DAYBREAK OIL & GAS, INC. - Quarter Report: 2017 May (Form 10-Q)

At July 13, 2017 the registrant had 51,532,364 outstanding shares of $0.001 par value common stock.

TABLE OF CONTENTS

PART I - FINANCIAL INFORMATION

PART II - OTHER INFORMATION

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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

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DAYBREAK OIL AND GAS, INC.

Statements of Operations – Unaudited

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

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DAYBREAK OIL AND GAS, INC.

Statements of Cash Flows – Unaudited

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

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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”) under the laws of the State of Washington on March 11, 1955, Daybreak Uranium was organized to explore for, acquire, and develop mineral properties in the Western United States.  During 2005, management of the Company decided to enter the oil and natural gas exploration 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 and natural gas 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 and natural gas.  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 include the level of global demand for petroleum products, foreign supply of crude oil and natural gas, the establishment of and compliance with production quotas by oil-exporting countries, the relative strength of the U.S. dollar, weather conditions, the price and availability of alternative fuels, and overall economic conditions, both foreign and domestic.

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 three months ended May 31, 2017 are not necessarily indicative of the results that may be expected for the fiscal year ending February 28, 2018.

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, 2017.

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:

·

The reliance on estimates of proved reserves to compute the provision for depreciation, depletion and amortization and to determine the amount of any impairment of proved properties;

·

The valuation of unproved acreage and proved crude oil and natural gas properties to determine the amount of any impairment of crude oil and natural gas properties;

·

Judgment regarding the productive status of in-progress exploratory wells to determine the amount of any provision for abandonment; and

·

Estimates regarding abandonment obligations.

Reclassifications

Certain reclassifications have been made to conform the prior period’s financial information to the current period’s presentation.  These reclassifications had no effect on previously reported net loss or accumulated deficit.

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NOTE 2 — GOING CONCERN:

Financial Condition

The Company’s financial statements for the three months ended May 31, 2017 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 losses since entering the crude oil and natural gas exploration industry and as of May 31, 2017 has an accumulated deficit of $36,646,757 and a working capital deficit of $13,838,048 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 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 in these wells is 36.6% and the average NRI is 28.4% for these same wells.

The Company anticipates its revenue will continue to increase as the Company participates in the drilling of more wells in the East Slopes Project in California and as our exploratory drilling project begins in Michigan.  However given the current decline and instability in hydrocarbon prices, the timing of any drilling activity in California and Michigan will be dependent on a sustained improvement in hydrocarbon prices and a successful refinancing or restructuring of our credit facility.

The Company believes that our liquidity will improve when there is a sustained improvement in hydrocarbon prices.  Daybreak’s sources of funds in the past have included the debt or equity markets and the sale of assets.  While the Company has experienced revenue growth, which has resulted in positive cash flow from its crude oil and natural gas properties, it has not yet established a positive cash flow on a company-wide basis.  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 May 31, 2017 do not include any adjustments that might result from the inability to implement or execute Daybreak’s plans to improve our ability to continue as a going concern.

NOTE 3 — CONCENTRATION OF CREDIT RISK:

Substantially all of the Company’s trade accounts receivable result from crude oil and natural gas sales or joint interest billings to its working interest partners.  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 as well as other related factors.  Trade accounts receivable are generally not collateralized.

At the Company’s East Slopes project in California there is only one buyer available for the purchase of all crude oil production.  The Company has no natural gas production in California.  At May 31, 2017 and February 28, 2017 this one customer represented 100.0% of crude oil sales receivable.  If this buyer is unable to resell its products or if they lose a significant sales contract then the Company may incur difficulties in selling its crude oil production.

The Company’s accounts receivable balances from California crude oil sales of $75,887 and $83,405 at May 31, 2017 and February 28, 2017, respectively were from one customer, Plains Marketing.  Crude oil sales receivables balances of $75,887 and $83,405 at May 31, 2017 and February 28, 2017 represent crude oil sales that occurred in May and February 2017, respectively.  

Joint interest participant receivables balances of $78,479 and $55,154 at May 31, 2017 and February 28, 2017, respectively represent amounts due from working interest partners in California, where the Company is the Operator.  There were no allowances for doubtful accounts for the Company’s trade accounts receivable at May 31, 2017 and February 28, 2017 as the joint interest owners have a history of paying their obligations.

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NOTE 4 — CRUDE OIL AND NATURAL GAS PROPERTIES:

Crude oil and natural gas property balances at May 31, 2017 and February 28, 2017 are set forth in the table below.

For the three months ended May 31, 2017, a $51,486 revision in unproved crude oil and natural gas properties occurred to properly recognize geologic and geophysical lease expenses associated with our Michigan exploratory joint drilling project development.

NOTE 5 — ACCOUNTS PAYABLE:

On March 1, 2009, the Company became the operator for its East Slopes Project.  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 default, $244,849 remains unpaid and is included in the May 31, 2017 accounts payable balance.

NOTE 6 — ACCOUNTS PAYABLE- RELATED PARTIES:

The May 31, 2017 and February 28, 2017 accounts payable – related parties balances of $1,473,274 and $1,414,481 respectively, were comprised primarily of deferred salaries of the Company’s Executive Officers and certain employees; directors’ fees; expense reimbursements; and deferred interest payments on a 12% Subordinated Notes owed to the Company’s President and Chief Executive Officer.  Payment of these deferred items has been delayed until the Company’s cash flow situation improves.

