Promissory Note (the “Note”), as borrower, with James Forrest Westmoreland and Angela Marie Westmoreland, Co-Trustees of the James and Angela Westmoreland Revocable Trust, or its assigns (the “Noteholder”), as the lender. James F. Westmoreland is the Company’s Chairman, President and Chief Executive Officer. Pursuant to the Note, the Noteholder loaned the Company an aggregate principal amount of $155,548. After the deduction of loan fees of $10,929 the net proceeds from the loan were $144,619. The loan fees are being amortized as original issue discount (OID) over the term of the loan. The interest rate of the loan is 2.25%. The Note requires monthly payments on the Note balance until repaid in full. The maturity date of the Note is December 21, 2035. For the six months ended August 31, 2022, the Company made principal payments of $4,384 and amortized debt discount of $364. The obligations under the Note are secured by a lien on and security interest in the Company’s crude oil assets located in Kern County, California, as described in a Deed of Trust entered into by the Company in favor of the Noteholder to secure the obligations under the Note. Such lien shall be a first priority lien, subject only to a pre-existing lien filed by a working interest partner of the Company.

Secured Debt

Chief Executive Officer 

The Company may prepay the Note at any time. Upon the occurrence of any Event of Default and expiration of any applicable cure period, and at any time thereafter during the continuance of such Event of Default, the Noteholder may at its option, by written notice to the Company: (a) declare the entire principal amount of the Note, together with all accrued interest thereon and all other amounts payable hereunder, immediately due and payable; (b) exercise any of its remedies with respect to the collateral set forth in the Deed of Trust; and/or (c) exercise any or all of its other rights, powers or remedies under applicable law.

Current portion of note payable – related party balances at August 31, 2022 and February 28, 2022 are set forth in the table below:

Short-Term and Long-Term Borrowings - Schedule of Related Party Notes Payable

Note payable – related party long-term balances at August 31, 2022 and February 28, 2022 are set forth in the table below:

Future estimated payments on the outstanding note payable – related party are set forth in the table below:

Short-Term and Long-Term Borrowings - Schedule of Future Estimated Payments

Short-term Convertible Note Payable

Convertible Debt 

During the twelve months ended February 28, 2022, the Company executed a convertible promissory note with a third party for $200,000. The interest rate was 18% per annum and is payable in kind (PIK) solely by additional shares of the Company’s common stock. Regardless of when the conversion occurred, a full 12 months of interest would be payable upon conversion. On May 5, 2022, the Company received notice of conversion of the promissory note. The face amount of the note and $36,000 in interest were converted at a rate of $0.0085 per share into 27,764,706 shares of the Company’s common stock during the six months ended August 31, 2022.

12% Subordinated Notes

Private Placement

Subordinated Debt

The Company’s 12% Subordinated Notes (“the Notes”) issued pursuant to a January 2010 private placement offering to accredited investors, resulted in $595,000 in gross proceeds (of which $250,000 was from a related party) to the Company and accrue interest at 12% per annum, payable semi-annually on January 29th and July 29th. On January 29, 2015, the Company and 12 of the 13 holders of the Notes agreed to extend the maturity date of the Notes for an additional two years to January 29, 2017. Effective January 29, 2017, the maturity date of the Notes and the expiration date of the warrants that were issued in conjunction with the Notes were extended for an additional two years to January 29, 2019.

As a result of the Company restructuring its balance sheet through conversions of related party debt to common stock, the related party 12% Noteholder, James F. Westmoreland, the Company’s President and Chief Executive Officer, chose to convert the principal and accrued interest of their Notes to the Company’s common stock. The related party Note for $250,000 and accrued interest of $264,986 were converted to common stock at a rate of approximately $0.45 for every dollar of principal and interest resulting in 1,144,415 shares of common stock being issued.

During the six months ended August 31, 2022, one 12% Note holder chose to convert the principal balance and accrued interest in to the Company’s common stock. The $25,000 Note and accrued interest of $10,520 were converted at a rate of approximately $0.45 for every dollar of principal and interest resulting in 78,934 shares of common stock being issued.

The Company has informed the Note holders that the payment of principal and final interest will be late and is subject to future financing being completed and the Company’s cash flow. The Notes principal of $290,000 has not been paid. The terms of the Notes, state that should the Board of Directors decide that the payment of the principal and any unpaid interest would impair the financial condition or operations of the Company, the Company may then elect a mandatory conversion of the unpaid principal and interest into the Company’s common stock at a conversion rate equal to 75% of the average closing price of the Company’s common stock over the 20 consecutive trading days preceding December 31, 2018. The accrued interest on the 12% Notes at August 31, 2022 and February 28, 2022 was $142,251 and $135,229, respectively.

12% Note balances at August 31, 2022 and February 28, 2022 are set forth in the table below:

Short-Term and Long-Term Borrowings - Schedule of Subordinated Notes

12% Subordinated Notes

Related Party Notes

Line of Credit

Line of Credit 

The Company had an existing $890,000 line of credit for working capital purposes with UBS Bank USA (“UBS”), established pursuant to a Credit Line Agreement dated October 24, 2011 that was secured by the personal guarantee of its Chairman, President and Chief Executive Officer. On May 26, 2022, the Company paid off the outstanding balance of $809,930 on the line of credit. The payoff of the line of credit was previously approved under terms of the Equity Exchange Agreement in which the Company acquired the Reabold property in California. The payoff was a part of the use of proceeds from the Company’s sale of common stock to a third party.

Production Revenue Payable

Beginning in December 2018, the Company conducted a fundraising program to fund the drilling of future wells in California and Michigan and to settle some of its historical debt. The purchaser(s) of a production revenue payment interest received a production revenue payment on future wells to be drilled in California and Michigan in exchange for their purchase. The production payment interest entitles the purchasers to receive production payments equal to twice their original amount paid, payable from a percentage of the Company’s future net production payments from wells drilled after the date of the purchase and until the Production Payment Target (as described below) is met.  The Company shall pay fifty percent of its net production payments from the relevant wells to the purchasers until each purchaser has received two times the purchase price (the “Production Payment Target”). Once the Company pays the purchasers amounts equal to the Production Payment Target, it shall thereafter pay a pro-rated eight percent (8%) of $1.3 million on its net production payments from the relevant wells to each of the purchasers. However, if the total raised is less than the target $1.3 million, then the payment will be a proportionate amount of the eight percent (8%). Additionally, if the Production Payment Target is not met within the first three years, the Company shall pay seventy-five percent of its production payments from the relevant wells to the purchasers until the Production Payment Target is met.

The Company accounted for the amounts received from these sales in accordance with ASC 470-10-25 and 470-10-35 which require amounts recorded as debt to be amortized under the interest method as described in ASC 835-30, Interest Method. Consequently, the program balance of $885,606 has been recognized as a production revenue payable. The Company determined an effective interest rate based on future expected cash flows to be paid to the holders of the production payment interests. This rate represents the discount rate that equates estimated cash flows with the initial proceeds received from the sales and is used to compute the amount of interest to be recognized each period. Estimating the future cash outflows under this agreement requires the Company to make certain estimates and assumptions about future revenues and payments and such estimates are subject to significant variability. Therefore, the estimates are likely to change which may result in future adjustments to the accretion of the interest expense and the amortized cost based carrying value of the related payables.

Accordingly, the Company has estimated the cash flows associated with the production revenue payments of $984,601 and determined a discount of $98,995 as of August 31, 2022, which is being accounted as interest expense over the estimated period over which payments will be made based on expected future revenue streams. For the six months ended August 31, 2022 and 2021, amortization of the debt discount on these payables amounted to $68,482 and $54,304, respectively, which has been included in interest expense in the statements of operations.

