Daybreak Oil and Gas (DBRM) 10-K 27 May 21 2021 FY Annual report Financial data

Cover

Cover - USD ($)	12 Months Ended
	Feb. 28, 2021	May 26, 2021	Aug. 31, 2020
Cover [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Feb. 28, 2021
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2021
Current Fiscal Year End Date	--02-28
Entity File Number	000-50107
Entity Registrant Name	DAYBREAK OIL & GAS, INC.
Entity Central Index Key	0001164256
Entity Incorporation, State or Country Code	WA
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			$ 514,624
Entity Common Stock, Shares Outstanding		60,491,122

Balance Sheets

Balance Sheets - USD ($)	Feb. 28, 2021	Feb. 29, 2020
CURRENT ASSETS:
Cash and cash equivalents	$ 33,528	$ 94,043
Accounts receivable:
Crude oil sales	108,993	56,910
Joint interest participants	79,411	38,366
Prepaid expenses and other current assets	61,307	51,115
Total current assets	283,239	240,434
Crude oil properties, successful efforts method, net
Proved properties	556,456	598,735
Unproved properties	55,978	55,978
Prepaid drilling costs	16,452	16,452
Operating lease, right-of-use asset		5,857
Total long-term assets	628,886	677,022
Total assets	912,125	917,456
CURRENT LIABILITIES:
Accounts payable and other accrued liabilities	1,710,922	1,555,700
Accounts payable, related parties	988,966	919,888
Accrued interest	123,659	73,962
Note payable	120,000
Note payable, related party, current, net of unamortized discount	7,870
Convertible Note payable, related party		27,835
12% Notes payable	315,000	315,000
12% Note payable, related party	250,000	250,000
Operating lease liability		5,857
Line of credit	840,904	872,401
Production revenue payable, current, net of unamortized discount	111,753	43,069
Total current liabilities	4,469,074	4,063,712
LONG TERM LIABILITIES:
Note payable		120,000
Note payable, related party, net of current portion and net of unamortized discount	135,460
Production revenue payable, net of current portion and net of unamortized discount	1,391,669	1,345,202
Asset retirement obligation	33,062	27,149
Total long-term liabilities	1,560,191	1,492,351
Total liabilities	6,029,265	5,556,063
COMMITMENTS AND CONTINGENCIES
STOCKHOLDERS' DEFICIT:
Preferred stock
Common stock	60,491	53,532
Additional paid-in capital	24,250,556	24,223,783
Accumulated deficit	(29,428,897)	(28,916,632)
Total stockholders' deficit	(5,117,140)	(4,638,607)
Total liabilities and stockholders' deficit	912,125	917,456
Series A Convertible Preferred Stock
STOCKHOLDERS' DEFICIT:
Preferred stock	$ 710	$ 710

Balance Sheets (Parenthetical)

Balance Sheets (Parenthetical) - USD ($)	Feb. 28, 2021	Feb. 29, 2020
Preferred stock, par value in dollars	$ 0.001	$ 0.001
Preferred stock, shares authorized	10,000,000	10,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Common stock, par value in dollars	$ 0.001	$ 0.001
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	60,491,122	53,532,364
Common stock, shares outstanding	60,491,122	53,532,364
Note payable, related party, current, unamortized discount	$ 728	$ 0
Notes payable, related party, non-current, unamortized discount	$ 10,080	$ 0
Series A Convertible Preferred Stock
Preferred stock, par value in dollars	$ 0.001	$ 0.001
Preferred stock, shares authorized	2,400,000	2,400,000
Preferred stock, shares issued	709,568	709,568
Preferred stock, shares outstanding	709,568	709,568
Preferred stock, cumulative dividend rate	6.00%	6.00%

Statements of Operations

Statements of Operations - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
REVENUE:
Crude oil sales	$ 404,901	$ 663,512
OPERATING EXPENSES:
Production	187,858	180,982
Exploration and drilling	83	123
Depreciation, depletion, and amortization	60,063	55,443
General and administrative	505,704	703,032
Total operating expenses	753,708	939,580
OPERATING LOSS	(348,807)	(276,068)
OTHER INCOME (EXPENSE):
Interest expense, net	(237,813)	(478,576)
Gain on forgiveness, SBA paycheck protection program (PPP) loan	74,355
Total other expenses	(163,458)	(478,576)
NET LOSS	(512,265)	(754,644)
Cumulative convertible preferred stock dividend requirement	(127,714)	(128,063)
NET LOSS AVAILABLE TO COMMON SHAREHOLDERS	$ (639,979)	$ (882,707)
NET LOSS PER COMMON SHARE - Basic and diluted	$ (0.01)	$ (0.02)
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING - Basic and diluted	57,916,382	53,192,364

Statements of Changes in Sotckh

Statements of Changes in Sotckholders' Deficit - USD ($)	Series A Convertible Preferred Stock	Common Stock	Additional Paid-In Capital	Accumulated Deficit	Total
Beginning balance, value at Feb. 28, 2019	$ 710	$ 51,532	$ 22,997,759	$ (28,161,988)	$ (5,111,987)
Beginning balance, shares at Feb. 28, 2019	709,568	51,532,364
Issuance of common stock for accounts payable settlement, value		$ 2,000	4,000		6,000
Issuance of common stock for accounts payable settlement, shares		2,000,000
Forgiveness of liabilities to related parties			1,215,145		1,215,145
Recognition of warrants for investor relations services			6,879		6,879
Net loss				(754,644)	(754,644)
Ending balance, value at Feb. 29, 2020	$ 710	$ 53,532	24,223,783	(28,916,632)	(4,638,607)
Ending balance, shares at Feb. 29, 2020	709,568	53,532,364
Issuance of common stock for convertible note payable, related party, value		$ 6,959	20,876		27,835
Issuance of common stock for convertible note payable, related party, shares		6,958,758
Recognition of warrants for 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)
Ending balance, shares at Feb. 28, 2021	709,568	60,491,122

Statements of Cash Flows

Statements of Cash Flows - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$ (512,265)	$ (754,644)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Gain on forgiveness of PPP loan	(74,355)
Depreciation, depletion and amortization	60,063	55,443
Amortization of debt discount	115,272	361,583
Operating lease expense in conjunction with right of use asset	5,857	7,930
Warrant issued for investor relations services	5,897	6,879
Changes in assets and liabilities:
Accounts receivable, crude oil and natural gas sales	(52,083)	18,500
Accounts receivable, joint interest participants	(41,045)	16,517
Prepaid expenses and other current assets	54,896	11,561
Accounts payable and other accrued liabilities	152,816	153,279
Accounts payable, related parties	69,078	90,722
Operating lease liability change in conjunction with right of use asset	(5,857)	(7,930)
Accrued interest	78,200	81,451
Net cash provided by (used in) operating activities	(143,526)	41,291
CASH FLOWS FROM FINANCING ACTIVITIES
Additions to line of credit		74,000
Payments to line of credit	(60,000)	(60,000)
Proceeds from convertible note payable, related party		27,835
Insurance financing repayments	(74,553)	(19,161)
Proceeds from note payable, related party	144,619
Payments to note payable, related party	(1,410)
Proceeds from SBA PPP loan	74,355
Net cash provided by financing activities	83,011	22,674
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(60,515)	63,965
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	94,043	30,078
CASH AND CASH EQUIVALENTS AT END OF PERIOD	33,528	94,043
Cash paid for Interest	15,106	5,225
Cash paid for Income taxes
SUPPLEMENTAL CASH FLOW INFORMATION:
ARO asset and liability decrease due to changes in estimates	1,863	6,864
Unpaid additions to crude oil and natural gas properties	11,871	210
Operating lease - right-of-use assets and associated liabilities		13,787
Non-cash addition to line of credit due to monthly interest	28,503	31,548
Financing of insurance premiums	65,088	39,500
Forgiveness of liabilities to related parties credited to additional paid in capital		1,215,145
Settlement of related party debt with production revenue interest		250,100
Common stock issued for settlement of accounts payable		$ 6,000
Common stock issued on conversion of related party debt	$ 27,835

Organization and Basis of Prese

Organization and Basis of Presentation	12 Months Ended
	Feb. 28, 2021
Organization, Consolidation and Presentation of Financial Statements [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, 2021
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, 2021 and February 29, 2020 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 $29.4 million and a working capital deficit of approximately $4.2 million Management Plans to Continue as a Going Concern The Company continues to implement plans to enhance its ability to continue as a going concern. Daybreak currently has a net revenue interest in 20 producing crude oil wells in its East Slopes Project located in Kern County, California (the “East Slopes Project”). The revenue from these wells has created a steady and reliable source of revenue. The Company’s average working interest in these wells is 36.6% and the average net revenue interest is 28.4% for these same wells. 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, President Trump signed into law the Coronavirus Aid, Relief, and Economic Security Act commonly referred to as the CARES Act. 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 PPP provides funds to pay up to eight weeks of payroll costs including benefits. Funds can also be used to pay interest on mortgages, rent, and utilities. The Company applied for, and was accepted to participate in this program. The Company received funding for approximately $74,355. On February 23, 2021, the SBA notified our lender that the loan was forgiven in full. 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 and our project in Michigan. However given the current decline and instability in hydrocarbon prices, the timing of any drilling activity in California will be dependent on a sustained improvement in hydrocarbon prices and success in securing financing for the Company’s drilling program. The Company believes that our liquidity will improve when there is a sustained improvement in hydrocarbon prices. Daybreak’s sources of funds in the past have included the debt or equity markets and the sale of assets. While the Company has experienced 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, 2021 and February 29, 2020 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, 2021
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, 2021 and February 29, 2020. 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” The Company did not recognize any asset impairment for the twelve months ended February 28, 2021 and February 29, 2020. 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 Fixed assets are stated at cost. Depreciation on vehicles is provided using the straight-line method over expected useful lives of three years. Depreciation on machinery and equipment is provided using the straight-line method over expected useful life of three years. Depreciation of production facilities and natural gas pipelines are recorded using the unit-of-production method based on estimated reserves. 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, 2021 and February 29, 2020, 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. 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, 2021 and February 29, 2020, this one individual customer represented 100.0% of crude oil sales receivable from operations. If this buyer is unable to resell its products or if they lose a significant sales contract then the Company may incur difficulties in selling its crude oil production. The Company’s accounts receivable in California for crude oil sales at February 28, 2021 and February 29, 2020, respectively are set forth in the table below. February 28, 2021 February 29, 2020 Project Customer Accounts Receivable Crude Oil Sales Percentage Accounts Receivable Crude Oil Sales Percentage California – East Slopes Project (Crude oil) Plains Marketing $ 108,993 100.0 % $ 56,910 100.0 % 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, 2021
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 $108,993 and $56,910 at February 28, 2021 and February 29, 2020, represent crude oil sales that occurred in February 2021 and 2020, respectively. Joint interest participant receivables balances of $79,411 and $38,366 at February 28, 2021 and February 29, 2020, respectively, represent amounts due from working interest partners in California, where the Company is the Operator. There were no allowances for doubtful accounts for the Company’s trade accounts receivable at February 28, 2021 and February 29, 2020.