NOTE 7 — ASSET RETIREMENT OBLIGATION (ARO):

For the three months ended May 31, 2017 the credit adjusted risk free rate (CARFR) percentage used in the calculation of the asset retirement obligation (“ARO”) was revised from 10% to 15% to more accurately reflect the Company’s current cost of funds.  This revision resulted in a $40,108 reduction in the ARO liability balance shown on the Company’s Balance Sheet at May 31, 2017.  The ARO balance at May 31, 2017 is set forth in the table below:

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

Current debt (Short-term borrowings)

Note Payable – Related Party

At May 31, 2017 and February 28, 2017, the Company had a loan balance of $250,100 with the Company’s Chairman, President and Chief Executive Officer which were obtained during the years ended February 29, 2012 and February 28, 2013, that was used for a variety of corporate purposes including an escrow requirement on a loan commitment; maturity extension fees on third party loans; and a reduction of principal on the Company’s credit line with UBS Bank.  These loans are non-interest bearing loans and repayment will be made upon a mutually agreeable date in the future.

Line of Credit

The Company has 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 is secured by the personal guarantee of its Chairman, President and Chief Executive Officer.  At May 31, 2017 and February 28, 2017, the Line of Credit had an outstanding balance of $811,681 and $817,622, respectively.  Interest is payable monthly at a stated reference rate of 0.249% + 337.5 basis points and was $9,059 and $8,913, respectively for the three months ended May 31, 2017 and 2016.  The reference rate is based on the 30 day LIBOR (“London Interbank Offered Rate”) and is subject to change from UBS.

Maximilian Loan Agreement (Credit Facility)

Maximilian Loan - Amended and Restated Loan Agreement

In connection with the Company’s acquisition of a working interest from App Energy, LLC, a Kentucky limited liability company (“App Energy”) in the Twin Bottoms Field in Lawrence County, Kentucky, the Company amended its loan agreement with Maximilian on August 28, 2013.  The amendment increased the amount of the credit facility to $90 million and reduced the annual interest rate to 12%.  The Company evaluated the amendment of the revolving credit facility under ASC 470-50-40 and determined that the Company’s borrowing capacity under the amended loan agreement exceeded its borrowing capacity under the old loan agreement.  Consequently, the unamortized discount and deferred financing costs as of the date of amendment are being amortized over the term of the amended loan agreement.

On October 31, 2016, the Company entered into a Fourth Amendment to the Amended and Restated Loan and Security Agreement with Maximilian, which amended the Company’s loan agreement with Maximilian (the “Restructuring Agreement”).  Pursuant to the Restructuring Agreement, in exchange for the proceeds it received from the Kentucky Sale, Maximilian and the Company have agreed to a commitment by Maximilian to advance up to $250,000 in financing to the Company over the following six month period and the pursuit of the Michigan exploratory joint drilling project using the $250,000 set aside from the Kentucky Sale.

As a result of the decline in hydrocarbon prices that started in June of 2014, the Company has been unable to make any type of interest or principal payments required under the amended terms of its credit facility with Maximilian since December of 2015.  Under the terms of the Restructuring Amendment all unpaid interest is currently being accrued.  Historically, a series of waivers have been granted by Maximilian for the principal and interest payments that have not been made.  Due to the waivers granted by Maximilian, the Company is currently not considered to be in default under terms of the credit facility.  Maximilian is continuing to work with the Company in restructuring the credit facility terms during this period of lower hydrocarbon prices, but there can be no assurances that this cooperation will continue.  Further, our lender is under no obligation to advance us any additional funding and, rather, there can be no assurances that out lender will not declare the Company to be in default under the credit facility.  A change of control or management of our lender, among other reasons, could also result in our loan being called due and payable.

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Maximilian Promissory Note – Michigan Exploratory Joint Drilling Project

As of May 31, 2017, the Company had received $94,650 in aggregate from multiple advances starting in the year ended February 28, 2017 from Maximilian under a separate promissory note agreement dated January 17, 2017 and amended on February 10, 2017 regarding the development of an exploratory joint drilling project in Michigan.  Advances under this agreement are subject to a 5% (five percent) per annum interest rate.  If a well that the Company elects to participate in is scheduled to be spudded at the Michigan exploratory joint drilling project on or before December 31, 2017, then the advances under the promissory note must be repaid in full upon the earlier of (a) the time that is ten days prior to the first well being spudded on the Michigan exploratory joint drilling project or (b) December 31, 2017.  If there is not a well scheduled to be spudded at the Michigan exploratory joint drilling project on or before December 31, 2017 that the Company elects to participate in, then the Company will assign to Maximilian its working interest in the Michigan exploratory joint drilling project, in full payment and satisfaction of the advances under the promissory note.  Advances under the promissory note may be prepaid at any time without penalty.  In the event of a default of any of the Company’s obligations under the promissory note, the amounts due may be called immediately due and payable at Maximilian’s option.

In accordance with the guidance found in ASC-470-10-45, the entire balance of the Maximilian loan is presented under the current liabilities section of the balance sheets.  In accordance with the guidance found in ASC 835-30 the net amount of the deferred finance costs associated with the credit facility are included with the debt discount as a reduction of the loan balance shown on the Balance Sheets as of May 31, 2017 and February 28, 2017, respectively.