Production revenue payable balances at August 31, 2022 and February 28, 2022 are set forth in the table below:

Short-Term and Long-Term Borrowings - Schedule of Production Revenue Payable Balances

Encumbrances

On October 17, 2018, a working interest partner in California filed a UCC financing statement in regards to payable amounts owed to the partner by the Company.

NOTE 9 — LEASES:

The Company leases approximately 988 rentable square feet of office space from an unaffiliated third party for our corporate office located in Spokane Valley, Washington. Additionally, we lease approximately 416 and 695 rentable square feet from unaffiliated third parties for our regional operations office in Friendswood, Texas and storage and auxiliary office space in Wallace, Idaho, respectively. The lease in Friendswood is a 12-month lease that expires on October 31, 2022 and as such is considered a short-term lease. The Company has elected to not apply the recognition requirements of ASC 842 to this short-term lease. The Spokane Valley and Wallace leases are currently on a month-to-month basis. The Company’s lease agreements do not contain any residual value guarantees, restrictive covenants or variable lease payments. The Company has not entered into any financing leases.

Rent expense for the six months ended August 31, 2022 and 2021 was $11,895 and $11,895, respectively.

NOTE 10 — STOCKHOLDERS’ EQUITY (DEFICIT):

Preferred Stock

With the filing of the Company’s Second Amended and Restated Articles of Incorporation with the Washington Secretary of State in May 2022, the Company no longer has any preferred shares. The Company has only one class of stock, common stock.

Common Stock

The Company is authorized to issue up to 500,000,000 shares of $0.001 par value common stock of which 384,735,402 and 67,802,273 shares were issued and outstanding as of August 31, 2022 and February 28, 2022, respectively.

During the six months ended August 31, 2022, there were 316,933,129 shares of common stock issued in aggregate. There were 78,934 shares issued to a third party on conversion of a $25,000 12% Subordinated Note and $10,520 in accumulated interest. There were 27,764,706 shares issued on conversion of a $200,000 convertible note and $36,000 in accumulated interest. There were 160,964,489 shares issued for the acquisition of the Reabold California, LLC crude oil and natural gas properties. There were 128,125,000 shares issued through the sale of common stock to a third party, which then became a related party through the sale.

NOTE 11 — WARRANTS:

Share Based Payment Arrangement - Non-Employee

During the twelve months ended February 29, 2020 there were 2.1 million warrants issued to a third party for investor relations services. The fair value of the warrants was determined by the Black-Scholes pricing model, was $17,689, and is being amortized over the 3 year vesting period of the warrants. The Black-Scholes valuation encompassed the following assumptions: a risk free interest rate of 1.68%; volatility rate of 260.23%; and a dividend yield of 0.0%.

The warrants contains a vesting blocking provision that prevents the vesting of any warrants that such vesting would cause the warrant holder’s beneficial ownership (as such term is defined in Section 13d-3 of the Securities Exchange Act of 1934, as amended) to exceed more than four and ninety-nine one-hundredths percent (4.99%) of the Company’s outstanding Common Stock. The foregoing restriction may not be waived by either party. The warrants vested in equal parts over a three year period beginning on January 2, 2020 and were fully vested at January 2, 2022. The warrants expire on January 2, 2024.

 As of August 31, 2022, there were 2,100,000 exercisable warrants. At August 31, 2022, both the outstanding warrants and the exercisable warrants have a weighted average exercise price of $0.01, a weighted average remaining life of 1.33 years. Both the outstanding warrants and the exercisable warrants have an intrinsic value of $84,000. For the six months ended August 31, 2022 and 2021, the recorded amount of warrant expense was $-0- and $1,474, respectively.

Warrant activity for the six months ended August 31, 2022 is set forth in the table below:

Warrants - Schedule of Warrant Activity

NOTE 12 — INCOME TAXES:

On December 22, 2017, the federal government enacted a tax bill H.R.1, an act to provide for reconciliation pursuant to Titles II and V of the concurrent resolution on the budget for fiscal year 2018, commonly referred to as the Tax Cuts and Jobs Act. The Tax Cuts and Jobs Act contains significant changes to corporate taxation, including, but not limited to, reducing the U.S. federal corporate income tax rate from 35% to 21% and modifying or limiting many business deductions. The Company has re-measured its deferred tax liabilities based on rates at which they are expected to be utilized in the future, which is generally 21%.

Reconciliation between actual tax expense (benefit) and income taxes computed by applying the U.S. federal income tax rate and state income tax rates to income from continuing operations before income taxes is set forth in the table below:

Income Taxes - Schedule of Reconciliation Between Actual Tax Expense Benefit and Income Taxes Computed by Applying Income Tax Rate

Tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred liabilities are set forth in the table below:

Income Taxes - Schedule of Deferred Tax Assets and Liabilities

At August 31, 2022, the Company had estimated net operating loss (“NOL”) carryforwards for federal and state income tax purposes of approximately $20,364,166 which will begin to expire, if unused, beginning in 2024. Under the Tax Cuts and Jobs Act, the NOL portion of the loss incurred in the year ended February 28, 2018 of $340,749; the loss incurred in the year ended February 29, 2020 of $339,299; the loss incurred in the year ended February 28, 2021 of $416,898; the loss incurred in the year ended February 28, 2022 of $279,773; and the loss incurred for the six months ended August 31, 2022 in the amount of approximately $1,359,807 will not expire and will carry over indefinitely. The valuation allowance increased approximately $401,678 for the six months ended August 31, 2022 and increased approximately $107,740 for the year ended February 28, 2023, respectively. Section 382 of the Internal Revenue Code places annual limitations on the Company’s net operating loss (NOL) carryforward.

The above estimates are based on management’s decisions concerning elections which could change the relationship between net income and taxable income. Management decisions are made annually and could cause estimates to vary significantly. The Company files federal income tax returns with the United States Internal Revenue Service and state income tax returns in various state tax jurisdictions. As a general rule the Company’s tax returns for the fiscal years after 2016 currently remain subject to examinations by appropriate tax authorities. None of our tax returns are under examination at this time.

NOTE 13 — COMMITMENTS AND CONTINGENCIES:

Various lawsuits, claims and other contingencies arise in the ordinary course of the Company’s business activities. While the ultimate outcome of any future contingency is not determinable at this time, management believes that any liability or loss resulting therefrom will not materially affect the financial position, results of operations or cash flows of the Company.

The Company, as an owner or lessee and operator of crude oil properties, is subject to various federal, state and local laws and regulations relating to discharge of materials into, and protection of, the environment. These laws and regulations may, among other things, impose liability on the lessee under a crude oil lease for the cost of pollution clean-up resulting from operations and subject the lessee to liability for pollution damages. In some instances, the Company may be directed to suspend or cease operations in the affected area. The Company maintains insurance coverage that is customary in the industry, although the Company is not fully insured against all environmental risks.

Sunflower Lawsuit

Sunflower Alliance v. California Department of Conservation, Geologic Energy Management Division.  This case challenges the state agency’s compliance with the California Environmental Quality Act (CEQA) with respect to the PAL Reabold 072-00-0001 Project, for wastewater injection into an existing well.  The Petition was filed on December 29, 2021 in the Alameda County Superior Court.  The Petitioner seeks an order setting aside the state agency’s approval of a wastewater injection permit; damages are not sought in the lawsuit.  On February 22, 2022, Real Party in Interest Reabold California, LLC filed a motion to transfer the case to the Contra Costa County Superior Court.  On March 22, 2022, the Alameda County Superior Court ordered the case transferred to the Contra Costa County Superior Court.  On August 15, 2022, the Contra Costa County Superior Court provided notice that the transfer has been completed and the case filed in that court.  If successful, the lawsuit would prevent Reabold from injecting wastewater into an existing well until any CEQA deficiencies are addressed.  The California Attorney General is defending the state agency, which disputes Petitioner’s claims.  At this time, it is unclear when the litigation will be resolved. 

