Daybreak Oil and Gas (DBRM) 10-K 15 Jun 22 2022 FY Annual report Financial data

Cover

Cover - USD ($)	12 Months Ended
	Feb. 28, 2022	Jun. 14, 2022	Aug. 31, 2021
Cover [Abstract]
Document Type	10-K
Amendment Flag	false
Document Annual Report	true
Document Transition Report	false
Document Period End Date	Feb. 28, 2022
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2022
Current Fiscal Year End Date	--02-28
Entity File Number	000-50107
Entity Registrant Name	DAYBREAK OIL AND GAS, INC.
Entity Central Index Key	0001164256
Entity Tax Identification Number	91-0626366
Entity Incorporation, State or Country Code	WA
Entity Address, Address Line One	1101 N. Argonne Road
Entity Address, Address Line Two	Suite A-211
Entity Address, City or Town	Spokane Valley
Entity Address, State or Province	WA
Entity Address, Postal Zip Code	99212
City Area Code	(509)
Local Phone Number	232-7674
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	true
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 1,810,516
Entity Common Stock, Shares Outstanding		384,735,402
Auditor Firm ID	206
Auditor Name	MaloneBailey, LLP
Auditor Location	Houston, Texas

Balance Sheets

Balance Sheets - USD ($)	Feb. 28, 2022	Feb. 28, 2021
CURRENT ASSETS:
Cash and cash equivalents	$ 139,573	$ 33,528
Accounts receivable:
Crude oil sales	117,727	108,993
Joint interest participants	85,339	79,411
Prepaid expenses and other current assets	74,012	61,307
Total current assets	416,651	283,239
OIL AND GAS PROPERTIES, successful efforts method, net
Proved properties	536,032	556,456
Unproved properties		55,978
PREPAID DRILLING COSTS	16,452	16,452
Vehicles and Equipment, net	6,569
Total long-term assets	559,053	628,886
Total assets	975,704	912,125
CURRENT LIABILITIES:
Accounts payable and other accrued liabilities	1,649,119	1,710,922
Accounts payable - related parties	49,228	988,966
Accrued interest	176,229	123,659
Note payable	120,000	120,000
Note payable - related party, current, net of unamortized discount of $729 and $728, respectively	8,100	7,870
Convertible Note payable, related party	200,000
12% Note payable	315,000	315,000
12% Note payable - related party		250,000
Line of credit	808,182	840,904
Production revenue payable, current, net of unamortized discount	78,877	111,753
Total current liabilities	3,404,735	4,469,074
LONG TERM LIABILITIES:
Note payable - related party, net of current portion and net of unamortized discount of $9,350 and $10,080, respectively	127,360	135,460
Production revenue payable, net of current portion and net of unamortized discount	738,248	1,391,669
Asset retirement obligation	52,565	33,062
Total long-term liabilities	918,173	1,560,191
Total liabilities	4,322,908	6,029,265
STOCKHOLDERS’ DEFICIT:
Preferred stock
Common stock- 200,000,000 shares authorized; $0.001 par value, 67,802,273 and 60,491,122 shares issued and outstanding, respectively	67,802	60,491
Additional paid-in capital	26,115,450	24,250,556
Accumulated deficit	(29,530,456)	(29,428,897)
Total stockholders’ deficit	(3,347,204)	(5,117,140)
Total liabilities and stockholders' deficit	975,704	912,125
Series A Convertible Preferred Stock
STOCKHOLDERS’ DEFICIT:
Preferred stock		$ 710

Balance Sheets (Parenthetical)

Balance Sheets (Parenthetical) - USD ($)	Feb. 28, 2022	Feb. 28, 2021
Unamortized discount, current	$ 729	$ 728
Unamortized discount, noncurrent	$ 9,350	$ 10,080
Preferred stock, shares authorized	10,000,000	10,000,000
Preferred stock, par value	$ 0.001	$ 0.001
Common stock, shares authorized	200,000,000	200,000,000
Common stock, par value	$ 0.001	$ 0.001
Common stock, shares issued	67,802,273	60,491,122
Common stock, shares outstanding	67,802,273	60,491,122
Series A Convertible Preferred Stock
Preferred stock, shares authorized	2,400,000	2,400,000
Preferred stock, par value	$ 0.001	$ 0.001
Preferred stock, cumulative dividend rate	6.00%	6.00%
Preferred stock, shares issued	709,568	709,568
Preferred stock, shares outstanding	709,568	709,568

Statement of Operations

Statement of Operations - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
REVENUE:
Crude oil sales	$ 680,107	$ 404,901
OPERATING EXPENSES:
Production	231,275	187,858
Exploration and drilling	56,213	83
Depreciation, depletion and amortization	49,590	60,063
General and administrative	603,808	505,704
Total operating expenses	940,886	753,708
OPERATING LOSS	(260,779)	(348,807)
OTHER INCOME (EXPENSE):
Interest expense, net	(220,085)	(237,813)
Gain on asset disposal	9,614
Gain on debt forgiveness – SBA paycheck protection program (PPP) loan	72,800	74,355
Total other expenses	(137,671)	(163,458)
NET LOSS	(398,450)	(512,265)
Cumulative convertible preferred stock dividend requirement		(127,714)
NET LOSS AVAILABLE TO COMMON SHAREHOLDERS	$ (398,450)	$ (639,979)
NET LOSS PER COMMON SHARE
Basic and diluted	$ (0.01)	$ (0.01)
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING
Basic and diluted	61,548,414	57,916,382

Statements of Changes in Stockh

Statements of Changes in Stockholders' Deficit - USD ($)	Series A Convertible Preferred Stock	Common Stock	Additional Paid-In Capital	Accumulated Deficit	Total
Beginning balance, value at Feb. 29, 2020	$ 710	$ 53,532	$ 24,223,783	$ (28,916,632)	$ (4,638,607)
Shares outstanding at Feb. 29, 2020	709,568	53,532,364
Convertible note payable – related party		$ 6,959	20,876		27,835
Convertible note payable - related party, shares		6,958,758
Investor relations services			5,897		5,897
Net Loss				(512,265)	(512,265)
Ending balance, value at Feb. 28, 2021	$ 710	$ 60,491	24,250,556	(29,428,897)	(5,117,140)
Shares outstanding at Feb. 28, 2021	709,568	60,491,122
Convertible note payable – related party
Investor relations services			4,913		4,913
Net Loss				(398,450)	(398,450)
Conversion of accrued employee salaries		$ 1,398	627,649	52,530	681,577
Conversion of accrued employee salaries, shares		1,397,880
Conversion of accrued director fees		$ 318	142,651		142,969
Conversion of accrued director fees, shares		317,708
Conversion of 12% Note principal and interest – related party		$ 1,144	513,842		514,986
Conversion of 12% Note principal and interest - related party, shares		1,144,415
Conversion of production revenue program principal – related party		$ 1,222	548,878		550,100
Conversion of production revenue program principal - related party, shares		1,222,444
Conversion of Series A preferred stock	$ (710)	$ 2,129	(1,419)
Conversion of Series A preferred stock, shares	(709,568)
Conversion of Series A preferred stock, shares		2,128,704
Conversion of Series A accumulated dividend		$ 1,100	28,380	(29,480)
Conversion of Series A accumulated dividend, shares		1,100,000			1,100,000
Debt forgiveness accrued salary - related party				53,125	$ 53,125
Debt forgiveness production revenue program interest – related party				232,170	232,170
Settlement of receivables and payables – related party				(11,454)	(11,454)
Ending balance, value at Feb. 28, 2022		$ 67,802	$ 26,115,450	$ (29,530,456)	$ (3,347,204)
Shares outstanding at Feb. 28, 2022		67,802,273

Statements of Cash Flows

Statements of Cash Flows - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$ (398,450)	$ (512,265)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Gain on forgiveness of PPP 2nd draw and 1st draw loans, respectively	(72,800)	(74,355)
Depreciation, depletion and amortization	49,590	60,063
Impairment of unproved crude oil properties	55,978	0
Amortization of debt discount	96,703	115,272
Operating lease expense in conjunction with right of use asset		5,857
Warrants issued for investor relations services	4,913	5,897
Changes in assets and liabilities:
Accounts receivable – crude oil and natural gas sales	(8,734)	(52,083)
Accounts receivable – joint interest participants	(5,928)	(41,045)
Prepaid expenses and other current assets	68,449	54,896
Accounts payable and other accrued liabilities	52,922	152,816
Accounts payable – related parties	64,153	69,078
Operating lease liability change in conjunction with right of use asset		(5,857)
Accrued interest	79,848	78,200
Net cash used in operating activities	(13,356)	(143,526)
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to crude oil and natural gas properties	(6,772)
Purchase of fixed asset (used pickup truck)	(9,460)
Net cash used in investing activities	(16,232)
CASH FLOWS FROM FINANCING ACTIVITIES:
Payments to line of credit	(60,000)	(60,000)
Proceeds from convertible note payable	200,000
Insurance financing repayments	(68,568)	(74,553)
Proceeds from note payable – related party		144,619
Payments to note payable – related party	(8,599)	(1,410)
Proceeds from SBA PPP 2nd draw loan and 1st draw loans, respectively	72,800	74,355
Net cash provided by financing activities	135,633	83,011
NET INCREASE (DECREASE) IN CASH AND  CASH EQUIVALENTS	106,045	(60,515)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	33,528	94,043
CASH AND CASH EQUIVALENTS AT END OF PERIOD	139,573	33,528
CASH PAID FOR:
Interest	14,446	15,106
Income taxes
SUPPLEMENTAL CASH FLOW INFORMATION:
ARO asset and liability increase due to changes in estimates	10,929	1,863
Unpaid additions to crude oil and natural gas properties		11,871
Non-cash addition to line of credit due to monthly interest	27,278	28,503
Financing of insurance premiums	81,154	65,088
Forgiveness of production revenue payable interest	232,170
Settlement of accrued employee salaries credited to common stock, APIC and accumulated deficit	681,577
Settlement of accrued director fees credited to common stock and APIC	142,969
Settlement of 12% Note - related party credited to common stock and APIC	514,986
Settlement of production revenue program - related party credited to additional paid in capital	550,100
Settlement of Series A accumulated dividend credited to additional paid in capital	28,380
Common stock issued for related party debt		27,835
Common stock issued for conversion of Series A preferred stock	710
Common stock issued for Series A preferred accumulated dividend	1,100
Debt forgiveness of related party accrued gross salary and employer payroll taxes	53,125
Settlement of related party receivables and payables	11,454
Reclassification of related party accounts payable to accounts payable	$ 66,719

ORGANIZATION AND BASIS OF PRESE

ORGANIZATION AND BASIS OF PRESENTATION	12 Months Ended
	Feb. 28, 2022
Accounting Policies [Abstract]
ORGANIZATION AND BASIS OF PRESENTATION	NOTE 1 — ORGANIZATION AND BASIS OF PRESENTATION 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 and production industry. On October 25, 2005, the Company’s 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 that 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 include the level of global demand for petroleum products, foreign supply of crude oil and natural gas, the establishment of and compliance with production quotas by crude oil-exporting countries, the relative strength of the U.S. dollar, weather conditions, the price and availability of alternative fuels, and overall economic conditions, both foreign and domestic, crude oil disputes between OPEC members; and national and international pandemics like the coronavirus outbreak.