Current debt balances at May 31, 2017 and February 28, 2017 are set forth in the table below:

Deferred financing cost balances of $136,148 and $238,598 at May 31, 2017 and February 28, 2017, respectively includes the fair value of common shares and warrants issued to Maximilian and to a third party that assisted in both the original and the amended financing transactions.  The unamortized deferred financing costs are netted against debt in the balance sheets.  Amortization expense of deferred financing costs was $102,450 and $107,524, respectively for the three months ended May 31, 2017 and 2016.

Encumbrances

The Company’s debt obligations, pursuant to the above mentioned credit facility loan agreement and promissory notes entered into by and between Maximilian and the Company are secured by a perfected first priority security interest in substantially all of the personal property of the Company, and two mortgages; one covering its leases in California and the other covering its leases in Michigan.

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Non-current debt (Long-term borrowings)

12% Subordinated Notes

12% Note balances at May 31, 2017 and February 28, 2017 are set forth in the table below:

12% Note balances – related parties at February 28, 2017 and February 29, 2016 are set forth in the table below:

NOTE 9 — DISCONTINUED OPERATIONS:

Effective October 31, 2016, the Company finalized the sale of its interest in the Twin Bottoms Field in Kentucky.  The sale included Daybreak’s working interest in 14 producing horizontal crude oil wells, its mineral rights, its lease acreage and infrastructure.  In accordance with the guidance provided in ASC 205-20, the Company concluded that this sale qualified for presentation as discontinued operations.  The Company has no ongoing or future plans to be involved in this segment of its crude oil and natural gas projects.  Prior period income statement balances applicable to the Twin Bottoms Field in Kentucky have been reclassified and are included under the Discontinued Operations caption in the statements of operations for May 31, 2016.

Operating income, interest income, operating expenses and interest expense related to Kentucky for the three months ended May 31, 2017 and May 31, 2016 are set forth in the tables below.

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The statements of cash flows include certain significant non-cash operating items for discontinued operations in Kentucky during the three months ended May 31, 2016, comprised of depreciation, depletion and amortization (“DD&A”) expense of $62,050 and debt modification fees of $71,591.  Investing items related to discontinued operations in Kentucky for the three months ended May 31, 2016 were $2,350.

NOTE 10 — STOCKHOLDERS’ DEFICIT:

Preferred Stock

The Company is authorized to issue up to 10,000,000 shares of preferred stock with a par value of $0.001.  The Company’s preferred stock may be entitled to preference over the common stock with respect to the distribution of assets of the Company in the event of liquidation, dissolution, or winding-up of the Company, whether voluntarily or involuntarily, or in the event of any other distribution of assets of the Company among its shareholders for the purpose of winding-up its affairs.  The authorized but unissued shares of preferred stock may be divided into and issued in designated series from time to time by one or more resolutions adopted by the Board of Directors.  The directors in their sole discretion shall have the power to determine the relative powers, preferences, and rights of each series of preferred stock.

Series A Convertible Preferred Stock

The Company has designated 2,400,000 shares of the 10,000,000 preferred shares as Series A Convertible Preferred Stock (“Series A Preferred”), with a $0.001 par value.  At May 31, 2017 and February 28, 2017, there were 709,568 and 724,565 shares issued and outstanding, respectively, that had not been converted into our common stock.  As of May 31, 2017, there are 44 accredited investors who have converted 690,197 Series A Preferred shares into 2,070,591 shares of Daybreak common stock.

The conversions of Series A Preferred that have occurred since the Series A Preferred was first issued in July 2006 are set forth in the table below.

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Holders of Series A Preferred shall accrue dividends, in the amount of 6% of the original purchase price per annum.  Dividends may be paid in cash or common stock at the discretion of the Company.  Dividends are cumulative whether or not in any dividend period or periods we have assets legally available for the payment of such dividends.  Accumulations of dividends on Series A Preferred do not bear interest.  Dividends are payable upon declaration by the Board of Directors.  As of May 31, 2017 no dividends have been declared or paid.  Dividends earned since issuance for each fiscal year and the three months ended May 31, 2017 are set forth in the table below:

Common Stock

The Company is authorized to issue up to 200,000,000 shares of $0.001 par value common stock of which 51,532,364 and 51,487,373 shares were issued and outstanding as of May 31, 2017 and February 28, 2017, respectively.  For the three months ended May 31, 2017, there was one shareholder of Series A Preferred that converted 14,997 shares to 44,991 shares of the Company’s common stock.  Issuances of common stock since February 28, 2017 are set forth in the table below:

NOTE 11 — WARRANTS:

Warrants outstanding and exercisable as of May 31, 2017 are set forth in the table below:

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Warrant activity for the three months ended May 31, 2017 is set forth in the table below:

During the three months ended May 31, 2017, there were no warrants issued, exercised, cancelled or that expired.  The remaining outstanding warrants as of May 31, 2017, have a weighted average exercise price of $0.05, a weighted average remaining life of 1.27 years, and an intrinsic value of $-0-.

NOTE 12 — INCOME TAXES:

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:

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:

At May 31, 2017, Daybreak had estimated net operating loss (“NOL”) carryforwards for federal and state income tax purposes of approximately $26,673,498 which will begin to expire, if unused, beginning in 2024.  The valuation allowance increased $295,554 and $1,303,816 for the three months ended May 31, 2017 and the year ended February 28, 2017, 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 2011 currently remain subject to examinations by appropriate tax authorities.  None of our tax returns are under examination at this time.