Crude Oil Properties

Crude Oil Properties	12 Months Ended
	Feb. 28, 2021
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Crude Oil Properties	NOTE 5 — CRUDE OIL PROPERTIES: Crude oil property balances at February 28, 2021 and February 29, 2020 are set forth in the table below: February 28, 2021 February 29, 2020 Proved leasehold costs $ 115,119 $ 115,119 Unproved leasehold costs 55,978 55,978 Costs of wells and development 2,291,924 2,278,190 Capitalized exploratory well costs 1,341,494 1,341,494 Total cost of oil and gas properties 3,804,515 3,790,781 Accumulated depletion, depreciation amortization and impairment (3,192,081 ) (3,136,068 ) Oil and gas properties, net $ 612,434 $ 654,713 For the twelve months ended February 28, 2021 and February 29, 2020, the Company recognized depletion expense of $56,013 and $51,025, respectively which is included in DD&A in the statement of operations.

Asset Retirement Obligation (AR

Asset Retirement Obligation (ARO)	12 Months Ended
	Feb. 28, 2021
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, 2021 and February 29, 2020, 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, 2021 and February 29, 2020, the Company recognized accretion expense of $4,050 and $4,418, respectively which is included in DD&A in the statements of operations. Changes in the asset retirement obligations for the twelve months ended February 28, 2021 and February 29, 2020 are set forth in the table below. February 28, 2021 February 29, 2020 Asset retirement obligation, beginning of period $ 27,149 $ 29,595 Accretion expense 4,050 4,418 Revisions to asset retirement obligation 1,863 (6,864 ) Asset retirement obligation, end of period $ 33,062 $ 27,149

Accounts Payable

Accounts Payable	12 Months Ended
	Feb. 28, 2021
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 million liability 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. Approximately $244,849 of the $1.5 million default remains unpaid and is included in the February 28, 2021 and February 29, 2020 accounts payable balance. Payment of this liability has been delayed until the Company’s cash flow situation improves. On October 17, 2018, a working interest partner in California filed a UCC financing statement in regards to payables owed to the partner by the Company. At February 28, 2021 and February 29, 2020, the balance owed this working interest partner was $88,905 and $101,544, respectively and is included in the accounts payable balances.

Accounts Payable - Related Part

Accounts Payable - Related Parties	12 Months Ended
	Feb. 28, 2021
Related Party Transactions [Abstract]
Accounts Payable - Related Parties	NOTE 8 — ACCOUNTS PAYABLE- RELATED PARTIES: The February 28, 2021 and February 29, 2020 accounts payable – related parties balances of $988,966 and $919,888, respectively, were comprised primarily of deferred salaries of one of the Company’s Executive Officers and certain employees; directors’ fees; expense reimbursements; and deferred interest payments on a 12% Subordinated Notes owed to the Company’s Chairman, President and Chief Executive Officer. On August 22, 2019, an agreement was reached between the Company and the Company’s Chairman, President and Chief Executive Officer whereby all deferred salary owed by the Company to this related party was forgiven. The agreement has an effective date of June 1, 2019. This agreement resulted in a decrease of approximately $882,043 in net salary payable from the prior related party payables balance. This agreement also resulted in a decrease of $123,414 in estimated payroll taxes from accounts payable balances. Additionally, on August 22, 2019 the three non-employee directors of the Company to whom director fees were owed agreed to forgive 50% (fifty percent) of the amounts owed to each individual director. These agreements had an effective date of June 1, 2019 and resulted in a reduction of $209,688 in the related party payables balance. The total amount of liability forgiveness was approximately $1.2 million and was recorded as an addition to additional paid in capital (APIC) for the twelve months ended February 29, 2020. Payment of any other deferred items has been delayed until the Company’s cash flow situation improves.