GOING CONCERN

GOING CONCERN	12 Months Ended
	Feb. 28, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
GOING CONCERN	NOTE 2 — GOING CONCERN Financial Condition Daybreak’s financial statements for the twelve months ended February 28, 2022 and February 28, 2021 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. Daybreak has incurred net losses since inception and has accumulated a deficit of approximately $ 29.5 $ 3.0 Management Plans to Continue as a Going Concern Revenue The Company continues to implement plans to enhance its ability to continue as a going concern. Daybreak currently has a net revenue interest in 20 36.6 28.4 In December 2019, the 2019 novel coronavirus (“COVID-19") surfaced in Wuhan, China. The World Health Organization declared a global emergency on January 30, 2020, with respect to the outbreak and several countries, including the United States, Japan, parts of Europe and Australia have initiated travel restrictions to and from China. The impacts of the outbreak are unknown and rapidly evolving. This widespread health crisis and the governmental restrictions associated with it, have adversely affected demand for crude oil, depressed crude oil prices, and affected our ability to access capital. These factors, in turn, have had a negative impact on our operations, and financial condition as evidenced by the unprecedented decline in crude oil prices and our revenues during this same time period. On March 27, 2020, the Coronavirus Aid, Relief, and Economic Security Act commonly referred to as the CARES Act became law. One component of the CARES Act was the paycheck protection program (“PPP”) which provides small business with the resources needed to maintain their payroll and cover applicable overhead. The PPP is implemented by the Small Business Administration (“SBA”) with support from the Department of the Treasury. The Company applied for, and was accepted to participate in this program. On May 11, 2020, the Company received funding for approximately $ 74,355 72,800 Second Draw PPP loans can be used to help fund payroll costs, including benefits. Funds can also be used to pay for mortgage interest, rent and utilities over a 24 week period. On October 20, 2021, the Company entered into an Equity Exchange Agreement (the “Exchange Agreement”) by and between Daybreak, Reabold California LLC, a California limited liability company (“Reabold”), and Gaelic Resources Ltd., a private company incorporated in the Isle of Man and the 100% owner of Reabold (“Gaelic”), pursuant to which the parties propose for (i) Daybreak to acquire 100% ownership of Reabold, in exchange for (ii) Daybreak issuing 160,964,489 shares of its common stock, par value $0.001 (“Common Stock”) to Gaelic (the “Exchange Shares”), which will result in Reabold becoming a wholly-owned subsidiary of Daybreak and Gaelic becoming the owner of the Exchange Shares and a major shareholder of Daybreak (the foregoing transaction and the transactions contemplated thereby, the “Equity Exchange”). At a special meeting of shareholders held on May 20, 2022, shareholders approved the Equity Exchange Agreement between Daybreak, Reabold California, LLC (“Reabold”) and Gaelic Resources, Ltd. (“Gaelic”). As a result of this approval, on May 25, 2022, the Company proceeded with the acquisition of Reabold and its producing crude oil and natural gas properties in California. The acquisition was completed by Daybreak issuing 160,964,489 common stock shares to Gaelic, along with the customary closing terms and conditions for acquisitions of this nature. Also during the special meeting of shareholders, approval was granted to Amend and Restate the Company’s Articles of Incorporation. This would allow for the increase in the number of authorized common stock shares of the Company from 200,000,000 shares to 500,000,000 shares. The increase in common stock shares will give the Company enough authorized common stock shares to complete the transaction with Reabold and Gaelic. Also, all the Preferred stock classification was eliminated. In conjunction with the Company’s efforts to acquire Reabold, and as a condition of closing the acquisition, the Company was to secure a capital raise of $2,500,000 through the issuance of shares of the Company’s common stock. The commitment for that capital raise was executed on May 5, 2022, and subsequently 128,125,000 shares were issued. As of February 28, 2022, all of the conditions for the closing of the Exchange Agreement had not yet been met. The Company was continuing to work towards satisfying all of the Exchange Agreement conditions including having certain conditions of the Exchange Agreement approved by the Company’s shareholders. Please refer to Note 16 The Company anticipates revenue will continue to increase as the Company participates in the drilling of more wells in the East Slopes Project in California. Daybreak’s sources of funds in the past have included the debt or equity markets and the sale of assets. While the Company has experienced periodic revenue growth, which has resulted in positive cash flow from its crude oil and natural gas properties, it has not yet established a positive cash flow on a company-wide basis. It will be necessary for the Company to obtain additional funding from the private or public debt or equity markets in the future. However, the Company cannot offer any assurance that it will be successful in executing the aforementioned plans to continue as a going concern. Daybreak’s financial statements as of February 28, 2022 and February 28, 2021 do not include any adjustments that might result from the inability to implement or execute Daybreak’s plans to improve our ability to continue as a going concern.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Feb. 28, 2022
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	NOTE 3 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Cash and Cash Equivalents Cash equivalents include demand deposits with banks and all highly liquid investments with original maturities of three months or less. The Company has in the past maintained balances in financial institutions where deposits may exceed the federally insured deposit limit of $250,000. The Company has not experienced any losses from such accounts and does not believe it is exposed to any significant credit risk on cash. Accounts Receivable The Company routinely assesses the recoverability of all material trade and other receivables. The Company accrues a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of any reserve may be reasonably estimated. Actual write-offs may exceed the recorded allowance. Substantially all of the Company’s trade accounts receivable result from crude oil in California or joint interest billings to its working interest partners in California. This concentration of customers and joint interest owners may impact the Company’s overall credit risk as these entities could be affected by similar changes in economic conditions as well as other related factors. Trade accounts receivable are generally not collateralized. There were no allowances for doubtful accounts for the Company’s trade accounts receivable at February 28, 2022 and February 28, 2021. Crude Oil and Natural Gas Properties The Company uses the successful efforts method of accounting for crude oil and natural gas property acquisition, exploration, development, and production activities. Costs to acquire mineral interests in crude oil and natural gas properties, to drill and equip exploratory wells that find proved reserves, and to drill and equip development wells are capitalized as incurred. Costs to drill exploratory wells that are unsuccessful in finding proved reserves are expensed as incurred. In addition, the geological and geophysical costs, and costs of carrying and retaining unproved properties are expensed as incurred. Costs to operate and maintain wells and field equipment are expensed as incurred. Capitalized proved property acquisition costs are amortized by field using the unit-of-production method based on estimated proved reserves. Capitalized exploration well costs and development costs (plus estimated future dismantlement, surface restoration, and property abandonment costs, net of equipment salvage values) are amortized in a similar fashion (by field) based on their estimated proved developed reserves. Support equipment and other property and equipment are depreciated over their estimated useful lives. Pursuant to the provisions of Financial Accounting Standards Codification (“ASC”) Topic 360, “Property, Plant and Equipment” For the twelve months ended February 28, 2022, the Company recognized an impairment of unproved properties in Michigan and wrote down the entire $ 55,978 On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated DD&A with a resulting gain or loss recognized in income. Property and Equipment Vehicles Machinery and Equipment Fixed assets are stated at cost. Depreciation on vehicles is provided using the straight-line method over expected useful lives of three years three years Long Lived Assets The Company reviews long-lived assets and identifiable intangibles whenever events or circumstances indicate that the carrying amounts of such assets may not be fully recoverable. The Company evaluates the recoverability of long-lived assets by measuring the carrying amounts of the assets against the estimated undiscounted cash flows associated with these assets. If this evaluation indicates that the future undiscounted cash flows of certain long-lived assets are not sufficient to recover the assets' carrying value, the assets are adjusted to their fair values (based upon discounted cash flows). Fair Value of Financial Instruments The carrying value of short-term financial instruments including cash, receivables, prepaid expenses, accounts payable, and other accrued liabilities, short-term liabilities and the line of credit approximated their fair values due to the relatively short period to maturity for these instruments. The long-term notes payable approximates fair value since the related rates of interest approximate current market rates. Share Based Payments Stock awards are accounted for under FASB ASC Topic 718, “Compensation-Stock Compensation” . The Company estimates the fair value of stock purchase warrants on the grant date using the Black-Scholes option pricing model (“Black-Scholes Model”) as its method of valuation for warrant awards granted during the year. The Company’s determination of fair value of warrant awards on the date of grant using an option-pricing model is affected by the Company’s stock price, as well as assumptions regarding a number of subjective variables. These variables include, but are not limited to, the Company’s expected price volatility over the term of the awards and discount rates assumed. Earnings (Loss) per Share of Common Stock Basic earnings (loss) per share of Common Stock is calculated by dividing net earnings (loss) available to common stockholders by the weighted average number of common shares issued and outstanding during the year. Diluted earnings per share is computed based on the weighted average number of common shares outstanding, increased by dilutive Common Stock equivalents. For the years ended February 28, 2022 and February 28, 2021, Common Stock equivalents are excluded from the calculations since their effect is anti-dilutive due to the Company’s net loss. Concentration of Credit Risk Substantially all of the Company’s accounts receivable result from crude oil sales in California or joint interest billings to its working interest partners in California. This concentration of customers and joint interest owners may impact the Company’s overall credit risk as these entities could be affected by similar changes in economic conditions as well as other related factors. Customer Concentration At the Company’s East Slopes project in California we deal with only one buyer for the purchase of all crude oil production. The Company has no natural gas production in California. At February 28, 2022 and February 28, 2021, this one individual customer represented 100.0 The Company’s accounts receivable in California for crude oil sales at February 28, 2022 and February 28, 2021, respectively are set forth in the table below. Summary of Significant Accounting Policies - Schedule of Concentration of Risk, by Risk Factor Customer Concentration Risk Accounts Receivable - Crude Oil Sales February 28, 2022 February 28, 2021 Project Customer Accounts Receivable Crude Oil Sales Percentage Accounts Receivable Crude Oil Sales Percentage California – East Slopes Project (Crude oil) Plains Marketing $ 117,727 100.0 % $ 108,993 100.0 % Revenue Recognition The Company recognizes revenue under ASC 606, Revenue from Contracts with Customers Asset Retirement Obligation (“ARO”) The Company follows the provisions of FASB ASC Topic 410, “Asset Retirement and Environmental Obligations” , Suspended Well Costs The Company accounts for any suspended well costs in accordance with FASB ASC Topic 932, “Extractive Activities – Oil and Gas In addition, ASC 932 requires annual disclosure of: (1) net changes from period to period of capitalized exploratory well costs for wells that are pending the determination of proved reserves, (2) the amount of exploratory well costs that have been capitalized for a period greater than one year after the completion of drilling and (3) an aging of exploratory well costs suspended for greater than one year, designating the number of wells the aging is related to. Further, the disclosures should describe the activities undertaken to evaluate the reserves and the projects, the information still required to classify the associated reserves as proved and the estimated timing for completing the evaluation. Income Taxes The Company follows the provisions of FASB ASC Topic 740, “Income Taxes ASC 740 prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. Under ASC 740, the Company recognizes tax benefits only for tax positions that are more likely than not to be sustained upon examination by tax authorities. The amount recognized is measured as the largest amount of benefit that is greater than 50% (percent) likely to be realized upon settlement. A liability for “unrecognized tax benefits” is recorded for any tax benefits claimed in our tax returns that do not meet these recognition and measurement standards. Use of Estimates and Assumptions 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 reported amounts of revenues and expenses during the reporting periods. Actual results could differ materially from those estimates. The accounting policies most affected by management’s estimates and assumptions are as follows: · The reliance on estimates of proved reserves to compute the provision for depreciation, depletion and amortization and to determine the amount of any impairment of proved properties; · The valuation of unproved acreage and proved crude oil and natural gas properties to determine the amount of any impairment of crude oil and natural gas properties; · Judgment regarding the productive status of in-progress exploratory wells to determine the amount of any provision for abandonment; and · Estimates regarding the timing and cost of future abandonment obligations; and, · Estimates regarding projected cash flows used in determining the production payable discount. Recent Accounting Pronouncements Accounting Standards Issued and Adopted The Company does not believe that any recently issued effective pronouncements, or pronouncements issued but not yet effective, if adopted, would have a material effect on the Company’s financial statements.

ACCOUNTS RECEIVABLE

ACCOUNTS RECEIVABLE	12 Months Ended
	Feb. 28, 2022
Receivables [Abstract]
ACCOUNTS RECEIVABLE	NOTE 4 — ACCOUNTS RECEIVABLE Accounts receivable consists primarily of receivables from the sale of crude oil production by the Company and receivables from the Company’s working interest partners in crude oil projects in which the Company acts as Operator of the project. Crude oil sales receivables balances of $ 117,727 108,993 Joint interest participant receivables balances of $ 85,339 79,411 There were no allowances for doubtful accounts for the Company’s trade accounts receivable at February 28, 2022 and February 28, 2021.

CRUDE OIL PROPERTIES

CRUDE OIL PROPERTIES	12 Months Ended
	Feb. 28, 2022
Extractive Industries [Abstract]
CRUDE OIL PROPERTIES	NOTE 5 — CRUDE OIL PROPERTIES Crude oil property balances at February 28, 2022 and February 28, 2021 are set forth in the table below: Crude Oil Properties - Schedule of Crude Oil Activities February 28, 2022 February 28, 2021 Proved leasehold costs $ 115,119 $ 115,119 Unproved leasehold costs — 55,978 Costs of wells and development 2,309,628 2,291,924 Capitalized exploratory well costs 1,341,494 1,341,494 Total cost of oil and gas properties 3,766,241 3,804,515 Accumulated depletion, depreciation amortization and impairment (3,230,209 ) (3,192,081 ) Oil and gas properties, net $ 536,032 $ 612,434 For the twelve months ended February 28, 2022 and February 28, 2021, the Company recognized depletion expense of $ 38,125 56,013 55,978 0

ASSET RETIREMENT OBLIGATION (_A

ASSET RETIREMENT OBLIGATION (“ARO”)	12 Months Ended
	Feb. 28, 2022
Asset Retirement Obligation Disclosure [Abstract]
ASSET RETIREMENT OBLIGATION (“ARO”)	NOTE 6 — ASSET RETIREMENT OBLIGATION (“ARO”) The Company’s financial statements reflect the provisions of ASC 410. The ARO primarily represents the estimated present value of the amount the Company will incur to plug, abandon and remediate its producing properties at the end of their productive lives, in accordance with applicable state laws. The Company determines the ARO on its crude oil and natural gas properties by calculating the present value of estimated cash flows related to the liability. As of February 28, 2022 and February 28, 2021, ARO obligations were considered to be long-term based on the estimated timing of the anticipated cash flows. For the twelve months ended February 28, 2022 and February 28, 2021, the Company recognized accretion expense of $ 8,574 4,050 Changes in the asset retirement obligations for the twelve months ended February 28, 2022 and February 28, 2021 are set forth in the table below. Asset Retirement Obligation (“ARO”) - Schedule of Changes in the Asset Retirement Obligations February 28, 2022 February 28, 2021 Asset retirement obligation, beginning of period $ 33,062 $ 27,149 Accretion expense 8,574 4,050 Revisions to asset retirement obligation 10,929 1,863 Asset retirement obligation, end of period $ 52,565 $ 33,062

ACCOUNTS PAYABLE

ACCOUNTS PAYABLE	12 Months Ended
	Feb. 28, 2022
Payables and Accruals [Abstract]
ACCOUNTS PAYABLE	NOTE 7 — ACCOUNTS PAYABLE On March 1, 2009, the Company became the operator for the East Slopes Project located in Kern County, California. Additionally, the Company then assumed certain original defaulting partners’ approximate $ 1.5 representing a 25% working interest in the drilling and completion costs associated with the East Slopes Project four earning wells program. The Company subsequently sold the 25% working interest on June 11, 2009 244,849 1.5 76,268 88,905 52,530 135,687 301,527

ACCOUNTS PAYABLE- RELATED PARTI

ACCOUNTS PAYABLE- RELATED PARTIES	12 Months Ended
	Feb. 28, 2022
Accounts Payable- Related Parties
ACCOUNTS PAYABLE- RELATED PARTIES	NOTE 8 — ACCOUNTS PAYABLE- RELATED PARTIES The February 28, 2022 and February 28, 2021 accounts payable – related parties balances of $ 49,228 988,966 During the twelve months ended February 28, 2022, the Company worked to restructure its balance sheet through the conversion of related party debt to the Company’s common stock. Accrued employee net salaries of approximately $ 493,359 1,096,353 142,969 317,708 264,986 588,859