The Company is not aware of any environmental claims existing as of August 31, 2021. There can be no assurance, however, that current regulatory requirements will not change or that past non-compliance with environmental issues will not be discovered on the Company’s crude oil properties.

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

The following discussion is management’s assessment of the current and historical financial and operating results of the Company and of our financial condition. It is intended to provide information relevant to an understanding of our financial condition, changes in our financial condition and our results of operations and cash flows and should be read in conjunction with our unaudited financial statements and notes thereto included elsewhere in this Quarterly Report on Form 10-Q for the six months ended August 31, 2022 and in our Annual Report on Form 10-K for the year ended February 28, 2022. References to “Daybreak”, the “Company”, “we”, “us” or “our” mean Daybreak Oil and Gas, Inc.

Cautionary Statement Regarding Forward-Looking Statements

Certain statements contained in our Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”) are intended to be covered by the safe harbor provided for under Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Exchange Act.

All statements other than statements of historical fact contained in this MD&A report are inherently uncertain and are forward-looking statements. Statements that relate to results or developments that we anticipate will or may occur in the future are not statements of historical fact. Words such as “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “predict,” “project,” “will” and similar expressions identify forward-looking statements. Examples of forward-looking statements include, without limitation, statements about the following:

We have based these forward-looking statements on assumptions and analyses made in light of our experience and our perception of historical trends, current conditions, and expected future developments. However, you should be aware that these forward-looking statements are only our predictions and we cannot guarantee any such outcomes. Future events and actual results may differ materially from the results set forth in or implied in the forward-looking statements. Important factors that could cause actual results to differ materially from our expectations include, but are not limited to, the following risks and uncertainties:

Our reserve estimates are determined through a subjective process and are subject to revision.

Should one or more of the risks or uncertainties described above or elsewhere in our Form 10-K for the year ended February 28, 2022 and in this Form 10-Q for the six months ended August 31, 2022 occur, or should any underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. We specifically undertake no obligation to publicly update or revise any information contained in any forward-looking statement or any forward-looking statement in its entirety, whether as a result of new information, future events, or otherwise, except as required by law.

All forward-looking statements attributable to us are expressly qualified in their entirety by this cautionary statement.

Introduction and Overview

We are an independent crude oil and natural gas exploration, development and production company. Our basic business model is to increase shareholder value by finding and developing crude oil and natural gas reserves through exploration and development activities, and selling the production from those reserves at a profit. To be successful, we must, over time, be able to find crude oil and natural gas reserves and then sell the resulting production at a price that is sufficient to cover our finding costs, operating expenses, administrative costs and interest expense, plus offer us a return on our capital investment. A secondary means of generating returns can include the sale of either producing or non-producing lease properties.

Our longer-term success depends on, among many other factors, the acquisition and drilling of commercial grade crude oil and natural gas properties and on the prevailing sales prices for crude oil and natural gas along with associated operating expenses. The volatile nature of the energy markets makes it difficult to estimate future prices of crude oil and natural gas; however, any prolonged period of depressed prices or market volatility, such as we have experienced in the last 18 months, will have a material adverse effect on our results of operations and financial condition.

Our operations are focused on identifying and evaluating prospective crude oil and natural gas properties and funding projects that we believe have the potential to produce crude oil and natural gas in commercial quantities. We conduct all of our drilling, exploration and production activities in the United States, and all of our revenues are derived from sales to customers within the United States. Currently, we are in the process of developing a multi-well oilfield project in Kern County, California.

Our management cannot provide any assurances that Daybreak will ever operate profitably. While, in the past, we have had positive cash flow from our crude oil operations in the East Slopes project in California, we have not yet generated sustainable positive cash flow or earnings on a company-wide basis. As a small company, we are more susceptible to the numerous business, investment and industry risks that have been described in Item 1A. Risk Factors of our Annual Report on Form 10-K for the fiscal year ended February 28, 2022 and in Part III, Item 1A. Risk Factors of this 10-Q Report. Throughout this Quarterly Report on Form 10-Q, crude oil is shown in barrels (“Bbls”); natural gas is shown in thousands of cubic feet (“Mcf”) unless otherwise specified, and hydrocarbon totals are expressed in barrels of crude oil equivalent (“BOE”).

Below is brief summary of our two crude oil and natural gas projects in California. Refer to our discussion in Item 2. Properties, in our Annual Report on Form 10-K for the year ended February 28, 2022 for more information on our multi-well oilfield East Slopes project in California.

Kern County, California (East Slopes Project)

The East Slopes Project is located in the southeastern part of the San Joaquin Basin near Bakersfield, California. Drilling targets are porous and permeable sandstone reservoirs that exist at depths of 1,200 feet to 4,500 feet. Since January 2009, we have participated in the drilling of 25 wells in this project. We have been the Operator at the East Slopes Project since March 2009.

The crude oil produced from our acreage in the Vedder Sand is considered heavy oil. The gravity of the crude oil ranges from 14° to 16° API (American Petroleum Institute) gravity and must be heated to separate and remove water prior to sale. Our crude oil wells in the East Slopes Project produce from five reservoirs at our Sunday, Bear, Black, Ball and Dyer Creek locations. The Sunday property has six producing wells, while the Bear property has nine producing wells. The Black property is the smallest of all currently producing reservoirs, and currently has two producing wells at this property. The Ball property also has two producing wells while the Dyer Creek property has one producing well. During the six months ended August 31, 2021 we had production from 20 crude oil wells. Our average working interest (“WI”) and net revenue interest (“NRI”) in these 20 wells is 36.6% and 27.6%, respectively.

We plan on acquiring additional acreage exhibiting the same seismic characteristics and on trend with the Bear, Black and Dyer Creek reservoirs. Some of these prospects, if successful, would utilize the Company’s existing production facilities. In addition to the current field development, there are several other exploratory prospects that have been identified from the seismic data, which we plan to drill in the future.

California Drilling Plans

We are currently in the planning and permitting process to undertake a multi-well developmental drilling program commencing in the late fall of 2022 or first quarter of 2023. These plans are dependent on a stabilization of crude oil prices. We plan to spend approximately $435,000 drilling three development wells in the current 2022-2023 fiscal year.

Monterey and Contra Costa Counties, California (Reabold California, LLC)

In May 2022, we acquired Reabold California, LLC (“Reabold”) from a third party. This property includes producing wells in both Monterey and Contra Costa counties of California.

The Burnett Lease and the Doud Lease are located in close proximity to each another in Monterey County. They are part of a geological feature named the Monroe Swell. The Burnett Lease presently has two directional wells that are being produced from a depth of 2,900’ from the Beedy Sand zone. The oil being produced is 19° gravity. We have future plans of drilling one horizontal well on this lease and to convert and old well bore into a salt water disposal well (“SWDW”). The Doud Lease has four directional well bores with three of those being produced from a depth of 3,300’ from the Doud A Sand zone. The oil being produced is 22° gravity. We have future plans of drilling one additional directional well on this lease. The SWDW for the Burnett Lease will be utilized for the Doud lease as well.

The Brentwood Lease is located in Contra-Costa County. This lease is part of a geological feature named the Meganos Unconformity. There are presently two directional wells producing from this lease. Additionally, another well bore will be worked over after a SWDW permit has been approved before putting it back in production. The wells are producing from the Second Massive Sand from a depth of between 4,000’- 4,500’. The oil being produced is 32° gravity. A work over was successfully completed on one well to decrease water production and to increase oil production. It will be brought back into production when the SWDW is completed.

