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~~November 3130, 2022

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)

Washington		91-0626366
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

1414 S. Friendswood Dr., Suite 212, Friendswood, TX		77546
(Address of principal executive offices)		(Zip code)

(~~509~~281) ~~232~~996-~~7674~~4176

(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:

Title of each class

Trading Symbol(s)

Name of each exchange

on which registered

n/a

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.

Large accelerated filer ¨		Accelerated filer ¨

Non-accelerated filer þ		Smaller reporting company ☑

		Emerging growth company ¨

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

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

At ~~October~~January 2517, ~~2022~~2023 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	3
	Consolidated Balance Sheets at August 31, 2022 and February 28, 2022 (Unaudited)	3
	Consolidated Balance Sheets at November 30, 2022 and February 28, 2022 (Unaudited)	3
	Consolidated Statements of Operations for the Three and Six Months Ended August 31, 2022 and August 31, 2021 (Unaudited)	4
	Consolidated Statements of Operations for the Three and Nine Months Ended November 30, 2022 and November 30, 2021 (Unaudited)	4
	Consolidated Statements of Changes in Stockholders’ Deficit for the Three and Six Months Ended August 31, 2022 and August 31, 2021 (Unaudited)	5
	Consolidated Statements of Changes in Stockholders’ Equity (Deficit) for the Three and Nine Months Ended November 30, 2022 and November 30, 2021 (Unaudited)	5
	Consolidated Statements of Cash Flows for the Six Months Ended August 31, 2022 and August 31, 2021 (Unaudited)	6
	Consolidated Statements of Cash Flows for the Nine Months Ended November 30, 2022 and November 30, 2021 (Unaudited)	6
	NOTES TO UNAUDITED FINANCIAL STATEMENTS	7
ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	16
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	30
ITEM 4.	CONTROLS AND PROCEDURES	30
PART II - OTHER INFORMATION
ITEM 1.	LEGAL PROCEEDINGS	31
ITEM 1A.	RISK FACTORS	31
ITEM 6.	EXHIBITS	32
Signatures		33

PART I

FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DAYBREAK OIL AND GAS, INC.

Balance Sheets – Unaudited

	As of August 31, 2022			As of February 28, 2022
	As of November 30, 2022			As of February 28, 2022
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	~~412~~403,~~949~~498		$	139,573
Restricted cash		275,000			—
Accounts receivable:
Crude oil sales		~~223~~178,~~639~~679			117,727
Joint interest participants		~~305~~404,~~774~~085			85,339
Prepaid expenses and other current assets		23138,~~068~~322			74,012
Total current assets		1,~~240~~399,~~430~~584			416,651
LONG-TERM ASSETS:
Crude oil properties, successful efforts method, net
Proved properties		5,~~423~~468,~~957~~324			536,032
Unproved properties		—			—
Prepaid drilling costs		16,452			16,452
Property, plant and equipment, net		4,~~992~~204			6,569
Goodwill, crude oil and natural gas properties		1,876,264			—
Total long-term assets		7,~~321~~365,~~665~~244			559,053
Total assets	$	8,~~562~~764,~~095~~828		$	975,704
LIABILITIES AND STOCKHOLDERS’ DEFICIT
LIABILITIES AND STOCKHOLDERS’ EQUITY (DEFICIT)
CURRENT LIABILITIES:
Accounts payable and other accrued liabilities	$	2,~~005~~477,~~762~~090		$	1,649,119
Accounts payable – related parties		2322,~~307~~164			49,228
Accrued interest		~~162~~173,~~251~~928			176,229
Note payable		120,000			120,000
Note payable – related party, current, net of unamortized discount of $729 and $729, respectively		8,~~218~~277			8,100
Convertible Notes payable – related party		—			200,000
12% Notes payable		290,000			315,000
Production revenue payable - current, net of unamortized discount		~~251~~162,~~734~~991			78,877
Line of credit		—			808,182
Total current liabilities		23,~~861~~254,~~272~~450			3,404,735
LONG-TERM LIABILITIES:
Note payable – related party, net of current portion and net of unamortized discount of $8,985 and $9,350, respectively		123,222			127,360
Note payable – related party, net of current portion and net of unamortized discount of $8,804 and $9,350, respectively		121,130			127,360
Production revenue payable, net of unamortized discount and current portion		~~633~~702,~~873~~489			738,248
Asset retirement obligation		~~215~~223,~~707~~243			52,565
Total long-term liabilities		~~972~~1,~~802~~046,862			918,173
Total liabilities		34,~~834~~301,~~074~~312			4,322,908
COMMITMENTS AND CONTINGENCIES
STOCKHOLDERS’ EQUITY (DEFICIT):
Common stock – 500,000,000 shares authorized; $0.001 par value, 384,735,402 and 67,802,273 shares issued and outstanding, respectively		384,735			67,802
Additional paid-in capital		35,297,706			26,115,450
Accumulated deficit		(3031,~~954~~218,~~420~~925	)		(29,530,456	)
Total stockholders’ equity and (deficit)		4,~~728~~463,~~021~~516			(3,347,204	)
Total liabilities and stockholders’ equity and (deficit)	$	8,~~562~~764,~~095~~828		$	975,704

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

DAYBREAK OIL AND GAS, INC.

Statements of Operations – Unaudited

	For the Three Months Ended August 31,						For the Six Months Ended August 31,
	For the Three Months Ended November 30,						For the Nine Months Ended November 30,
	2022			2021			2022			2021
REVENUE:
Crude oil sales	$	~~531~~460,~~283~~165		$	~~169~~188,~~318~~792		$	~~778~~1,~~898~~239,063		$	~~316~~505,~~618~~410
Natural gas sales		95,~~748~~846			—			915,~~748~~594			—
Total crude oil and natural gas sales	$	~~541~~466,~~031~~011		$	~~169~~188,~~318~~792		$	~~788~~1,~~646~~254,657		$	~~316~~505,~~618~~410
OPERATING EXPENSES:
Production		~~298~~383,~~482~~251			5265,~~843~~788			~~359~~742,~~199~~450			99165,~~569~~357
Exploration and drilling (G&G)		~~1,170~~—			~~201~~34			1,170			~~201~~235
Depreciation, depletion, and amortization (DD&A)		~~137~~64,~~888~~382			1415,~~860~~196			~~149~~214,~~664~~046			2844,~~808~~004
Transaction (acquisition) expenses		—60,613			—			1,~~025~~086,~~541~~154			—
General and administrative		~~286~~236,~~322~~989			~~119~~161,~~163~~164			~~538~~775,~~460~~449			~~286~~447,~~788~~952
Total operating expenses		~~723~~745,~~862~~235			~~187~~242,~~067~~182			2,~~074~~819,~~034~~269			~~415~~657,~~366~~548
OPERATING LOSS		(~~182~~279,~~831~~224	)		(1753,~~749~~390	)		(1,~~285~~564,~~388~~612	)		(98152,~~748~~138	)
OTHER INCOME (EXPENSE):
Gain on asset disposal		—			—			—			9,614
Interest expense, net		(67,646	)		(54,331	)		(138,576	)		(115,597	)
Gain on SBA PPP loan forgiveness		—			72,800			—			72,800
NET LOSS		(250,477	)		(72,080	)		(1,423,964	)		(204,731	)
Interest expense, net		14,719			(62,623	)		(123,857	)		(178,220	)
Cumulative convertible preferred stock dividend requirement		—			(32,191	)		—			(64,382	)
NET LOSS		(264,505	)		(43,213	)		(1,688,469	)		(247,944	)
NET LOSS AVAILABLE TO COMMON SHAREHOLDERS	$	(250,477	)	$	(104,271	)	$	(1,423,964	)	$	(269,113	)
Cumulative convertible preferred stock dividend requirement		—			(31,841	)		—			(96,223	)
NET LOSS PER COMMON SHARE, basic and diluted	$	(0.001	)	$	(0.002	)	$	(0.006	)	$	(0.004	)
NET LOSS AVAILABLE TO COMMON SHAREHOLDERS	$	(264,505	)	$	(75,054	)	$	(1,688,469	)	$	(344,167	)
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING - Basic and diluted		384,618,402			60,491,122			239,424,109			60,491,122
NET LOSS PER COMMON SHARE, basic and diluted	$	(0.001	)	$	(0.001	)	$	(0.006	)	$	(0.006	)
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING - Basic and diluted		384,735,402			60,491,122			287,558,715			60,491,122

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

DAYBREAK OIL AND GAS, INC.