SHORT-TERM AND LONG-TERM BORROW

SHORT-TERM AND LONG-TERM BORROWINGS	12 Months Ended
	Feb. 28, 2022
Debt Disclosure [Abstract]
SHORT-TERM AND LONG-TERM BORROWINGS	NOTE 9 — 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 2,000,000 6,000 January 1, 2022 10 st 38,000 26,000 Note Payable – Related Party Chief Executive Officer Secured Debt On December 22, 2020, the Company entered into a Secured Promissory Note (the “ Note Noteholder Pursuant to the Note, the Noteholder loaned the Company an aggregate principal amount of $ 155,548 10,929 144,619 2.25 December 21, 2035 8,599 729 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 February 28, 2022 and February 28, 2021 are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Related Party Notes Payable February 28, 2022 February 28, 2021 Note payable – related party, current portion $ 8,829 $ 8,598 Unamortized debt issuance expenses (729 ) (728 ) Note payable – related party, current portion, net $ 8,100 $ 7,870 Note payable – related party long-term balances at February 28, 2022 and February 28, 2021 are set forth in the table below: February 28, 2022 February 28, 2021 Note payable – related party, non-current $ 136,710 $ 145,540 Unamortized debt issuance expenses (9,350 ) (10,080 ) Note payable – related party, non-current, net $ 127,360 $ 135,460 Future estimated payments on the outstanding note payable – related party are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Future Estimated Payments Twelve month periods ending February 28/29, 2023 8,829 2024 9,065 2025 9,309 2026 9,558 2027 9,815 Thereafter 98,963 Total $ 145,539 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 18 The conversion price was to be determined by one of two cases. In Case 1, the conversion price would be $0.017 and in Case 2, the conversion price would be $0.0085. The Case 1 conversion price scenario would apply if the terms of the Equity Exchange Agreement were met by a Long Stop Date of April 29, 2022. The Case 2 conversion price scenario would apply if the terms of the Equity Exchange Agreement were not met by a Long Stop Date of April 29, 2022. The terms of the Equity Exchange Agreement were not met by the Long Stop Date of April 29, 2022 and the conversion price was determined to be the $0.0085 rate. On May 5, 2022, the Company received notice from the third party of their intent to convert the note principal and interest in the amount of $ 236,000 0.0085 27,764,706 12% Subordinated Notes The Company’s 12% Subordinated Notes (“the Notes”) issued pursuant to a January 2010 private placement offering to accredited investors, resulted in $ 595,000 250,000 12 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 was extended for an additional two years to January 29, 2019. Private Placement 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. The Notes principal of $ 565,000 565,000 As a result of the Company restructuring its balance sheet through conversions of related party debt to common stock, the related party 12% Noteholder chose to convert the principal and accrued interest of their Notes to the Company’s common stock. The related party Note for $ 250,000 264,986 0.45 1,144,415 135,229 340,042 12% Note balances at February 28, 2022 and February 28, 2021 are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Subordinated Notes 12% Subordinated Notes February 28, 2022 February 28, 2021 12% Subordinated notes – third party $ 315,000 $ 315,000 12% subordinated notes – related party — 250,000 12% Subordinated notes balance $ 315,000 $ 565,000 The accrued interest at February 28, 2021 owed on the 12% Subordinated Note to the related party is presented on the Company’s Balance Sheets under the caption Accounts payable – related party Accrued interest Line of Credit Line of Credit The Company has an existing $ 890,000 secured by the personal guarantee of our President and Chief Executive Officer a new interest rate benchmark the UBS Variable Rate (UBSVR) would replace the existing 30-day LIBOR (“London Interbank Offered Rate”) benchmark. The UBSVR is comprised of the compounded 30-day average of the Secured Overnight Financing Rate (SOFR) plus a fixed spread adjustment of 0.110%. The Company’s new all-on rate will consist of the UBSVR plus its current spread over LIBOR During the twelve months ended February 28, 2022 and February 28, 2021, we did not receive any advances on the line of credit, respectively. During the twelve months ended February 28, 2022 and February 28, 2021, we made payments to the line of credit of $ 60,000 27,278 28,503 808,182 840,904 Production Revenue Payable Since December 2018, the Company has been conducting a fundraising program to fund the drilling of future wells in California and to settle some of its existing historical debt. The purchasers of production payment interests receive a production revenue payment on future wells to be drilled in California in exchange for their purchase. On August 22, 2019, the Company entered into a Note Payoff Agreement with the Company’s Chairman, President and Chief Executive Officer as payment in full of the $ 250,100 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 seventy-five percent (75%) 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%). At February 28, 2022, the Production Payment Target has not been met within the original three years and all future payments will be at the seventy-five percent (75%) rate. 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 $ 950,100 Accordingly, the Company has estimated the cash flows associated with the production revenue payments and determined a discount of $ 941,259 95,974 115,151 As a result of the Company restructuring its balance sheet through conversions of debt to common stock the related party with the production revenue interest chose to convert the original principal investment of $ 550,100 0.45 1,222,444 232,170 As of February 28, 2022 and February 28, 2021, the production revenue payment program balance was $ 400,000 950,100 Short-Term and Long-Term Borrowings - Schedule of Production Revenue Payable Balances February 28, 2022 February 28, 2021 Estimated payments of production revenue payable $ 941,259 $ 2,000,258 Less: unamortized discount (124,134 ) (496,836 ) 817,125 1,503,422 Less: current portion (78,877 ) (111,753 ) Net production revenue payable – long term $ 738,248 $ 1,391,669 Paycheck Protection Program (PPP) Loan In March 2020, the Coronavirus Aid, Relief, and Economic Security Act commonly referred to as the CARES Act became law. One component of the CARES Act was the paycheck protection program (“PPP”) which provides small business with the resources needed to maintain their payroll and cover applicable overhead. The PPP is implemented by the Small Business Administration (“SBA”) with support from the Department of the Treasury. The Company applied for, and was accepted to participate in this program. On May 11, 2020, the Company received funding for approximately $ 74,355 On March 4, 2021, the Company applied for, and was accepted to participate in the SBA PPP Second Draw program with funding pursuant to the Economic Aid Act that was passed in December, 2020. On March 15, 2021, Daybreak received funding for $ 72,800 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.

LEASES

LEASES	12 Months Ended
	Feb. 28, 2022
Leases
LEASES	NOTE 10 — LEASES The Company leases approximately 988 416 695 12 October 2021 Rent expense for the twelve months ended February 28, 2022 and February 28, 2021 was $ 23,489 23,589

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Feb. 28, 2022
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	NOTE 11 — RELATED PARTY TRANSACTIONS Chief Operating Officer The Company’s Chief Operating Officer, Bennett Anderson is fifty percent (50%) owner in Great Earth Power, a company that provides a portion of the electrical service to Daybreak for its production operations at the East Slopes Project in Bakersfield, California. Great Earth Power began providing solar powered electricity for the production operations in California in September 2020. For the twelve months ended February 28, 2022 and February 28, 2021, Mr. Anderson received approximately $ 11,507 9,000 Mr. Anderson is also a fifty percent (50%) owner in ABPlus Net Holdings, a company that provides tank rentals to Daybreak for its production operations in Kern County, California. The Company began renting tanks from ABPlus Net Holdings in November 2020. For the twelve months ended February 28, 2022 and February 28, 2021, Mr. Anderson received approximately $ 6,720 2,440

STOCKHOLDERS_ DEFICIT

STOCKHOLDERS’ DEFICIT	12 Months Ended
	Feb. 28, 2022
Equity [Abstract]
STOCKHOLDERS’ DEFICIT	NOTE 12 — STOCKHOLDERS’ DEFICIT Preferred Stock The Company is authorized to issue up to 10,000,000 0.001 preferred stock may be divided into and issued in designated series from time to time by one or more resolutions adopted by the Board of Directors. The directors in their sole discretion shall have the power to determine the relative powers, preferences, and rights of each series of preferred stock. 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 stock shares. The Company has only one class of stock and that is common stock. Series A Convertible Preferred Stock The Company has designated 2,400,000 10,000,000 0.001 1,399,765 100 The terms of the Series A Preferred are disclosed in the Company’s Amended and Restated Articles of Incorporation. Conversion of Series A Preferred to the Company’s Common Stock by the accredited investors relies upon an exemption from registration provided by Section 3(a)(9) of the Securities Act of 1933 relating to securities exchanged by the issuer with its existing security holders exclusively where no commission or other remuneration is paid or given directly or indirectly for soliciting such exchange. During the twelve months ended February 28, 2022, the Company proposed to all 56 remaining Series A shareholders, who had not previously converted to the Company’s common stock, the conversion of their Series A shares into three shares of the Company’s common stock. Included with this proposal, the Company offered to pay any accrued Series A dividend, on a pro rata basis, with 1,100,000 shares of common stock. In order for the conversion to occur and the dividend to be paid, a majority of the Series A shares had to vote to accept the conversion proposal. With a majority of 53.6%, the outstanding shares voted in favor of the conversion and dividend issuance. There were 46.4% of the outstanding shares who chose to vote no; not to vote or had their notices of the conversion vote returned to the Company as an invalid address. As a result of the affirmative vote, 709,568 2,128,704 1,100,000 2,449,979 The following is a summary of the rights and preferences of the Series A Preferred. Conversion: At February 28, 2022, there were no shares issued and outstanding that had not been converted into our Common Stock. As of February 28, 2021, there were 44 690,197 2,070,591 The conversions of Series A Preferred that have occurred since the Series A Preferred was first issued in July 2006 are set forth in the table below. Stockholders’ Deficit - Schedule of Conversions of Series A Preferred Stock Fiscal Period Shares of Series A Preferred Converted to Common Stock Shares of Common Stock Issued from Conversion Number of Accredited Investors Year Ended February 29, 2008 102,300 306,900 10 Year Ended February 28, 2009 237,000 711,000 12 Year Ended February 28, 2010 51,900 155,700 4 Year Ended February 28, 2011 102,000 306,000 4 Year Ended February 29, 2012 — — — Year Ended February 28, 2013 18,000 54,000 2 Year Ended February 28, 2014 151,000 453,000 9 Year Ended February 28, 2015 3,000 9,000 1 Year Ended February 29, 2016 10,000 30,000 1 Year Ended February 28, 2017 — — — Year Ended February 28, 2018 14,997 44,991 1 Year Ended February 28, 2019 — — — Year Ended February 29, 2020 — — — Year Ended February 28, 2021 — — — Year Ended February 28, 2022 709,568 2,128,704 56 Totals 1,399,765 4,199,295 100 Dividends: Holders of Series A Preferred shall be paid dividends, in the amount of 6% of the original purchase price per annum. Dividends may be paid in cash or Common Stock at the discretion of the Company. Dividends are cumulative from the date of the final closing of the private placement, whether or not in any dividend period or periods we have assets legally available for the payment of such dividends. Accumulations of dividends on shares of Series A Preferred do not bear interest. Dividends are payable upon declaration by the Board of Directors. During the twelve months ended February 28, 2022, all accumulated dividends of $ 2,449,979 1,100,000 Cumulative dividends earned for each twelve month period since issuance are set forth in the table below: Stockholders’ Deficit - Schedule of Preferred Stock Dividends Earned Fiscal Year Ended Shareholders at Period End Accumulated Dividends February 28, 2007 100 $ 155,311 February 29, 2008 90 242,126 February 28, 2009 78 209,973 February 28, 2010 74 189,973 February 28, 2011 70 173,707 February 29, 2012 70 163,624 February 28, 2013 68 161,906 February 28, 2014 59 151,323 February 28, 2015 58 132,634 February 29, 2016 57 130,925 February 28, 2017 57 130,415 February 28, 2018 56 128,231 February 28, 2019 56 127,714 February 29, 2020 56 128,063 February 28, 2021 56 127,714 February 28, 2022 — 96,340 $ 2,449,979 At a special meeting of shareholders on May 20, 2022 the Company’s shareholders approved the Second Amended and Restated Articles of Incorporation, which eliminates the classification of the Series A Preferred. Common Stock The Company is authorized to issue up to 200,000,000 0.001 67,802,273 60,491,122 Common Stock Balance Par Value Common stock, Issued and Outstanding, February 28, 2019 51,532,364 Share issuances during the twelve months ended February 29, 2020 2,000,000 $ 2,000 Common stock, Issued and Outstanding, February 29, 2020 53,532,364 Share issuances during the twelve months ended February 28, 2021 6,958,758 $ 6,959 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 During the twelve months ended February 28, 2022, there were 7,311,151 7,311,151 4,082,447 3,228,704 2,449,979 6,958,758 27,835 All shares of Common Stock are equal to each other with respect to voting, liquidation, dividend and other rights. Owners of shares of Common Stock are entitled to one vote for each share of Common Stock owned at any shareholders’ meeting. Holders of shares of Common Stock are entitled to receive such dividends as may be declared by the Board of Directors out of funds legally available therefore; and upon liquidation, are entitled to participate pro rata in a distribution of assets available for such a distribution to shareholders. There are no conversion, preemptive, or other subscription rights or privileges with respect to any shares of our Common Stock. Our stock does not have cumulative voting rights, which means that the holders of more than 50% of the shares voting in an election of directors may elect all of the directors if they choose to do so. In such event, the holders of the remaining shares aggregating less than 50% would not be able to elect any directors. At a special meeting of shareholders on May 20, 2022 the Company’s shareholders approved an increase in the number of authorized common stock shares to 500,000,000 200,000,000