Short-Term and Long-Term Borrow

Short-Term and Long-Term Borrowings	12 Months Ended
	Feb. 28, 2021
Debt Disclosure [Abstract]
Short-Term and Long-Term Borrowings	NOTE 9 — SHORT-TERM AND LONG-TERM BORROWINGS: Note Payable – Related Party On December 22, 2020, the Company entered into a Secured Promissory Note (the “ Note Noteholder 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, 2021 and February 29, 2020 are set forth in the table below: February 28, 2021 February 29, 2020 Note payable – related party, current portion $ 8,598 $ — Unamortized debt issuance expenses (728 ) — Note payable – related party, current portion, net $ 7,870 $ — Note payable –related party long-term balances at February 28, 2021 and February 29, 2020 are set forth in the table below: February 28, 2021 February 29, 2020 Note payable – related party, non-current $ 145,540 $ — Unamortized debt issuance expenses (10,080 ) — Note payable– related party, non-current, net $ 135,460 $ — Future estimated payments on the outstanding note payable - related party are set forth in the table below: Twelve month periods ending February 28/29 2022 $ 8,598 2023 8,829 2024 9,065 2025 9,309 2026 9,558 Thereafter 108,779 Total $ 154,138 Convertible Note Payable – Related Party During the twelve months ended February 29, 2020, the Company’s Chairman, President and Chief Executive Officer loaned the Company $27,835 for general operating expenses under a Convertible Note Purchase Agreement. The Note had a maturity date of 180 days, or July 12, 2020 and carried no interest, fees or penalties. On July 13, 2020, the note payable was converted to 6,958,758 shares of the Company’s common stock. The note payable had a conversion price of $0.004 per share. 12% Subordinated Notes The Company’s 12% Subordinated Notes (“the Notes”) issued pursuant to a January 2010 private placement offering to accredited investors, resulted in $595,000 in gross proceeds (of which $250,000 was from a related party) to the Company and accrue interest at 12% per annum, payable semi-annually on January 29th and July 29th. On January 29, 2015, the Company and 12 of the 13 holders of the Notes agreed to extend the maturity date of the Notes for an additional two years to January 29, 2017. Effective January 29, 2017, the maturity date of the Notes was extended for an additional two years to January 29, 2019. The 980,000 warrants held by ten noteholders expired on January 29, 2019. 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 was payable in full at the amended maturity date of the Notes, and has not been paid. Interest continues to accrue on the unpaid $565,000 principal balance. The terms of the Notes, state that should the Board of Directors, on any future maturity date, decide that the payment of the principal and any unpaid interest would impair the financial condition or operations of the Company, the Company may then elect a mandatory conversion of the unpaid principal and interest into the Company’s common stock at a conversion rate equal to 75% of the average closing price of the Company’s common stock over the 20 consecutive trading days preceding December 31, 2018. The accrued interest on the 12% Notes at February 28, 2021 and February 29, 2020 was $340,042 and $272,428, respectively. 12% Note balances at February 28, 2021 and February 29, 2020 are set forth in the table below: February 28, 2021 February 29, 2020 12% Subordinated notes - third party $ 315,000 $ 315,000 12% Subordinated notes - related party 250,000 250,000 Net 12% Subordinated Note balance $ 565,000 $ 565,000 The accrued interest 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 The Company has an existing $890,000 line of credit for working capital purposes with UBS Bank USA (“UBS”), established pursuant to a Credit Line Agreement dated October 24, 2011 that is secured by the personal guarantee of our President and Chief Executive Officer. On July 10, 2017, a $700,000 portion of the outstanding credit line balance was converted to a 24-month fixed term annual interest rate of 3.244% with interest payable monthly. On July 10, 2019, the 24-month fixed term loan amount of $700,000 was renewed at the same annual percentage interest rate of 3.244% for an additional 24 months. The remaining balance of the credit line has a stated reference rate of 0.249% + 337.5 basis points with interest payable monthly. The reference rate is based on the 30-day LIBOR (“London Interbank Offered Rate”) and is subject to change from UBS. During the twelve months ended February 28, 2021 and February 29, 2020, we received advances on the line of credit of $-0- and $74,000, respectively. During the twelve months ended February 28, 2021 and February 29, 2020, the Company made payments to the line of credit of $60,000 and $60,000, respectively. Interest converted to principal for the twelve months ended February 28, 2021 and February 29, 2020 was $28,503 and $31,548, respectively. At February 28, 2021 and February 29, 2020, the line of credit had an outstanding balance of $840,904 and $872,401, respectively. Note Payable In December 2018, the Company was able to settle an outstanding balance owed to one of its third-party vendors. This settlement resulted in a $120,000 note payable being issued to the vendor. Additionally, the Company agreed to issue 2,000,000 shares of the Company’s common stock as a part of the settlement agreement. Based on the closing price of the Company’s common stock on the date of the settlement agreement, the value of the common stock transaction was determined to be $6,000. The common stock shares were issued during the twelve months ended February 29, 2020. The note has a maturity date of January 1, 2022 and bears an interest rate of 10% rate per annum. Monthly interest is accrued and payable on January 1 st Production Revenue Payable Since December 2018, the Company has been conducting a fundraising program to fund the drilling of future wells in California and Michigan 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 and Michigan 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 that had been loaned to the Company during the fiscal years ended February 29, 2012 and February 28, 2013. Pursuant to the Note Payoff Agreement, the Company issued a production payment interest in certain of the Company’s production revenue from the drilling of future wells in California and Michigan. The production payment interest was granted for a deemed consideration amount of the balance of the Notes. The grant was made on the same terms as the Company has sold production payment interests to other third parties in the 2018-2019 fiscal year pursuant to its previously disclosed program. As of February 28, 2021 and February 29, 2020, the production revenue payment program balance was $950,100, respectively, of which $550,100, respectively, was owed to a related party - the Company’s Chairman, President and Chief Executive Officer. The production payment interest entitles the purchasers to receive production payments equal to twice their original amount paid, payable from a percentage of the Company’s future net production payments from wells drilled after the date of the purchase and until the Production Payment Target (as described below) is met. The Company shall pay fifty percent (50%) of its net production payments from the relevant wells to the purchasers until each purchaser has received two times the purchase price (the “Production Payment Target”). Once the Company pays the purchasers amounts equal to the Production Payment Target, it shall thereafter pay a pro-rated eight percent (8%) of $1.3 million on its net production payments from the relevant wells to each of the purchasers. However, if the total raised is less than the target $1.3 million, then the payment will be a proportionate amount of the eight percent (8%). Additionally, if the Production Payment Target is not met within the first three years, the Company shall pay seventy-five percent (75%) of its production payments from the relevant wells to the purchasers until the Production Payment Target is met. At February 28, 2021, 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 has been recognized as a production revenue payable. The Company determined an effective interest rate based on future expected cash flows to be paid to the holders of the production payment interests. This rate represents the discount rate that equates estimated cash flows with the initial proceeds received from the sales and is used to compute the amount of interest to be recognized each period. Estimating the future cash outflows under this agreement requires the Company to make certain estimates and assumptions about future revenues and payments and such estimates are subject to significant variability. Therefore, the estimates are likely to change which may result in future adjustments to the accretion of the interest expense and the amortized cost based carrying value of the related payables. Accordingly, the Company has estimated the cash flows associated with the production revenue payments and determined a discount of $1,050,158 as of February 28, 2021, which is being accounted as interest expense over the estimated period over which payments will be made based on expected future revenue streams. For the twelve months ended February 28, 2020 and February 29, 2020, amortization of the debt discount on these payables amounted to $115,151 and $361,583, respectively, which has been included in interest expense in the statements of operations. Production revenue payable balances at February 28, 2020 and February 29, 2020 are set forth in the table below: February 28, 2021 February 29, 2020 Estimated payments of production revenue payable $ 2,000,258 $ 2,054,766 Less: unamortized discount (496,836 ) (666,495 ) 1,503,422 1,388,271 Less: current portion (111,753 ) (43,069 ) Net production revenue payable – long term $ 1,391,669 $ 1,345,202 Paycheck Protection Program (PPP) Loan On March 27, 2020, President Trump signed into law the Coronavirus Aid, Relief, and Economic Security Act commonly referred to as the CARES Act. One component of the CARES Act was the first draw 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 PPP provides funds to pay up to eight weeks of payroll costs including benefits. Funds can also be used to pay interest on mortgages, rent, and utilities. We applied for, and were accepted to participate in this program. On May 11, 2020, we received funding for $74,355. We used all the loan proceeds to partially subsidize direct payroll expenses. The loan is a two-year loan with a maturity date of May 5, 2022. The loan bears an annual interest rate of 1%. The loan shall be payable monthly with the first six monthly payments deferred. On February 12, 2021, we applied for loan forgiveness under the provisions of Section 1106 of the CARES Act. Loan forgiveness is subject to the sole approval of the SBA. On February 23, 2021, the SBA notified our lender that the loan was forgiven in full. On March 4, 2021, we applied for, and were accepted to participate in the SBA Second Draw PPP program. On March 15, 2021, we received funding for $72,800. It is the Company’s intent to apply for loan forgiveness for the Second Draw PPP loan. Loan forgiveness is subject to the sole approval of the SBA. The Company is eligible for loan forgiveness in an amount equal to payments made during the 24-week period beginning on the loan date, with the exception that no more than 25.0% of the amount of loan forgiveness may be for certain expenses other than payroll expenses. We intend to use all the loan proceeds to partially subsidize direct payroll expenses. 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. As of February 28, 2021, we had no encumbrances on our crude oil project in Michigan.

Leases

Leases	12 Months Ended
	Feb. 28, 2021
Leases [Abstract]
Leases	NOTE 10 — LEASES: The Company leases approximately 988 rentable square feet of office space from an unaffiliated third party for our corporate office located in Spokane Valley, Washington. Additionally, we lease approximately 416 and 695 rentable square feet from unaffiliated third parties for our regional operations office in Friendswood, Texas and storage and auxiliary office space in Wallace, Idaho, respectively. The lease in Friendswood is a 12-month lease that expires in October 2021 and as such is considered a short-term lease. The Company has elected to not apply the recognition requirements of ASC 842 to this short-term lease. The Spokane Valley and Wallace leases are currently on a month-to-month basis. The Company’s lease agreements do not contain any residual value guarantees, restrictive covenants or variable lease payments. The Company has not entered into any financing leases. The Balance Sheet classification of lease assets and liabilities was as follows: February 28, 2021 February 29, 2020 Assets Operating lease right-of use assets, beginning balance $ 5,857 $ 13,787 Current period amortization (5,857 ) (7,930 ) Total operating lease right-of-use asset — 5,857 Liabilities Operating lease liability – current — 5,857 Operating lease liability – long-term — — Total lease liabilities $ — $ 5,857 Rent expense for the twelve months ended February 28, 2021 and February 29, 2020 was $23,589 and $23,489, respectively.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Feb. 28, 2021
Related Party Transactions [Abstract]
Related Party Transactions	NOTE 11 — RELATED PARTY TRANSACTIONS: 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. Mr. Anderson received approximately $9,000 from Great Earth Power during the twelve months ended February 28, 2021. 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. Mr. Anderson received approximately $2,440 from ABPlus Net Holdings during the twelve months ended February 28, 2021.

Stockholders' Deficit

Stockholders' Deficit	12 Months Ended
	Feb. 28, 2021
Equity [Abstract]
Stockholders' Deficit	NOTE 12 — STOCKHOLDERS’ DEFICIT: Preferred Stock The Company is authorized to issue up to 10,000,000 shares of preferred stock with a par value of $0.001. The Company’s preferred stock may be entitled to preference over the common stock with respect to the distribution of assets of the Company in the event of liquidation, dissolution, or winding-up of the Company, whether voluntarily or involuntarily, or in the event of any other distribution of assets of the Company among its shareholders for the purpose of winding-up its affairs. The authorized but unissued shares of preferred stock may be divided into and issued in designated series from time to time by one or more resolutions adopted by the Board of Directors. The directors in their sole discretion shall have the power to determine the relative powers, preferences, and rights of each series of preferred stock. Series A Convertible Preferred Stock The Company has designated 2,400,000 shares of the 10,000,000 preferred shares as Series A Convertible Preferred Stock (“Series A Preferred”), with a $0.001 par value. In July 2006, we completed a private placement of the Series A Preferred that resulted in the issuance of 1,399,765 shares to 100 accredited investors. The following is a summary of the rights and preferences of the Series A Preferred. Voluntary Conversion: The Series A Preferred that is currently issued and outstanding is eligible to be converted by the shareholder at any time into three shares of the Company’s Common Stock. During the twelve months ended February 28, 2021 and February 29, 2020, there were no conversions of Series A Preferred. At February 28, 2021, there were 709,568 shares issued and outstanding that had not been converted into our Common Stock. As of February 28, 2021, there were 44 accredited investors who had converted 690,197 Series A Preferred shares into 2,070,591 shares of Daybreak Common Stock. The conversions of Series A Preferred that have occurred since the Series A Preferred was first issued in July 2006 are set forth in the table below. 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 — — — Totals 690,197 2,070,591 44 Automatic Conversion: The Series A Preferred shall be automatically converted into Common Stock, if the Common Stock into which the Series A Preferred is convertible, any time the Company’s Common Stock closes at or above $3.00 per share for 20 out of 30 trading days. Dividend: 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. There have been no cash or common stock dividends declared by the Board of Directors to date. Cumulative dividends earned for each twelve month period since issuance are set forth in the table below: 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 $ 2,353,639 Liquidation Preference: In the event of any liquidation, dissolution or winding up of the Company, either voluntary or involuntary, the holders of the Series A Preferred shall be entitled to receive, prior and in preference to any distribution of any of the assets or surplus funds of the Company to the holders of Common Stock by reason of their ownership thereof, and subject to the rights of any series of preferred stock that may rank on liquidation prior to the Series A Preferred, an amount equal to all accrued or declared but unpaid dividends on such shares, for each share of Series A Preferred then held by them. The remaining assets shall be distributed ratably to the holders of Common Stock and Series A Preferred on a common equivalent basis. Certain other events, as described in our Amended and Restated Articles of Incorporation, including a consolidation or merger of the Company or the disposition of the Company’s assets, may trigger the payment of the liquidation preference to the holders of Series A Preferred. Voting Rights: The holders of the Series A Preferred will vote together with the Common Stock and not as a separate class except as specifically provided or as otherwise required by law. Each share of the Series A Preferred shall have a number of votes equal to the number of shares of Common Stock then issuable upon conversion of such shares of Series A Preferred. Common Stock The Company is authorized to issue up to 200,000,000 shares of $0.001 par value Common Stock of which 60,491,122 and 53,532,364 shares were issued and outstanding as of February 28, 2021 and February 29, 2020, respectively. 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 During the twelve months ended February 28, 2021, there were 6,958,758 common stock shares issued to settle a related party note payable debt. The value of the common stock transaction was determined to be $27,835. During the twelve months ended February 29, 2020, there were 2,000,000 common stock shares issued to a third-party vendor as part of a settlement agreement for outstanding accounts payable. Based on the closing price of the Company’s common stock on the settlement agreement date, the value of the common stock transaction was determined to be $6,000. 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.