Consolidated Statements of Changes in Stockholders' Equity (Deficit)

For the Three and ~~Six~~Nine Months Ended ~~August~~November 3130, 2022 ~~August~~and 2021

	Series A Convertible										Additional			~~Additional~~
	Preferred Stock					Common Stock		~~Common Stock~~			Paid-In		Accumulated	~~Paid-In~~			~~Accumulated~~
	Shares		Amount	~~Amount~~		Shares		~~Shares~~	Amount		~~Amount~~Capital		Deficit	~~Capital~~		Total	~~Deficit~~			~~Total~~
BALANCE, FEBRUARY 28, 2022		—	$	$—	—		67,802,273		~~67,802,273~~$	67,802	$	6726,~~802~~115,450	$	$(29,530,456	~~26,115,450~~)	$	$(3,347,204	~~(29,530,456~~)	)	$	~~(3,347,204~~	)
Issuance of common stock for:
Conversion of 12% Note principal and interest		—		—	—		78,934		~~78,934~~	79		7935,441		—	~~35,441~~		35,520	—			~~35,520~~
Conversion of Convertible Note		—		—	—		27,764,706		~~27,764,706~~	27,765		27208,~~765~~235		—	~~208,235~~		236,000	—			~~236,000~~
Acquisition of oil and gas property		—		—	—		160,964,489		~~160,964,489~~	160,964		~~160~~6,~~964~~438,580		—	~~6,438,580~~		6,599,544	—			~~6,559,544~~
Sale of common stock		—		—	—		128,125,000		~~128,125,000~~	128,125		~~128~~2,~~125~~500,000		—	~~2,500,000~~		2,628,125	—			~~2,628,125~~
Net loss		—		—	—		—		—	—		—		(1,173,487	—)		(1,173,487	~~(1,173,487~~)	)		~~(1,173,487~~	)
BALANCE, MAY 31, 2022		—	$	$—	—		384,735,402		~~384,735,402~~$	384,735	$	~~384~~35,~~735~~297,706	$	$(30,703,943	~~35,297,706~~)	$	$4,978,498	~~(30,703,943~~	)	$	~~4,978,498~~
Net loss		—		—	—		—		—	—		—		(250,477	—)		(250,477	~~(250,477~~)	)		~~(250,477~~	)
BALANCE, AUGUST 31, 2022		—	$	$—	—		384,735,402		~~384,735,402~~$	384,735	$	~~384~~35,~~735~~297,706	$	$(30,954,420	~~35,297,706~~)	$	$4,728,021	~~(30,954,420~~	)	$	~~4,728,021~~
Net loss		—		—			—			—		—		(264,505	)		(264,505	)
BALANCE, NOVEMBER 30, 2022		—	$	—			384,735,402		$	384,735	$	35,297,706	$	(31,218,925	)	$	4,463,516

	Series A Convertible										Additional			~~Additional~~
	Preferred Stock					Common Stock		~~Common Stock~~			Paid-In		Accumulated	~~Paid-In~~			~~Accumulated~~
	Shares		Amount	~~Amount~~		Shares		~~Shares~~	Amount		~~Amount~~Capital		Deficit	~~Capital~~		Total	~~Deficit~~			~~Total~~
BALANCE, FEBRUARY 28, 2021		709,568	$	$710	~~710~~		60,491,122		~~60,491,122~~$	60,491	$	6024,~~491~~250,556	$	$(29,428,897	~~24,250,556~~)	$	$(5,117,140	~~(29,428,897~~)	)	$	~~(5,117,140~~	)
Recognition of warrants issued for:
Investor relations services		—		—	—		—		—	—		—1,474		—	~~1,474~~		1,474	—			~~1,474~~
Net loss		—		—	—		—		—	—		—		(132,651	—)		(132,651	~~(132,651~~)	)		~~(132,651~~	)
BALANCE, MAY 31, 2021		709,568	$	$710	~~710~~		60,491,122		~~60,491,122~~$	60,491	$	6024,~~491~~252,030	$	$(29,561,548	~~24,252,030~~)	$	$(5,248,317	~~(29,561,548~~)	)	$	~~(5,248,317~~	)
Recognition of warrants issued for:
Investor relations services		—		—	—		—		—	—		—1,474		—	~~1,474~~		1,474	—			~~1,474~~
Net loss		—		—	—		—		—	—		—		(72,080	—)		(72,080	~~(72,080~~)	)		~~(72,080~~	)
BALANCE, AUGUST 31, 2021		709,568	$	$710	~~710~~		60,491,122		~~60,491,122~~$	60,491	$	6024,~~491~~253,504	$	$(29,633,628	~~24,253,504~~)	$	$(5,318,923	~~(29,633,628~~)	)	$	~~(5,318,923~~	)
Recognition of warrants issued for:
Investor relations services		—		—			—			—		1,474		—			1,474
Net loss		—		—			—			—		—		(43,213	)		(43,213	)
BALANCE, NOVEMBER 30, 2021		709,568	$	710			60,491,122		$	60,491	$	24,254,978	$	(29,676,841	)	$	(5,360,662	)

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

	Six Months Ended
	Nine Months Ended
	August 31, 2022			August 31, 2021
	November 30, 2022			November 30, 2021
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(1,~~423~~688,~~964~~469	)	$	(~~204~~247,~~731~~944	)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Depreciation, depletion, amortization and impairment expense		~~149~~214,~~664~~046			2844,~~808~~004
Amortization of debt discount		6848,~~846~~900			5487,~~668~~554
Financing fee expense		512,500			—
Warrant issued for investor relations services		—			24,~~948~~422
Gain on forgiveness of PPP 2nd Draw loan		—			(72,800	)
Changes in assets and liabilities:
Accounts receivable – crude oil sales		(~~105~~60,~~912~~952	)		15(2,~~644~~789	)
Accounts receivable – joint interest participants		(~~220~~318,~~435~~746	)		392,~~459~~166
Prepaid expenses and other current assets		50(64,~~944~~310	)		3945,~~276~~968
Accounts payable and other accrued liabilities		~~416~~786,~~073~~976			~~(24~~120,~~292~~577	)
Accounts payable – related parties		(2527,~~921~~064	)		50(7,~~543~~332	)
Accrued interest		(132,~~978~~301	)		3958,~~006~~158
Net cash provided by (used in) operating activities		(592,183	)		41,329
Net cash (used in) provided by operating activities		(599,420	)		31,984
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to crude oil properties		—			(35,~~647~~213	)
Purchase of fixed assets		—			(9,460	)
Net cash used in investing activities		—			(1314,~~107~~673	)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from paycheck protection program (PPP) loan		—			72,800
Payments to line of credit		(808,182	)		(3045,000	)
Proceeds from sale of common stock		1,987,500			—
Insurance financing repayments		(34,375	)		(4354,~~140~~820	)
Payments on note payable – related party		(46,~~384~~598	)		(46,~~271~~427	)
Net cash (used in) provided by financing activities		1,140,559			(4,611	)
Net cash provided by (used in) financing activities		1,138,345			(33,447	)
NET INCREASE (DECREASE) IN CASH AND RESTRICTED CASH		~~548~~538,~~376~~925			23(16,~~611~~136	)
CASH AND RESTRICTED CASH AT BEGINNING OF PERIOD		139,573			33,528
CASH AND RESTRICTED CASH AT END OF PERIOD	$	~~687~~678,~~949~~498		$	5717,~~139~~392
CASH PAID FOR:
Interest	$	15,227		$	6,887
Income taxes	$	—		$	—
SUPPLEMENTAL CASH FLOW INFORMATION:
Non-cash increase to line of credit due to monthly interest	$	—		$	13,951
Common stock issued for conversion of 12% Subordinated Note	$	35,520		$	—
Common stock issued for conversion of convertible Note	$	236,000		$	—
Common stock issued for acquisition of crude oil and natural gas property	$	6,599,544		$	—
Common stock issued for financing fees	$	128,125		$	—
Goodwill from acquisition of O&G properties	$	1,876,264		$	—
ARO asset and liability increase due to acquisition of O&G properties	$	154,133		$	—


CASH PAID FOR:
Interest	$	23,891	$	10,145
Income taxes	$	—	$	—

SUPPLEMENTAL CASH FLOW INFORMATION:
Unpaid additions to crude oil and natural gas properties	$		$
Non-cash increase to line of credit due to monthly interest	$	—	$	20,679
Financing of insurance premiums	$	—	$	81,154
Common stock issued for conversion of 12% Subordinated Note	$	35,520	$	—
Common stock issued for conversion of convertible Note	$	236,000	$	—
Common stock issued for acquisition of crude oil and natural gas property	$	6,599,544	$	—
Common stock issued for financing fees	$	128,125	$	—
Goodwill from acquisition of O&G properties	$	1,876,264	$	—
ARO asset and liability increase due to acquisition of O&G properties	$	154,133	$	—

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~~nine months ended ~~August~~November 3130, 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:

The reliance on estimates of proved reserves to compute the provision for depreciation, depletion and amortization (“DD&A”) and to determine the amount of any impairment of proved properties;

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

Estimates regarding projected cash flows used in determining the production payable discount.