WARRANTS

WARRANTS	12 Months Ended
	Feb. 28, 2022
Warrants
WARRANTS	NOTE 13 — WARRANTS Share Based Payment Arrangement - Non-Employee During the twelve months ended February 29, 2020 there were 2.1 17,689 three 1.68 260.23 0.0 The warrant 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 vest in equal parts over a three year period beginning on January 2, 2020 and all warrants expire on January 2, 2024. As of February 28, 2022 and February 28, 2021, there were 893,333 528,507 0.01 1.84 20,265 4,913 5,897 Warrant activity for the twelve months ended February 28, 2022 and February 28, 2021 is set forth in the table below: Warrants - Schedule of Warrant Activity Warrants Weighted Average Exercise Price Warrants outstanding, February 29, 2020 2,100,000 $ 0.01 Changes during the twelve months ended February 28,2021: Issued — Expired / Cancelled / Forfeited — Warrants outstanding, February 28. 2021 2,100,000 $ 0.01 Warrants exercisable, February 28, 2021 528,507 Changes during the twelve months ended February 28, 2022: Issued — $ Expired / Cancelled / Forfeited — Warrants outstanding, February 28, 2022 2,100,000 $ 0.01 Warrants exercisable, February 28, 2022 893,333 $ 0.01

INCOME TAXES

INCOME TAXES	12 Months Ended
	Feb. 28, 2022
Income Tax Disclosure [Abstract]
INCOME TAXES	NOTE 14 — 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 21 Reconciliation between actual tax expense (benefit) and income taxes computed by applying the U.S. federal income tax rate and state income tax rate to income from continuing operations before income taxes is as follows: Income Taxes - Schedule of Reconciliation Between Actual Tax Expense Benefit and Income Taxes Computed by Applying Income Tax Rate February 28, 2022 February 28, 2021 Computed at U.S. and state statutory rates $ (118,897 ) $ (152,860 ) Permanent differences 11,157 15,342 Changes in valuation allowance 107,740 137,518 Total $ — $ — Tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred liabilities are presented below: Income Taxes - Schedule of Deferred Tax Assets and Liabilities February 28, 2022 February 28, 2021 Deferred tax assets: Net operating loss carryforwards $ 5,670,900 $ 5,587,416 Oil and gas properties 87,694 63,438 Stock based compensation 66,187 66,187 Other 27,838 27,838 Less valuation allowance (5,852,619 ) (5,744,879 ) Total $ — $ — At February 28, 2022, the Company had a net operating loss (“NOL”) carryforwards for federal and state income tax purposes of approximately $ 19,035,827 340,749 339,299 416,898 311,241 107,740 137,518 The above estimates are based upon management’s decisions concerning certain elections that could change the relationship between net income and taxable income. Management decisions are made annually and could cause the estimates to vary significantly. The Company’s 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.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Feb. 28, 2022
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	NOTE 15 — 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 the aforementioned contingencies are not determinable at this time, management believes that any liability or loss resulting therefrom will not materially affect the financial position, results of operations or cash flows of the Company. The Company, as an owner or lessee and operator of oil and gas properties, is subject to various federal, state and local laws and regulations relating to discharge of materials into, and protection of, the environment. These laws and regulations may, among other things, impose liability on the lessee under an oil and gas lease for the cost of pollution cleanup resulting from operations and subject the lessee to liability for pollution damages. In some instances, the Company may be directed to suspend or cease operations in the affected area. The Company maintains insurance coverage that is customary in the industry, although the Company is not fully insured against all environmental risks. The Company is not aware of any environmental claims existing as of February 28, 2022. There can be no assurance, however, that current regulatory requirements will not change, or past non-compliance with environmental issues will not be discovered on the Company’s oil and gas properties.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Feb. 28, 2022
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	NOTE 16 — SUBSEQUENT EVENTS Short-term Convertible Note Payable Subsequent Event During the twelve months ended February 28, 2022, the Company executed a convertible promissory note with a third party for $200,000. On May 5, 2022, the Company received notice from the third party of their intent to convert the note principal and interest in the amount of $ 236,000 0.0085 27,764,706 Results of Special Shareholders Meeting At a special meeting of shareholders held on May 20, 2022, Daybreak shareholders approved the Equity Exchange Agreement between Daybreak, Reabold California, LLC (“Reabold”) and Gaelic Resources, Ltd. (“Gaelic”). As a result of this approval, the Company proceeded with the acquisition of Reabold and its producing crude oil and natural gas properties in California. The acquisition was completed by Daybreak issuing 160,964,489 common stock shares to Gaelic, and in accordance with the customary closing terms and conditions for acquisitions of this nature. At the same meeting shareholders adopted the Second and Amended Articles of Incorporation, including increasing the authorized number of common stock shares from 200,000,000 500,000,000 In conjunction with the Company’s efforts to acquire Reabold, and as a condition of closing the acquisition, the Company was to secure a capital raise of $2,500,000 through the issuance of shares of the Company’s common stock. That commitment for that capital raise was executed on May 5, 2022, and subsequently 128,125,000 shares were issued. Additionally, in a majority vote by shareholders a fourth person - Mr. Darren Williams, a nominee of Reabold, was added to the Board of Directors as of the date of the closing of the exchange agreement, May 25, 2022.

SUPPLEMENTARY INFORMATION FOR C

SUPPLEMENTARY INFORMATION FOR CRUDE OIL PRODUCING ACTIVITIES (UNAUDITED)	12 Months Ended
	Feb. 28, 2022
Extractive Industries [Abstract]
SUPPLEMENTARY INFORMATION FOR CRUDE OIL PRODUCING ACTIVITIES (UNAUDITED)	NOTE 17 SUPPLEMENTARY INFORMATION FOR CRUDE OIL PRODUCING ACTIVITIES (UNAUDITED) Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities Supplementary Information for Crude Oil Producing Activities - Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities As of February 28, 2022 As of February 28, 2021 Proved leasehold costs Mineral Interests $ 115,119 $ 115,119 Wells, equipment and facilities 3,651,122 3,633,418 Total Proved Properties 3,766,241 3,748,537 Unproved properties Mineral Interests — 55,978 Uncompleted wells, equipment and facilities — — Total unproved properties — 55,978 Less accumulated depreciation, depletion amortization and impairment (3,230,209 ) (3,192,081 ) Net capitalized costs $ 536,032 $ 612,434 Costs Incurred in Oil and Gas Producing Activities Supplementary Information for Crude Oil Producing Activities - Costs Incurred in Oil and Gas Producing Activities 12 Months Ended 12 Months Ended February 28, 2022 February 28, 2021 Acquisition of proved properties $ — $ — Acquisition of unproved properties — — Development costs 6,773 11,871 Exploration costs — — Total costs incurred $ 6,773 $ 11,871 Results of Operations from Oil and Gas Producing Activities Supplementary Information for Crude Oil Producing Activities - Results of Operations from Oil and Gas Producing Activities 12 Months Ended 12 Months Ended February 28, 2022 February 28, 2021 Oil and gas revenues $ 680,107 $ 404,901 Production costs (231,275 ) (187,858 ) Exploration expenses (56,213 ) (83 ) Depletion, depreciation and amortization (49,590 ) (60,063 ) Impairment of oil properties — — Result of oil and gas producing operations before income taxes 343,029 156,897 Provision for income taxes — — Results of oil and gas producing activities $ 343,029 $ 156,897 Proved Reserves The Company’s proved oil and natural gas reserves have been estimated by the certified independent engineering firm, PGH Petroleum and Environmental Engineers, LLC. Proved reserves are the estimated quantities that geologic and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved developed reserves are the quantities expected to be recovered through existing wells with existing equipment and operating methods when the estimates were made. Due to the inherent uncertainties and the limited nature of reservoir data, such estimates are subject to change as additional information becomes available. The reserves actually recovered and the timing of production of these reserves may be substantially different from the original estimate. Revisions result primarily from new information obtained from development drilling and production history; acquisitions of oil and natural gas properties; and changes in economic factors. As of February 28, 2022, our total reserves were comprised of our working interest in East Slopes Project located in Kern County, California. Our proved reserves are summarized in the table below: Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Oil and Gas Reserves Oil (Barrels) Natural Gas (Mcf) BOE (Barrels) Proved reserves: February 29, 2020 495,977 — 495,977 Revisions (1) (50,784 ) — (50,784 ) Discoveries and extensions — — — Production (10,970 ) — (10,970 ) February 28, 2021 434,223 — 434,223 Revisions (2) 3,052 — 3,052 Discoveries and extensions 89,493 — 89,493 Production (9,613 ) — (9,613 ) February 28, 2022 517,155 — 517,155 (1) The revisions of previous estimates resulted from a decrease in the estimated economic life of the reservoirs due to lowest realized crude oil prices in the energy markets. (2) The revisions of previous estimates resulted from higher realized crude oil prices in the energy markets. (3) The discoveries and extensions resulted from additional PUD located being added due to higher oil prices in the energy markets. The Company’s proved reserves are set forth in the table below. Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Developed and Undeveloped Reserves Oil Developed Undeveloped Total Reserves Oil (Bbls) BOE (Bbls) Oil (Bbls) BOE (Bbls) Oil (Bbls) BOE (Bbls) February 29, 2020 113,779 113,779 382,198 382,198 495,977 495,977 February 28, 2021 95,120 95,120 339,103 339,103 434,223 434,223 February 28, 2022 117,844 117,844 399,311 399,311 517,155 517,155 Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves The following information is based on the Company’s best estimate of the required data for the Standardized Measure of Discounted Future Net Cash Flows as of February 28, 2022 and February 28, 2021 in accordance with ASC 932, “Extractive Activities – Oil and Gas” which requires the use of a 10% discount rate. This information is not the fair market value, nor does it represent the expected present value of future cash flows of the Company’s proved oil and gas reserves. Future cash inflows for the years ended February 28, 2022 and February 28, 2021 were estimated as specified by the SEC through calculation of an average price based on the 12-month unweighted arithmetic average of the first-day-of-the-month price for the period from March through February during each respective fiscal year. The resulting net cash flow are reduced to present value by applying a 10% discount factor. Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves Supplementary Information for Crude Oil Producing Activities - Standardized Measure of Discounted Future Cash Flows Relating to Proved Oil and Gas Reserves 12 Months Ended February 28, 2022 February 28, 2021 Future cash inflows $ 35,580,251 $ 15,692,834 Future production costs (1) (16,217,379 ) (8,076,769 ) Future development costs (3,603,561 ) (2,510,625 ) Future income tax expenses (2) — — Future net cash flows 15,759,311 5,105,440 10% annual discount for estimated timing of cash flows (9,567,367 ) (3,457,022 ) Standardized measure of discounted future net cash flows at the end of the fiscal year $ 6,191,944 $ 1,648,418 (1) Production costs include crude oil and natural gas operations expense, production ad valorem taxes, transportation costs and G&A expense supporting the Company’s crude oil and natural gas operations. (2) The Company has sufficient tax deductions and allowances related to proved crude oil and natural gas reserves to offset future net revenues. Average hydrocarbon prices are set forth in the table below. Supplementary Information for Crude Oil Producing Activities - Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure Crude Oil Average Price Natural Natural Gas Crude Oil (Bbl) Gas (Mcf) Year ended February 29, 2020 (1) $ 60.25 $ — Year ended February 28, 2021 (1) $ 36.91 $ — Year ended February 28, 2022 (1) $ 70.75 $ — (1) Average prices were based on 12-month unweighted arithmetic average of the first-day-of-the-month prices for the period from March through February during each respective fiscal year. Future production and development costs, which include dismantlement and restoration expense, are computed by estimating the expenditures to be incurred in developing and producing the Company’s proved crude oil and natural gas reserves at the end of the year, based on year-end costs, and assuming continuation of existing economic conditions. Sources of Changes in Discounted Future Net Cash Flows Principal changes in the aggregate standardized measure of discounted future net cash flows attributable to the Company’s proved crude oil and natural gas reserves, as required by ASC 932, at fiscal year-end are set forth in the table below. Supplementary Information for Crude Oil Producing Activities - Schedule of Sources of Changes in Discounted Future Net Cash Flows 12 Months Ended February 28, 2022 February 28, 2021 Standardized measure of discounted future net cash flows at the beginning of the year $ 1,648,418 $ 4,652,142 Extensions, discoveries and improved recovery, less related costs 906,390 — Revisions of previous quantity estimates 44,898 (287,596 ) Net changes in prices and production costs 3,320,241 (1,899,026 ) Accretion of discount 164,842 465,214 Sales of oil produced, net of production costs (448,832 ) (217,043 ) Changes in future development costs (267,335 ) (9,077 ) Changes in timing of future production 823,322 (1,074,350 ) Net changes in income taxes — — Standardized measure of discounted future net cash flows at the end of the year $ 6,191,944 $ 1,648,418