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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 oil and natural gas 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 an oil and natural gas 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.

The Company is not aware of any environmental claims existing as of May 31, 2017.  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 oil and natural gas properties.

NOTE 14 — SUBSEQUENT EVENT:

On July 13, 2017, in connection with receiving from Maximilian a current waiver of default covering all the principal and interest payments due through July 1, 2017 that the Company has been unable to make, the Company agreed to cross-collateralize its California and Michigan properties for both the credit facility and the Michigan promissory note loans.

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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 three months ended May 31, 2017 and in our Annual Report on Form 10-K for the year ended February 28, 2017.  References to “Daybreak”, the “Company”, “we”, “us” or “our” mean Daybreak Oil and Gas, Inc.

Cautionary Statement Regarding Forward-Looking Statements

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:

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Our future operating results;

·

Our future capital expenditures;

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Our future financing;

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Our expansion and growth of operations; and

·

Our future investments in and acquisitions of oil and natural gas properties.

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:

·

General economic and business conditions;

·

Exposure to market risks in our financial instruments;

·

Fluctuations in worldwide prices and demand for crude oil and natural gas;

·

Our ability to find, acquire and develop crude oil and natural gas properties;

·

Fluctuations in the levels of our crude oil and natural gas exploration and development activities;

·

Risks associated with crude oil and natural gas exploration and development activities;

·

Competition for raw materials and customers in the crude oil and natural gas industry;

·

Technological changes and developments in the crude oil and natural gas industry;

·

Legislative and regulatory uncertainties, including proposed changes to federal tax law and climate change legislation, regulation of hydraulic fracturing and potential environmental liabilities;

·

Our ability to continue as a going concern;

·

Our ability to secure financing under any commitments as well as additional capital to fund operations; and

·

Other factors discussed elsewhere in this Form 10-Q and in our other public filings, press releases, and discussions with Company management.

Our reserve estimates are determined through a subjective process and are subject to periodic 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, 2017 and in this Form 10-Q for the three months ended May 31, 2017 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.

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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 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 would 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 or 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 and an exploratory joint drilling project in Michigan.  During the twelve months ended February 28, 2017, we sold all of our working interest in the Twin Bottoms Field in Kentucky.

Below is brief summary of our crude oil projects in California and Michigan.  Refer to our discussion in Item 2. Properties, in our Annual Report on Form 10-K for the year ended February 28, 2017 for more information on the California project or the sale of our working interest in the Twin Bottoms Field in Lawrence County, Kentucky.

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 from the Vedder Sand is considered heavy oil.  The crude oil ranges from 14° to 16° API 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 three months ended May 31, 2017 we had production from 20 vertical crude oil wells.  Our average working interest and NRI in these 20 wells is 36.6% and 28.4%, respectively.

There are several other similar prospects on trend with the Bear, Black and Dyer Creek reservoirs exhibiting the same seismic characteristics.  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.

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California Drilling Plans

Planned drilling activity and implementation of our oilfield development plan will not begin until there is a sustained improvement in crude oil prices and additional financing is in put in place.  We plan to spend approximately $75,000 in new capital investments within the East Slopes Project area in the 2017 – 2018 fiscal year.

Michigan Acreage Acquisition

In January 2017, Daybreak acquired a 30% working interest in 1,400 acres in the Michigan Basin where we have two shallow crude oil prospects.  The leases have been secured and multiple targets have been identified through a 2-D seismic interpretation.  A 3-D seismic survey was obtained in January and February of 2017.  An analysis of the seismic survey confirmed the prospect identified on the 2-D seismic, as well as identified several additional drilling locations.  We will obtain an additional 3-D survey to better delineate the other locations before a drilling program commences.  The wells will be drilled vertically with conventional completions and no hydraulic fracturing will be required.  The first well is expected to be drilled during the late summer of 2017.  We plan to spend approximately $300,000 in new capital investments within the Michigan acreage area in the 2017-2018 fiscal year.

Encumbrances

Results of Operations – Three Months Ended May 31, 2017 compared to the Three Months Ended May 31, 2016

California Crude Oil Prices

The price we receive for crude oil sales in California is based on prices quoted on the New York Mercantile Exchange (“NYMEX”) for spot West Texas Intermediate (“WTI”) Cushing, Oklahoma delivery contracts, less deductions that vary by grade of crude oil sold and transportation costs.  We do not have any natural gas revenues in California.

There has been a significant amount of volatility in crude oil prices and dramatic decline 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.  This decline in the price of crude oil has had a substantial negative impact on our cash flow from our producing California properties.  While there has been an improvement in crude oil prices for the three months ended May 31, 2017 in comparison to the three months ended May 31, 2016 there is no guarantee that this trend will continue.  In fact, both the average WTI price of crude oil and our average realized price of crude oil was lower in May 2017 (the third month of our quarter) than in March 2017.  It is beyond our ability to accurately predict how long crude oil prices will continue to remain at these lower price levels; when or at what level they may begin to stabilize; or when they may start to rebound as there are many factors beyond our control that dictate the price we receive on our crude oil sales.

A comparison of the average WTI price, average realized crude oil sales price for the three months ended May 31, 2017 and 2016 is shown in the table below:

For the three months ended May 31, 2017, the average WTI price was $49.62 and our average realized crude oil sale price was $41.62, representing a discount of $8.00 per barrel or 16.1% lower than the average WTI price.  In comparison, for the three months ended May 31, 2016, the average WTI price was $41.67 and our average realized sale price was $31.70 representing a discount of $9.97 per barrel or 23.9% lower than the average WTI price.  Historically, the sale price we receive for California 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.