Sunflower Lawsuit

Sunflower Alliance v. California Department of Conservation, Geologic Energy Management Division.  This case challenges the state agency’s compliance with the California Environmental Quality Act (CEQA) with respect to the PAL Reabold 072-00-0001 Project, for wastewater injection into an existing well.  The Petition was filed on December 29, 2021 in the Alameda County Superior Court.  The Petitioner seeks an order setting aside the state agency’s approval of a wastewater injection permit; damages are not sought in the lawsuit.  On February 22, 2022, Real Party in Interest Reabold California, LLC filed a motion to transfer the case to the Contra Costa County Superior Court.  On March 22, 2022, the Alameda County Superior Court ordered the case transferred to the Contra Costa County Superior Court.  On August 15, 2022, the Contra Costa County Superior Court provided notice that the transfer has been completed and the case filed in that court.  If successful, the lawsuit would prevent Reabold from injecting wastewater into an existing well until any CEQA deficiencies are addressed.  The California Attorney General is defending the state agency, which disputes Petitioner’s claims.  At this time, it is unclear when the litigation will be resolved. 

The Company is not aware of any environmental claims existing as of August 31, 2021. There can be no assurance, however, that current regulatory requirements will not change or that past non-compliance with environmental issues will not be discovered on the Company’s crude oil properties.

Encumbrances

On October 17, 2018, a working interest partner in the East Slopes Project in California filed a UCC financing statement in regards to payables owed to the partner by the Company.

Results of Operations – Six months ended August 31, 2022 compared to the six months ended August 31, 2021

California Crude Oil Prices

The prices we receive for crude oil sales in California from the East Slopes project and from Reabold California, LLC (“Reabold”) are based on prices posted for Midway-Sunset and Buena Vista crude oil delivery contracts, respectively. All posted pricing is subject to adjustments that vary by grade of crude oil, transportation costs, market differentials and other local conditions. Both the posted Midway-Sunset and Buena Vista prices generally move in correlation to prices quoted on the New York Mercantile Exchange (NYMEX”) for spot West Texas intermediate (“WTI”) crude oil, Cushing, Oklahoma delivery contracts.

California Natural Gas Prices

The price we receive for natural gas sales from Reabold is based on ninety-five (95%) of the price published in Natural Gas Intelligence (“NGI”) Gas Price Index under the column “Bidweek Averages” for “California”, “PG&E Citygate” less an amount per MMBtu equal to the Silverado Path On System As-Available transport date, less the Silverado Path On System transmission shrinkage

rate for Silverado. The price we receive generally moves in correlation to prices quoted on the New York Mercantile Exchange (NYMEX”) for spot Henry Hub natural gas prices.

There continues to be a significant amount of volatility in hydrocarbon prices and a corresponding fluctuation in our realized sale price of crude oil does exist. An example of this volatility is that in June of 2014 the monthly average price of WTI oil was $105.79 per barrel and our realized price per barrel of crude oil was $98.78 while in April 2020, the monthly average price of WTI crude oil was $16.55 and our monthly realized price was $16.96 per barrel. Finally, in August 2022, the monthly average price of WTI oil was $93.67 per barrel and our realized price per barrel of crude oil was $92.43. This volatility in crude oil prices has continued throughout most of the fiscal year ended February 28, 2023. Any downward volatility in the price of crude oil will have a prolonged and substantial negative impact on our profitability and cash flow from our producing California properties. It is beyond our ability to accurately predict crude oil prices over any substantial length of time.

A comparison of the average WTI crude oil price and the average realized crude oil sales price for the six months ended August 31, 2022 and 2021 is shown in the table below:

For the six months ended August 31, 2022, the average WTI price was $104.99 and our average realized crude oil sale price was $102.97, representing a discount of $2.02 per barrel or 1.9% lower than the average WTI price. In comparison, for the six months ended August 31, 2021, the average WTI price was $66.80 and our average realized sale price was $64.77 representing a discount of $2.03 per barrel or 3.0% lower than the average WTI price. Historically, the sale price we receive for East Slopes crude oil has been less than the quoted WTI price because of the lower API gravity of our East Slopes crude oil in comparison to the API gravity of quoted WTI crude oil.

California Crude Oil Revenue and Production

Crude oil revenue in California for the six months ended August 31, 2022 increased $462,579 or 146.1% to $779,197 in comparison to revenue of $316,618 for the six months ended August 31, 2021. The reason for the increase was the acquisition of the Reabold wells in central California. The average sale price of a barrel of crude oil for the six months ended August 31, 2022 was $102.97 in comparison to $64.77 for the six months ended August 31, 2021. The 2019 novel coronavirus (“COVID-19") that has spread throughout the world including the United States had a substantial negative impact on the demand for crude oil and was largely responsible for the volatility in crude oil prices for the last 18 months. The increase of $38.20 or 59.0% per barrel in the average realized price of a barrel of crude oil accounted for 40.4% of the increase in crude oil revenue for the six months ended August 31, 2022.

Our net crude oil sales volume for the six months ended August 31, 2022 was 7,567 barrels of crude oil in comparison to 4,888 barrels sold for the six months ended August 31, 2021. This increase in crude oil sales volume of 2,679 barrels or 54.8% was primarily due to our acquisition of the Reabold property and its producing wells in central California. The gravity of our produced crude oil in the East Slopes project ranges between 14° API and 16° API. The gravity of our produced crude oil in the Reabold project ranges between 17° API and 38° API.

Our crude oil sales revenue for the six months ended August 31, 2022 and 2021 are set forth in the following table:

Our natural gas sales revenue for the six months ended August 31, 2022 and 2021 is set forth in the following table:

Our average realized sale price on a BOE basis of crude oil and natural gas for the six months ended August 31, 2022 was $102.00 in comparison to $64.77 for the six months ended August 31, 2021, representing an increase of $37.23 or 57.5% per barrel.

Operating Expenses

Total operating expenses for the six months ended August 31, 2022 were $2,074,034, an increase of $1,658,668 or 399.3% compared to $415,366 for the six months ended August 31, 2021. Operating expenses for the six months ended August 31, 2022 and 2021 are set forth in the table below:

Production expenses include expenses associated with the production of crude oil. These expenses include contract pumpers, electricity, road maintenance, control of well insurance, property taxes and well workover expenses; and, relate directly to the number of wells that are in production. For the six months ended August 31, 2022, these expenses increased by $259,630 or 260.8% to $359,199 in comparison to $99,569 for the six months ended August 31, 2021. For the six months ended August 31, 2022, we had 24 wells on production from the East Slopes and Reabold projects in comparison to 20 wells on production in the East Slopes project for the six months ended August 31, 2021. The increase of four wells was from the Reabold acquisition that occurred in late May 2022. The increase in production expenses for the six months ended August 31, 2022, was primarily due to the replacement and upgrading of pumps in seven wells of the East Slopes project for $42,920 and the expenses associated with salt water disposal of $158,100 from the Reabold project. A salt water disposal well is currently being permitted which, when put into operation will significantly lower operating costs of the Reabold project. Production expense on a barrel of oil equivalent (“BOE”) basis for the six months ended August 31, 2022 and 2021 were $46.46 and $20.37, respectively. Production expenses represented 17.3% and 24.0% of total operating expenses for the six months ended August 31, 2022 and 2021, respectively.

Exploration and drilling expenses include geological and geophysical (“G&G”) expenses as well as leasehold maintenance, plugging and abandonment (“P&A”) expenses and dry hole expenses. For the six months ended August 31, 2022 and 2021, these expenses were $1,170 and $201, respectively. Exploration and drilling expenses represented 0.1% and 0.0% of total operating expenses for the six months ended August 31, 2022 and 2021, respectively.