Warrants

Warrants	12 Months Ended
	Feb. 28, 2021
Equity [Abstract]
Warrants	NOTE 13 - WARRANTS: During the twelve months ended February 29, 2020 there were 2.1 million warrants issued to a third party for investor relations services. The fair value of the warrants was determined by the Black-Scholes pricing model, was $17,689, and is being amortized over the three year vesting period of the warrants. The Black-Scholes valuation encompassed the following assumptions: a risk-free interest rate of 1.68%; volatility rate of 260.23%; and a dividend yield of 0.0%. The 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, 2021 and February 29, 2020, there were 528,507 and 190,000 exercisable warrants. At February 28, 2021, the outstanding warrants have a weighted average exercise price of $0.01; a weighted average remaining life of 2.83 years, and an intrinsic value of $6,300. At February 29, 2020, both the outstanding warrants and the exercisable warrants had a weighted average exercise price of $0.01; a weighted average remaining life of 3.83 years, and an intrinsic value of -$0-. The recorded amount of warrant expense for the twelve months ended February 28, 2021 and February 29, 2020 was $5,897 and $6,879, respectively. Warrant activity for the twelve months ended February 28, 2021 and February 29, 2020 is set forth in the table below: Warrants Weighted Average Exercise Price Warrants outstanding, February 28, 2019 — $ — Changes during the twelve months ended February 29, 2020: Issued 2,100,000 0.01 Expired / Cancelled / Forfeited — Warrants outstanding, February 29, 2020 2,100,000 $ 0.01 Warrants exercisable, February 29, 2020 190,000 Changes during the twelve months ended February 28, 2021: Issued — $ 0.01 Expired / Cancelled / Forfeited — Warrants outstanding, February 28, 2021 2,100,000 $ 0.01 Warrants exercisable, February 28, 2021 528,507 $ 0.01

Income Taxes

Income Taxes	12 Months Ended
	Feb. 28, 2021
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% to 21% and modifying or limiting many business deductions. The Company has re-measured its deferred tax liabilities based on rates at which they are expected to be utilized in the future, which is generally 21%. Reconciliation between actual tax expense (benefit) and income taxes computed by applying the U.S. federal income tax rate and state income tax rate to income from continuing operations before income taxes is as follows: February 28, 2021 February 29, 2020 Computed at U.S. and state statutory rates (29.84%) $ (152,860 ) $ (225,186 ) Permanent differences 15,342 111,854 Changes in valuation allowance 137,518 113,332 Total $ — $ — Tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred liabilities are presented below: February 28, 2021 February 29, 2020 Deferred tax assets: Net operating loss carryforwards $ 5,587,416 $ 5,463,014 Oil and gas properties 63,438 50,322 Stock based compensation 66,187 66,187 Other 27,838 27,838 Less valuation allowance (5,744,879 ) (5,607,361 ) Total $ — $ — At February 28, 2021, the Company had a net operating loss (“NOL”) carryforwards for federal and state income tax purposes of approximately $18,724,586, which will begin to expire, if unused, beginning in 2024. Under the Tax Cuts and Jobs Act, the NOL portion of the loss incurred in the 2018 and 2020 period of $340,749 and $339,299, respectively, and the loss incurred for the year ended February 28, 2021 in the amount of $416,918 will not expire and will carry over indefinitely. The valuation allowance increased approximately $137,518 for the year ended February 28, 2021 and increased approximately $113,332 for the year ended February 29, 2020. Section 382 Rule of the Internal Revenue Code will place annual limitations on the Company’s NOL carryforward. 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, 2021
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, 2021. 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, 2021
Subsequent Events [Abstract]
Subsequent Events	NOTE 16 — SUBSEQUENT EVENTS: On March 15, 2021, the Company received $72,800 in funding through the second draw paycheck protection program (“PPP”) pursuant to The Economic Aid Act. The PPP is implemented by the Small Business Administration (“SBA”) with support from the Department of the Treasury. The loan is a five-year loan with a maturity date of March 6, 2026. The loan bears an annual interest rate of 1%. The monthly payment is $1,670 with the first payment due on July 6, 2022. It is the Company’s intent to apply for loan forgiveness under the provisions of the second draw PPP program. Loan forgiveness is subject to the sole approval of the SBA. The receipt of these funds will be reflected in the Company’s first quarter financial statements covering the three-month period ended May 31, 2021.

Supplementary Information for C

Supplementary Information for Crude Oil Producing Activities	12 Months Ended
	Feb. 28, 2021
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Supplementary Information for Crude Oil Producing Activities	NOTE 17 SUPPLEMENTARY INFORMATION FOR CRUDE OIL PRODUCING ACTIVITIES (UNAUDITED) Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities As of February 28, 2021 As of February 29, 2020 Proved leasehold costs Mineral Interests $ 115,119 $ 115,119 Wells, equipment and facilities 3,633,418 3,619,684 Total Proved Properties 3,748,537 3,734,803 Unproved properties Mineral Interests 55,978 55,978 Uncompleted wells, equipment and facilities — — Total unproved properties 55,978 55,978 Less accumulated depreciation, depletion amortization and impairment (3,192,081 ) (3,136,068 ) Net capitalized costs $ 612,434 $ 654,713 Costs Incurred in Oil and Gas Producing Activities 12 Months Ended 12 Months Ended February 28, 2021 February 29, 2020 Acquisition of proved properties $ — $ — Acquisition of unproved properties — 210 Development costs 11,871 — Exploration costs — — Total costs incurred $ 11,871 $ 210 Results of Operations from Oil and Gas Producing Activities 12 Months Ended 12 Months Ended February 28, 2021 February 29, 2020 Oil and gas revenues $ 404,901 $ 663,512 Production costs (187,858 ) (180,982 ) Exploration expenses (83 ) (123 ) Depletion, depreciation and amortization (60,063 ) (55,443 ) Impairment of oil properties — — Result of oil and gas producing operations before income taxes 156,897 426,964 Provision for income taxes — — Results of oil and gas producing activities $ 156,897 $ 426,964 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, 2021, 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: Oil (Barrels) Natural Gas (Mcf) BOE (Barrels) Proved reserves: February 28, 2019 454,261 — 454,261 Revisions (1) 40,003 — 40,003 Discoveries and extensions 12,726 — 12,726 Production (11,013 ) — (11,013 ) February 29, 2020 495,977 — 495,977 Revisions (2) (50,784 ) — (50,784 ) Discoveries and extensions — — — Production (10,970 ) — (10,970 ) February 28, 2021 434,223 — 434,223 (1) The revisions of previous estimates resulted from an improvement of reservoir performance offset by lower 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 lower realized crude oil prices in the energy markets. The Company’s proved reserves are set forth in the table below. Developed Undeveloped Total Reserves Oil (Bbls) BOE (Bbls) Oil (Bbls) BOE (Bbls) Oil (Bbls) BOE (Bbls) February 28, 2019 118,114 118,114 336,147 336,147 454,261 454,261 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 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, 2021 and February 29, 2020 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, 2021 and February 29, 2020 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. 12 Months Ended February 28, 2021 February 29, 2020 Future cash inflows $ 15,692,834 $ 29,585,007 Future production costs (1) (8,076,769 ) (13,481,167 ) Future development costs (2,510,625 ) (3,063,750 ) Future income tax expenses (2) — — Future net cash flows 5,105,440 13,040,090 10% annual discount for estimated timing of cash flows (3,457,022 ) (8,387,948 ) Standardized measure of discounted future net cash flows at the end of the fiscal year $ 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. Average hydrocarbon prices are set forth in the table below. Average Price Natural Crude Oil (Bbl) Gas (Mcf) Year ended February 28, 2021 (1) $ 36.91 $ — Year ended February 29, 2020 (1) $ 60.25 $ — Year ended February 28, 2019 (1) $ 63.58 $ — (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. 12 Months Ended February 28, 2021 February 29, 2020 Standardized measure of discounted future net cash flows at the beginning of the year $ 4,652,142 $ 4,916,671 Extensions, discoveries and improved recovery, less related costs — 48,310 Revisions of previous quantity estimates (287,596 ) 463,375 Net changes in prices and production costs (1,899,026 ) 57,891 Accretion of discount 465,214 491,667 Sales of oil produced, net of production costs (217,043 ) (482,530 ) Development costs incurred during the period — — Changes in future development costs 9,077 (9,152 ) Changes in timing of future production (1,074,350 ) (834,090 ) Net changes in income taxes — — Standardized measure of discounted future net cash flows at the end of the year $ 1,648,418 $ 4,652,142

Accounting Policies (Policies)