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California Crude Oil Revenue and Production

Crude oil revenue in California for the three months ended May 31, 2017 increased $28,578 or 27.2% to $133,724 in comparison to revenue of $105,145 for the three months ended May 31, 2016.  The average sale price of a barrel of crude oil for the three months ended May 31, 2017 was $41.62 in comparison to $31.70 for the three months ended May 31, 2016.  The increase of $9.92 per barrel or 31.3% in the average realized price of a barrel of crude oil accounted for 100% of the increase in crude oil revenue for the three months ended May 31, 2017.

Our net sales volume for the three months ended May 31, 2017 was 3,213 barrels of crude oil in comparison to 3,317 barrels sold for the three months ended May 31, 2016.  This decrease in crude oil sales volume of 104 barrels or 3.1% was primarily due to the natural decline in reservoir pressure during the three months ended May 31, 2017.

The gravity of our produced crude oil in California ranges between 14° API and 16° API.  Production for the three months ended May 31, 2017 was from 20 wells resulting in 1,828 well days of production in comparison to 1,829 well days of production for the three months ended May 31, 2016.

Our crude oil sales revenue for the three months ended May 31, 2017 and 2016 are set forth in the following table:

*Our average realized sale price on a BOE basis for the three months ended May 31, 2017 was $41.62 in comparison to $31.70 for the three months ended May 31, 2016, representing an increase of $9.92 or 31.3% per barrel.

Operating Expenses

Total operating expenses for the three months ended May 31, 2017 were $421,133, an increase of $65,661 or 18.5% compared to $355,472 for the three months ended May 31, 2016.  The increase was due to the exploration work associated with our new Michigan exploratory joint drilling project in the amount of $77,849.  Operating expenses for the three months ended May 31, 2017 and May 31, 2016 are set forth in the table below:

Production expenses include expenses associated with the production of crude oil and natural gas.  These expenses include pumpers, electricity, road maintenance, control of well insurance, property taxes and well workover costs; and, relate directly to the number of wells that are in production.  For the three months ended May 31, 2017, these expenses increased by $6,748 or 16.5% to $47,768 in comparison to $41,020 for the three months ended May 31, 2016.  For the three months ended May 31, 2017 and May 31, 2016 we had 20 wells on production in California.  Production expense on a barrel of oil equivalent (“BOE”) basis for the three months ended May 31, 2017 and 2016 were $14.87 and $12.37, respectively.  Production expenses represented 11.4% of total operating expenses.

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.  These expenses increased $91,890 to $92,347 in comparison to $457 for the three months ended May 31, 2016.  The two primary reasons for the increase were the seismic and exploration work being done on the new Michigan exploratory joint drilling project for $77,849 and the P&A operations on two non-producing well bores in California for $14,492 representing $92,340 in aggregate.  Exploration and drilling expenses represented 21.9% of total operating expenses.

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DD&A expenses relate to equipment, proven reserves and property costs, along with impairment, and is another component of operating expenses.  For the three months ended May 31, 2017, DD&A expenses decreased $1,506 or 5.5% to $25,719 in comparison to $27,225 for the three months ended May 31, 2016.  On a BOE basis DD&A represented $8.01 and $8.21 for the three months ended May 31, 2017 and 2016, respectively.  DD&A and impairment expenses represented 6.1% of total operating expenses.

G&A expenses include the salaries of our six employees, including management.  Other items included in our G&A expenses are legal and accounting expenses, director fees, stock compensation, investor relations fees, travel expenses, insurance, Sarbanes-Oxley (“SOX”) compliance expenses and other administrative expenses necessary for an operator of crude oil and natural gas properties as well as for running a public company.  For the three months ended May 31, 2017, these expenses decreased $31,471 or 11.0% to $255,299 in comparison to $286,770 for the three months ended May 31, 2016.  For the three months ended May 31, 2017, we received, as Operator, administrative overhead reimbursement of $13,322 for the East Slopes Project which was used to directly offset certain employee salaries.  We are continuing a program of reducing all of our G&A costs wherever possible.  G&A expenses represented 60.6% of total operating expenses for the three months ended May 31, 2017.

Interest income for the three months ended May 31, 2017 was $14 in comparison to $22 for the three months ended May 31, 2016.

Interest expense for the three months ended May 31, 2017 decreased $378,798 or 44.1% to $479,893 in comparison to $858,691 for the three months ended May 31, 2016.  The decrease in interest expense was due to a lower loan balance on our credit facility with Maximilian since the proceeds from the Kentucky project sale were used to pay-down a portion of the loan balance.  Refer to the discussion below under the caption Current debt (Short-term borrowings) for more information on the Maximilian loan.

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.  Revenue 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 ongoing 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 Michigan and the availability of capital resource financing.  Since June 2014, there has been a significant decline in the WTI price of crude oil and consequently in the realized price we receive from crude oil sales in California.  This decline in the price of crude oil has had a substantial negative impact on our cash flow, financial statements and our ability to implement an aggressive drilling program in California.