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~~nine months ended ~~August~~November 3130, 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~~November 3130, 2022 has an accumulated deficit of $3031.952 million and a working capital deficit of $1.685 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~~November 3130, 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~~the natural gas production in the Reabold project. The Company has no natural gas production in the East Slopes project. At ~~August~~November 3130, 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~~Crude ~~interest~~oil ~~participant~~and natural gas sales receivables balances of of $~~305~~178,~~774~~679 and $85117,~~339~~727 at ~~August~~November 3130, 2022 and February 28, 2022, ~~respectively,~~ represent ~~amounts~~crude ~~due~~oil ~~from our working interest partners in both the East Slopes~~ and ~~Reabold~~natural ~~projects.~~gas ~~There~~sales ~~were~~that nooccurred ~~allowances~~in ~~for doubtful accounts for the Company’s trade accounts receivable~~November ~~at August 31, 2022~~ and February ~~28,~~ 2022, ~~as the joint interest owners have a history of paying their obligations~~respectively.

Joint interest participant receivables balances of $404,085 and $85,339 at November 30, 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 November 30, 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~~November 3130, 2022 and February 28, 2022 are set forth in the table below.

	August 31, 2022			February 28, 2022
	November 30, 2022			February 28, 2022
Proved leasehold costs	$	115,119		$	115,119
Costs of wells and development		7,~~327~~437,~~473~~055			2,309,628
Capitalized exploratory well costs		1,341,494			1,341,494
Cost of proved crude oil properties		8,784,086			3,766,241
Accumulated depletion, depreciation, amortization and impairment		(3,~~360~~425,~~129~~344	)		(3,230,209	)
Proved crude oil properties, net	$	5,~~423~~468,~~957~~324		$	536,032
Unproved crude oil properties		—			—
Total proved and unproved crude oil properties, net	$	5,~~423~~468,~~957~~324		$	536,032

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.

Crude oil and natural gas property and equipment	$	4,694,563
Goodwill		1,876,264
Accounts payable		(263,619	)
Other liabilities		(292,336	)
Purchase price, net of closing adjustments	$	6,599,544

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~~the $6,599,544 amount, total assets acquired of $4,694,563 was deducted, and ~~total~~ liabilities acquired of $~~555~~263,~~955~~619, and liabilities paid of $292,336 were added back to arrive at the $1,876,264 amount of Goodwill recorded at November 30, 2022. The Company incurred approximately $95445,~~120~~ 529 in transaction costs directly 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.

Of the $1.5 million liability, $244,849 remains unpaid and is included in both the November 30, 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 November 30, 2022 and February 28, 2022, the balance owed this working interest partner was $65,381 and $76,268, respectively, and is included in the approximate $2.5 million and 1.65 million accounts payable balance at November 30, 2022 and February 28, 2022, respectively.

NOTE 7 — ACCOUNTS PAYABLE- RELATED PARTIES:

The ~~August~~November 3130, 2022 and February 28, 2022 accounts payable – related party balances of approximately $2322,~~307~~164 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~~nine months ended ~~August~~November 3130, ~~2022~~ 2022 and 2021, Great Earth Power was paid $913,~~716~~300 and $1020,~~675~~038, respectively. For the ~~six~~nine months ended ~~August~~November 3130, 2022 and 2021, ABPlus Net holdings was paid $58,~~760~~640 and $510,~~760~~560, respectively.

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

Note Payable

In December 2018, the Company was able to settle an 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~~ had a maturity date of January 1, 2022 and bears an interest rate of 10% rate per annum. ~~Monthly~~The note principal has not been paid and the Company is considered to be in default. There is no default interest rate associated with the note. Interest is accrued monthly and is payable on January 1st of each anniversary date ~~until maturity~~ of the note. At ~~August~~November 3130, 2022, the principal and a portion of the accrued interest had not been paid and was outstanding. The accrued interest on the Note was $4423,000 and $38,000 at ~~August~~November 3130, 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

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 nine months ended November 30, 2022, the Company made principal payments of $6,598 and amortized debt discount of $546. 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:

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

	August 31, 2022			February 28, 2022
Note payable – related party, current portion	$	8,946		$	8,829
Unamortized debt issuance expenses		(729	)		(729	)
Note payable – related party, current portion, net	$	8,218		$	8,100

~~Note~~Current portion of note payable – related party ~~long-term balances~~ balances at ~~August~~November 3130, 2022 and February 28, 2022 are set forth in the table below:

	August 31, 2022			February 28, 2022
Note payable – related party, non-current	$	132,207		$	136,710
Unamortized debt issuance expenses		(8,985	)		(9,350	)
Note payable – related party, non-current, net	$	123,222		$	127,360

	November 30, 2022			February 28, 2022
Note payable – related party, current portion	$	9,006		$	8,829
Unamortized debt issuance expenses		(729	)		(729	)
Note payable – related party, current portion, net	$	8,277		$	8,100

Note payable – related party long-term balances at November 30, 2022 and February 28, 2022 are set forth in the table below:

	November 30, 2022			February 28, 2022
Note payable – related party, non-current	$	129,934		$	136,710
Unamortized debt issuance expenses		(8,804	)		(9,350	)
Note payable – related party, non-current, net	$	121,130		$	127,360

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

Twelve month periods ending August 31,
Twelve month periods ending November 30
2023	$	89,~~946~~006
2024		9,~~186~~247
2025		9,~~433~~495
2026		9,~~686~~750
2027		910,~~945~~011
Thereafter		9391,~~957~~431
Total	$	~~141~~138,~~153~~940

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~~nine months ended ~~August~~November 3130, 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~~nine months ended ~~August~~November 3130, 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~~ 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~~ 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.11

~~12%~~The Company has informed the Note ~~balances~~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 ~~August~~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 November 30, 2022 and February 28, 2022 ~~are~~was ~~set~~$150,927 ~~forth~~and in$135,229, ~~the table below:~~respectively.

12% Note balances at November 30, 2022 and February 28, 2022 are set forth in the table below:

12% Subordinated Notes

Related Party Notes

	August 31, 2022		February 28, 2022
	November 30, 2022		February 28, 2022
12% Subordinated Notes	$	290,000	$	315,000
12% Subordinated Notes – related party		—		—
Total 12% Subordinated Note balance	$	290,000	$	315,000

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 net program balance of $~~885~~865,~~606~~480 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~~951,~~601~~417 and determined a discount of $9885,~~995~~937 as of ~~August~~November 3130, 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~~nine months ended ~~August~~November 3130, 2022 and 2021, amortization of the debt discount on these payables amounted to $6850,~~482~~063 and $5487,~~304~~008, 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:~~12

Production revenue payable balances at November 30, 2022 and February 28, 2022 are set forth in the table below:

	August 31, 2022			February 28, 2022
	November 30, 2022			February 28, 2022
Estimated payments of production revenue payable	$	~~984~~951,~~601~~417		$	941,259
Less: unamortized discount		(9885,~~994~~937	)		(124,134	)
		885,607			817,125
		865,480			817,125
Less: current portion		(~~251~~162,~~734~~991	)		(78,877	)
Net production revenue payable – long-term	$	~~633~~702,~~873~~489		$	738,248

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 former corporate office located in Spokane Valley, Washington. Additionally, we 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~~2023 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~~nine months ended ~~August~~November 3130, ~~2022~~ 2022 and 2021 was $1117,~~895~~867 and $1117,~~895~~542, 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~~November 3130, 2022 ~~and~~ and February 28, 2022, respectively.