Accounting Policies (Policies)	12 Months Ended
	Feb. 28, 2021
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, 2021 and February 29, 2020.
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” The Company did not recognize any asset impairment for the twelve months ended February 28, 2021 and February 29, 2020. 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 Fixed assets are stated at cost. Depreciation on vehicles is provided using the straight-line method over expected useful lives of three years. Depreciation on machinery and equipment is provided using the straight-line method over expected useful life of three years. Depreciation of production facilities and natural gas pipelines are recorded using the unit-of-production method based on estimated reserves.
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, 2021 and February 29, 2020, 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. 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, 2021 and February 29, 2020, this one individual customer represented 100.0% of crude oil sales receivable from operations. If this buyer is unable to resell its products or if they lose a significant sales contract then the Company may incur difficulties in selling its crude oil production.
Revenue Recognition	Revenue Recognition The Company recognizes revenue under ASC 606, Revenue from Contracts with Customers
Asset Retirement Obligation	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_2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Feb. 28, 2021
Accounting Policies [Abstract]
Schedule of Concentration of Risk, by Risk Factor	February 28, 2021 February 29, 2020 Project Customer Accounts Receivable Crude Oil Sales Percentage Accounts Receivable Crude Oil Sales Percentage California – East Slopes Project (Crude oil) Plains Marketing $ 108,993 100.0 % $ 56,910 100.0 %

Crude Oil Properties (Tables)

Crude Oil Properties (Tables)	12 Months Ended
	Feb. 28, 2021
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Schedule of Crude Oil Property Balances	Crude oil property balances at February 28, 2021 and February 29, 2020 are set forth in the table below: February 28, 2021 February 29, 2020 Proved leasehold costs $ 115,119 $ 115,119 Unproved leasehold costs 55,978 55,978 Costs of wells and development 2,291,924 2,278,190 Capitalized exploratory well costs 1,341,494 1,341,494 Total cost of oil and gas properties 3,804,515 3,790,781 Accumulated depletion, depreciation amortization and impairment (3,192,081 ) (3,136,068 ) Oil and gas properties, net $ 612,434 $ 654,713

Asset Retirement Obligation (_2

Asset Retirement Obligation (ARO) (Tables)	12 Months Ended
	Feb. 28, 2021
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Changes in Asset Retirement Obligation	Changes in the asset retirement obligations for the twelve months ended February 28, 2021 and February 29, 2020 are set forth in the table below. February 28, 2021 February 29, 2020 Asset retirement obligation, beginning of period $ 27,149 $ 29,595 Accretion expense 4,050 4,418 Revisions to asset retirement obligation 1,863 (6,864 ) Asset retirement obligation, end of period $ 33,062 $ 27,149

Short-Term and Long-Term Borr_2

Short-Term and Long-Term Borrowings (Tables)	12 Months Ended
	Feb. 28, 2021
Debt Disclosure [Abstract]
Schedule of Related Party Note Payables	Note payable –related party short-term balances at February 28, 2021 and February 29, 2020 are set forth in the table below: February 28, 2021 February 29, 2020 Note payable – related party, current portion $ 8,598 $ — Unamortized debt issuance expenses (728 ) — Note payable – related party, current portion, net $ 7,870 $ — Note payable –related party long-term balances at February 28, 2021 and February 29, 2020 are set forth in the table below: February 28, 2021 February 29, 2020 Note payable – related party, non-current $ 145,540 $ — Unamortized debt issuance expenses (10,080 ) — Note payable– related party, non-current, net $ 135,460 $ —
Schedule of Future Estimated Payments	Future estimated payments on the outstanding note payable – related party are set forth in the table below: Twelve month periods ending February 28/29 2022 $ 8,598 2023 8,829 2024 9,065 2025 9,309 2026 9,558 Thereafter 108,779 Total $ 154,138
Schedule of Note Payables	12% Note balances at February 28, 2021 and February 29, 2020 are set forth in the table below: February 28, 2021 February 29, 2020 12% Subordinated notes - third party $ 315,000 $ 315,000 12% Subordinated notes - related party 250,000 250,000 Net 12% Subordinated Note balance $ 565,000 $ 565,000
Schedule of Accounts Payable and Accrued Liabilities	Production revenue payable balances at February 28, 2020 and February 29, 2020 are set forth in the table below: February 28, 2021 February 29, 2020 Estimated payments of production revenue payable $ 2,000,258 $ 2,054,766 Less: unamortized discount (496,836 ) (666,495 ) 1,503,422 1,388,271 Less: current portion (111,753 ) (43,069 ) Net production revenue payable – long term $ 1,391,669 $ 1,345,202

Leases (Tables)

Leases (Tables)	12 Months Ended
	Feb. 28, 2021
Leases [Abstract]
Schedule of Operating Lease Assets and Liabilities	The Balance Sheet classification of lease assets and liabilities was as follows: February 28, 2021 February 29, 2020 Assets Operating lease right-of use assets, beginning balance $ 5,857 $ 13,787 Current period amortization (5,857 ) (7,930 ) Total operating lease right-of-use asset — 5,857 Liabilities Operating lease liability – current — 5,857 Operating lease liability – long-term — — Total lease liabilities $ — $ 5,857

Stockholders' Deficit (Tables)

Stockholders' Deficit (Tables)	12 Months Ended
	Feb. 28, 2021
Equity [Abstract]
Schedule of Stockholder's Equity	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. 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 — — — Totals 690,197 2,070,591 44
Schedule of Dividends Payable	Cumulative dividends earned for each twelve month period since issuance are set forth in the table below: 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 $ 2,353,639
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

Warrants (Tables)

Warrants (Tables)	12 Months Ended
	Feb. 28, 2021
Equity [Abstract]
Schedule of Warrant Activity	Warrant activity for the twelve months ended February 28, 2021 and February 29, 2020 is set forth in the table below: Warrants Weighted Average Exercise Price Warrants outstanding, February 28, 2019 — $ — Changes during the twelve months ended February 29, 2020: Issued 2,100,000 0.01 Expired / Cancelled / Forfeited — Warrants outstanding, February 29, 2020 2,100,000 $ 0.01 Warrants exercisable, February 29, 2020 190,000 Changes during the twelve months ended February 28, 2021: Issued — $ 0.01 Expired / Cancelled / Forfeited — Warrants outstanding, February 28, 2021 2,100,000 $ 0.01 Warrants exercisable, February 28, 2021 528,507 $ 0.01

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Feb. 28, 2021
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation	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: February 28, 2021 February 29, 2020 Computed at U.S. and state statutory rates (29.84%) $ (152,860 ) $ (225,186 ) Permanent differences 15,342 111,854 Changes in valuation allowance 137,518 113,332 Total $ — $ —
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: February 28, 2021 February 29, 2020 Deferred tax assets: Net operating loss carryforwards $ 5,587,416 $ 5,463,014 Oil and gas properties 63,438 50,322 Stock based compensation 66,187 66,187 Other 27,838 27,838 Less valuation allowance (5,744,879 ) (5,607,361 ) Total $ — $ —

Supplementary Information for_2

Supplementary Information for Crude Oil Producing Activities (Tables)	12 Months Ended
	Feb. 28, 2021
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities	Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities As of February 28, 2021 As of February 29, 2020 Proved leasehold costs Mineral Interests $ 115,119 $ 115,119 Wells, equipment and facilities 3,633,418 3,619,684 Total Proved Properties 3,748,537 3,734,803 Unproved properties Mineral Interests 55,978 55,978 Uncompleted wells, equipment and facilities — — Total unproved properties 55,978 55,978 Less accumulated depreciation, depletion amortization and impairment (3,192,081 ) (3,136,068 ) Net capitalized costs $ 612,434 $ 654,713
Cost Incurred in Oil and Gas Producing Activities	Costs Incurred in Oil and Gas Producing Activities 12 Months Ended 12 Months Ended February 28, 2021 February 29, 2020 Acquisition of proved properties $ — $ — Acquisition of unproved properties — 210 Development costs 11,871 — Exploration costs — — Total costs incurred $ 11,871 $ 210
Results of Operations from Oil and Gas Producing Activities	Results of Operations from Oil and Gas Producing Activities 12 Months Ended 12 Months Ended February 28, 2021 February 29, 2020 Oil and gas revenues $ 404,901 $ 663,512 Production costs (187,858 ) (180,982 ) Exploration expenses (83 ) (123 ) Depletion, depreciation and amortization (60,063 ) (55,443 ) Impairment of oil properties — — Result of oil and gas producing operations before income taxes 156,897 426,964 Provision for income taxes — — Results of oil and gas producing activities $ 156,897 $ 426,964
Schedule of Proved Developed and Undeveloped Oil and Gas Reserves	Our proved reserves are summarized in the table below: Oil (Barrels) Natural Gas (Mcf) BOE (Barrels) Proved reserves: February 28, 2019 454,261 — 454,261 Revisions (1) 40,003 — 40,003 Discoveries and extensions 12,726 — 12,726 Production (11,013 ) — (11,013 ) February 29, 2020 495,977 — 495,977 Revisions (2) (50,784 ) — (50,784 ) Discoveries and extensions — — — Production (10,970 ) — (10,970 ) February 28, 2021 434,223 — 434,223 (1) The revisions of previous estimates resulted from an improvement of reservoir performance offset by lower 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 lower realized crude oil prices in the energy markets. The Company’s proved reserves are set forth in the table below. Developed Undeveloped Total Reserves Oil (Bbls) BOE (Bbls) Oil (Bbls) BOE (Bbls) Oil (Bbls) BOE (Bbls) February 28, 2019 118,114 118,114 336,147 336,147 454,261 454,261 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
Standardized Measure of Discounted Future Cash Flows Relating to Proved Oil and Gas Reserves	12 Months Ended February 28, 2021 February 29, 2020 Future cash inflows $ 15,692,834 $ 29,585,007 Future production costs (1) (8,076,769 ) (13,481,167 ) Future development costs (2,510,625 ) (3,063,750 ) Future income tax expenses (2) — — Future net cash flows 5,105,440 13,040,090 10% annual discount for estimated timing of cash flows (3,457,022 ) (8,387,948 ) Standardized measure of discounted future net cash flows at the end of the fiscal year $ 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.
Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure	Average hydrocarbon prices are set forth in the table below. Average Price Natural Crude Oil (Bbl) Gas (Mcf) Year ended February 28, 2021 (1) $ 36.91 $ — Year ended February 29, 2020 (1) $ 60.25 $ — Year ended February 28, 2019 (1) $ 63.58 $ — (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.
Schedule of Sources of Changes in Discounted Future Net Cash Flows	12 Months Ended February 28, 2021 February 29, 2020 Standardized measure of discounted future net cash flows at the beginning of the year $ 4,652,142 $ 4,916,671 Extensions, discoveries and improved recovery, less related costs — 48,310 Revisions of previous quantity estimates (287,596 ) 463,375 Net changes in prices and production costs (1,899,026 ) 57,891 Accretion of discount 465,214 491,667 Sales of oil produced, net of production costs (217,043 ) (482,530 ) Development costs incurred during the period — — Changes in future development costs 9,077 (9,152 ) Changes in timing of future production (1,074,350 ) (834,090 ) Net changes in income taxes — — Standardized measure of discounted future net cash flows at the end of the year $ 1,648,418 $ 4,652,142