Depreciation, depletion and amortization (“DD&A”) expenses relate to equipment, proven reserves and property costs, along with impairment, and is another component of operating expenses. For the six months ended August 31, 2022, DD&A expenses increased $120,856 or 419.5% to $149,664 in comparison to $28,808 for the six months ended August 31, 2021. On a BOE basis, DD&A expense was $19.36 and $5.89 for the six months ended August 31, 2022 and 2021, respectively. DD&A expenses represented 7.2% and 6.9% of total operating expenses for the six months ended August 31, 2022 and 2021, respectively.

For the six months ended August 31, 2022, we incurred transaction expenses of $1,025,541 related to the acquisition of funding and to acquire the Reabold crude oil and natural gas properties located in central California and to eliminate our line of credit balance. For the six months ended August 31, 2021, we did not incur any related expenses. Transaction expenses represented 49.4% and 0.0% of total operating expenses for the six months ended August 31, 2022 and 2021, respectively.

General and administrative (“G&A”) expenses include the salaries of six employees, including management. Other items included in our G&A expenses are legal and accounting expenses, investor relations fees, travel expenses, insurance expenses and other administrative expenses necessary for an operation of crude oil and natural gas properties as well as for the running a public company. For the six months ended August 31, 2022, G&A expenses increased $251,672 or 87.8% to $538,460 in comparison to $286,788 for the six months ended August 31, 2021. The primary reasons for the increase in G&A expense are related to the expenses of both the special shareholders and the annual shareholders meetings, in the amount of approximately $122,200 in aggregate, that were held during the six months ended August 31, 2022 and professional legal and accounting fees of approximately $70,000 related to the Reabold acquisition. We are continuing a program of controlling our G&A costs wherever possible. G&A expenses represented 26.0% and 69.1% of total operating expenses for the six months ended August 31, 2022 and 2021, respectively.

During the six months ended August 31, 2021, the Company recognized a gain on asset disposal of $9,614. The gain was the result of an insurance settlement on the theft of a company vehicle that was fully depreciated.

Interest expense, net for the six months ended August 31, 2022 increased $22,979 or 19.9% to $138,576 in comparison to $115,597 for the six months ended August 31, 2021.

Results of Operations – Three months ended August 31, 2022 compared to the three months ended August 31, 2021

A comparison of the average WTI crude oil price and the average realized crude oil sales price for the three months ended August 31, 2022 and 2021 is shown in the table below:

For the three months ended August 31, 2022, the average WTI price was $103.38 and our average realized crude oil sale price was $101.56, representing a discount of $1.82 per barrel or 1.8% lower than the average WTI price. In comparison, for the three months ended August 31, 2021, the average WTI price was $70.52 and our average realized sale price was $67.75 representing a discount of $2.77 per barrel or 3.9% lower than the average WTI price. Historically, the sale price we receive for East Slopes heavy crude oil has been less than the quoted WTI price because of the lower API gravity of our California crude oil in comparison to the API gravity of quoted WTI crude oil.

California Crude Oil Revenue and Production

Crude oil revenue in California for the three months ended August 31, 2022, increased $362,264 or 214.0% to $531,582 in comparison to revenue of $169,318 for the three months ended August 31, 2021. The primary reason for the increase was the acquisition of the Reabold wells in central California. The average sale price of a barrel of crude oil for the three months ended August 31, 2022 was $101.56 in comparison to $67.75 for the three months ended August 31, 2021. The increase of $33.81 or 49.9% per barrel in the average realized price of a barrel of crude oil accounted for 23.3% of the increase in crude oil revenue for the three months ended August 31, 2022.

Our net sales volume for the three months ended August 31, 2022 was 5,234 barrels of crude oil in comparison to 2,499 barrels sold for the three months ended August 31, 2021. This increase in crude oil sales volume of 2,735 barrels or 109.4% was due to our acquisition of the Reabold property and its producing wells in central California. The gravity of our produced crude oil in the East Slopes project ranges between 14° API and 16° API. The gravity of our produced crude oil in the Reabold project ranges between 17° API and 38° API.

Our crude oil sales revenue for the three months ended August 31, 2022 and 2021 are set forth in the following table:

Our natural gas sales revenue for the three months ended August 31, 2022 and 2021 is set forth in the following table:

Our average realized sale price on a BOE basis of crude oil and natural gas for the three months ended August 31, 2022 was $100.21 in comparison to $67.75 for the three months ended August 31, 2021, representing an increase of $32.46 or 47.9% per barrel.

Operating Expenses

Total operating expenses for the three months ended August 31, 2022 were $723,862, an increase of $536,795 or 287.0% compared to $187,067 for the three months ended August 31, 2021. Operating expenses for the three months ended August 31, 2022 and 2021 are set forth in the table below:

Production expenses for the three months ended August 31, 2022, increased by $245,639 or 464.8% to $298,482 in comparison to $52,843 for the three months ended August 31, 2021. For the three months ended August 31, 2022 and 2021, we had 19 and 20 wells, respectively, on production in our East Slopes project. For the three months ended August 31, 2022, we had four wells on production in the Reabold project that we acquired in May 2022. The increase in production expenses for the three months ended August 31, 2022, was primarily due to the replacement and upgrading of pumps in seven wells of the East Slopes project for $42,920 and the expenses associated with salt water disposal of $158,100 from the Reabold project. A salt water disposal well is currently being permitted which, when put into operation will significantly lower operating costs of the Reabold project. Production expense on a barrel of oil equivalent (“BOE”) basis for the three months ended August 31, 2022 and 2021 were $55.28 and $21.15, respectively. Production expenses represented 41.2% and 28.3% of total operating expenses for the three months ended August 31, 2022 and 2021, respectively.

Exploration and drilling expenses for the three months ended August 31, 2022 were $1,170 in comparison to $201 for the three months ended August 31, 2021. Exploration and drilling expenses represented 0.1% and 0.1% of total operating expenses for the three months ended August 31, 2022 and 2021, respectively.

DD&A expenses for the three months ended August 31, 2022, increased $123,028 or 827.9% to $137,888 in comparison to $14,860 for the three months ended August 31, 2021. DD&A on a BOE basis was $25.54 and $5.95 for the three months ended August 31, 2022 and 2021, respectively. DD&A expenses represented 19.0% and 7.9% of total operating expenses for the three months ended August 31, 2022 and 2021, respectively.

General and administrative (“G&A”) expenses include the salaries of five employees, including management. Other items included in our G&A expenses are legal and accounting expenses, investor relations fees, travel expenses, insurance expenses and other administrative expenses necessary for an operator of crude oil properties as well as for running a public company. G&A expenses for the three months ended August 31, 2022, increased $167,159 or 140.3% to $286,322 in comparison to $119,163 for the three months ended August 31, 2021. The primary reasons for the increase in G&A expense are related to the special shareholders meeting held during the three months ended May 31, 2022 and the annual shareholders meeting held during the three months ended August 31, 2022 in the amount of approximately $54,200 in aggregate and professional legal and accounting services of approximately $61,000 related to the Reabold acquisition on May 2022. We are continuing a program of controlling our G&A costs wherever possible. G&A expenses represented 39.6% and 63.7% of total operating expenses for the three months ended August 31, 2022 and 2021, respectively.

Interest expense, net for the three months ended August 31, 2022 increased $13,315 or 24.5% to $67,646 in comparison to $54,331 for the three months ended August 31, 2021.

Due to the nature of our business, we expect that revenues, as well as all categories of expenses, will continue to fluctuate substantially on a quarter-to-quarter and year-to-year basis. Revenues are highly dependent on the volatility of hydrocarbon prices and production volumes. Production expenses will fluctuate according to the number and percentage ownership of producing wells as well as the amount of revenues we receive based on the price of crude oil. Exploration and drilling expenses will be dependent upon the amount of capital that we have to invest in future development projects, as well as the success or failure of such projects. Likewise, the amount of DD&A expense will depend upon the factors cited above including the size of our proven reserves base and the market price of energy products. G&A expenses will also fluctuate based on our current requirements, but will generally tend to increase as we expand the business operations of the Company. An on-going goal of the Company is to improve cash flow to cover the current level of G&A expenses and to fund our drilling programs in California and Michigan.