	Common Stock Balance		Par Value
Common stock, Issued and Outstanding, February 28, 2021		60,491,122
Shares issued for Series A Preferred conversion		2,128,704	$	2,129
Shares issued for Series A accumulated dividend		1,100,000	$	1,100
Shares issued for debt conversion of accrued salaries		1,397,880	$	1,398
Shares issued for debt conversion of accrued directors fees		317,708	$	318
Shares issued for conversion of 12% Note principal and interest – related party		1,144,415	$	1,144
Shares issued for investment principal in production revenue program		1,222,444	$	1,222
Common stock, Issued and Outstanding, February 28, 2022		67,802,273
Shares issued for conversion of 12% Note principal and interest		78,934	$	79
Shares issued for conversion of convertible note		27,764,706	$	27,765
Shares issued for acquisition of crude oil and natural gas properties		160,964,489	$	160,964
Shares issued from sale of stock		128,125,000	$	128,125
Common stock, Issued and Outstanding, August 31, 2022		384,735,402
Common stock, Issued and Outstanding, November 30, 2022		384,735,402

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.13

During the nine months ended November 30, 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 that became a related party through the sale.

NOTE 11 — WARRANTS:

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.

13 As of November 30, 2022, there were 2,100,000 exercisable warrants. At November 30, 2022, both the outstanding warrants and the exercisable warrants have a weighted average exercise price of $0.01, a weighted average remaining life of 1.08 years. Both the outstanding warrants and the exercisable warrants have an intrinsic value of $65,520. For the nine months ended November 30, 2022 and 2021, the recorded amount of warrant expense was $-0- and $4,422, respectively.

AsWarrant ofactivity ~~August~~for ~~31, 2022, there were 2,100,000 exercisable warrants. At August 31, 2022, both~~ the ~~outstanding~~nine 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~~November 30, 2022 ~~and~~is ~~2021,~~set ~~the~~forth ~~recorded~~in ~~amount~~the oftable ~~warrant expense was $-0- and $1,474, respectively.~~below:

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

Warrants - Schedule of Warrant Activity

	Warrants		Weighted Average Exercise Price
Warrants outstanding, February 28, 2022		2,100,000	$	0.01
Changes during the six months ended August 31, 2022:
Changes during the nine months ended November 30, 2022:
Issued		—	$	—
Expired / cancelled / forfeited		—	$	—
Warrants outstanding, August 31, 2022		2,100,000	$	0.01
Warrants outstanding, November 30, 2022		2,100,000	$	0.01
Warrants exercisable, August 31, 2022		2,100,000	$	0.01
Warrants exercisable, November 30, 2022		2,100,000	$	0.01

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:

	August 31, 2022			February 28, 2022
	November 30, 2022			February 28, 2022
Computed at U.S. and state statutory rates	$	(~~424~~415,~~910~~033	)	$	(118,897	)
Permanent differences		2319,~~232~~527			11,157
Changes in valuation allowance		~~401~~395,~~678~~506			107,740
Total	$	—		$	—

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:

	August 31, 2022			February 28, 2022
	November 30, 2022			February 28, 2022
Deferred tax assets:
Net operating loss carryforwards	$	6,~~076~~097,~~666~~746		$	5,670,900
Crude oil properties		8356,~~606~~354			87,694
Stock based compensation		66,187			66,187
Other		27,838			27,838
Less valuation allowance		(6,~~254~~248,~~297~~125	)		(5,852,619	)
Total	$	—		$	—

At ~~August~~November 3130, 2022, the Company had estimated net operating loss (“NOL”) carryforwards for federal and state income tax purposes of approximately $20,~~364~~434,~~166~~807 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~~nine months ended ~~August~~November 3130, 2022 in the amount of approximately $1,~~359~~430,~~807~~448 will not expire and will carry over indefinitely. The valuation allowance increased approximately $~~401~~395,~~678~~506 for the ~~six~~nine months ended ~~August 31~~November 30, 2022 and increased approximately $107,740 for the year ended February 28, ~~2023~~2022, respectively. Section 382 of the Internal Revenue Code places annual limitations on the Company’s net operating loss (NOL) carryforward.

14 Tax Year 2018

Tax Year 2020

Tax Year 2021

Tax Year 2022

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~~had 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. On December 22, 2022, the Superior Court issued an order finding CEQA deficiencies, and directing the state agency to rescind its approval of the project. Reabold will appeal the Superior Court’s order. 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~~November 3130, ~~2021~~2022. 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~~nine months ended ~~August~~November 3130, 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:

Our future operating results;

Our future capital expenditures;

Our future financing;

Our expansion and growth of operations; and

Our future investments in and acquisitions of crude oil 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;

National and international pandemics such as the novel coronavirus COVID-19 outbreak;

Exposure to market risks in our financial instruments;

Fluctuations in worldwide prices and demand for crude oil;

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

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

Risks associated with crude oil exploration and development activities;

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

Technological changes and developments in the crude oil 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; in our other public filings and press releases; and discussions with Company management.

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~~nine months ended ~~August~~November 3130, ~~2022~~ 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~~nine months ended ~~August~~November 3130, ~~2021~~2022 we normally had production from 20 crude oil wells, however during this same nine month time period multiple wells had workovers done to replace the downhole pumps. 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.

East Slopes, Kern County, California Drilling Plans

We are currently in the planning and permitting process to undertake a multi-well developmental drilling program commencing in the second quarter of 2023. These plans are also dependent on a stabilization of crude oil prices. We plan to spend approximately $825,000 drilling three development wells and one water disposal well in this drilling program.

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 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 19approximately 17° API gravity. We have future plans of drilling one horizontal well on this lease and to convert ~~and~~an old well bore into a salt water disposal well (“~~SWDW~~SWD”). 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 22approximately 23° API gravity. We have future plans of drilling one additional directional well on this lease. The ~~SWDW~~SWD 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,~~A ~~another~~work over was successfully completed on a third well ~~bore~~to decrease water production and to increase oil production. This third well will be ~~worked~~put ~~over~~back ~~after~~on aproduction ~~SWDW~~once ~~permit~~the ~~has~~Sunflower ~~been~~Alliance ~~approved~~lawsuit ~~before~~is ~~putting~~settled itand ~~back~~a inSWD ~~production~~permit has been approved. The wells are producing from the Second Massive Sand from a depth of between 4,000’- 4,500’. The oil being produced is 32approximately 38° 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

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~~Nine months ended ~~August~~November 3130, 2022 compared to the ~~six~~nine months ended ~~August~~November 3130, 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~~California ~~for~~Natural ~~Silverado.~~Gas ~~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.~~Prices

~~There~~The ~~continues to be a significant amount of volatility in hydrocarbon prices and a corresponding fluctuation in our realized sale~~ price ofwe ~~crude~~receive ~~oil~~for ~~does~~natural ~~exist.~~gas Ansales ~~example~~from ~~of this volatility~~Reabold is ~~that~~based inon ~~June~~ninety-five ofpercent ~~2014~~(95%) of the ~~monthly average~~ price ofpublished ~~WTI~~in ~~oil~~Natural ~~was~~Gas ~~$105.79~~Intelligence ~~per~~(“NGI”) ~~barrel~~Gas ~~and~~Price ~~our~~Index ~~realized~~under ~~price per barrel of crude oil was~~the ~~$98.78~~column ~~while~~“Bidweek inAverages” ~~April~~for ~~2020~~“California”, ~~the~~“PG&E ~~monthly~~Citygate” ~~average~~less ~~price~~an ofamount ~~WTI~~per ~~crude~~MMBtu ~~oil~~equal ~~was~~to the ~~$16.55~~Silverado ~~and~~Path ~~our~~On ~~monthly~~System ~~realized~~As-Available ~~price~~transport ~~was $16.96 per barrel. Finally~~date, inless ~~August 2022,~~ the ~~monthly~~Silverado ~~average~~Path ~~price~~On ofSystem ~~WTI~~transmission ~~oil~~shrinkage ~~was~~rate ~~$93~~for Silverado.67 The ~~per barrel and our realized~~ price ~~per~~we ~~barrel~~receive ofgenerally ~~crude~~moves ~~oil was $92.43. This volatility~~ in ~~crude~~correlation ~~oil~~to prices ~~has~~quoted ~~continued~~on ~~throughout most of~~ the ~~fiscal~~New ~~year~~York ~~ended~~Mercantile ~~February~~Exchange ~~28,~~(NYMEX”) ~~2023.~~for ~~Any~~spot ~~downward volatility~~Henry inHub ~~the~~natural ~~price~~gas ~~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~~.