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Feb. 28, 2022
Accounting Policies [Abstract]
Cash and Cash Equivalents	Cash and Cash Equivalents Cash equivalents include demand deposits with banks and all highly liquid investments with original maturities of three months or less. The Company has in the past maintained balances in financial institutions where deposits may exceed the federally insured deposit limit of $250,000. The Company has not experienced any losses from such accounts and does not believe it is exposed to any significant credit risk on cash.
Accounts Receivable	Accounts Receivable The Company routinely assesses the recoverability of all material trade and other receivables. The Company accrues a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of any reserve may be reasonably estimated. Actual write-offs may exceed the recorded allowance. Substantially all of the Company’s trade accounts receivable result from crude oil in California or joint interest billings to its working interest partners in California. This concentration of customers and joint interest owners may impact the Company’s overall credit risk as these entities could be affected by similar changes in economic conditions as well as other related factors. Trade accounts receivable are generally not collateralized. There were no allowances for doubtful accounts for the Company’s trade accounts receivable at February 28, 2022 and February 28, 2021.
Crude Oil and Natural Gas Properties	Crude Oil and Natural Gas Properties The Company uses the successful efforts method of accounting for crude oil and natural gas property acquisition, exploration, development, and production activities. Costs to acquire mineral interests in crude oil and natural gas properties, to drill and equip exploratory wells that find proved reserves, and to drill and equip development wells are capitalized as incurred. Costs to drill exploratory wells that are unsuccessful in finding proved reserves are expensed as incurred. In addition, the geological and geophysical costs, and costs of carrying and retaining unproved properties are expensed as incurred. Costs to operate and maintain wells and field equipment are expensed as incurred. Capitalized proved property acquisition costs are amortized by field using the unit-of-production method based on estimated proved reserves. Capitalized exploration well costs and development costs (plus estimated future dismantlement, surface restoration, and property abandonment costs, net of equipment salvage values) are amortized in a similar fashion (by field) based on their estimated proved developed reserves. Support equipment and other property and equipment are depreciated over their estimated useful lives. Pursuant to the provisions of Financial Accounting Standards Codification (“ASC”) Topic 360, “Property, Plant and Equipment” For the twelve months ended February 28, 2022, the Company recognized an impairment of unproved properties in Michigan and wrote down the entire $ 55,978 On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated DD&A with a resulting gain or loss recognized in income.
Property and Equipment	Property and Equipment Vehicles Machinery and Equipment Fixed assets are stated at cost. Depreciation on vehicles is provided using the straight-line method over expected useful lives of three years three years
Long Lived Assets	Long Lived Assets The Company reviews long-lived assets and identifiable intangibles whenever events or circumstances indicate that the carrying amounts of such assets may not be fully recoverable. The Company evaluates the recoverability of long-lived assets by measuring the carrying amounts of the assets against the estimated undiscounted cash flows associated with these assets. If this evaluation indicates that the future undiscounted cash flows of certain long-lived assets are not sufficient to recover the assets' carrying value, the assets are adjusted to their fair values (based upon discounted cash flows).
Fair Value of Financial Instruments	Fair Value of Financial Instruments The carrying value of short-term financial instruments including cash, receivables, prepaid expenses, accounts payable, and other accrued liabilities, short-term liabilities and the line of credit approximated their fair values due to the relatively short period to maturity for these instruments. The long-term notes payable approximates fair value since the related rates of interest approximate current market rates.
Share Based Payments	Share Based Payments Stock awards are accounted for under FASB ASC Topic 718, “Compensation-Stock Compensation” . The Company estimates the fair value of stock purchase warrants on the grant date using the Black-Scholes option pricing model (“Black-Scholes Model”) as its method of valuation for warrant awards granted during the year. The Company’s determination of fair value of warrant awards on the date of grant using an option-pricing model is affected by the Company’s stock price, as well as assumptions regarding a number of subjective variables. These variables include, but are not limited to, the Company’s expected price volatility over the term of the awards and discount rates assumed.
Earnings (Loss) per Share of Common Stock	Earnings (Loss) per Share of Common Stock Basic earnings (loss) per share of Common Stock is calculated by dividing net earnings (loss) available to common stockholders by the weighted average number of common shares issued and outstanding during the year. Diluted earnings per share is computed based on the weighted average number of common shares outstanding, increased by dilutive Common Stock equivalents. For the years ended February 28, 2022 and February 28, 2021, Common Stock equivalents are excluded from the calculations since their effect is anti-dilutive due to the Company’s net loss.
Concentration of Credit Risk	Concentration of Credit Risk Substantially all of the Company’s accounts receivable result from crude oil sales in California or joint interest billings to its working interest partners in California. This concentration of customers and joint interest owners may impact the Company’s overall credit risk as these entities could be affected by similar changes in economic conditions as well as other related factors. Customer Concentration At the Company’s East Slopes project in California we deal with only one buyer for the purchase of all crude oil production. The Company has no natural gas production in California. At February 28, 2022 and February 28, 2021, this one individual customer represented 100.0 The Company’s accounts receivable in California for crude oil sales at February 28, 2022 and February 28, 2021, respectively are set forth in the table below. Summary of Significant Accounting Policies - Schedule of Concentration of Risk, by Risk Factor Customer Concentration Risk Accounts Receivable - Crude Oil Sales February 28, 2022 February 28, 2021 Project Customer Accounts Receivable Crude Oil Sales Percentage Accounts Receivable Crude Oil Sales Percentage California – East Slopes Project (Crude oil) Plains Marketing $ 117,727 100.0 % $ 108,993 100.0 %
Revenue Recognition	Revenue Recognition The Company recognizes revenue under ASC 606, Revenue from Contracts with Customers
Asset Retirement Obligation (“ARO”)	Asset Retirement Obligation (“ARO”) The Company follows the provisions of FASB ASC Topic 410, “Asset Retirement and Environmental Obligations” ,
Suspended Well Costs	Suspended Well Costs The Company accounts for any suspended well costs in accordance with FASB ASC Topic 932, “Extractive Activities – Oil and Gas In addition, ASC 932 requires annual disclosure of: (1) net changes from period to period of capitalized exploratory well costs for wells that are pending the determination of proved reserves, (2) the amount of exploratory well costs that have been capitalized for a period greater than one year after the completion of drilling and (3) an aging of exploratory well costs suspended for greater than one year, designating the number of wells the aging is related to. Further, the disclosures should describe the activities undertaken to evaluate the reserves and the projects, the information still required to classify the associated reserves as proved and the estimated timing for completing the evaluation.
Income Taxes	Income Taxes The Company follows the provisions of FASB ASC Topic 740, “Income Taxes ASC 740 prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. Under ASC 740, the Company recognizes tax benefits only for tax positions that are more likely than not to be sustained upon examination by tax authorities. The amount recognized is measured as the largest amount of benefit that is greater than 50% (percent) likely to be realized upon settlement. A liability for “unrecognized tax benefits” is recorded for any tax benefits claimed in our tax returns that do not meet these recognition and measurement standards.
Use of Estimates and Assumptions	Use of Estimates and Assumptions 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 reported amounts of revenues and expenses during the reporting periods. Actual results could differ materially from those estimates. The accounting policies most affected by management’s estimates and assumptions are as follows: · The reliance on estimates of proved reserves to compute the provision for depreciation, depletion and amortization and to determine the amount of any impairment of proved properties; · The valuation of unproved acreage and proved crude oil and natural gas properties to determine the amount of any impairment of crude oil and natural gas properties; · Judgment regarding the productive status of in-progress exploratory wells to determine the amount of any provision for abandonment; and · Estimates regarding the timing and cost of future abandonment obligations; and, · Estimates regarding projected cash flows used in determining the production payable discount.
Recent Accounting Pronouncements	Recent Accounting Pronouncements Accounting Standards Issued and Adopted The Company does not believe that any recently issued effective pronouncements, or pronouncements issued but not yet effective, if adopted, would have a material effect on the Company’s financial statements.

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Feb. 28, 2022
Accounting Policies [Abstract]
Summary of Significant Accounting Policies - Schedule of Concentration of Risk, by Risk Factor	The Company’s accounts receivable in California for crude oil sales at February 28, 2022 and February 28, 2021, respectively are set forth in the table below. Summary of Significant Accounting Policies - Schedule of Concentration of Risk, by Risk Factor Customer Concentration Risk Accounts Receivable - Crude Oil Sales February 28, 2022 February 28, 2021 Project Customer Accounts Receivable Crude Oil Sales Percentage Accounts Receivable Crude Oil Sales Percentage California – East Slopes Project (Crude oil) Plains Marketing $ 117,727 100.0 % $ 108,993 100.0 %

CRUDE OIL PROPERTIES (Tables)

CRUDE OIL PROPERTIES (Tables)	12 Months Ended
	Feb. 28, 2022
Extractive Industries [Abstract]
Crude Oil Properties - Schedule of Crude Oil Activities	Crude oil property balances at February 28, 2022 and February 28, 2021 are set forth in the table below: Crude Oil Properties - Schedule of Crude Oil Activities February 28, 2022 February 28, 2021 Proved leasehold costs $ 115,119 $ 115,119 Unproved leasehold costs — 55,978 Costs of wells and development 2,309,628 2,291,924 Capitalized exploratory well costs 1,341,494 1,341,494 Total cost of oil and gas properties 3,766,241 3,804,515 Accumulated depletion, depreciation amortization and impairment (3,230,209 ) (3,192,081 ) Oil and gas properties, net $ 536,032 $ 612,434

ASSET RETIREMENT OBLIGATION (_2

ASSET RETIREMENT OBLIGATION (“ARO”) (Tables)	12 Months Ended
	Feb. 28, 2022
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation (“ARO”) - Schedule of Changes in the Asset Retirement Obligations	Changes in the asset retirement obligations for the twelve months ended February 28, 2022 and February 28, 2021 are set forth in the table below. Asset Retirement Obligation (“ARO”) - Schedule of Changes in the Asset Retirement Obligations February 28, 2022 February 28, 2021 Asset retirement obligation, beginning of period $ 33,062 $ 27,149 Accretion expense 8,574 4,050 Revisions to asset retirement obligation 10,929 1,863 Asset retirement obligation, end of period $ 52,565 $ 33,062

SHORT-TERM AND LONG-TERM BORR_2

SHORT-TERM AND LONG-TERM BORROWINGS (Tables)	12 Months Ended
	Feb. 28, 2022
Debt Disclosure [Abstract]
Short-Term and Long-Term Borrowings - Schedule of Related Party Notes Payable	Current portion of note payable – related party balances at February 28, 2022 and February 28, 2021 are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Related Party Notes Payable February 28, 2022 February 28, 2021 Note payable – related party, current portion $ 8,829 $ 8,598 Unamortized debt issuance expenses (729 ) (728 ) Note payable – related party, current portion, net $ 8,100 $ 7,870 Note payable – related party long-term balances at February 28, 2022 and February 28, 2021 are set forth in the table below: February 28, 2022 February 28, 2021 Note payable – related party, non-current $ 136,710 $ 145,540 Unamortized debt issuance expenses (9,350 ) (10,080 ) Note payable – related party, non-current, net $ 127,360 $ 135,460
Short-Term and Long-Term Borrowings - Schedule of Future Estimated Payments	Future estimated payments on the outstanding note payable – related party are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Future Estimated Payments Twelve month periods ending February 28/29, 2023 8,829 2024 9,065 2025 9,309 2026 9,558 2027 9,815 Thereafter 98,963 Total $ 145,539
Short-Term and Long-Term Borrowings - Schedule of Subordinated Notes	12% Note balances at February 28, 2022 and February 28, 2021 are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Subordinated Notes 12% Subordinated Notes February 28, 2022 February 28, 2021 12% Subordinated notes – third party $ 315,000 $ 315,000 12% subordinated notes – related party — 250,000 12% Subordinated notes balance $ 315,000 $ 565,000
Short-Term and Long-Term Borrowings - Schedule of Production Revenue Payable Balances	As of February 28, 2022 and February 28, 2021, the production revenue payment program balance was $ 400,000 950,100 Short-Term and Long-Term Borrowings - Schedule of Production Revenue Payable Balances February 28, 2022 February 28, 2021 Estimated payments of production revenue payable $ 941,259 $ 2,000,258 Less: unamortized discount (124,134 ) (496,836 ) 817,125 1,503,422 Less: current portion (78,877 ) (111,753 ) Net production revenue payable – long term $ 738,248 $ 1,391,669

STOCKHOLDERS_ DEFICIT (Tables)

STOCKHOLDERS’ DEFICIT (Tables)	12 Months Ended
	Feb. 28, 2022
Equity [Abstract]
Stockholders’ Deficit - Schedule of Conversions of Series A Preferred Stock	The conversions of Series A Preferred that have occurred since the Series A Preferred was first issued in July 2006 are set forth in the table below. Stockholders’ Deficit - Schedule of Conversions of Series A Preferred Stock Fiscal Period Shares of Series A Preferred Converted to Common Stock Shares of Common Stock Issued from Conversion Number of Accredited Investors Year Ended February 29, 2008 102,300 306,900 10 Year Ended February 28, 2009 237,000 711,000 12 Year Ended February 28, 2010 51,900 155,700 4 Year Ended February 28, 2011 102,000 306,000 4 Year Ended February 29, 2012 — — — Year Ended February 28, 2013 18,000 54,000 2 Year Ended February 28, 2014 151,000 453,000 9 Year Ended February 28, 2015 3,000 9,000 1 Year Ended February 29, 2016 10,000 30,000 1 Year Ended February 28, 2017 — — — Year Ended February 28, 2018 14,997 44,991 1 Year Ended February 28, 2019 — — — Year Ended February 29, 2020 — — — Year Ended February 28, 2021 — — — Year Ended February 28, 2022 709,568 2,128,704 56 Totals 1,399,765 4,199,295 100
Stockholders’ Deficit - Schedule of Preferred Stock Dividends Earned	Cumulative dividends earned for each twelve month period since issuance are set forth in the table below: Stockholders’ Deficit - Schedule of Preferred Stock Dividends Earned Fiscal Year Ended Shareholders at Period End Accumulated Dividends February 28, 2007 100 $ 155,311 February 29, 2008 90 242,126 February 28, 2009 78 209,973 February 28, 2010 74 189,973 February 28, 2011 70 173,707 February 29, 2012 70 163,624 February 28, 2013 68 161,906 February 28, 2014 59 151,323 February 28, 2015 58 132,634 February 29, 2016 57 130,925 February 28, 2017 57 130,415 February 28, 2018 56 128,231 February 28, 2019 56 127,714 February 29, 2020 56 128,063 February 28, 2021 56 127,714 February 28, 2022 — 96,340 $ 2,449,979
Stockholders' Deficit - Schedule of Common Stock Outstanding	Common Stock Balance Par Value Common stock, Issued and Outstanding, February 28, 2019 51,532,364 Share issuances during the twelve months ended February 29, 2020 2,000,000 $ 2,000 Common stock, Issued and Outstanding, February 29, 2020 53,532,364 Share issuances during the twelve months ended February 28, 2021 6,958,758 $ 6,959 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

WARRANTS (Tables)