Going Concern (Details Narrativ

Going Concern (Details Narrative)	12 Months Ended
	Feb. 28, 2021USD ($)Number	Feb. 29, 2020USD ($)
Accumulated deficit	$ (29,428,897)	$ (28,916,632)
Working capital deficit	4,200,000
Proceeds received from SBA's Paycheck Protection Program	74,355
Forgiveness of SBA paycheck protection program (PPP) loan	$ (74,355)
Revenue
Number of producing oil wells, net revenue interest | Number	20
Average working interest	36.60%
Average net revenue interest	28.40%

Summary of Significant Accoun_3

Summary of Significant Accounting Policies - Schedule of Concentration of Risk, by Risk Factor (Details) - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
Concentration Risk [Line Items]
Revenue receivable	$ 108,993	$ 56,910
Percent of revenue	100.00%
Customer Concentration Risk | Accounts Receivable - Crude Oil Sales | Plains Marketing (California - East Slopes Project (Crude Oil))
Concentration Risk [Line Items]
Revenue receivable	$ 108,993	$ 56,910
Percent of revenue	100.00%	100.00%

Summary of Significant Accoun_4

Summary of Significant Accounting Policies (Details Narrative)	12 Months Ended
	Feb. 28, 2021
Cash and Cash Equivalents
Federally insured/uninsured deposit, description	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.
Property and Equipment
Expected useful lives	3 years
Depreciation methods	Depreciation on vehicles is provided using the straight-line method. Depreciation on machinery and equipment is provided using the straight-line method. Depreciation of production facilities and natural gas pipelines are recorded using the unit-of-production method based on estimated reserves.
Concentration Risk
Concentration risk, customer	One individual customer
Crude oil and gas sales receivables, customer concentration	100.00%

Accounts Receivable (Details Na

Accounts Receivable (Details Narrative) - USD ($)	Feb. 28, 2021	Feb. 29, 2020
Receivables [Abstract]
Accounts receivable - crude oil and natural gas sales	$ 108,993	$ 56,910
Accounts receivable - joint interest participants	$ 79,411	$ 38,366

Crude Oil Properties - Schedule

Crude Oil Properties - Schedule of Crude Oil Property Balances (Details) - USD ($)	Feb. 28, 2021	Feb. 29, 2020
Oil and Natural Gas Property, Successful Effort Method, Net
Proved leasehold costs	$ 115,119	$ 115,119
Unproved leasehold costs	55,978	55,978
Costs of wells and development	2,291,924	2,278,190
Capitalized exploratory well costs	1,341,494	1,341,494
Total cost of oil and gas properties	3,804,515	3,790,781
Accumulated depletion, depreciation, amortization and impairment	(3,192,081)	(3,136,068)
Oil and gas properties, net	$ 612,434	$ 654,713

Crude Oil Properties (Details N

Crude Oil Properties (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Crude oil properties, depletion expense	$ 56,013	$ 51,025

Asset Retirement Obligation (_3

Asset Retirement Obligation (ARO) - Schedule of Changes in Asset Retirement Obligation (Details) - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
Asset Retirement Obligation, Roll Forward Analysis
Balance at beginning of period	$ 27,149	$ 29,595
Accretion expense	4,050	4,418
Revision to asset retirement obligation	(1,863)	(6,864)
Balance at end of period	$ 33,062	$ 27,149

Asset Retirement Obligation (_4

Asset Retirement Obligation (ARO) (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
Asset Retirement Obligation Disclosure [Abstract]
Accretion expense	$ 4,050	$ 4,418

Accounts Payable (Details Narra

Accounts Payable (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
Acquisition and disposition of East Slopes Project	On March 1, 2009, the Company became the operator for the East Slopes Project. The Company assumed certain original defaulting partners' approximate $1.5 million liability representing a 25% working interest in the drilling and completion costs associated with the East Slopes Project four earning well program. The Company subsequently sold the 25% working interest on June 11, 2009.
Accounts payable balance, approximate	$ 244,849	$ 244,849
Working Interest Partner, California
Accounts payable balance, approximate	$ 88,905	$ 101,544

Accounts Payable - Related Pa_2

Accounts Payable - Related Parties (Details Narrative) - USD ($)	12 Months Ended
	Feb. 29, 2020	Feb. 28, 2019	Feb. 28, 2021
Related Party Transactions [Abstract]
Accounts payable, related parties	$ 919,888		$ 988,966
Decrease in related party payable		$ (882,043)
Decrease in estimated payroll taxes		(123,414)
Reduction in related party payable		$ (209,688)
Forgiveness of liabilities to related parties, approximate	$ 1,200,000

Short-Term and Long-Term Borr_3

Short-Term and Long-Term Borrowings - Schedule of Related Party Note Payables (Details) - USD ($)	Feb. 28, 2021	Feb. 29, 2020
Note payable, related party, current portion	$ 7,870
Note payable, related party, non-current	135,460
Note Payable - Related Party, Long-Term Balances
Note payable, related party, non-current	145,540
Unamortized debt issuance expenses	(10,080)
Note payable, related party, non-current	135,460
Note Payable - Related Party, Short-Term Balances
Note payable, related party, current portion	8,598
Unamortized debt issuance expenses	(728)
Note payable, related party, current portion, net	$ 7,870

Short-Term and Long-Term Borr_4

Short-Term and Long-Term Borrowings - Schedule of Future Estimated Payments (Details)	Feb. 28, 2021USD ($)
Twelve month periods ending February 28/29
2022	$ 8,598
2023	8,829
2024	9,065
2025	9,309
2026	9,558
Thereafter	108,779
Total	$ 154,138

Short-Term and Long-Term Borr_5

Short-Term and Long-Term Borrowings - Schedule of Subordinated Notes (Details) - USD ($)	Feb. 28, 2021	Feb. 29, 2020
Debt Instrument [Line Items]
12% Subordinated notes	$ 315,000	$ 315,000
12% Subordinated notes, related party	250,000	250,000
12% Subordinated Notes
Debt Instrument [Line Items]
12% Subordinated notes	315,000	315,000
12% Subordinated notes, related party	250,000	250,000
Net 12% Subordinated Note balance	$ 565,000	$ 565,000

Short-Term and Long-Term Borr_6

Short-Term and Long-Term Borrowings - Schedule of Production Revenue Payable Balances (Details) - USD ($)	Feb. 28, 2021	Feb. 29, 2020
Debt Disclosure [Abstract]
Estimated payments of production revenue payable	$ 2,000,258	$ 2,054,766
Less: unamortized discount	(496,836)	(666,495)
Production revenue payable, net	1,503,422	1,388,271
Less: current portion	(111,753)	(43,069)
Net production revenue payable, long-term	$ 1,391,669	$ 1,345,202