In the current fiscal year we plan to spend approximately $75,000 in capital investments in California and $300,000 in Michigan; however our actual expenditures may vary significantly from this estimate if our plans for exploration and development activities change during the year or if we are not able to obtain financing to fund these capital investments.  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 May 31, 2017 in comparison with February 28, 2017 are set forth in the table below:

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Our working capital deficit increased approximately $685,120 or 5.2% to $13,838,048 at May 31, 2017 in comparison to $13,152,928 at February 28, 2017.  The increase in our working capital deficit was due to an increase in accounts payable and accrued interest as well as our borrowings under the Maximilian credit facility and for the Michigan exploratory joint drilling project.

While we have ongoing positive cash flow from our crude oil operations in California, we have not yet been able to generate sufficient cash flow to cover all of our G&A and interest expense requirements.  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.  While we have achieved positive cash flow from operations in California, 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 and natural gas 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 decline in crude oil prices since June of 2014, may restrict our ability to obtain needed capital.  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 three months ended May 31, 2017 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 and natural gas exploration industry and as of three months ended May 31, 2017 have an accumulated deficit of $36,646,757 and a working capital deficit of $13,838,048 which raises substantial doubt about our ability to continue as a going concern.

In the current fiscal year, we will continue to seek additional financing for our planned exploration and development activities in California and Michigan.  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 three months ended May 31, 2017, we received crude oil sales revenue from 20 wells in California.  Our commitment to improving corporate profitability remains unchanged.  During the three months ended May 31, 2017, we had an operating loss of $287,409 in comparison to an operating loss of $250,326 for the three months ended May 31, 2016.  An increase of $9.92 per barrel BOE in our average realized price of crude oil for the three months ended May 31, 2017 resulted in a revenue increase of $28,578 or 27.2% in comparison to the three months ended May 31, 2016.

Our balance sheet at May 31, 2017 reflects total assets of approximately $1.2 million in comparison to approximately $1.3 million at February 28, 2017.  This decrease is primarily due to a $50,000 reclass of unproved properties to exploration expenses in Michigan, plus DD&A and a revision in recognition of our asset retirement obligation in California.

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At May 31, 2017, total liabilities were approximately $14.8 million in comparison to approximately $14.1 million at February 28, 2017.  The increase in liabilities was due to increases in payables, accrued interest and our credit facility balance with Maximilian.

For the three months ended May 31, 2017, there were 44,991 shares of common stock issued as a result of the conversion of 14,997 shares of Series A Convertible Preferred stock.  The issued and outstanding shares of common stock at May 31, 2017 was 51,532,364.

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 and natural gas reserves and changes in the balances of non-cash accounts, receivables, payables or other non-energy property asset account balances.  For the three months ended May 31, 2017, cash flow used in operating activities was $31,239 in comparison to $10,062 provided by operating activities for the three months ended May 31, 2016.  This decrease of $41,301 in our cash flow provided from operating activities for the three months ended May 31, 2017 was primarily due to an increase in our liability account balances and a decrease in our accrued interest balance in comparison to the three months ended May 31, 2016.  Variations in cash flow from operating activities may impact our level of exploration and development expenditures.

Cash Flow Provided By Investing Activities

Cash flow from investing activities is derived from changes in oil and gas property balances and other investment activities.  Cash flow provided by investing activities for the three months ended May 31, 2017 was $-0-, in comparison to $2,350 provided by our investing activities for the three months ended May 31, 2016.

Cash Flow Provided By (Used In) Financing Activities

Cash flow from financing activities is derived from changes in long-term liability account balances, our borrowing activities or in equity account balances, excluding retained earnings.  Cash flow used in financing activities for the three months ended May 31, 2017 was $29,059 an increase of $35,146 in comparison to the $6,087 used in financing activities in the three months ended May 31, 2016.  For the three months ended May 31, 2017, we received advances on the Maximilian credit facility and our Michigan exploratory joint drilling project of $45,650 in aggregate.  Refer to the caption “Current debt – Maximilian Loan Agreement for further discussion of the Maximilian loan.

The following discussion is a summary of cash flows provided by or used in our financing activities at May 31, 2017.

Related Party

At May 31, 2017 and February 28, 2017, the Company had a loan balance of $250,100 with the Company’s Chairman, President and Chief Executive Officer which were obtained during the years ended February 29, 2012 and February 28, 2013, that was used for a variety of corporate purposes including an escrow requirement on a loan commitment; maturity extension fees on third party loans; and a reduction of principal on the Company’s credit line with UBS Bank.  These loans are non-interest bearing loans and repayment will be made upon a mutually agreeable date in the future.

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Line of Credit

The Company has 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 is secured by the personal guarantee of its Chairman, President and Chief Executive Officer.  At May 31, 2017 and February 28, 2017, the Line of Credit had an outstanding balance of $811,681 and $817,622, respectively.  Interest is payable monthly at a stated reference rate of 0.249% + 337.5 basis points and was $9,059 and $8,913, respectively for the three months ended May 31, 2017 and 2016.  The reference rate is based on the 30 day LIBOR (“London Interbank Offered Rate”) and is subject to change from UBS.

Maximilian Loan Agreement (Credit Facility)

On October 31, 2012, the Company entered into a loan agreement with Maximilian Resources LLC, a Delaware limited liability company and successor by assignment to Maximilian Investors LLC (either party, as appropriate, is referred to in this Quarterly Report on Form 10-Q as “Maximilian”), which provided for a revolving credit facility of up to $20 million, that matured on October 31, 2016, with a minimum commitment of $2.5 million.  On October 31, 2016 through the Fourth Amendment to the Amended and Restated Loan and Security Agreement, the maturity date of the loan was changed to February 28, 2020.