Capital Resources and Liquidity

Our primary financial resource is our proven crude oil reserve base. Our ability to fund any future capital expenditure programs is dependent upon the prices we receive from crude oil sales, the success of our drilling programs in California and the availability of capital resource financing. There continues to be a significant amount of volatility in crude oil prices and dramatic fluctuation in our realized sale price of crude oil since June of 2014, when the monthly average price of WTI crude oil was $105.79 per barrel, and our realized sale price per barrel of crude oil was $98.78. As an example, for the month of April 2020 the monthly average closing price of WTI crude oil was $16.55 and our monthly realized oil price was $16.96 per barrel. Finally, in May 2022, the monthly average price of WTI oil was $109.55 per barrel and our realized price per barrel of crude oil was $106.56. Again in August, 2022, our average realized price was $92.36 per barrel. This volatility in crude oil prices continued into the current fiscal year. Any downward volatility in the price of crude oil will have a prolonged and substantial negative impact on our profitability and cash flow from our producing California properties. It is beyond our ability to accurately predict crude oil prices over any substantial length of time.

We plan to spend approximately $435,000 drilling three development wells in the current 2022-2023 fiscal year; however our actual expenditures may vary significantly from this estimate if our plans for exploration and development activities change during the year. Factors such as changes in operating margins and the availability of capital resources could increase or decrease our ultimate level of expenditures during the current fiscal year.

Changes in our capital resources at August 31, 2022 in comparison to February 28, 2022 are set forth in the table below:

Our working capital deficit decreased approximately $1.37 million or 45.8% to approximately $1.6 million at August 31, 2022 in comparison to approximately $2.99 million at February 28, 2022. The decrease in our working capital deficit was primarily due to the proceeds we received in connection with the sale of common stock. We anticipate an increase in our cash flow will occur when we are able to return to our planned drilling program that will result in an increase in the number of wells on production.

Our business is capital intensive. Our ability to grow is dependent upon favorably obtaining outside capital and generating cash flows from operating activities necessary to fund our investment activities. There is no assurance that we will be able to achieve profitability. Since our future operations will continue to be dependent on successful exploration and development activities and our ability to seek and secure capital from external sources, should we be unable to achieve sustainable profitability this could cause any equity investment in the Company to become worthless.

Major sources of funds in the past for us have included the debt or equity markets and the sale of assets. We anticipate that we will have to rely on these capital markets to fund future operations and growth. Our business model is focused on acquiring exploration or development properties as well as existing production. Our ability to generate future revenues and operating cash flow will depend on successful exploration, and/or acquisition of crude oil producing properties, which may very likely require us to continue to raise equity or debt capital from outside sources.

Daybreak has ongoing capital commitments to develop certain leases pursuant to their underlying terms. Failure to meet such ongoing commitments may result in the loss of the right to participate in future drilling on certain leases or the loss of the lease itself. These ongoing capital commitments will cause us to seek additional forms of financing through various methods, including issuing debt securities, equity securities, bank debt, or combinations of these instruments which could result in dilution to existing security holders and increased debt and leverage. The current uncertainty in the credit and capital markets as well as the instability and volatility in crude oil prices since June of 2014, has restricted our ability to obtain needed capital. The 2019 novel coronavirus (“COVID-19") that spread to countries throughout the world including the United States had a substantial negative impact on the demand for crude oil and is largely responsible for the decline in crude oil prices. No assurance can be given that we will be able to obtain funding under any loan commitments or any additional financing on favorable terms, if at all. Sales of interests in our assets may be another source of cash flow available to us.

The Company’s financial statements for the six months ended August 31, 2022 have been prepared on a going concern basis, which contemplates the realization of assets and the settlement of liabilities in the normal course of business. We have incurred net losses since entering the crude oil exploration industry in 2005, and as of the six months ended August 31, 2022, we have an accumulated deficit of $30.95 million and a working capital deficit of $1.6 million which raises substantial doubt about our ability to continue as a going concern.

In the current fiscal year, we will need to seek additional financing for our planned exploration and development activities in California. We could obtain financing through one or more various methods, including issuing debt securities, equity securities, or bank debt, or combinations of these instruments, which could result in dilution to existing security holders and increased debt and leverage. No assurance can be given that we will be able to obtain funding under any loan commitments or any additional financing on favorable terms, if at all. Sales of interests in our assets may be another source of cash flow.

Changes in Financial Condition

During the six months ended August 31, 2021, we received crude oil sales revenue from our 20 producing wells in the East slopes project as well as crude oil and natural gas sales revenue from four producing wells in the recently acquired Reabold project. Both of these projects are located in California. Our commitment to improving corporate profitability remains unchanged. We experienced an increase in revenues of $472,028 or 149.1% to $788,646 for the six months ended August 31, 2022 in comparison to revenues of $316,618 for the six months ended August 31, 2021. The increase of $37.23 or 57.5% in the average realized price BOE accounted for 38.6% of the increase in crude oil revenue for the six months ended August 31, 2022. The increase in sales volume BOE accounted for the remaining 61.5% of the revenue increase. The increase in volume was primarily due to the four producing wells that we acquired in the recently completed acquisition of Reabold California, LLC. For the six months ended August 31, 2022, we had an operating loss of $1,285,388 in comparison to an operating loss of $98,748 for the six months ended August 31, 2021. The increase in the operating loss was due to transaction expenses related to the acquisition of the Reabold property, fundraising, and the expenses of holding both a special shareholders’ meeting to approve the acquisition and a regular annual shareholders meeting.

Our balance sheet at August 31, 2022 reflects total assets of approximately $8.56 million in comparison to approximately $0.98 million at February 28, 2022. The increase of approximately $7.5 million is directly related to the acquisition of crude oil and natural gas assets in California.

At August 31, 2022, total liabilities were approximately $3.8 million in comparison to approximately $4.3 million at February 28, 2022. The decrease in liabilities of approximately $488,000 was primarily due elimination of the line of credit with UBS Bank in conjunction with the completion of the sale of common stock through a private sale.

At August 31, 2022, there were 384,735,402 issued and outstanding shares of common stock in comparison to 67,802,273 shares at February 28, 2022. The increase in shares issued and outstanding of 316,933,129 shares was directly related to the acquisition of producing crude oil and natural gas assets, associated fundraising and the restructuring of our balance sheet eliminating debt in exchange for equity.

Additional paid in capital (APIC) increased approximately $9.2 million at August 31, 2022 to $35,297,706 from $26,115,450 at February 28, 2022, as a result of the same acquisition of producing crude oil and natural gas assets, associated fundraising and the restructuring of our balance sheet eliminating debt in exchange for equity.

Cash Flows

Changes in the net funds provided by and (used in) our operating, investing and financing activities are set forth in the table below:

Cash Flow Provided By (Used In) Operating Activities

Cash flow from operating activities is derived from the production of our crude oil reserves and changes in the balances of non-cash accounts, receivables, payables or other non-energy property asset account balances. For the six months ended August 31, 2022, cash flow used in operating activities was $592,183 in comparison to cash flow provided by operating activities of $41,329 for the six months ended August 31, 2021. The increase in our cash flow used in operating activities of

633,512 for the six months ended August 31, 2022 was primarily due to increases in our accounts receivable crude oil and natural gas sales and receivables form our working interest partners. Both of these increases were directly related to our acquisition of producing crude oil and natural gas assets in California from a third party. Changes in non-cash account balances primarily relating to financing fees, DD&A and amortization of debt discount increased by approximately $644,000 in comparison to the six month ended August 31, 2021. Variations in cash flow from operating activities may impact our level of exploration and development expenditures.