WARRANTS (Tables)	12 Months Ended
	Feb. 28, 2022
Warrants
Warrants - Schedule of Warrant Activity	Warrant activity for the twelve months ended February 28, 2022 and February 28, 2021 is set forth in the table below: Warrants - Schedule of Warrant Activity Warrants Weighted Average Exercise Price Warrants outstanding, February 29, 2020 2,100,000 $ 0.01 Changes during the twelve months ended February 28,2021: Issued — Expired / Cancelled / Forfeited — Warrants outstanding, February 28. 2021 2,100,000 $ 0.01 Warrants exercisable, February 28, 2021 528,507 Changes during the twelve months ended February 28, 2022: Issued — $ Expired / Cancelled / Forfeited — Warrants outstanding, February 28, 2022 2,100,000 $ 0.01 Warrants exercisable, February 28, 2022 893,333 $ 0.01

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Feb. 28, 2022
Income Tax Disclosure [Abstract]
Income Taxes - Schedule of Reconciliation Between Actual Tax Expense Benefit and Income Taxes Computed by Applying Income Tax Rate	Reconciliation between actual tax expense (benefit) and income taxes computed by applying the U.S. federal income tax rate and state income tax rate to income from continuing operations before income taxes is as follows: Income Taxes - Schedule of Reconciliation Between Actual Tax Expense Benefit and Income Taxes Computed by Applying Income Tax Rate February 28, 2022 February 28, 2021 Computed at U.S. and state statutory rates $ (118,897 ) $ (152,860 ) Permanent differences 11,157 15,342 Changes in valuation allowance 107,740 137,518 Total $ — $ —
Income Taxes - Schedule of Deferred Tax Assets and Liabilities	Tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred liabilities are presented below: Income Taxes - Schedule of Deferred Tax Assets and Liabilities February 28, 2022 February 28, 2021 Deferred tax assets: Net operating loss carryforwards $ 5,670,900 $ 5,587,416 Oil and gas properties 87,694 63,438 Stock based compensation 66,187 66,187 Other 27,838 27,838 Less valuation allowance (5,852,619 ) (5,744,879 ) Total $ — $ —

SUPPLEMENTARY INFORMATION FOR_2

SUPPLEMENTARY INFORMATION FOR CRUDE OIL PRODUCING ACTIVITIES (UNAUDITED) (Tables)	12 Months Ended
	Feb. 28, 2022
Extractive Industries [Abstract]
Supplementary Information for Crude Oil Producing Activities - Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities	Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities Supplementary Information for Crude Oil Producing Activities - Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities As of February 28, 2022 As of February 28, 2021 Proved leasehold costs Mineral Interests $ 115,119 $ 115,119 Wells, equipment and facilities 3,651,122 3,633,418 Total Proved Properties 3,766,241 3,748,537 Unproved properties Mineral Interests — 55,978 Uncompleted wells, equipment and facilities — — Total unproved properties — 55,978 Less accumulated depreciation, depletion amortization and impairment (3,230,209 ) (3,192,081 ) Net capitalized costs $ 536,032 $ 612,434
Supplementary Information for Crude Oil Producing Activities - Costs Incurred in Oil and Gas Producing Activities	Costs Incurred in Oil and Gas Producing Activities Supplementary Information for Crude Oil Producing Activities - Costs Incurred in Oil and Gas Producing Activities 12 Months Ended 12 Months Ended February 28, 2022 February 28, 2021 Acquisition of proved properties $ — $ — Acquisition of unproved properties — — Development costs 6,773 11,871 Exploration costs — — Total costs incurred $ 6,773 $ 11,871
Supplementary Information for Crude Oil Producing Activities - Results of Operations from Oil and Gas Producing Activities	Results of Operations from Oil and Gas Producing Activities Supplementary Information for Crude Oil Producing Activities - Results of Operations from Oil and Gas Producing Activities 12 Months Ended 12 Months Ended February 28, 2022 February 28, 2021 Oil and gas revenues $ 680,107 $ 404,901 Production costs (231,275 ) (187,858 ) Exploration expenses (56,213 ) (83 ) Depletion, depreciation and amortization (49,590 ) (60,063 ) Impairment of oil properties — — Result of oil and gas producing operations before income taxes 343,029 156,897 Provision for income taxes — — Results of oil and gas producing activities $ 343,029 $ 156,897
Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Oil and Gas Reserves	Our proved reserves are summarized in the table below: Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Oil and Gas Reserves Oil (Barrels) Natural Gas (Mcf) BOE (Barrels) Proved reserves: February 29, 2020 495,977 — 495,977 Revisions (1) (50,784 ) — (50,784 ) Discoveries and extensions — — — Production (10,970 ) — (10,970 ) February 28, 2021 434,223 — 434,223 Revisions (2) 3,052 — 3,052 Discoveries and extensions 89,493 — 89,493 Production (9,613 ) — (9,613 ) February 28, 2022 517,155 — 517,155 (1) The revisions of previous estimates resulted from a decrease in the estimated economic life of the reservoirs due to lowest realized crude oil prices in the energy markets. (2) The revisions of previous estimates resulted from higher realized crude oil prices in the energy markets. (3) The discoveries and extensions resulted from additional PUD located being added due to higher oil prices in the energy markets.
Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Developed and Undeveloped Reserves	The Company’s proved reserves are set forth in the table below. Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Developed and Undeveloped Reserves Oil Developed Undeveloped Total Reserves Oil (Bbls) BOE (Bbls) Oil (Bbls) BOE (Bbls) Oil (Bbls) BOE (Bbls) February 29, 2020 113,779 113,779 382,198 382,198 495,977 495,977 February 28, 2021 95,120 95,120 339,103 339,103 434,223 434,223 February 28, 2022 117,844 117,844 399,311 399,311 517,155 517,155
Supplementary Information for Crude Oil Producing Activities - Standardized Measure of Discounted Future Cash Flows Relating to Proved Oil and Gas Reserves	Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves Supplementary Information for Crude Oil Producing Activities - Standardized Measure of Discounted Future Cash Flows Relating to Proved Oil and Gas Reserves 12 Months Ended February 28, 2022 February 28, 2021 Future cash inflows $ 35,580,251 $ 15,692,834 Future production costs (1) (16,217,379 ) (8,076,769 ) Future development costs (3,603,561 ) (2,510,625 ) Future income tax expenses (2) — — Future net cash flows 15,759,311 5,105,440 10% annual discount for estimated timing of cash flows (9,567,367 ) (3,457,022 ) Standardized measure of discounted future net cash flows at the end of the fiscal year $ 6,191,944 $ 1,648,418
Supplementary Information for Crude Oil Producing Activities - Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure	Average hydrocarbon prices are set forth in the table below. Supplementary Information for Crude Oil Producing Activities - Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure Crude Oil Average Price Natural Natural Gas Crude Oil (Bbl) Gas (Mcf) Year ended February 29, 2020 (1) $ 60.25 $ — Year ended February 28, 2021 (1) $ 36.91 $ — Year ended February 28, 2022 (1) $ 70.75 $ — (1) Average prices were based on 12-month unweighted arithmetic average of the first-day-of-the-month prices for the period from March through February during each respective fiscal year.
Supplementary Information for Crude Oil Producing Activities - Schedule of Sources of Changes in Discounted Future Net Cash Flows	Principal changes in the aggregate standardized measure of discounted future net cash flows attributable to the Company’s proved crude oil and natural gas reserves, as required by ASC 932, at fiscal year-end are set forth in the table below. Supplementary Information for Crude Oil Producing Activities - Schedule of Sources of Changes in Discounted Future Net Cash Flows 12 Months Ended February 28, 2022 February 28, 2021 Standardized measure of discounted future net cash flows at the beginning of the year $ 1,648,418 $ 4,652,142 Extensions, discoveries and improved recovery, less related costs 906,390 — Revisions of previous quantity estimates 44,898 (287,596 ) Net changes in prices and production costs 3,320,241 (1,899,026 ) Accretion of discount 164,842 465,214 Sales of oil produced, net of production costs (448,832 ) (217,043 ) Changes in future development costs (267,335 ) (9,077 ) Changes in timing of future production 823,322 (1,074,350 ) Net changes in income taxes — — Standardized measure of discounted future net cash flows at the end of the year $ 6,191,944 $ 1,648,418

GOING CONCERN (Details Narrativ

GOING CONCERN (Details Narrative)	Oct. 20, 2021	Oct. 06, 2021USD ($)	Mar. 15, 2021USD ($)	May 11, 2020USD ($)	May 20, 2022	Feb. 28, 2021USD ($)	Feb. 28, 2022USD ($)Number	Feb. 28, 2021USD ($)
Product Information [Line Items]
Accumulated deficit						$ 29,428,897	$ 29,530,456	$ 29,428,897
Working capital deficit							3,000,000
Proceeds from PPP loan							72,800	$ 74,355
Forgiveness of debt							$ 53,125
Subsequent Event | Reabold California, LLC ("Reabold") and Gaelic Resources, Ltd. ("Gaelic")
Product Information [Line Items]
Contingent consideration arrangement, description					In conjunction with the Company’s efforts to acquire Reabold, and as a condition of closing the acquisition, the Company was to secure a capital raise of $2,500,000 through the issuance of shares of the Company’s common stock. The commitment for that capital raise was executed on May 5, 2022, and subsequently 128,125,000 shares were issued.
Equity Exchange Agreement
Product Information [Line Items]
Equity exchange agreement, description	the Company entered into an Equity Exchange Agreement (the “Exchange Agreement”) by and between Daybreak, Reabold California LLC, a California limited liability company (“Reabold”), and Gaelic Resources Ltd., a private company incorporated in the Isle of Man and the 100% owner of Reabold (“Gaelic”), pursuant to which the parties propose for (i) Daybreak to acquire 100% ownership of Reabold, in exchange for (ii) Daybreak issuing 160,964,489 shares of its common stock, par value $0.001 (“Common Stock”) to Gaelic (the “Exchange Shares”), which will result in Reabold becoming a wholly-owned subsidiary of Daybreak and Gaelic becoming the owner of the Exchange Shares and a major shareholder of Daybreak (the foregoing transaction and the transactions contemplated thereby, the “Equity Exchange”).
Equity Exchange Agreement | Subsequent Event
Product Information [Line Items]
Equity exchange agreement, additional information					At a special meeting of shareholders held on May 20, 2022, shareholders approved the Equity Exchange Agreement between Daybreak, Reabold California, LLC (“Reabold”) and Gaelic Resources, Ltd. (“Gaelic”). As a result of this approval, on May 25, 2022, the Company proceeded with the acquisition of Reabold and its producing crude oil and natural gas properties in California. The acquisition was completed by Daybreak issuing 160,964,489 common stock shares to Gaelic, along with the customary closing terms and conditions for acquisitions of this nature.
Equity exchange agreement, special meeting, additional information					approval was granted to Amend and Restate the Company’s Articles of Incorporation. This would allow for the increase in the number of authorized common stock shares of the Company from 200,000,000 shares to 500,000,000 shares. The increase in common stock shares will give the Company enough authorized common stock shares to complete the transaction with Reabold and Gaelic. Also, all the Preferred stock classification was eliminated.
SBA Paycheck Protection Program
Product Information [Line Items]
Proceeds from PPP loan				$ 74,355
Forgiveness of debt						$ 74,355
SBA Paycheck Protection Program Second Draw
Product Information [Line Items]
Proceeds from PPP loan			$ 72,800
Forgiveness of debt		$ 72,800
Revenue
Product Information [Line Items]
Number of producing crude oil wells | Number							20
Average working interest							36.60%
Average net revenue interest							28.40%

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Schedule of Concentration of Risk, by Risk Factor (Details) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
Product Information [Line Items]
Revenue receivable	$ 117,727	$ 108,993
Customer Concentration
Product Information [Line Items]
Percent of revenue	100.00%
Customer Concentration | Accounts Receivable - Crude Oil Sales | Plains Marketing (California - East Slopes Project (Crude Oil))
Product Information [Line Items]
Revenue receivable	$ 117,727	$ 108,993
Percent of revenue	100.00%	100.00%

SUMMARY OF SIGNIFICANT ACCOUN_5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
Property, Plant and Equipment [Line Items]
Impairment of unproved properties	$ 55,978	$ 0
Customer Concentration Risk
Property, Plant and Equipment [Line Items]
Concentration risk	100.00%
Vehicles
Property, Plant and Equipment [Line Items]
Expected useful lives	three years
Machinery and Equipment
Property, Plant and Equipment [Line Items]
Expected useful lives	three years

ACCOUNTS RECEIVABLE (Details Na

ACCOUNTS RECEIVABLE (Details Narrative) - USD ($)	Feb. 28, 2022	Feb. 28, 2021
Receivables [Abstract]
Crude oil sales receivable, balance	$ 117,727	$ 108,993
Joint interest participant receivable, balance	$ 85,339	$ 79,411

Crude Oil Properties - Schedule

Crude Oil Properties - Schedule of Crude Oil Activities (Details) - USD ($)	Feb. 28, 2022	Feb. 28, 2021
Extractive Industries [Abstract]
Proved leasehold costs	$ 115,119	$ 115,119
Unproved leasehold costs	0	55,978
Costs of wells and development	2,309,628	2,291,924
Capitalized exploratory well costs	1,341,494	1,341,494
Total cost of oil and gas properties	3,766,241	3,804,515
Accumulated depletion, depreciation amortization and impairment	(3,230,209)	(3,192,081)
Oil and gas properties, net	$ 536,032	$ 612,434

CRUDE OIL PROPERTIES (Details N

CRUDE OIL PROPERTIES (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
Extractive Industries [Abstract]
Depletion expense	$ 38,125	$ 56,013
Impairment of unproved crude oil properites	$ 55,978	$ 0

Asset Retirement Obligation (_3

Asset Retirement Obligation (“ARO”) - Schedule of Changes in the Asset Retirement Obligations (Details) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligation, beginning of period	$ 33,062	$ 27,149
Accretion expense	8,574	4,050
Revisions to asset retirement obligation	10,929	1,863
Asset retirement obligation, end of period	$ 52,565	$ 33,062

ASSET RETIREMENT OBLIGATION (_4

ASSET RETIREMENT OBLIGATION (“ARO”) (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
Asset Retirement Obligation Disclosure [Abstract]
Accretion expense	$ 8,574	$ 4,050