AThere ~~comparison~~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. For example, in April 2020, the monthly average price of WTI crude oil was $16.55 and our monthly realized price was $16.96 per barrel. Then in May 2022, the monthly average price of WTI oil was $109.55 per barrel and our realized price per barrel of crude oil ~~sales~~was $106.56. Finally, in November 2022, our average realized price ~~for~~was $84.37 per barrel. This volatility in crude oil prices has continued throughout most of the ~~six~~fiscal ~~months~~year ended ~~August~~February 3128, ~~2022~~2023. Any downward volatility in the price of crude oil will have a prolonged and substantial ~~2021~~negative impact on our profitability and cash flow from our producing California properties. It is ~~shown~~beyond inour ~~the~~ability ~~table~~to ~~below:~~accurately predict crude oil prices over any substantial length of time.

	Six Months Ended
	August 31, 2022		August 31, 2021		Percentage Change
Average six month WTI crude oil price (Bbl)	$	104.99	$	66.80		57.2	%
Average six month realized crude oil sales price (Bbl)	$	102.97	$	64.77		59.0	%

A comparison of the average WTI crude oil price and the average realized crude oil sales price for the nine months ended November 30, 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.

	Nine Months Ended
	November 30, 2022		November 30, 2021		Percentage Change
Average nine month WTI crude oil price (Bbl)	$	98.46	$	70.34	40.0%
Average nine month realized crude oil sales price (Bbl)	$	95.69	$	67.97	40.8%

For the nine months ended November 30, 2022, the average WTI price was $98.46 and our average realized crude oil sale price was $95.69, representing a discount of $2.77 per barrel or 2.8% lower than the average WTI price. In comparison, for the nine months ended November 30, 2021, the average WTI price was $70.34 and our average realized sale price was $67.97 representing a discount of $2.37 per barrel or 3.4% lower than the average WTI price.

California Crude Oil Revenue and Production

Crude oil revenue in California for the ~~six~~nine months ended ~~August~~November 3130, 2022 increased $~~462~~733,~~579~~653 or ~~146~~145.12146.6% to $~~779~~1,~~197~~239,063 in comparison to revenue of $~~316~~505,~~618~~410 for the ~~six~~nine months ended November ~~August 31~~30, 2021. The reason for the increase was the acquisition of the Reabold California, LLC wells in central California. The average sale price of a barrel of crude oil for the ~~six~~nine months ended ~~August~~November 3130, 2022 was $~~102~~95.9769 in comparison to $6467.7797 for the ~~six~~nine months ended ~~August~~November 3130, 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 $3827.2072 or 5940.08% per barrel in the average realized price of a barrel of crude oil accounted for 40 27.48% of the increase in crude oil revenue for the ~~six~~nine months ended ~~August~~November 3130, 2022.

Our net crude oil sales volume for the ~~six~~nine months ended ~~August~~November 3130, 2022 was 713,~~567~~027 barrels of crude oil in comparison to 47,~~888~~436 barrels sold for the ~~six~~nine months ended ~~August~~November 3130, 2021. ~~This~~ This increase in crude oil sales volume of 25,~~679~~591 barrels or 5475.82% was primarily due to our acquisition of the Reabold property and its ~~producing~~ producing wells in central California. The gravity of our produced crude oil in the East Slopes project ranges between 14° API and 16° API. 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. 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~~nine months ended ~~August~~November 3130, 2022 and 2021 are set forth in the following table:

	Six Months Ended August 31, 2022							Six Months Ended August 31, 2021
	Nine Months Ended November 30, 2022						Nine Months Ended November 30, 2021
Project	Revenue		Percentage	~~Percentage~~			Revenue	~~Revenue~~		Percentage		~~Percentage~~
East Slopes Project – crude oil sales	$	~~440~~609,~~039~~924		49.2	~~56.5~~%	%	$	$505,410	~~316,618~~		100.0	%	~~100.0~~	%
Reabold Project – crude oil sales		~~338~~629,~~859~~139		50.8	~~43.5~~%	%		—	—		—		—
California Totals	$	~~778~~1,~~898~~239,063		100.0	~~100.0~~%	%	$	$505,410	~~316,618~~		100.0	%	~~100.0~~	%

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

	Six Months Ended August 31, 2022					Six Months Ended August 31, 2021
Project	Revenue		Percentage			Revenue		Percentage
Reabold Project – natural gas sales	$	9,748		100.0	%	$	—		—

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.

Our natural gas sales revenue for the nine months ended November 30, 2022 and 2021 is set forth in the following table:

Nine Months Ended

November 30, 2022

Nine Months Ended

November 30, 2021

Project

Revenue

Percentage

Revenue

Percentage

Reabold Project – natural gas sales

15,594

100.0

—

Our average realized sale price on a barrel of oil equivalent (BOE) basis of crude oil and natural gas for the nine months ended November 30, 2022 was $94.87 in comparison to $67.97 for the nine months ended November 30, 2021, representing an increase of $26.90 or 39.6% per barrel.

Operating Expenses

Total operating expenses for the ~~six~~nine months ended ~~August~~November 3130, 2022 were $2,~~074~~819,~~034~~269, an increase of $12,~~658~~161,~~668~~721 or ~~399~~328.38% compared to $~~415~~657,~~366~~548 for the ~~six~~nine months ended ~~August~~November 3130, 2021. Operating expenses for the ~~six~~nine months ended ~~August~~November 3130, 2022 and 2021 are set forth in the table below:

	Six Months Ended August 31, 2022							Six Months Ended August 31, 2021
	Nine Months Ended November 30, 2022							Nine Months Ended November 30, 2021
	Expenses		Percentage			BOE Basis		Expenses		Percentage			BOE Basis
Production expenses	$	~~359~~742,~~199~~450		1726.3	%			$	99165,~~569~~357		2425.01	%
Exploration and drilling expenses		1,170		0.1	%				~~201~~235		0.0	%
Depreciation, depletion, amortization (“DD&A”)		~~149~~214,~~664~~046		7.26	%				2844,~~808~~004		6.97	%
Transaction (acquisition) expenses		1,~~025~~086,~~541~~154		4938.45	%				—		—
General and administrative (“G&A”) expenses		~~538~~775,~~460~~449		2627.05	%				~~286~~447,~~788~~952		6968.12	%
Total operating expenses	$	2,~~074~~819,~~034~~269		100.0	%	$	~~268~~211.2493	$	~~415~~657,~~366~~548		100.0	%	$	8488.9843

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~~nine months ended ~~August~~November 3130, 2022, these expenses increased by $~~259~~577,~~630~~093 or ~~260~~349.80% to $~~359~~742,~~199~~450 in comparison to $99165,~~569~~357 for the ~~six~~nine months ended ~~August~~November 3130, 2021. For the ~~six~~nine months ended ~~August~~November 3130, 2022, we had 2425 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~~nine months ended ~~August~~November 3130, 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~~nine months ended ~~August~~November 3130, 2022, was primarily due to the replacement and upgrading of pumps in seven wells of the East Slopes project for $4256,~~920~~549 and the expenses associated with salt water disposal of $~~158~~318,~~100~~052 from the Reabold project. A salt water disposal well is currently being permitted which, when put into operation ~~will~~ is expected to significantly lower operating costs of the Reabold project. Production expense on a barrel of oil equivalent (“BOE”) basis for the ~~six~~nine months ended ~~August~~November 3130, 2022 and 2021 were $4655.4681 and $2022.3724, respectively. Production expenses represented 1727.35% and 24 25.01% of total operating expenses for the ~~six~~nine months ended ~~August~~November 3130, 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~~nine months ended ~~August~~November 3130, 2022 and 2021, these expenses were $1,170 and $~~201~~235, respectively. Exploration and drilling expenses represented 0.1% and 0.0% of total operating expenses for the ~~six~~ nine months ended ~~August~~November 3130, 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~~nine months ended ~~August~~November 3130, 2022, DD&A expenses increased $~~120~~170,~~856~~042 or ~~419~~386.54% to $~~149~~214,~~664~~046 in comparison to $2844,~~808~~004 for the nine ~~six~~ months ended ~~August~~November 3130, 2021. On a BOE basis, DD&A expense was $1916.3609 and $5.8992 for the ~~six~~nine months ended ~~August~~November 3130, 2022 and 2021, respectively. DD&A expenses represented 7.26% and 6.97% of total operating expenses for the ~~six~~nine months ended ~~August~~November 3130, ~~2022~~ 2022 and 2021, respectively.