Cash Flow Used In Investing Activities

Cash flow from investing activities is derived from changes in crude oil property balances and any lending activities. Cash flow used in our investing activities for the six months ended August 31, 2022 was $-0- in comparison to cash flow used in our investing activities of $13,107 for the six months ended August 31, 2021.

Cash Flow Provided By (Used In) Financing Activities

Cash flow from financing activities is derived from changes in long-term liability account balances or in equity account balances, excluding retained earnings. Cash flow provided by our financing activities was $1,140,559 for the six months ended August 31, 2022 in comparison to cash flow used in our financing activities of $4,611 for the six months ended August 31, 2021. During the six months ended August 31, 2022 we secured a capital raise of $1,987,500 net of transaction expenses from the sale of 128,125,000 shares of our common stock. Additionally, during the six months ended August 31, 2022, we paid off the balance of $808,182 on the line of credit with UBS Bank.

The following discussion is a summary of cash flows provided by, and used in, the Company’s financing activities at August 31, 2022.

SHORT-TERM AND LONG-TERM BORROWINGS:

Note Payable

In December 2018, the Company was able to settle an outstanding balance owed to one of its third-party vendors. This settlement resulted in a $120,000 note payable being issued to the vendor. Additionally, the Company agreed to issue 2,000,000 shares of the Company’s common stock as a part of the settlement agreement. Based on the closing price of the Company’s common stock on the date of the settlement agreement, the value of the common stock transaction was determined to be $6,000. The common stock shares were issued during the twelve months ended February 29, 2020. The note has a maturity date of January 1, 2022 and bears an interest rate of 10% rate per annum. Monthly interest is accrued and payable on January 1^st of each anniversary date until maturity of the note. At August 31, 2022, the accrued interest had not been paid and was outstanding. The accrued interest on the Note was $44,000 and $38,000 at August 31, 2022 and February 28, 2022, respectively.

Note Payable – Related Party

On December 22, 2020, the Company entered into a Secured Promissory Note (the “Note”), as borrower, with James Forrest Westmoreland and Angela Marie Westmoreland, Co-Trustees of the James and Angela Westmoreland Revocable Trust, or its assigns (the “Noteholder”), as the lender. James F. Westmoreland is the Company’s Chairman, President and Chief Executive Officer. Pursuant to the Note, the Noteholder loaned the Company an aggregate principal amount of $155,548. After the deduction of loan fees of $10,929 the net proceeds from the loan were $144,619. The loan fees are being amortized as original issue discount (OID) over the term of the loan. The interest rate of the loan is 2.25%. The Note requires monthly payments on the Note balance until repaid in full. The maturity date of the Note is December 21, 2035. For the six months ended August 31, 2022, the Company made principal payments of $4,384 and amortized debt discount of $364. The obligations under the Note are secured by a lien on and security interest in the Company’s crude oil assets located in Kern County, California, as described in a Deed of Trust entered into by the Company in favor of the Noteholder to secure the obligations under the Note. Such lien shall be a first priority lien, subject only to a pre-existing lien filed by a working interest partner of the Company.

The Company may prepay the Note at any time. Upon the occurrence of any Event of Default and expiration of any applicable cure period, and at any time thereafter during the continuance of such Event of Default, the Noteholder may at its option, by written notice to the Company: (a) declare the entire principal amount of the Note, together with all accrued interest thereon and all other amounts payable hereunder, immediately due and payable; (b) exercise any of its remedies with respect to the collateral set forth in the Deed of Trust; and/or (c) exercise any or all of its other rights, powers or remedies under applicable law.

Current portion of note payable – related party balances at August 31, 2022 and February 28, 2022 are set forth in the table below:

Note payable – related party long-term balances at August 31, 2022 and February 28, 2022 are set forth in the table below:

Future estimated payments on the outstanding note payable – related party are set forth in the table below:

Short-term Convertible Note Payable

During the twelve months ended February 28, 2022, the Company executed a convertible promissory note with a third party for $200,000. The interest rate was 18% per annum and is payable in kind (PIK) solely by additional shares of the Company’s common stock. Regardless of when the conversion occurred, a full 12 months of interest would be payable upon conversion. On May 5, 2022, the Company received notice of conversion of the promissory note. The face amount of the note and $36,000 in interest were converted at a rate of $0.0085 per share into 27,764,706 share of the Company’s common stock during the six months ended August 31, 2022.

12% Subordinated Notes

The Company’s 12% Subordinated Notes (“the Notes”) issued pursuant to a January 2010 private placement offering to accredited investors, resulted in $595,000 in gross proceeds (of which $250,000 was from a related party) to the Company and accrue interest at 12% per annum, payable semi-annually on January 29th and July 29th. On January 29, 2015, the Company and 12 of the 13 holders of the Notes agreed to extend the maturity date of the Notes for an additional two years to January 29, 2017. Effective January 29, 2017, the maturity date of the Notes and the expiration date of the warrants that were issued in conjunction with the Notes were extended for an additional two years to January 29, 2019.

As a result of the Company restructuring its balance sheet through conversions of related party debt to common stock, the related party 12% Noteholder, James F. Westmoreland, the Company’s President and Chief Executive Officer, chose to convert the principal and accrued interest of their Notes to the Company’s common stock. The related party Note for $250,000 and accrued interest of $264,986 were converted to common stock at a rate of approximately $0.45 for every dollar of principal and interest resulting in 1,144,415 shares of common stock being issued.

During the six months ended August 31, 2022, one 12% Note holder chose to convert the principal balance and accrued interest in to the Company’s common stock. The $25,000 Note and accrued interest of $10,520 were converted at a rate of approximately $0.45 for every dollar of principal and interest resulting in 78,934 shares of common stock being issued.

The Company has informed the Note holders that the payment of principal and final interest will be late and is subject to future financing being completed and the Company’s cash flow. The Notes principal of $290,000 has not been paid. The terms of the Notes, state that should the Board of Directors decide that the payment of the principal and any unpaid interest would impair the financial condition or operations of the Company, the Company may then elect a mandatory conversion of the unpaid principal and interest into the Company’s common stock at a conversion rate equal to 75% of the average closing price of the Company’s common stock over the 20 consecutive trading days preceding December 31, 2018. The accrued interest on the 12% Notes at August 31, 2022 and February 28, 2022 was $142,251 and $135,229, respectively.

12% Note balances at August 31, 2022 and February 28, 2022 are set forth in the table below:

Line of Credit

The Company had an existing $890,000 line of credit for working capital purposes with UBS Bank USA (“UBS”), established pursuant to a Credit Line Agreement dated October 24, 2011 that was secured by the personal guarantee of its Chairman, President and Chief Executive Officer. On May 26, 2022, the Company paid off the outstanding balance of $809,930 on the line of credit. The payoff of the line of credit was previously approved under terms of the Equity Exchange Agreement in which the Company acquired the Reabold property in California. The payoff was a part of the use of proceeds from the Company’s sale of common stock to a third party.

Production Revenue Payable

Beginning in December 2018, the Company conducted a fundraising program to fund the drilling of future wells in California and Michigan and to settle some of its historical debt. The purchaser(s) of a production revenue payment interest received a production revenue payment on future wells to be drilled in California and Michigan in exchange for their purchase. The production payment interest entitles the purchasers to receive production payments equal to twice their original amount paid, payable from a percentage of the Company’s future net production payments from wells drilled after the date of the purchase and until the Production Payment Target (as described below) is met.  The Company shall pay fifty percent of its net production payments from the relevant wells to the purchasers until each purchaser has received two times the purchase price (the “Production Payment Target”). Once the Company pays the purchasers amounts equal to the Production Payment Target, it shall thereafter pay a pro-rated eight percent (8%) of $1.3 million on its net production payments from the relevant wells to each of the purchasers. However, if the total raised is less than the target $1.3 million, then the payment will be a proportionate amount of the eight percent (8%). Additionally, if the Production Payment Target is not met within the first three years, the Company shall pay seventy-five percent of its production payments from the relevant wells to the purchasers until the Production Payment Target is met.