ACCOUNTS PAYABLE (Details Narra

ACCOUNTS PAYABLE (Details Narrative) - USD ($)	1 Months Ended	3 Months Ended	12 Months Ended
	Mar. 31, 2009	Jun. 11, 2009	Feb. 28, 2022	Feb. 28, 2021
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Liabilities Assumed	$ 1,500,000
Business Combination, Assets and Liabilities Arising from Contingencies, Description		representing a 25% working interest in the drilling and completion costs associated with the East Slopes Project four earning wells program. The Company subsequently sold the 25% working interest on June 11, 2009
Accounts Payable				$ 244,849
Working Interest Partner, California
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Accounts Payable			$ 76,268	$ 88,905
Employer payroll tax estimates			52,530
Estimated employee payroll taxes			$ 135,687
Shares issued, accrued employee payroll taxes			301,527

ACCOUNTS PAYABLE- RELATED PAR_2

ACCOUNTS PAYABLE- RELATED PARTIES (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
Defined Benefit Plan Disclosure [Line Items]
Accounts Payable, Related Parties, Current	$ 49,228	$ 988,966
Accrued Employee Salaries
Defined Benefit Plan Disclosure [Line Items]
Value of shares issued to satisfy related party debt	$ 493,359
Shares issued to satisfy related party debt	1,096,353
Accrued Directors Fees
Defined Benefit Plan Disclosure [Line Items]
Value of shares issued to satisfy related party debt	$ 142,969
Shares issued to satisfy related party debt	317,708
12% Note Interest - Related Party
Defined Benefit Plan Disclosure [Line Items]
Value of shares issued to satisfy related party debt	$ 264,986
Shares issued to satisfy related party debt	588,859

Short-Term and Long-Term Borr_3

Short-Term and Long-Term Borrowings - Schedule of Related Party Notes Payable (Details) - USD ($)	Feb. 28, 2022	Feb. 28, 2021
Debt Disclosure [Abstract]
Note payable – related party, current portion	$ 8,829	$ 8,598
Unamortized debt issuance expenses	(729)	(728)
Note payable – related party, current portion, net	8,100	7,870
Note payable – related party, non-current	136,710	145,540
Unamortized debt issuance expenses	(9,350)	(10,080)
Note payable – related party, non-current, net	$ 127,360	$ 135,460

Short-Term and Long-Term Borr_4

Short-Term and Long-Term Borrowings - Schedule of Future Estimated Payments (Details)	Feb. 28, 2022USD ($)
Twelve month periods ending February 28/29,
2023	$ 8,829
2024	9,065
2025	9,309
2026	9,558
2027	9,815
Thereafter	98,963
Total	$ 145,539

Short-Term and Long-Term Borr_5

Short-Term and Long-Term Borrowings - Schedule of Subordinated Notes (Details) - 12% Subordinated Notes - USD ($)	Feb. 28, 2022	Feb. 28, 2021
Debt Instrument [Line Items]
12% Subordinated notes balance	$ 315,000	$ 565,000
Related Party
Debt Instrument [Line Items]
12% Subordinated notes balance		250,000
Third Party
Debt Instrument [Line Items]
12% Subordinated notes balance	$ 315,000	$ 315,000

Short-Term and Long-Term Borr_6

Short-Term and Long-Term Borrowings - Schedule of Production Revenue Payable Balances (Details) - USD ($)	Feb. 28, 2022	Feb. 28, 2021
Debt Disclosure [Abstract]
Estimated payments of production revenue payable	$ 941,259	$ 2,000,258
Less: unamortized discount	(124,134)	(496,836)
Production revenue payable, net	817,125	1,503,422
Less: current portion	(78,877)	(111,753)
Net production revenue payable – long term	$ 738,248	$ 1,391,669

SHORT-TERM AND LONG-TERM BORR_7

SHORT-TERM AND LONG-TERM BORROWINGS (Details Narrative) - USD ($)

May 05, 2022

Oct. 06, 2021

Mar. 15, 2021

Dec. 22, 2020

May 11, 2020

Oct. 24, 2011

Feb. 28, 2021

Dec. 31, 2018

Jan. 29, 2015

Jan. 31, 2010

Feb. 28, 2022

Feb. 28, 2021

Feb. 29, 2020

Feb. 28, 2019

Short-term Debt [Line Items]

Amortization of debt discount

$ 96,703

$ 115,272

Proceeds from convertible promissory note

200,000

Payments to line of credit

60,000

60,000

Gain on debt forgiveness

72,800

74,355

Proceeds from PPP loan

72,800

74,355

Forgiveness of debt

$ 53,125

SBA Paycheck Protection Program

Short-term Debt [Line Items]

Proceeds from PPP loan

$ 74,355

Forgiveness of debt

$ 74,355

SBA Paycheck Protection Program Second Draw

Short-term Debt [Line Items]

Proceeds from PPP loan

$ 72,800

Forgiveness of debt

$ 72,800

Line of Credit | UBS Bank USA

Short-term Debt [Line Items]

Line of credit, maximum borrowing

$ 890,000

Line of credit, collateral

secured by the personal guarantee of our President and Chief Executive Officer

Line of credit, interest rate description

a new interest rate benchmark the UBS Variable Rate (UBSVR) would replace the existing 30-day LIBOR (“London Interbank Offered Rate”) benchmark. The UBSVR is comprised of the compounded 30-day average of the Secured Overnight Financing Rate (SOFR) plus a fixed spread adjustment of 0.110%. The Company’s new all-on rate will consist of the UBSVR plus its current spread over LIBOR

Payments to line of credit

$ 60,000

60,000

Paid-in-kind interest

27,278

28,503

Line of credit, balance

840,904

$ 808,182

840,904

Convertible Debt | Third Party

Short-term Debt [Line Items]

Interest rate

18.00%

Proceeds from convertible promissory note

$ 200,000

Terms of conversion, description

The conversion price was to be determined by one of two cases. In Case 1, the conversion price would be $0.017 and in Case 2, the conversion price would be $0.0085. The Case 1 conversion price scenario would apply if the terms of the Equity Exchange Agreement were met by a Long Stop Date of April 29, 2022. The Case 2 conversion price scenario would apply if the terms of the Equity Exchange Agreement were not met by a Long Stop Date of April 29, 2022. The terms of the Equity Exchange Agreement were not met by the Long Stop Date of April 29, 2022 and the conversion price was determined to be the $0.0085 rate.

Convertible Debt | Third Party | Subsequent Event

Short-term Debt [Line Items]

Conversion of original principal investment

$ 236,000

Conversion price, per share

$ 0.0085

Conversion of original principal investment, shares issued

27,764,706

Chief Executive Officer

Short-term Debt [Line Items]

Settlement of debt

$ 250,100

Secured Debt | Chief Executive Officer

Short-term Debt [Line Items]

Proceeds from issuance of secured debt

$ 155,548

Loan fees

10,929

Net proceeds from loan

$ 144,619

Interest rate

2.25%

Maturity date

Dec. 21, 2035

Principal payments

$ 8,599

Amortization of debt discount

729

12% Subordinated Notes

Short-term Debt [Line Items]

Subordinated Debt

565,000

315,000

565,000

Debt Instrument, Increase, Accrued Interest

$ 135,229

340,042

12% Subordinated Notes | Related Party

Short-term Debt [Line Items]

Conversion price, per share

$ 0.45

Conversion of original principal investment, shares issued

1,144,415

Subordinated Debt

250,000

250,000

Debt Instrument, Increase, Accrued Interest

264,986

12% Subordinated Notes | Private Placement

Short-term Debt [Line Items]

Notes payable

$ 565,000

Interest rate

12.00%

Proceeds from subordinated notes

$ 595,000

Portion of total gross proceeds received from related party

$ 250,000

Maturity date, description

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 was extended for an additional two years to January 29, 2019.

Third-Party Vendors

Short-term Debt [Line Items]

Notes payable

$ 120,000

Shares issued as part of accounts payable settlement

2,000,000

Shares issued as part of accounts payable settlement, value

$ 6,000

Maturity date

Jan. 1, 2022

Interest rate

10.00%

Accrued interest

26,000

38,000

26,000

Production Payment Program

Short-term Debt [Line Items]

Amortization of debt discount

95,974

115,151

Conversion of original principal investment

$ 550,100

Conversion price, per share

$ 0.45

Conversion of original principal investment, shares issued

1,222,444

Fundraising program, description

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 seventy-five percent (75%) 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%). At February 28, 2022, the Production Payment Target has not been met within the original three years and all future payments will be at the seventy-five percent (75%) rate.

Production revenue payable, balance

$ 950,100

$ 950,100

Interest expense on production revenue payments

$ 941,259

Gain on debt forgiveness

$ 232,170

LEASES (Details Narrative)

LEASES (Details Narrative)	12 Months Ended
	Feb. 28, 2022USD ($)ft²	Feb. 28, 2021USD ($)
Lease expense | $	$ 23,489	$ 23,589
Spokane Valley, Washington
Leased properties, square feet	988
Friendswood, Texas
Leased properties, square feet	416
Lease, term of contract	12 months
Lease, maturity date	October 2021
Wallace, Idaho
Leased properties, square feet	695

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details Narrative) - Chief Operating Officer - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
Great Earth Power
Related Party Transaction [Line Items]
Payments to suppliers	$ 11,507	$ 9,000
ABPlus Net Holdings
Related Party Transaction [Line Items]
Payments to suppliers	$ 6,720	$ 2,440

Stockholders_ Deficit - Schedul

Stockholders’ Deficit - Schedule of Conversions of Series A Preferred Stock (Details)	12 Months Ended
	Feb. 28, 2022Numbershares	Feb. 28, 2021Numbershares	Feb. 29, 2020Numbershares	Feb. 28, 2019Numbershares	Feb. 28, 2018Numbershares	Feb. 28, 2017Numbershares	Feb. 29, 2016Numbershares	Feb. 28, 2015Numbershares	Feb. 28, 2014Numbershares	Feb. 28, 2013Numbershares	Feb. 29, 2012Numbershares	Feb. 28, 2011Numbershares	Feb. 28, 2010Numbershares	Feb. 28, 2009Numbershares	Feb. 29, 2008Numbershares
Class of Stock [Line Items]
Shares of common stock issued from conversion	4,199,295	2,070,591
Number of accredited investors | Number	100
Shares of Series A Preferred converted to Common Stock	1,399,765	690,197
Series A Convertible Preferred Stock
Class of Stock [Line Items]
Shares of common stock issued from conversion	2,128,704	0	0	0	44,991	0	30,000	9,000	453,000	54,000	0	306,000	155,700	711,000	306,900
Number of accredited investors | Number	56	0	0	0	1	0	1	1	9	2	0	4	4	12	10
Shares of Series A Preferred converted to Common Stock	709,568				14,997		10,000	3,000	151,000	18,000		102,000	51,900	237,000	102,300

Stockholders_ Deficit - Sched_2

Stockholders’ Deficit - Schedule of Preferred Stock Dividends Earned (Details)	12 Months Ended
	Feb. 28, 2022USD ($)Number	Feb. 28, 2021USD ($)Number	Feb. 29, 2020USD ($)Number	Feb. 28, 2019USD ($)Number	Feb. 28, 2018USD ($)Number	Feb. 28, 2017USD ($)Number	Feb. 29, 2016USD ($)Number	Feb. 28, 2015USD ($)Number	Feb. 28, 2014USD ($)Number	Feb. 28, 2013USD ($)Number	Feb. 29, 2012USD ($)Number	Feb. 28, 2011USD ($)Number	Feb. 28, 2010USD ($)Number	Feb. 28, 2009USD ($)Number	Feb. 29, 2008USD ($)Number	Feb. 28, 2007USD ($)Number
Equity [Abstract]
Shareholders at Period End | Number		56	56	56	56	57	57	58	59	68	70	70	74	78	90	100
Dividends, Preferred Stock	$ 96,340	$ 127,714	$ 128,063	$ 127,714	$ 128,231	$ 130,415	$ 130,925	$ 132,634	$ 151,323	$ 161,906	$ 163,624	$ 173,707	$ 189,973	$ 209,973	$ 242,126	$ 155,311
Accumulated dividends	$ 2,449,979

Stockholders' Deficit - Schedul

Stockholders' Deficit - Schedule of Common Stock Outstanding (Details) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021	Feb. 29, 2020
Accumulated Other Comprehensive Income (Loss) [Line Items]
Convertible note payable - related party		$ 27,835
Conversion of Series A preferred stock
Conversion of Series A accumulated dividend, shares	1,100,000
Conversion of accrued employee salaries	$ 681,577
Conversion of accrued director fees	142,969
Conversion of 12% Note principal and interest - related party	514,986
Conversion of production revenue program principal - related party	$ 550,100
Common Stock
Accumulated Other Comprehensive Income (Loss) [Line Items]
Shares outstanding	60,491,122	53,532,364	51,532,364
Accounts payable settlement, shares			2,000,000
Accounts payable settlement, shares			$ 2,000
Convertible note payable - related party, shares		6,958,758
Convertible note payable - related party		$ 6,959
Conversion of Series A preferred stock, shares	2,128,704
Conversion of Series A preferred stock	$ 2,129
Conversion of Series A accumulated dividend, shares	1,100,000
Conversion of Series A accumulated dividend	$ 1,100
Conversion of accrued employee salaries, shares	1,397,880
Conversion of accrued employee salaries	$ 1,398
Conversion of accrued director fees, shares	317,708
Conversion of accrued director fees	$ 318
Conversion of 12% Note principal and interest - related party, shares	1,144,415
Conversion of 12% Note principal and interest - related party	$ 1,144
Conversion of production revenue program principal - related party, shares	1,222,444
Conversion of production revenue program principal - related party	$ 1,222
Shares outstanding	67,802,273	60,491,122	53,532,364