For the ~~six~~nine months ended ~~August~~November 3130, 2022, we ~~incurred~~ incurred transaction expenses of $1,~~025~~086,~~541~~154 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~~nine months ended ~~August~~November 3130, 2021, we did not incur any related expenses. Transaction expenses represented 4938.45% and 0.0% of total operating expenses for the ~~six~~nine months ended ~~August~~November 3130, 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~~General and administrative (“G&A”) expenses include the salaries of ~~Operations~~nine –employees, ~~Three~~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 nine months ended ~~August~~November 30, 2022, G&A 31expenses increased $327,497 or 73.1% to $775,449 in comparison to $447,952 for the nine months ended November 30, 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 nine months ended November 30, 2022 ~~compared~~and professional legal and accounting fees of approximately $70,000 related to the ~~three~~Reabold acquisition. We are continuing a program of controlling our G&A costs wherever possible. G&A expenses represented 27.5% and 68.2% of total operating expenses for the nine months ended ~~August~~November 3130, 2022 and 2021, respectively.

ADuring ~~comparison~~the nine months ended November 30, 2021, the Company recognized a gain on asset disposal of $9,614. The gain was the ~~average~~result ~~WTI~~of ~~crude~~an ~~oil~~insurance ~~price~~settlement ~~and~~ on the theft ~~average~~of ~~realized~~a ~~crude~~company ~~oil~~vehicle ~~sales~~that ~~price~~was ~~for~~fully depreciated. Additionally, during the ~~three~~nine months ended ~~August~~November 3130, ~~2022~~2021, ~~and~~the ~~2021~~Company isrecognized a ~~shown~~gain on debt forgiveness in the ~~table~~amount ~~below:~~of $72,800 due to notification that the SBA had approved the company’s application for loan forgiveness on a Paycheck Protection Program (PPP) 2nd Draw loan.

	Three Months Ended
	August 31, 2022		August 31, 2021		Percentage Change
Average three month WTI crude oil price (Bbl)	$	103.38	$	70.52		46.4	%
Average three month realized crude oil sales price (Bbl)	$	101.56	$	67.75		49.9	%

Interest expense, net for the nine months ended November 30, 2022 decreased $54,363 or 30.5% to $123,857 in comparison to $178,220 for the nine months ended November 30, 2021.

~~For~~Results ~~the~~of ~~three~~Operations – Three months ended ~~August 31~~November 30, 2022, ~~the~~compared ~~average WTI~~to ~~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~~November 3130, 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.

A comparison of the average WTI crude oil price and the average realized crude oil sales price for the three months ended November 30, 2022 and 2021 is shown in the table below:

	Three Months Ended
	November 30, 2022		November 30, 2021		Percentage Change
Average three month WTI crude oil price (Bbl)	$	85.39	$	77.43		10.3	%
Average three month realized crude oil sales price (Bbl)	$	85.39	$	74.12		15.2	%

For the three months ended November 30, 2022, the average WTI price was $85.39 and our average realized crude oil sale price was also $85.39. In comparison, for the three months ended November 30, 2021, the average WTI price was $77.43 and our average realized sale price was $74.12 representing a discount of $3.31 per barrel or 4.3% lower than the average WTI price.

California Crude Oil Revenue and Production

Crude oil revenue in California for the three months ended ~~August~~November 3130, 2022, increased $~~362~~271,~~264~~373 or ~~214~~143.07% to $~~531~~460,~~582~~165 in comparison to revenue of $~~169~~188,~~318~~792 for the three months ended ~~August~~November 3130, 2021. The primary reason for the increase was the acquisition of the Reabold California, LLC wells in central California. The average sale price of a barrel of crude oil for the three months ended ~~August~~November 3130, 2022 was $~~101~~85.5639 in comparison to $6774.7512 for the three months ended ~~August 31~~November 30, 2021. The increase of $3311.8127 or 4915.92% per barrel in the average realized price of a barrel of crude oil accounted for 23 120.36% of the increase in crude oil revenue for the three months ended ~~August~~November 3130, 2022.

Our net sales volume for the three months ended ~~August~~November 3130, 2022 was 5,~~234~~389 barrels of crude oil in comparison to 2,~~499~~547 barrels sold for the three months ended ~~August~~November 3130, 2021. This increase in crude oil sales volume of 2,~~735~~842 barrels or ~~109~~111.46% 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~~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. 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~~November 3130, 2022 and 2021 are set forth in the following table:

	Three Months Ended August 31, 2022							Three Months Ended August 31, 2021
	Three Months Ended November 30, 2022						Three Months Ended November 30, 2021
Project	Revenue		Percentage	~~Percentage~~			Revenue	~~Revenue~~		Percentage		~~Percentage~~
East Slopes Project – crude oil sales	$	~~192~~169,~~424~~885		36.9	~~36.2~~%	%	$	$188,792	~~169,318~~		100.0	%	~~100.0~~	%
Reabold Project – crude oil sales		~~338~~290,~~859~~280		63.1	~~63.8~~%	%		—	—		—		—
California Totals	$	~~531~~460,~~283~~165		100.0	~~100.0~~%	%	$	$188,792	~~169,318~~		100.0	%	~~100.0~~	%

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

	Three Months Ended August 31, 2022					Three Months Ended August 31, 2021
Project	Revenue		Percentage			Revenue		Percentage
Reabold Project – natural gas sales	$	9,748		100.0	%	$	—		—

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.

Our natural gas sales revenue for the three months ended November 30, 2022 and 2021 is set forth in the following table:

Three Months Ended

November 30, 2022

Three Months Ended

November 30, 2021

Project

Revenue

Percentage

Revenue

Percentage

Reabold Project – natural gas sales

5,846

100.0

—

Our average realized sale price on a barrel of oil equivalent (BOE) basis of crude oil and natural gas for the three months ended November 30, 2022 was $84.72 in comparison to $74.12 for the three months ended November 30, 2021, representing an increase of $10.60 or 14.3% per barrel.

Operating Expenses

Total operating expenses for the three months ended ~~August~~November 3130, 2022 were $~~723~~745,~~862~~236, an increase of $~~536~~442,~~795~~ 304 or ~~287~~207.07% compared to $~~187~~242,~~067~~182 for the three months ended ~~August~~November 3130, 2021. Operating expenses for the three months ended ~~August~~November 3130, 2022 and 2021 are set forth in the table below:

	Three Months Ended August 31, 2022											Three Months Ended August 31, 2021
	Three Months Ended November 30, 2022									Three Months Ended November 30, 2021
	Expenses		Percentage	~~Percentage~~			BOE Basis	~~BOE Basis~~		Expenses		~~Expenses~~	Percentage			~~Percentage~~	BOE Basis		~~BOE Basis~~
Production expenses	$	~~298~~383,~~482~~251		51.4	~~41.2~~%	%				$	65,788	$	~~52,843~~	27.2	%		~~28.3~~	%
Exploration and drilling expenses		~~1,170~~—		0.0	~~0.2~~%	%					34		~~201~~	0.0	%		~~0.1~~	%
Depreciation, depletion, amortization (“DD&A”)		~~137~~64,~~888~~382		8.6	~~19.0~~%	%					15,196		~~14,860~~	6.3	%		~~7.9~~	%
General and administrative (“G&A”) expenses		286,322			39.6	%							119,163				63.7	%
Transaction (acquisition) expenses		60,613		8.2	%						—			—
Total operating expenses	$	723,862			100.0	%		$	134.07			$	187,067				100.0	%	$	74.86
General and administrative (“G&A”) expenses		236,989		31.8	%						161,164			66.5	%
Total operating expenses	$	745,235		100.0	%		$	135.47		$	242,182			100.0	%		$	95.09

Production expenses for the three months ended ~~August~~November 3130, 2022, increased by $~~245~~317,~~639~~463 or ~~464~~482.86% to $~~298~~383,~~482~~251 in comparison to $5265,~~843~~788 for the three months ended ~~August~~November 3130, 2021. For the three months ended ~~August~~November 3130, 2022 and 2021, we had 1920 and 20 wells, respectively, on production in our East Slopes project. For the three ~~months~~ months ended ~~August~~November 3130, 2022, we had ~~four~~five wells on production in the Reabold project that we acquired in May 2022. The increase in production expenses for the three months ended ~~August~~November 3130, 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~~November 3130, 2022 and 2021 were $5569.28 67 and $2125.1583, respectively. Production expenses represented 4151.24% and 2827.32% of total operating expenses for the three months ended ~~August~~ 31November 30, 2022 and 2021, respectively.

Exploration and drilling expenses for the three months ended ~~August~~November 3130, 2022 were $~~1,170~~-0- in comparison to $~~201~~34 for the three months ended ~~August~~November 3130, 2021. Exploration and drilling expenses represented 0.10% and 0.10% of total operating expenses for the three months ended ~~August 31~~November 30, 2022 and 2021, respectively.