Short-Term and Long-Term Borr_7

Short-Term and Long-Term Borrowings (Details Narrative) - USD ($)		Mar. 15, 2021	Feb. 28, 2021	Feb. 29, 2020	Feb. 28, 2019	Feb. 28, 2018	Feb. 28, 2017	Feb. 28, 2010	Feb. 29, 2012
Subordinated note			$ 315,000	$ 315,000
Amortization of debt discount			115,272	361,583
Credit facility, advances				74,000
Line of credit, amount outstanding			840,904	872,401
Payments on line of credit			60,000	60,000
Notes payable, related party			7,870
Settlement of debt				250,100
Proceeds from convertible debt				$ 27,835
Proceeds received from SBA's Paycheck Protection Program			$ 74,355
SBA Paycheck Protection Program
Interest rate			1.00%
Maturity date			May 5, 2022
Proceeds received from SBA's Paycheck Protection Program			$ 74,355
Loan, maturity date			May 5, 2022
Loan, interest rate			1.00%
SBA Paycheck Protection Program | Subsequent Event
Maturity date		Mar. 6, 2026
Proceeds received from SBA's Paycheck Protection Program		$ 72,800
Loan, maturity date		Mar. 6, 2026
Third-Party Vendors
Interest rate					10.00%
Maturity date					Jan. 1, 2022
Note 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
Accrued interest			$ 26,000	14,000
Loan, maturity date					Jan. 1, 2022
Loan, interest rate					10.00%
Production Payment Program
Amortization of debt discount			115,151	361,583
Fundraising program, description					The Company has been conducting a fundraising program to fund the drilling of future wells in California and Michigan and to settle some of its historical debt. The investors in this program are offered a production revenue payment on future wells to be drilled in California and Michigan in exchange for their investment. The production payment interests entitle the purchasers to a return of twice their original investment and a percentage of the Company's future net production payments from wells drilled after the date of the agreement and before the Production Payment Target is met. The Company shall pay fifty percent of its net production payments from the relevant wells to the purchasers until each purchaser has received two times the purchase price (the "Production Payment Target"). Once the Company pays the purchasers amounts equal to the Production Payment Target, it shall thereafter pay a pro-rated eight percent (8%) of $1.3 million on its net production payments from the relevant wells to each of the purchasers. However, if the total raised is less than the target $1.3 million, then the payment will be a proportionate amount of the eight percent (8%). Additionally, if the Production Payment Target is not met within the first three years, the Company shall pay seventy-five percent of its production payments from the relevant wells to the purchasers until the Production Payment Target is met.
Production revenue payable	[1]		950,100	950,100
Interest expense on production revenue payments	[2]		1,050,158
Line of Credit | UBS Bank USA
Maximum borrowing									$ 890,000
Credit facility, advances			0	74,000
Line of credit, amount outstanding			840,904	872,401		$ 700,000
Payments on line of credit			60,000	60,000
Line of credit, interest converted to to principal			$ 28,503	$ 31,548
Line of credit, interest rate description				On July 10, 2019, $700,000 was renewed at the same annual percentage interest rate of 3.244% with interest payable monthly. The remaining balance of the credit line has a stated reference rate of 0.249% + 337.5 basis points with interest payable monthly. The reference rate is based on the 30 day LIBOR (“London Interbank Offered Rate”) and is subject to change from UBS.		On July 10, 2017, $700,000 portion of the outstanding credit line balance was converted to a 24-month fixed term annual interest rate of 3.244% with interest payable monthly.
Chief Executive Officer
Settlement of debt				$ 250,100
Secured Promissory Note
Interest rate			2.50%
Maturity date			Dec. 21, 2035
Amortization expense			$ 121
Proceeds from issuance of secured debt			155,548
Loan fees			10,929
Net proceeds from borrowing			$ 144,619
Secured debt, collateral			Secured by a lien on and security interest in the Company’s oil and gas assets located in Kern County, California, as described in a deed of trust entered into by the Company in favor of the Noteholder to secure the obligations under the Note. Such lien shall be a first priority lien, subject only to a pre-existing lien filed by a working interest partner of the Company.
Principal payments			$ 1,410
Loan, maturity date			Dec. 21, 2035
Loan, interest rate			2.50%
Convertible Debt | Chief Executive Officer
Proceeds from convertible debt				$ 27,835
Convertible note payable converted into common stock				6,958,758
Conversion price				$ 0.004
12% Subordinated Notes
Interest rate								12.00%
Maturity date							Jan. 29, 2019	Jan. 29, 2017
Payment terms								Payable semi-annually on January 29th and July 29th. Should the Board of Directors, on any future maturity date, decide that the payment of the principal and any unpaid interest would impair the financial condition or operations of the Company, the Company may then elect a mandatory conversion of the unpaid principal and interest into the Company’s common stock at a conversion rate equal to 75% of the average closing price of the Company’s common stock over the 20 consecutive trading days preceding December 31, 2018.
Proceeds from subordinate notes								$ 595,000
Subordinated note			$ 315,000	$ 315,000
Subordinate note, principal balance			565,000	565,000
Warrants expired					980,000
Note payable					$ 565,000
Accrued interest			$ 340,042	$ 272,428
Loan, maturity date							Jan. 29, 2019	Jan. 29, 2017
Loan, interest rate								12.00%
[1]	$550,100 is owed to related party
[2]	Interest expense over the estimated period over which payments will be made based on expected future revenue streams.

Leases - Schedule of Operating

Leases - Schedule of Operating Lease Assets and Liabilities (Details) - USD ($)	Feb. 28, 2021	Feb. 29, 2020
Assets
Total operating lease right-of-use asset		$ 5,857
Liabilities
Operating lease liability, current		5,857
Operating Lease Right-Of-Use Asset
Assets
Operating lease right-of-use assets, beginning balance	$ 5,857	13,787
Current period amortization	(5,857)	(7,930)
Total operating lease right-of-use asset	0	5,857
Operating Lease Liabilities
Liabilities
Operating lease liability, current	0	5,857
Operating lease liability, long-term	0
Total lease liabilities	$ 0	$ 5,857

Leases (Details Narrative)

Leases (Details Narrative)	12 Months Ended
	Feb. 28, 2021USD ($)ft²	Feb. 29, 2020USD ($)
Rent expense | $	$ 23,589	$ 23,489
Spokane Valley, Washington
Leased properties, square feet	988
Friendswood, Texas
Leased properties, square feet	416
Lease, term of contract	12 months
Wallace, Idaho
Leased properties, square feet	695

Related Party Transactions (Det

Related Party Transactions (Details Narrative)	12 Months Ended
	Feb. 28, 2021
Related Party Transactions [Abstract]
Related party transactions	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. Mr. Anderson received approximately $9,000 from Great Earth Power during the twelve months ended February 28, 2021. 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. Mr. Anderson received approximately $2,440 from ABPlus Net Holdings during the twelve months ended February 28, 2021.

Stockholders' Deficit - Convers

Stockholders' Deficit - Conversions of Series A Preferred Stock (Details)	12 Months Ended
	Feb. 28, 2021Numbershares	Feb. 29, 2020Numbershares	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
Series A preferred shares converted to common stock	690,197
Shares of common stock issued from conversion	2,070,591
Accredited investors | Number	44
Series A Convertible Preferred Stock
Series A preferred shares converted to common stock	0	0	14,997	0	10,000	3,000	151,000	18,000	0	102,000	51,900	237,000	102,300
Shares of common stock issued from conversion	0	0	44,991	0	30,000	9,000	453,000	54,000	0	306,000	155,700	711,000	306,900
Accredited investors | Number	0	0	1	0	1	1	9	2	0	4	4	12	10

Stockholders' Deficit - Preferr

Stockholders' Deficit - Preferred Stock Dividends Earned (Details)	12 Months Ended
	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]
Preferred shareholders at period end | Number	56	56	56	56	57	57	58	59	68	70	70	74	78	90	100
Earned dividends	$ 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
Total accumulated dividends	$ 2,353,639

Stockholders' Deficit - Schedul

Stockholders' Deficit - Schedule of Common Stock Outstanding (Details) - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
Class of Stock [Line Items]
Common stock, Issued and Outstanding, beginning of period	53,532,364
Issuance of common stock to settle accounts payable	6,958,758
Common stock, Issued and Outstanding, end of period	60,491,122	53,532,364
Issuance of common stock to settle accounts payable, par value	$ 6,959
Issuance of common stock to settle related party note payable, par value	$ 27,835
Common Stock
Class of Stock [Line Items]
Common stock, Issued and Outstanding, beginning of period	53,532,364	51,532,364
Issuance of common stock to settle accounts payable		2,000,000
Issuance of common stock to settle related party note payable	6,958,758
Common stock, Issued and Outstanding, end of period		53,532,364
Issuance of common stock to settle accounts payable, par value		$ 2,000
Issuance of common stock to settle related party note payable, par value	$ 6,959

Stockholders' Deficit (Details

Stockholders' Deficit (Details Narrative)	1 Months Ended	12 Months Ended
	Jul. 31, 2006Numbershares	Feb. 28, 2021USD ($)Number$ / sharesshares	Feb. 29, 2020USD ($)Number$ / sharesshares	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	Feb. 28, 2019shares
Preferred stock, par value in dollars | $ / shares		$ 0.001	$ 0.001
Preferred stock, shares authorized		10,000,000	10,000,000
Preferred stock, shares issued		0	0
Preferred stock, shares outstanding		0	0
Series A preferred shares converted to common stock		690,197
Shares of common stock issued from conversion		2,070,591
Accredited investors | Number		44
Common stock, par value in dollars | $ / shares		$ 0.001	$ 0.001
Common stock, shares authorized		200,000,000	200,000,000
Common stock, shares issued		60,491,122	53,532,364
Common stock, shares outstanding		60,491,122	53,532,364
Third-Party Vendors
Shares issued as part of accounts payable settlement			2,000,000
Shares issued as part of accounts payable settlement, value | $			$ 6,000
Private Placement
Accredited investors | Number	100
Number of shares issued in private placement	1,399,765
Series A Convertible Preferred Stock
Preferred stock, par value in dollars | $ / shares		$ 0.001	$ 0.001
Preferred stock, shares authorized		2,400,000	2,400,000
Preferred stock, shares issued		709,568	709,568
Preferred stock, shares outstanding		709,568	709,568
Series A preferred shares converted to common stock		0	0	14,997	0	10,000	3,000	151,000	18,000	0	102,000	51,900	237,000	102,300
Shares of common stock issued from conversion		0	0	44,991	0	30,000	9,000	453,000	54,000	0	306,000	155,700	711,000	306,900
Preferred stock, cumulative dividend rate		6.00%	6.00%
Accredited investors | Number		0	0	1	0	1	1	9	2	0	4	4	12	10
Common Stock
Common stock, shares outstanding			53,532,364												51,532,364
Shares issued as part of accounts payable settlement		6,958,758
Shares issued as part of accounts payable settlement, value | $		$ 27,835

Warrants - Schedule of Warrant

Warrants - Schedule of Warrant Activity (Details) - $ / shares	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Warrants outstanding, beginning of period	2,100,000
Issued		2,100,000
Warrants outstanding, end of period	2,100,000	2,100,000
Warrants exercisable, end of period	528,507	190,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date
Weighted average exercise price of warrants outstanding, beginning of period	$ 0.01
Weighted average exercise price, Issued	0.01	0.01
Weighted average exercise price of warrants outstanding, end of period	0.01	$ 0.01
Weighted average exercise price of warrants exercisable, end of period	$ 0.01