STOCKHOLDERS_ DEFICIT (Details

STOCKHOLDERS’ DEFICIT (Details Narrative)	12 Months Ended
	Feb. 28, 2022USD ($)Number$ / sharesshares	Feb. 28, 2021USD ($)Number$ / sharesshares	Feb. 29, 2020shares	Feb. 28, 2019shares	Feb. 28, 2018shares	Feb. 28, 2017shares	Feb. 29, 2016shares	Feb. 28, 2015shares	Feb. 28, 2014shares	Feb. 28, 2013shares	Feb. 29, 2012shares	Feb. 28, 2011shares	Feb. 28, 2010shares	Feb. 28, 2009shares	Feb. 29, 2008shares	May 20, 2022shares
Class of Stock [Line Items]
Preferred stock, shares authorized	10,000,000	10,000,000
Preferred stock, par value | $ / shares	$ 0.001	$ 0.001
Conversion of stock, shares converted	1,399,765	690,197
Conversion of Series A accumulated dividend, shares	1,100,000
Shares of common stock issued upon conversion of preferred shares	4,199,295	2,070,591
Dividends | $	$ 2,449,979
Common stock, shares authorized	200,000,000	200,000,000
Common stock, par value | $ / shares	$ 0.001	$ 0.001
Common stock, shares issued	67,802,273	60,491,122
Common stock, shares outstanding	67,802,273	60,491,122
Convertible note payable – related party | $		$ 27,835
Subsequent Event
Class of Stock [Line Items]
Common stock, shares authorized																500,000,000
Equity Exchange Agreement
Class of Stock [Line Items]
Accumulated dividend | $	$ 2,449,979
Shares issued	7,311,151
Shares issued to satisfy related party debt	4,082,447
Shares issued to satisfy Series A preferred stock conversion	3,228,704
Common stock issued for related party debt, shares	6,958,758
Convertible note payable – related party | $	$ 27,835
Series A Convertible Preferred Stock
Class of Stock [Line Items]
Conversion of Series A preferred stock, shares	709,568
Convertible note payable – related party | $
Common Stock
Class of Stock [Line Items]
Conversion of Series A preferred stock, shares issued	2,128,704
Conversion of Series A accumulated dividend, shares	1,100,000
Accumulated dividend | $	$ 2,449,979
Common stock issued for related party debt, shares		6,958,758
Convertible note payable – related party | $		$ 6,959
Series A Convertible Preferred Stock
Class of Stock [Line Items]
Preferred stock, shares authorized	2,400,000	2,400,000
Preferred stock, par value | $ / shares	$ 0.001	$ 0.001
Conversion of stock, shares converted	709,568				14,997		10,000	3,000	151,000	18,000		102,000	51,900	237,000	102,300
Accredited investors | Number	100	44
Shares of common stock issued upon conversion of preferred shares	2,128,704	0	0	0	44,991	0	30,000	9,000	453,000	54,000	0	306,000	155,700	711,000	306,900

Warrants - Schedule of Warrant

Warrants - Schedule of Warrant Activity (Details) - $ / shares	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
Warrants
Warrants outstanding	2,100,000	2,100,000
Weighted average exercise price	$ 0.01	$ 0.01
Issued	0	0
Expired / cancelled / forfeited	0	0
Warrants exercisable	893,333	528,507
Warrants outstanding	2,100,000	2,100,000
Weighted average exercise price	$ 0.01	$ 0.01
Weighted average exercise price, warrants exercisable	$ 0.01

WARRANTS (Details Narrative)

WARRANTS (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021	Feb. 29, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Fair value of warrants issued	$ 4,913	$ 5,897
Warrants exercisable	893,333	528,507
Class of Warrant or Right, Exercise Price of Warrants or Rights	$ 0.01
Weighted average remaining life	1 year 10 months 2 days
Intrinsic value	$ 20,265
Warrant expense	$ 4,913	$ 5,897
Share Based Payment Arrangement - Non-Employee
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Warrants issued for investor relations services			2,100,000
Fair value of warrants issued			$ 17,689
Vesting period			3 years
Risk-free interest rate			1.68%
Volatility rate			260.23%
Dividend yield			0.00%

Income Taxes - Schedule of Reco

Income Taxes - Schedule of Reconciliation Between Actual Tax Expense Benefit and Income Taxes Computed by Applying Income Tax Rate (Details) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
Income Tax Disclosure [Abstract]
Computed at U.S. and state statutory rates	$ (118,897)	$ (152,860)
Permanent differences	11,157	15,342
Changes in valuation allowance	107,740	137,518
Total

Income Taxes - Schedule of Defe

Income Taxes - Schedule of Deferred Tax Assets and Liabilities (Details) - USD ($)	Feb. 28, 2022	Feb. 28, 2021
Deferred tax assets:
Net operating loss carryforwards	$ 5,670,900	$ 5,587,416
Oil and gas properties	87,694	63,438
Stock based compensation	66,187	66,187
Other	27,838	27,838
Less valuation allowance	(5,852,619)	(5,744,879)
Total

INCOME TAXES (Details Narrative

INCOME TAXES (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021	Feb. 28, 2020	Feb. 28, 2019	Feb. 29, 2020	Feb. 28, 2018
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	$ 19,035,827
Increase in valuation allowance	107,740	$ 137,518
Tax Cuts and Jobs Act
Operating Loss Carryforwards [Line Items]
Change in corporate income tax rate			21.00%	35.00%
NOL portion not subject to expiration	$ 311,241	$ 416,898			$ 339,299	$ 340,749

SUBSEQUENT EVENTS (Details Narr

SUBSEQUENT EVENTS (Details Narrative) - USD ($)	May 05, 2022	May 20, 2022	Feb. 28, 2022	Feb. 28, 2021
Subsequent Event [Line Items]
Increase in common stock authorized			200,000,000	200,000,000
Subsequent Event
Subsequent Event [Line Items]
Increase in common stock authorized		500,000,000
Subsequent Event | Reabold California, LLC ("Reabold") and Gaelic Resources, Ltd. ("Gaelic")
Subsequent Event [Line Items]
Contingent consideration arrangement, additional information		In conjunction with the Company’s efforts to acquire Reabold, and as a condition of closing the acquisition, the Company was to secure a capital raise of $2,500,000 through the issuance of shares of the Company’s common stock. That commitment for that capital raise was executed on May 5, 2022, and subsequently 128,125,000 shares were issued.
Subsequent Event | Common Stock
Subsequent Event [Line Items]
Acquisition, equity interest issuable, description		At a special meeting of shareholders held on May 20, 2022, Daybreak shareholders approved the Equity Exchange Agreement between Daybreak, Reabold California, LLC (“Reabold”) and Gaelic Resources, Ltd. (“Gaelic”). As a result of this approval, the Company proceeded with the acquisition of Reabold and its producing crude oil and natural gas properties in California. The acquisition was completed by Daybreak issuing 160,964,489 common stock shares to Gaelic, and in accordance with the customary closing terms and conditions for acquisitions of this nature.
Increase in common stock authorized		500,000,000
Subsequent Event | Convertible Debt | Third Party
Subsequent Event [Line Items]
Debt Conversion, Converted Instrument, Amount	$ 236,000
Debt Instrument, Convertible, Conversion Price	$ 0.0085
Debt Conversion, Converted Instrument, Shares Issued	27,764,706

Supplementary Information for_3

Supplementary Information for Crude Oil Producing Activities - Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities (Details) - USD ($)	Feb. 28, 2022	Feb. 28, 2021
Proved leasehold costs
Mineral Interests	$ 115,119	$ 115,119
Wells, equipment and facilities	3,651,122	3,633,418
Total Proved Properties	3,766,241	3,748,537
Unproved properties
Mineral Interests	0	55,978
Uncompleted wells, equipment and facilities	0	0
Total unproved properties	0	55,978
Less accumulated depreciation, depletion amortization and impairment	(3,230,209)	(3,192,081)
Oil and gas properties, net	$ 536,032	$ 612,434

Supplementary Information for_4

Supplementary Information for Crude Oil Producing Activities - Costs Incurred in Oil and Gas Producing Activities (Details) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
Extractive Industries [Abstract]
Acquisition of proved properties	$ 0	$ 0
Acquisition of unproved properties	0	0
Development costs	6,773	11,871
Exploration costs	0	0
Total costs incurred	$ 6,773	$ 11,871

Supplementary Information for_5

Supplementary Information for Crude Oil Producing Activities - Results of Operations from Oil and Gas Producing Activities (Details) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
Extractive Industries [Abstract]
Oil and gas revenues	$ 680,107	$ 404,901
Production costs	(231,275)	(187,858)
Exploration expenses	(56,213)	(83)
Depletion, depreciation and amortization	(49,590)	(60,063)
Impairment of oil properties	0	0
Result of oil and gas producing operations before income taxes	343,029	156,897
Provision for income taxes	0	0
Results of oil and gas producing activities	$ 343,029	$ 156,897

Supplementary Information for_6

Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Oil and Gas Reserves (Details)	12 Months Ended
	Feb. 28, 2022BoebblMcf		Feb. 28, 2021BoebblMcf
Reserve Quantities [Line Items]
Proved reserves | bbl	434,223		495,977
Proved reserves | Boe	434,223		495,977
Proved reserves | bbl	517,155		434,223
Proved reserves | Boe	517,155		434,223
Oil
Reserve Quantities [Line Items]
Proved reserves | bbl	434,223		495,977
Proved reserves, revisions | bbl	3,052	[1]	(50,784)	[2]
Proved reserves, discoveries and extensions | bbl	89,493		0
Proved reserves, production | bbl	(9,613)		(10,970)
Proved reserves | bbl	517,155		434,223
Natural Gas [Member]
Reserve Quantities [Line Items]
Proved reserves, revisions | Mcf	0	[1]	0	[2]
Proved reserves, discoveries and extensions | Mcf	0		0
Proved reserves, production | Mcf	0		0
BOE (Barrels)
Reserve Quantities [Line Items]
Proved reserves | Boe	434,223		495,977
Proved reserves, revisions | Boe	3,052	[1]	(50,784)	[2]
Proved reserves, discoveries and extensions | Boe	89,493		0
Proved reserves, production | Boe	(9,613)		(10,970)
Proved reserves | Boe	517,155		434,223
[1]	The revisions of previous estimates resulted from higher realized crude oil prices in the energy markets.
[2]	The revisions of previous estimates resulted from a decrease in the estimated economic life of the reservoirs due to lowest realized crude oil prices in the energy markets.

Supplementary Information for_7

Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Developed and Undeveloped Reserves (Details)	Feb. 28, 2022Boebbl	Feb. 28, 2021Boebbl	Feb. 29, 2020Boebbl
Reserve Quantities [Line Items]
Proved developed and undeveloped reserves, net | bbl	517,155	434,223	495,977
Proved developed and undeveloped reserves, net - BOE | Boe	517,155	434,223	495,977
Oil
Reserve Quantities [Line Items]
Proved developed reserves | bbl	117,844	95,120	113,779
Proved undeveloped reserves | bbl	399,311	339,103	382,198
Proved developed and undeveloped reserves, net | bbl	517,155	434,223	495,977
BOE (Barrels)
Reserve Quantities [Line Items]
Proved developed reserves - BOE | Boe	117,844	95,120	113,779
Proved undeveloped reserve - BOE | Boe	399,311	339,103	382,198
Proved developed and undeveloped reserves, net - BOE | Boe	517,155	434,223	495,977

Supplementary Information for_8

Supplementary Information for Crude Oil Producing Activities - Standardized Measure of Discounted Future Cash Flows Relating to Proved Oil and Gas Reserves (Details) - USD ($)		Feb. 28, 2022	Feb. 28, 2021	Feb. 29, 2020
Extractive Industries [Abstract]
Future cash inflows		$ 35,580,251	$ 15,692,834
Future production costs	[1]	(16,217,379)	(8,076,769)
Future development costs		(3,603,561)	(2,510,625)
Future income tax expenses	[2]	0	0
Future net cash flows		15,759,311	5,105,440
10% annual discount for estimated timing of cash flows		(9,567,367)	(3,457,022)
Standardized measure of discounted future net cash flows at the end of the fiscal year		$ 6,191,944	$ 1,648,418	$ 4,652,142
[1]	Production costs include crude oil and natural gas operations expense, production ad valorem taxes, transportation costs and G&A expense supporting the Company’s crude oil and natural gas operations.
[2]	The Company has sufficient tax deductions and allowances related to proved crude oil and natural gas reserves to offset future net revenues.

Supplementary Information for_9

Supplementary Information for Crude Oil Producing Activities - Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure (Details) - $ / PerUnit		12 Months Ended
		Feb. 28, 2022	Feb. 28, 2021	Feb. 29, 2020	Feb. 28, 2020
Crude Oil
Average oil and gas sales price	[1]	70.75	36.91	60.25
Natural Gas
Average oil and gas sales price	[1]	0	0		0
[1]	Average prices were based on 12-month unweighted arithmetic average of the first-day-of-the-month prices for the period from March through February during each respective fiscal year.

Supplementary Information fo_10

Supplementary Information for Crude Oil Producing Activities - Schedule of Sources of Changes in Discounted Future Net Cash Flows (Details) - USD ($)	12 Months Ended
	Feb. 28, 2022	Feb. 28, 2021
Extractive Industries [Abstract]
Standardized measure of discounted future net cash flows at the beginning of the year	$ 1,648,418	$ 4,652,142
Extensions, discoveries and improved recovery, less related costs	906,390	0
Revisions of previous quantity estimates	44,898	(287,596)
Net changes in prices and production costs	3,320,241	(1,899,026)
Accretion of discount	164,842	465,214
Sales of oil produced, net of production costs	(448,832)	(217,043)
Changes in future development costs	(267,335)	(9,077)
Changes in timing of future production	823,322	(1,074,350)
Net changes in income taxes	0	0
Standardized measure of discounted future net cash flows at the end of the year	$ 6,191,944	$ 1,648,418