DD&A expenses for the three months ended ~~August~~November 3130, 2022, increased $~~123~~49,~~028~~186 or ~~827~~323.97% to $~~137~~64,~~888~~382 in comparison to $1415,~~860~~196 for the three months ended ~~August~~November 3130, 2021. DD&A on a BOE basis was $2511.5470 and $5.95 97 for the three months ended ~~August~~November 3130, 2022 and 2021, respectively. DD&A expenses represented 19 8.06% and 76.93% of total operating expenses for the three months ended ~~August~~November 3130, 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~~November 3130, 2022, increased $~~167~~75,~~159~~ 825 or ~~140~~47.30% to $~~286~~236,~~322~~989 in comparison to $~~119~~161,~~163~~164 for the three months ended ~~August~~November 3130, 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 3931.68% and 6366.75% of total operating expenses for the three months ended November ~~August 31~~30, 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.

Interest expense, net for the three months ended November 30, 2022 decreased $77,342 to $14,719 due to an adjustment from prior periods in comparison to ($62,623) for the three months ended November 30, 2021.

Capital Resources and Liquidity

Our primary financial resource is our proven ~~crude~~ 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. AsFor an example, in ~~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,~~Then in 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 ~~in August~~November, 2022, our average realized price was $9284.3637 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.

WeEast ~~plan~~Slopes, toKern ~~spend approximately $435~~County,~~000~~ ~~drilling~~California ~~three development~~Drilling 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.Plans

~~Changes~~We inare ~~our~~currently ~~capital~~in ~~resources~~the atplanning ~~August~~and ~~31,~~permitting ~~2022~~process to undertake a multi-well developmental drilling program commencing in ~~comparison~~the second quarter of 2023. These plans are also dependent on a stabilization of crude oil prices. We plan to ~~February~~spend 28approximately $825,000 ~~2022~~drilling ~~are~~three ~~set~~development ~~forth~~wells and one water disposal well in ~~the~~this ~~table~~drilling ~~below:~~program.

	August 31, 2022			February 28, 2022			Increase (Decrease)			Percentage Change
Cash	$	412,949		$	139,573		$	273,376			195.9	%
Restricted Cash	$	275,000		$	—		$	275,000			100.0	%
Current assets	$	1,240,430		$	416,651		$	823,779			197.7	%
Total assets	$	8,562,095		$	975,704		$	7,586,391			777.5	%
Current liabilities	$	(2,861,272	)	$	(3,404,735	)	$	(543,463	)		(16.0	%)
Total liabilities	$	(3,834,074	)	$	(4,322,908	)	$	(488,834	)		(11.3	%)
Working capital	$	(1,620,842	)	$	(2,988,084	)	$	(1,367,242	)		(45.8	%)

Changes in our capital resources at November 30, 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.

	November 30, 2022			February 28, 2022			Increase (Decrease)			Percentage Change
Cash	$	403,498		$	139,573		$	263,925			189.1	%
Restricted Cash	$	275,000		$	—		$	275,000			100.0	%
Current assets	$	1,399,584		$	416,651		$	982,933			235.9	%
Total assets	$	8,764,828		$	975,704		$	7,789,124			798.3	%
Current liabilities	$	(3,254,450	)	$	(3,404,735	)	$	(150,285	)		(4.4	%)
Total liabilities	$	(4,301,312	)	$	(4,322,908	)	$	(21,596	)		(0.5	%)
Working capital deficit	$	(1,854,866	)	$	(2,988,084	)	$	(1,133,218	)		(37.9	%)

Our working capital deficit decreased approximately $1.13 million or 37.9% to approximately $1.85 million at November 30, 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 and the acquisition of the Reabold California, LLC current assets. 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 successful 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~~Major ~~Company’s financial~~sources ~~statements~~of ~~for~~funds in the ~~six~~past ~~months~~for ~~ended~~us ~~August~~have ~~31,~~included the ~~2022~~debt ~~have~~or ~~been~~equity ~~prepared~~markets onand athe ~~going~~sale ~~concern~~of ~~basis,~~assets. ~~which~~We ~~contemplates~~anticipate ~~the~~that ~~realization of~~we ~~assets~~will ~~and~~have ~~the~~to ~~settlement~~rely ofon ~~liabilities~~these incapital ~~the~~markets ~~normal~~to ~~course~~fund offuture ~~business~~operations and growth. WeOur ~~have~~business ~~incurred~~model ~~net~~is ~~losses~~focused ~~since~~on ~~entering~~acquiring ~~the crude oil~~ exploration ~~industry~~or indevelopment ~~2005,~~properties ~~and~~ as ofwell ~~the~~as ~~six~~existing ~~months~~production. ~~ended~~Our ~~August~~ability to ~~31,~~generate ~~2022,~~future werevenues ~~have~~and anoperating ~~accumulated~~cash ~~deficit~~flow ofwill ~~$30.95~~depend ~~million and~~on asuccessful ~~working~~exploration, ~~capital~~and/or ~~deficit~~acquisition of ~~$1.6~~crude ~~million~~oil producing properties, which ~~raises~~may ~~substantial~~very ~~doubt~~likely ~~about~~require ~~our~~us ~~ability~~ to continue asto araise ~~going~~equity ~~concern~~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") and its subsequent variants that spread to countries throughout the world including the United States continue to have an uncertain negative impact on the financial and energy markets. 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 nine months ended November 30, 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 nine months ended November 30, 2022, we have an accumulated deficit of $31.2 million and a working capital deficit of $1.85 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~~nine months ended ~~August~~November 3130, ~~2021~~2022, we ~~received~~ 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~~from five producing wells in the recently acquired Reabold project. Both of these projects are located in California. Our commitment to ~~improving~~ improving corporate profitability remains unchanged. We experienced an increase in revenues of $~~472~~749,~~028~~247 or ~~149~~148.12% to $~~788~~1,~~646~~254,657 for the nine ~~six~~ months ended ~~August~~November 3130, 2022 in comparison to revenues of $~~316~~505,~~618~~410 for the ~~six~~nine months ended ~~August~~November 3130, 2021. The increase of $3726.2390 or 5739.5% in the average realized price BOE accounted for 3826.64% of the increase in crude oil revenue for the ~~six~~nine months ended ~~August 31~~November 30, 2022. The increase in sales volume BOE accounted for the remaining 6173.56% of the revenue increase. The increase in volume was primarily ~~due~~ due to the ~~four~~ producing wells that we acquired in the recently completed acquisition of Reabold California, LLC. For the ~~six~~nine months ended ~~August~~November 3130, 2022, we had an operating loss of $1,~~285~~564,~~388~~612 in comparison to an operating loss of $98152,~~748~~138 for the ~~six~~nine months ended ~~August~~November 3130, 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~~November 3130, 2022 reflects total assets of approximately $8.568 million in comparison to approximately $0.98 million at February 28, 2022. The increase of approximately $7.58 million is directly related to the acquisition of crude oil and natural gas assets in California.

At ~~August~~November 3130, 2022, total liabilities ~~were~~decreased by approximately $321,600 to approximately $4.83 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~~November 3130, 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.24

Additional paid in capital (APIC) increased approximately $9.2 million at November 30, 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:

Six Months Ended August 31, 2022

Six Months Ended August 31, 2021

Increase (Decrease)

Percentage Change

Nine Months Ended November 30, 2022

Nine Months Ended November 30, 2021

Increase (Decrease)

Percentage Change

Net cash (used in) provided by operating activities

(~~592~~599,~~183~~420

)

4131,~~329~~984

(~~633~~631,~~512~~404

)

(1,~~532~~974.91

Net cash (used in) investing activities

—

(1314,~~107~~673

)

1314,~~107~~673

~~N/A~~100.0

Net cash provided by (used in) financing activities

1,~~140~~138,~~559~~345

(433,~~611~~447

)

1,~~145~~171,~~170~~792

243,~~835~~503.64

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~~ property asset account balances. For the ~~six~~nine months ended ~~August~~November 3130, 2022, cash flow used in operating activities was $~~592~~599,~~183~~420 in comparison to cash flow provided by operating activities of $4131,~~329~~984 for the ~~six~~nine months ended ~~August~~November 3130, 2021. The increase in our cash flow used in operating activities of $631,404 for the nine months ended November 30, 2022 was primarily due to increases in our accounts receivable crude oil and natural gas sales and receivables from 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 nine month ended November 30, 2021. Variations in cash flow from operating activities may impact our level of exploration and development expenditures.