Warrants - Schedule of Warran_2

Warrants - Schedule of Warrant Activity (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
Fair value of warrants	$ 5,897	$ 6,879
Third Party
Warrants issued for investor relations services		2,100,000
Fair value of warrants		$ 17,689
Risk free interest rate		1.68%
Volatility rate		260.23%
Dividend yield		0.00%
Vesting period		3 years
Vesting description		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.
Warrants expiration		Jan. 2, 2024
Weighted average exercise price	$ 0.01	$ 0.01
Warrants exercisable	528,507	190,000
Remaining life (years)	2 years 11 months	3 years 10 months
Intrinsic value	$ 6,300	$ 0
Warrant expense	$ 5,897	$ 6,879

Income Taxes - Reconciliation B

Income Taxes - Reconciliation Between Actual Tax Expense Benefit and Income Tax Computed by Applying Income Tax Rate (Details) - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
Income Tax Expense Benefit Continuing Operations Income Tax Reconciliation
Computed at U.S. and state statutory rates	$ (152,860)	$ (225,186)
Permanent differences	15,342	111,854
Changes in valuation allowance	137,518	113,332
Income tax expense (benefit)	$ 0	$ 0

Income Taxes - Schedule of Defe

Income Taxes - Schedule of Deferred Tax Assets and Liabilities (Details) - USD ($)	Feb. 28, 2021	Feb. 29, 2020
Deferred tax assets:
Net operating loss carryforwards	$ 5,587,416	$ 5,463,014
Oil and gas properties	63,438	50,322
Stock based compensation	66,187	66,187
Other	27,838	27,838
Less valuation allowance	(5,744,879)	(5,607,361)
Deferred tax assets, net	$ 0	$ 0

Income Taxes (Details Narrative

Income Taxes (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020	Feb. 28, 2019
Net operating loss carryforwards, federal and state, approximate	$ 18,724,586
Net operating loss carryforwards, expiration date	Feb. 28, 2024
Operating loss carryforwards, not subject to expiration	$ 416,918
Increase (Decrease) in valuation allowance, approximate	$ 137,518	$ 113,332
Tax Cuts and Jobs Act
Reduction in corporate income tax rate		21.00%	35.00%
Net operating loss carryforwards, federal and state, approximate		$ 339,299	$ 340,749

Subsequent Events (Details Narr

Subsequent Events (Details Narrative) - USD ($)	Mar. 15, 2021	Feb. 28, 2021
Subsequent Event [Line Items]
Proceeds received from SBA's Paycheck Protection Program		$ 74,355
SBA Paycheck Protection Program
Subsequent Event [Line Items]
Proceeds received from SBA's Paycheck Protection Program		$ 74,355
Maturity date		May 5, 2022
Subsequent Event | SBA Paycheck Protection Program
Subsequent Event [Line Items]
Proceeds received from SBA's Paycheck Protection Program	$ 72,800
Maturity date	Mar. 6, 2026
Interest rate	1.00%
Monthly payment	$ 1,670

Supplementary Information - Cap

Supplementary Information - Capitalized Costs Relating to Oil and Gas Producing Activities (Details) - USD ($)	Feb. 28, 2021	Feb. 29, 2020
Proved leasehold costs
Mineral Interests	$ 115,119	$ 115,119
Wells, equipment and facilities	3,633,418	3,619,684
Total Proved Properties	3,748,537	3,734,803
Unproved properties
Mineral Interests	55,978	55,978
Uncompleted wells, equipment and facilities	0	0
Total unproved properties	55,978	55,978
Less accumulated depreciation, depletion amortization and impairment	(3,192,081)	(3,136,068)
Net capitalized costs	$ 612,434	$ 654,713

Supplementary Information - Cos

Supplementary Information - Cost Incurred in Oil and Gas Producing Activities (Details) - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
Costs Incurred Acquisition Of Oil And Gas Properties
Acquisition of proved properties	$ 0	$ 0
Acquisition of unproved properties	0	210
Development costs	11,871	0
Exploration costs	0	0
Total costs incurred	$ 11,871	$ 210

Supplementary Information - Res

Supplementary Information - Results of Operations from Oil and Gas Producing Activities (Details) - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
Results Of Operations From Oil And Gas Producing Activities
Oil and gas revenues	$ 404,901	$ 663,512
Production costs	(187,858)	(180,982)
Exploration expenses	(83)	(123)
Depletion, depreciation and amortization	(60,063)	(55,443)
Impairment of oil properties	0	0
Result of oil and gas producing operations before income taxes	156,897	426,964
Provision for income taxes	0	0
Results of oil and gas producing activities	$ 156,897	$ 426,964

Supplementary Information - Sch

Supplementary Information - Schedule of Proved Oil and Gas Reserves (Details)	12 Months Ended
	Feb. 28, 2021BoebblMcf		Feb. 29, 2020BoebblMcf
Proved Developed and Undeveloped Reserves
Proved reserves - beginning balance | bbl	495,977		454,261
Proved reserves - ending balance | bbl	434,223		495,977
Proved Developed and Undeveloped Reserve (Energy)
Proved reserves - beginning balance | Boe	495,977		454,261
Proved reserves - ending balance | Boe	434,223		495,977
Oil (Barrels)
Proved Developed and Undeveloped Reserves
Proved reserves - beginning balance | bbl	495,977		454,261
Proved reserves - revisions | bbl	(50,784)	[1]	40,003	[2]
Proved reserves - discoveries and extensions | bbl	0		12,726
Proved reserves - production | bbl	10,970		11,013
Proved reserves - ending balance | bbl	434,223		495,977
Natural Gas (Mcf)
Proved Developed and Undeveloped Reserves
Proved reserves - beginning balance | Mcf	0		0
Proved reserves - revisions | Mcf	0		0
Proved reserves - discoveries and extensions | Mcf	0		0
Proved reserves - production | Mcf	0		0
Proved reserves - ending balance | Mcf	0		0
BOE (Barrels)
Proved Developed and Undeveloped Reserve (Energy)
Proved reserves - beginning balance | Boe	495,977		454,261
Proved reserves - revisions | Boe	(50,784)	[1]	40,003	[2]
Proved reserves - discoveries and extensions | Boe	0		12,726
Proved reserves - production | Boe	10,970		11,013
Proved reserves - ending balance | Boe	434,223		495,977
[1]	The revisions of previous estimates resulted from an decrease in the estimated economic life of the reservoirs due to lower realized crude oil prices in the energy markets.
[2]	The revisions of previous estimates resulted from an improvement of reservoir performance offset by lower realized crude oil prices in the energy markets.

Supplementary Information - S_2

Supplementary Information - Schedule of Proved Developed and Undeveloped Reserves (Details)	Feb. 28, 2021Boebbl	Feb. 29, 2020Boebbl	Feb. 28, 2019Boebbl
Reserve Quantities [Line Items]
Proved developed and undeveloped reserves, net | bbl	434,223	495,977	454,261
Proved developed and undeveloped reserves, net - BOE | Boe	434,223	495,977	454,261
Proved Developed Reserves
Reserve Quantities [Line Items]
Proved developed reserves | bbl	95,120	113,779	118,114
Proved developed reserves - BOE | Boe	95,120	113,779	118,114
Proved Undeveloped Reserves
Reserve Quantities [Line Items]
Proved undeveloped reserves | bbl	339,103	382,198	336,147
Proved undeveloped reserves - BOE | Boe	339,103	382,198	336,147

Supplementary Information - Sta

Supplementary Information - Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves (Details) - USD ($)		Feb. 28, 2021	Feb. 29, 2020	Feb. 28, 2019
Discounted Future Net Cash Flows Relating To Proved Oil And Gas Reserves Standardized Measure
Future cash inflows		$ 15,692,834	$ 29,585,007
Future production costs	[1]	(8,076,769)	(13,481,167)
Future development costs		(2,510,625)	(3,063,750)
Future income tax expenses	[2]	0	0
Future net cash flows		5,105,440	13,040,090
10% annual discount for estimated timing of cash flows		(3,457,022)	(8,387,948)
Standardized measure of discounted future net cash flows at the end of the fiscal year		$ 1,648,418	$ 4,652,142	$ 4,916,671
[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 - Oil

Supplementary Information - Oil and Gas Net Production, Average Sales Price and Production Costs (Details) - $ / PerUnit		12 Months Ended
		Feb. 28, 2021	Feb. 29, 2020	Feb. 28, 2019
Crude Oil (Bbl)
Oil and Gas, Average Sale Price and Production Cost Per Unit [Line Items]
Average oil and gas sales price	[1]	36.91	60.25	63.58
Natural Gas
Oil and Gas, Average Sale Price and Production Cost Per Unit [Line Items]
Average oil and gas sales price		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 - S_3

Supplementary Information - Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows (Details) - USD ($)	12 Months Ended
	Feb. 28, 2021	Feb. 29, 2020
Sources Of Changes In Standardized Measure Of Discounted Future Net Cash Flow Relating To Proved Oil And Gas Reserves [Roll Forward]
Standardized measure of discounted future net cash flows at the beginning of the year	$ 4,652,142	$ 4,916,671
Extensions, discoveries and improved recovery, less related costs	0	48,310
Revisions of previous quantity estimates	(287,596)	463,375
Net changes in prices and production costs	(1,899,026)	57,891
Accretion of discount	465,214	491,667
Sales of oil produced, net of production costs	(217,043)	(482,530)
Development costs incurred during the period	0	0
Changes in future development costs	9,077	(9,152)
Changes in timing of future production	(1,074,350)	(834,090)
Net changes in income taxes	0	0
Standardized measure of discounted future net cash flows at the end of the year	$ 1,648,418	$ 4,652,142