The Company accounted for the amounts received from these sales in accordance with ASC 470-10-25 and 470-10-35 which require amounts recorded as debt to be amortized under the interest method as described in ASC 835-30, Interest Method. Consequently, the program balance of $885,606 has been recognized as a production revenue payable. The Company determined an effective interest rate based on future expected cash flows to be paid to the holders of the production payment interests. This rate represents the discount rate that equates estimated cash flows with the initial proceeds received from the sales and is used to compute the amount of interest to be recognized each period. Estimating the future cash outflows under this agreement requires the Company to make certain estimates and assumptions about future revenues and payments and such estimates are subject to significant variability. Therefore, the estimates are likely to change which may result in future adjustments to the accretion of the interest expense and the amortized cost based carrying value of the related payables.

Accordingly, the Company has estimated the cash flows associated with the production revenue payments of $984,601 and determined a discount of $98,995 as of August 31, 2022, which is being accounted as interest expense over the estimated period over which payments will be made based on expected future revenue streams. For the six months ended August 31, 2022 and 2021, amortization of the debt discount on these payables amounted to $68,482 and $54,304, respectively, which has been included in interest expense in the statements of operations.

Production revenue payable balances at August 31, 2022 and February 28, 2022 are set forth in the table below:

Encumbrances

On October 17, 2018, a working interest partner in California filed a UCC financing statement in regards to payable amounts owed to the partner by the Company.

Operating Leases

The Company leases approximately 988 rentable square feet of office space from an unaffiliated third party for our corporate office located in Spokane Valley, Washington. Additionally, we lease approximately 416 and 695 rentable square feet from unaffiliated third parties for our regional operations office in Friendswood, Texas and storage and auxiliary office space in Wallace, Idaho, respectively. The lease in Friendswood is a 12 month lease that expires in October 2022. The Spokane Valley and Wallace leases are currently on a month-to-month basis. The Company’s lease agreements do not contain any residual value guarantees, restrictive covenants or variable lease payments. The Company has not entered into any financing leases.

The Company determines if an arrangement is a lease at inception. Operating leases are recorded in operating lease right of use assets, net, operating lease liability – current, and operating lease liability – long-term on its balance sheet.

Rent expense for the six months ended August 31, 2022 and 2021 was $11,895 and $11,745, respectively.

Related Party Transactions

In California at the East Slopes Project, two of the vendors that the Company uses for services are partially owned by a related party, the Company’s Chief Operating Officer. The Company’s Chief Operating Officer is a 50% owner in both Great Earth Power and ABPlus Net Holdings. Great Earth Power began providing a portion of the solar power electrical service for production operations in July 2020. ABPlus Net Holdings began providing portable tank rentals to the Company as a part of its water treatment and disposal operations in September 2020. The services provided by Great Earth Power and ABPlus Net Holdings are competitive with other vendors and save the Company significant expense. For the six months ended August 31, 2022 and 2021, Great Earth Power was paid $9,716 and $10,675, respectively. For the six months ended August 31, 2022 and 2021, ABPlus Net holdings was paid $5,760 and $5,760, respectively.

Capital Commitments

Daybreak has ongoing capital commitments to develop certain leases pursuant to their underlying terms. Failure to meet such ongoing commitments may result in the loss of the right to participate in future drilling on certain leases or the loss of the lease itself. These ongoing capital commitments may also cause us to seek additional capital from sources outside of the Company. The current uncertainty in the credit and capital markets, and the current economic downturn in the energy sector, may restrict our ability to obtain needed capital.

Management Plans to Continue as a Going Concern

We continue to implement plans to enhance our ability to continue as a going concern. Daybreak currently has a net revenue interest (“NRI”) in 20 producing crude oil wells in its East Slopes Project located in Kern County, California (the “East Slopes Project”). The revenue from these wells has created a steady and reliable source of income for the Company. The Company’s average working interest (“WI”) in these wells is 36.6% and the average net revenue interest (“NRI”) is 27.6% for these same wells.

In May 2022, we acquired Reabold California, LLC (“Reabold”) from a third party. This property currently includes four producing wells, five shut-in wells, and two potential disposal wells in the Monterey and Contra Costa counties of California. This project includes four producing wells. We have a 50% working interest with a 40% net revenue interest in this project.

In conjunction with our acquisition of Reabold, we were able to secure a capital raise of $2,500,000 through the issuances of the Company’s common stock.

We anticipate our revenue will continue to increase as the Company participates in the drilling of more wells in the East Slopes and the Reabold Projects in California. Daybreak’s sources of funds in the past have included the debt or equity markets and the sale of assets. It will be necessary for us to obtain additional funding from the private or public debt or equity markets in the future. However, we cannot offer any assurance that it will be successful in executing the aforementioned plans to continue as a going concern.

Our financial statements as of August 31, 2022 do not include any adjustments that might result from the inability to implement or execute our plans to improve our ability to continue as a going concern.

Critical Accounting Policies

Refer to Daybreak’s Annual Report on Form 10-K for the fiscal year ended February 28, 2022.

Off-Balance Sheet Arrangements

As of August 31, 2022, we did not have any off-balance sheet arrangements or relationships with unconsolidated entities or financial partners that have been, or are reasonably likely to have, a material effect on our financial position or results of operations.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

As a smaller reporting company, we are not required to provide the information otherwise required by this Item.

ITEM 4. CONTROLS AND PROCEDURES

Management’s Evaluation of Disclosure Controls and Procedures

As of the end of the reporting period, August 31, 2022, an evaluation was conducted by Daybreak management, including our President and Chief Executive Officer, who is also serving as our interim principal finance and accounting officer, as to the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Rule 13a-15(e) of the Exchange Act. Such disclosure controls and procedures are designed to ensure that information required to be disclosed by a company in the reports that it files under the Exchange Act is recorded, processed, summarized and reported within required time periods specified by the SEC rules and forms. Additionally, it is vital that such information is accumulated and communicated to our management, including our President and Chief Executive Officer, in a manner to allow timely decisions regarding required disclosures. Based on that evaluation, our management concluded that our disclosure controls were effective as of August 31, 2022.

Changes in Internal Control over Financial Reporting

During the three months ended August 31, 2022, there have not been any changes in the Company’s internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

Limitations

Our management does not expect that our disclosure controls or internal controls over financial reporting will prevent all errors or all instances of fraud. A control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that the control system’s objectives will be met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs.

Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within our company have been detected. These inherent limitations include the realities that judgments in decision-making can be faulty, and that breakdowns can occur because of simple error or mistake. Controls can also be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the controls. The design of any system of controls is based in part upon certain assumptions about the likelihood of future events, and any design may not succeed in achieving its stated goals under all potential future conditions.

Over time, controls may become inadequate because of changes in conditions or deterioration in the degree of compliance with policies or procedures. Because of the inherent limitation of a cost-effective control system, misstatements due to error or fraud may occur and not be detected.

PART II

OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

None

ITEM 1A. RISK FACTORS

In addition to the other information set forth in this Form 10-Q Report, you should carefully consider the various factors discussed in Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended February 28, 2022, which could materially affect our business, financial condition or future results. Our Annual Report is available from the SEC at www.sec.gov. The risks described in this report are not the only risks we face. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial could have a material adverse effect on our business, financial condition or future results of operations.

ITEM 6. EXHIBITS

The following Exhibits are filed as part of the report:

⁽¹⁾       Filed herewith.

⁽²⁾       Furnished herewith

SIGNATURES

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

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