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~~nine months ended ~~August~~November 3130, 2022 was $-0- in comparison to cash flow used in our investing activities of $1314,~~107~~673 for the ~~six~~nine months ended ~~August~~November 3130, 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~~138,~~559~~345 for the ~~six~~nine months ended ~~August~~November 3130, 2022 in comparison to cash flow used in our financing activities of $433,~~611~~447 for the ~~six~~nine months ended ~~August~~November 3130, 2021. During the ~~six~~nine months ended ~~August~~November 3130, 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~~nine months ended ~~August~~November 3130, 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~~November 3130, 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~~had a maturity date of January 1, 2022, and bears an interest rate of 10% rate per annum. ~~Monthly~~The note principal has not been paid and the Company is considered to be in default. There is no default interest rate associated with the note. Interest is accrued monthly and is payable on January 1st of each anniversary date ~~until maturity~~ of the note. At ~~August~~November 3130, 2022, the note principal and a portion of the accrued interest had not been paid and was outstanding. The accrued interest on the Note was $4423,000 and $38,000 at ~~August~~November 3130, 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~~nine months ended ~~August~~November 3130, 2022, the Company made principal payments of $46,~~384~~598 and amortized debt discount of $~~364~~546. 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.

25 Current portion of note payable – related party balances at November 30, 2022 and February 28, 2022 are set forth in the table below:

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

	November 30, 2022			February 28, 2022
Note payable – related party, current portion	$	9,006		$	8,829
Unamortized debt issuance expenses		(729	)		(729	)
Note payable – related party, current portion, net	$	8,277		$	8,100

	August 31, 2022			February 28, 2022
Note payable – related party, current portion	$	8,947		$	8,829
Unamortized debt issuance expenses		(729	)		(729	)
Note payable – related party, current portion, net	$	8,218		$	8,100

Note payable – related party long-term balances at November 30, 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:

	November 30, 2022			February 28, 2022
Note payable – related party, non-current	$	129,934		$	136,710
Unamortized debt issuance expenses		(8,804	)		(9,350	)
Note payable – related party, non-current, net	$	121,130		$	127,360

	August 31, 2022			February 28, 2022
Note payable – related party, non-current	$	132,207		$	136,710
Unamortized debt issuance expenses		(8,985	)		(9,350	)
Note payable – related party, non-current, net	$	123,222		$	127,360

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

Twelve month periods ending August 31
Twelve month periods ending November 30
2023	$	89,~~946~~006
2024		9,~~186~~247
2025		9,~~433~~495
2026		9,~~686~~750
2027		910,~~945~~011
Thereafter		9391,~~957~~431
Total	$	~~141~~138,~~153~~940

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~~nine months ended ~~August~~November 3130, 2022.

12% Subordinated Notes

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~~November 3130, 2022 and February 28, 2022 was $~~142~~150,~~251~~927 and $135,229, respectively.

26 12% Note balances at November 30, 2022 and February 28, 2022 are set forth in the table below:

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

	November 30, 2022		February 28, 2022
12% Subordinated Notes	$	290,000	$	315,000
12% Subordinated Notes – related party		—		—
Total 12% Subordinated Note balance	$	290,000	$	315,000

	August 31, 2022		February 28, 2022
12% Subordinated Notes	$	290,000	$	315,000
12% Subordinated Notes – related party		—		—
Total 12% Subordinated Note balance	$	290,000	$	315,000

Line of Credit

Production Revenue Payable

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.27

~~Accordingly,~~The ~~the~~ Company ~~has~~accounted ~~estimated~~for the ~~cash~~amounts ~~flows~~received from ~~associated~~these sales in accordance with ASC 470-10-25 and 470-10-35 which require amounts recorded as debt to be amortized under the ~~production~~interest ~~revenue~~method as ~~payments~~described ofin ~~$984~~ASC 835-30,~~601~~ ~~and~~Interest ~~determined~~Method. aConsequently, ~~discount~~the net program balance of $98865,~~995~~480 has been recognized as ofa ~~August~~production ~~31,~~revenue payable. ~~2022,~~The ~~which~~Company isdetermined ~~being accounted~~an aseffective interest ~~expense~~rate ~~over~~based ~~the~~on ~~estimated~~future ~~period~~expected ~~over~~cash ~~which~~flows ~~payments~~to ~~will~~ be ~~made~~paid ~~based~~to onthe ~~expected~~holders ~~future~~of ~~revenue~~the ~~streams~~production payment interests. ~~For~~ This rate represents the ~~six~~discount ~~months~~rate ~~ended~~that ~~August~~equates ~~31,~~estimated ~~2022~~cash flows with the initial proceeds received from the sales and ~~2021,~~is ~~amortization~~used to compute the amount of interest to be recognized each period. Estimating the ~~debt~~future ~~discount~~cash onoutflows ~~these~~under ~~payables~~this ~~amounted~~agreement requires the Company to ~~$68,482~~make certain estimates and ~~$54,304,~~assumptions ~~respectively,~~about future revenues and payments and such estimates are subject to significant ~~which~~variability. ~~has~~Therefore, ~~been~~the ~~included~~estimates are likely to change which may result in future adjustments to the accretion of the interest expense and in the ~~statements~~amortized cost based carrying value of ~~operations~~the related payables.

~~Production~~Accordingly, the Company has estimated the cash flows associated with the production revenue ~~payable~~payments ~~balances~~of at$951,417 ~~August~~and 31determined a discount of $85,937 as of November 30, 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 nine months ended November 30, 2022 and ~~February~~2021, 28amortization of the debt discount on these payables amounted to $50,063 ~~2022~~and ~~are~~$87,008, respectively, ~~set~~which ~~forth~~has been included in interest expense in the ~~table~~statements ~~below:~~of operations.

	August 31, 2022			February 28, 2022
Estimated payments of production revenue payable	$	984,601		$	941,259
Less: unamortized discount		(98,994	)		(124,134	)
		885,607			817,125
Less: current portion		(251,734	)		(78,877	)
Net production revenue payable – long-term	$	633,873		$	738,248

Production revenue payable balances at November 30, 2022 and February 28, 2022 are set forth in the table below:

	November 30, 2022			February 28, 2022
Estimated payments of production revenue payable	$	981,417		$	941,259
Less: unamortized discount		(85,937	)		(124,134	)
		865,480			817,125
Less: current portion		(162,991	)		(78,877	)
Net production revenue payable – long-term	$	702,489		$	738,248

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 former corporate office located in Spokane Valley, Washington. Additionally, we 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~~nine months ended ~~August~~November 3130, ~~2022~~ 2022 and 2021 was $1117,~~895~~867 and $1117,~~745~~542, respectively.

Related Party Transactions

In California at the East Slopes Project, two of ~~the~~ 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~~nine months ended ~~August~~ 31November 30, 2022 and 2021, Great Earth Power was paid $913,~~716~~300 and $1020,~~675~~038, respectively. For the ~~six~~nine months ended ~~August~~November 3130, 2022 and 2021, ABPlus Net holdings was paid $58,~~760~~640 and $510,~~760~~560, respectively.

Capital Commitments

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~~November 3130, 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~~November 3130, 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~~November 3130, 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~~November 3130, 2022.

Changes in Internal Control over Financial Reporting

During the three months ended ~~August~~November 3130, 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:

Exhibit Number		Description
3.02(1)		Second Amended and Restated Articles of Incorporation of Daybreak Oil and Gas, Inc. dated May 20, 2022.
4.02(1)		Description of Securities.
31.1(1)		Certification of principal executive and principal financial officer as required pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1(1)		Certification of principal executive and principal financial officer as required pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS(2)		Inline XBRL Instance Document
101.SCH(2)		Inline XBRL Taxonomy Schema
101.CAL(2)		Inline XBRL Taxonomy Calculation Linkbase
101.DEF(2)		Inline XBRL Taxonomy Definition Linkbase
101.LAB(2)		Inline XBRL Taxonomy Label Linkbase
101.PRE(2)		Inline XBRL Taxonomy Presentation Linkbase
104		Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

⁽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.

DAYBREAK OIL AND GAS, INC.
By:	/s/ JAMES F. WESTMORELAND
	James F. Westmoreland, its
	President, Chief Executive Officer and interim
	principal finance and accounting officer
	(Principal Executive Officer, Principal Financial
	Officer and Principal Accounting Officer)
Date:	~~October~~January 2717, ~~2022~~2023

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