Maximilian Loan - Amended and Restated Loan Agreement

In connection with the Company’s acquisition of a working interest from App Energy, LLC, a Kentucky limited liability company (“App Energy”) in the Twin Bottoms Field in Lawrence County, Kentucky, the Company amended its loan agreement with Maximilian on August 28, 2013.  The amendment increased the amount of the credit facility to $90 million and reduced the annual interest rate to 12%.  The Company evaluated the amendment of the revolving credit facility under ASC 470-50-40 and determined that the Company’s borrowing capacity under the amended loan agreement exceeded its borrowing capacity under the old loan agreement.  Consequently, the unamortized discount and deferred financing costs as of the date of amendment are being amortized over the term of the amended loan agreement.

On October 31, 2016, the Company entered into a Fourth Amendment to the Amended and Restated Loan and Security Agreement with Maximilian, which amended the Company’s loan agreement with Maximilian (the “Restructuring Agreement”).  Pursuant to the Restructuring Agreement, in exchange for the proceeds it received from the Kentucky Sale, Maximilian and the Company have agreed to a commitment by Maximilian to advance up to $250,000 in financing to the Company over the next six months and the pursuit of the Michigan exploratory joint drilling project using the $250,000 set aside from the Kentucky Sale.  The Company recognized a gain on debt settlement in aggregate of approximately $3.9 million through the sale of the Kentucky property and reduction in the outstanding credit facility balance.

As a result of the decline in hydrocarbon prices that started in June of 2014, the Company has been unable to make any type of interest or principal payments required under the amended terms of its credit facility with Maximilian since December of 2015.  Under the terms of the Restructuring Amendment all unpaid interest is currently being accrued.  A series of waivers have been granted by Maximilian for the principal and interest payments that have not been made.  Due to the waivers granted by Maximilian, the Company is currently not considered to be in default under terms of the credit facility.  Maximilian is continuing to work with the Company in restructuring the credit facility terms during this period of lower hydrocarbon prices, but there can be no assurances that this cooperation will continue.  Further, our lender is under no obligation to advance us any additional funding and, rather, there can be no assurances that out lender will not declare the Company to be in default under the credit facility.  A change of control or management of our lender, among other reasons, could also result in our loan being called due and payable.

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Maximilian Promissory Note – Michigan Exploratory Joint Drilling Project

As of May 31, 2017, the Company had received $94,650 in aggregate from multiple advances starting in the year ended February 28, 2017 from Maximilian under a separate promissory note agreement dated January 17, 2017 and amended on February 10, 2017 regarding the development of an exploratory joint drilling project in Michigan.  Advances under this agreement are subject to a 5% (five percent) per annum interest rate.  If a well that the Company elects to participate in is scheduled to be spudded on the Michigan exploratory joint drilling project on or before December 31, 2017, then the advances under the promissory note must be repaid in full upon the earlier of (a) the time that is ten days prior to the first well being spudded on the Michigan exploratory joint drilling project or (b) December 31, 2017.  If there is not a well scheduled to be spudded at the Michigan exploratory joint drilling project on or before December 31, 2017 that the Company elects to participate in, then the Company will assign to Maximilian its working interest in the Michigan exploratory joint drilling project, in full payment and satisfaction of the advances under the promissory note.  Advances under the promissory note may be prepaid at any time without penalty.  In the event of a default of any of the Company’s obligations under the promissory note, the amounts due may be called immediately due and payable at Maximilian’s option.

In accordance with the guidance found in ASC-470-10-45, the entire balance of the Maximilian loan is presented under the current liabilities section of the balance sheets.  In accordance with the guidance found in ASC 835-30 the net amount of the deferred finance costs associated with the credit facility are included with the debt discount as a reduction of the loan balance shown on the Balance Sheets as of May 31, 2017 and February 28, 2017, respectively.

Current debt balances at May 31, 2017 and February 28, 2017 are set forth in the table below:

Deferred financing costs at May 31, 2017 and February 28, 2017 relating to the original and the amended credit facility with Maximilian, are set forth in the table below:

Deferred financing costs of $136,148 and $238,598 at May 31, 2017 and February 28, 2017, respectively includes the fair value of common shares and warrants issued to Maximilian and to a third party that assisted in both the original and the amended financing transactions.  The unamortized deferred financing costs are netted against debt in the balance sheets.  Amortization expense of deferred financing costs was $102,450 and $107,524, respectively for the three months ended May 31, 2017 and 2016.

Encumbrances

The Company’s debt obligations, pursuant to the above mentioned credit facility loan agreement and promissory notes entered into by and between Maximilian and the Company are secured by a perfected first priority security interest in substantially all of the personal property of the Company, and two mortgages; one covering its leases in California and the other covering its leases in Michigan.

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Non-current debt (Long-term borrowings)

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.  There are ten noteholders, holding 980,000 warrants, who have not yet exercised their warrants.  The exercise price of the associated warrants was lowered from $0.14 to $0.07 as a part of the Note maturity extension.  The Notes principal of $565,000 is payable in full at the amended maturity date of the Notes.  The fair value of the warrant modification, as determined by the Black-Scholes option pricing model, was $29,075 and was recognized as a discount to debt and is being amortized over the extended maturity date of the Notes.  The Black-Scholes valuation encompassed the following weighted average assumptions: a risk free interest rate of 1.22%; volatility of 378.73%; and dividend yield of 0.0%.  Should the Board of Directors, on the maturity date, 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.  Amortization expense was $3,635 and $-0-, respectively at May 31, 2017 and 2016.  The unamortized debt discount at May 31, 2017 and February 28, 2017 was $24,229 and $27,864, respectively.

12% Note balances at May 31, 2017 and February 28, 2017 and February 29, 2016 are set forth in the table below:

12% Note balances – related parties at February 28, 2017 and February 29, 2016 are set forth in the table below:

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 economic downturn, may restrict our ability to obtain needed capital.

Restricted Stock and Restricted Stock Unit Plan

On April 6, 2009, the Board approved the Restricted Stock and Restricted Stock Unit Plan (the “2009 Plan”) allowing the executive officers, directors, consultants and employees of Daybreak and its affiliates to be eligible to receive restricted Common Stock and restricted Common Stock unit awards.  Subject to adjustment, the total number of shares of Daybreak Common Stock that will be available for the grant of awards under the 2009 Plan may not exceed 4,000,000 shares; provided, that, for purposes of this limitation, any stock subject to an award that is forfeited in accordance with the provisions of the 2009 Plan will again become available for issuance under the 2009 Plan.  We believe that awards of this type further align the interests of our employees and our shareholders by providing significant incentives for these employees to achieve and maintain high levels of performance.  Restricted stock and restricted stock units also enhance our ability to attract and retain the services of qualified individuals.

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At May 31, 2017, a total of 3,000,000 shares of restricted stock had been awarded and remained outstanding under the 2009 Plan, and 2,986,220 of the shares had fully vested.  A total of 1,013,780 Common Stock shares remained available at May 31, 2017 for issuance pursuant to the 2009 Plan.  A summary of the 2009 Plan issuances is set forth in the table below:

⁽¹⁾

Does not include shares that were withheld to satisfy such tax liability upon vesting of a restricted award by a Plan Participant, and subsequently returned to the 2009 Plan.

⁽²⁾

Reflects the number of common shares that were withheld pursuant to the settlement of the number of shares with a fair market value equal to such tax withholding liability, to satisfy such tax liability upon vesting of a restricted award by a Plan Participant.

For the three months ended May 31, 2017, the Company did not recognize any stock compensation expense related to the above restricted stock grants since all issuances have been fully amortized.

Management Plans to Continue as a Going Concern

We continue to implement plans to enhance Daybreak’s ability to continue as a going concern.  The Company currently has a net revenue interest in 20 producing crude oil wells in our East Slopes Project located in Kern County, California.  The revenue from these wells has created a steady and reliable source of revenue for the Company.  Our average working interest in these wells is 36.6% and the average net revenue interest is 28.4%.

We anticipate revenues will continue to increase as the Company participates in the drilling of more wells in the East Slopes Project in California and as our drilling operations begin in Michigan.  However given the current decline and instability in hydrocarbon prices, the timing of any drilling activity in California and Michigan will be dependent on a sustained improvement in hydrocarbon prices and a successful refinancing or restructuring of our credit facility.

We believe that our liquidity will improve when there is a sustained improvement in hydrocarbon prices.  Our sources of funds in the past have included the debt or equity markets and the sale of assets.  While the Company does have positive cash flow from its crude oil properties, it has not yet established a positive cash flow on a company-wide basis.  It will be necessary for the Company to obtain additional funding from the private or public debt or equity markets in the future.  However, we cannot offer any assurance that we will be successful in executing the aforementioned plans to continue as a going concern.

Our financial statements as of May 31, 2017 do not include any adjustments that might result from the inability to implement or execute Daybreak’s 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, 2017.

Off-Balance Sheet Arrangements

As of May 31, 2017, 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.

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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

Changes in Internal Control over Financial Reporting

There have not been any changes in the Company’s internal control over financial reporting during the three months ended May 31, 2017 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.

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PART II

OTHER INFORMATION

ITEM 1.  LEGAL PROCEEDINGS

None

ITEM 1A.  RISK FACTORS

In addition to the other information set forth in this report, you should carefully consider the factors discussed in Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the period ended February 28, 2017, which could materially affect our business, financial condition or future results.  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 and results of operations.

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

(a)

Recent Sales of Unregistered Securities:

On May 9, 2017, the Company issued 44,991 shares of Common Stock to an accredited investor pursuant to the terms of a Daybreak private placement offering held in July 2006, during which the accredited investor received shares of Daybreak Series A Convertible Preferred Stock, the terms of which are disclosed in the Company’s Amended and Restated Articles of Incorporation.  Each share of Series A Convertible Preferred Stock can be converted by the shareholder at any time into three shares of the Company’s Common Stock.  Pursuant to the terms of the Series A Convertible Preferred Stock, the Common Stock was issued to the accredited investor upon the conversion of 14,997 shares of Series A Convertible Preferred Stock by the accredited investor, in reliance on an exemption from registration provided by Section 3(a)(9) of the Securities Act of 1933 relating to securities exchanged by the issuer with its existing security holders exclusively where no commission or other remuneration is paid or given directly or indirectly for soliciting such exchange.

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ITEM 6.  EXHIBITS

The following Exhibits are filed as part of the report:

Exhibit

Number

Description

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SIGNATURES

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

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