Daybreak Oil and Gas (DBRM) 10-K 23 Jan 24 2023 FY Annual report Financial data

Cover

Cover - USD ($)	12 Months Ended
	Feb. 28, 2023	Jan. 23, 2024	Aug. 31, 2022
Cover [Abstract]
Document Type	10-K
Amendment Flag	false
Document Annual Report	true
Document Transition Report	false
Document Period End Date	Feb. 28, 2023
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2023
Current Fiscal Year End Date	--02-28
Entity File Number	000-50107
Entity Registrant Name	DAYBREAK OIL AND GAS, INC.
Entity Central Index Key	0001164256
Entity Tax Identification Number	91-0626366
Entity Incorporation, State or Country Code	WA
Entity Address, Address Line One	1414 S. Friendswood Drive
Entity Address, Address Line Two	Suite 212
Entity Address, City or Town	Friendswood
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77546
City Area Code	(281)
Local Phone Number	996-4176
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			$ 2,821,727
Entity Common Stock, Shares Outstanding		384,734,902
Auditor Firm ID	206
Auditor Name	MaloneBailey, LLP
Auditor Location	Houston, Texas

Balance Sheets

Balance Sheets - USD ($)	Feb. 28, 2023	Feb. 28, 2022
CURRENT ASSETS:
Cash and cash equivalents	$ 299,410	$ 139,573
Restricted cash	275,000
Accounts receivable:
Crude oil sales	131,510	117,727
Joint interest participants	353,009	85,339
Prepaid expenses and other current assets	95,034	74,012
Total current assets	1,153,963	416,651
OIL AND GAS PROPERTIES, successful efforts method, net
Proved developed properties	5,126,200	536,032
Prepaid drilling costs	16,452	16,452
Vehicles and Equipment, net	3,416	6,569
Goodwill – crude oil and natural gas properties	1,415,361
Total long-term assets	6,561,429	559,053
Total assets	7,715,392	975,704
CURRENT LIABILITIES:
Accounts payable and other accrued liabilities	2,129,208	1,649,119
Accounts payable – related parties	21,937	49,228
Revenue payable	192,341
Accrued interest	185,508	176,229
Accrued expenses	250,000
Note payable	120,000	120,000
Note payable – related party, current, net of unamortized discount of $728 and $729, respectively	8,337	8,100
Convertible Note payable, related party		200,000
12% Note payable	290,000	315,000
Line of credit		808,182
Production revenue payable, current, net of unamortized discount	56,915	78,877
Total current liabilities	3,254,246	3,404,735
LONG TERM LIABILITIES:
Note payable – related party, net of current portion and net of unamortized discount of $8,620 and $9,350, respectively	119,023	127,360
Production revenue payable, net of current portion and net of unamortized discount	816,366	738,248
Asset retirement obligation	315,509	52,565
Total long-term liabilities	1,250,898	918,173
Total liabilities	4,505,144	4,322,908
STOCKHOLDERS’ EQUITY (DEFICIT):
Common Stock- 500,000,000 shares authorized; $0.001 par value, 384,734,902 and 67,802,273 shares issued and outstanding, respectively	384,734	67,802
Additional paid-in capital	34,785,207	26,115,450
Accumulated deficit	(31,959,693)	(29,530,456)
Total stockholders’ equity (deficit)	3,210,248	(3,347,204)
Total liabilities and stockholders’ equity (deficit)	$ 7,715,392	$ 975,704

Balance Sheets (Parenthetical)

Balance Sheets (Parenthetical) - USD ($)	Feb. 28, 2023	Feb. 28, 2022
Statement of Financial Position [Abstract]
Unamortized discount, current	$ 728	$ 729
Unamortized discount, noncurrent	$ 8,620	$ 9,350
Common stock, shares authorized	500,000,000	500,000,000
Common stock, par value	$ 0.001	$ 0.001
Common stock, shares issued	384,734,902	67,802,273
Common stock, shares outstanding	384,734,902	67,802,273

Statements of Operations

Statements of Operations - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
REVENUE:
Natural gas sales	$ 1,613,286	$ 680,107
Total crude oil and natural gas sales	1,613,286	680,107
OPERATING EXPENSES:
Production	1,103,825	231,275
Exploration and drilling		56,213
Depreciation, depletion and amortization	504,118	49,590
Impairment of crude oil and natural gas properties	711,873	0
Transaction expenses	573,472
General and administrative	1,004,011	603,808
Total operating expenses	3,897,299	940,886
OPERATING LOSS	(2,284,013)	(260,779)
OTHER INCOME (EXPENSE):
Interest expense, net	(145,224)	(220,085)
Gain on asset disposal		9,614
Gain on debt forgiveness – SBA paycheck protection program (PPP) loan		72,800
Total other expenses	(145,224)	(137,671)
NET LOSS AVAILABLE TO COMMON SHAREHOLDERS	$ (2,429,237)	$ (398,450)
NET LOSS PER COMMON SHARE
Basic and diluted	$ (0.01)	$ (0.01)
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING
Basic and diluted	312,312,114	61,548,414
Crude Oil Sales
REVENUE:
Natural gas sales	$ 1,533,260	$ 680,107
Total crude oil and natural gas sales	1,533,260	680,107
Natural Gas Sales
REVENUE:
Natural gas sales	80,026
Total crude oil and natural gas sales	$ 80,026

Statements of Changes in Stockh

Statements of Changes in Stockholders' Deficit - USD ($)	Series A Convertible Preferred Stock	Common Stock	Additional Paid-In Capital	Accumulated Deficit	Total
Beginning balance, value at Feb. 28, 2021	$ 710	$ 60,491	$ 24,250,556	$ (29,428,897)	$ (5,117,140)
Shares outstanding at Feb. 28, 2021	709,568	60,491,122
Conversion of accrued employee salaries		$ 1,398	627,649	52,530	681,577
Conversion of accrued employee salaries, shares		1,397,880
Conversion of accrued director fees		$ 318	142,651		142,969
Conversion of accrued director fees, shares		317,708
Conversion of 12% Note principal and interest – related party		$ 1,144	513,842		514,986
Conversion of 12% Note principal and interest - related party, shares		1,144,415
Conversion of production revenue program principal – related party		$ 1,222	548,878		550,100
Conversion of production revenue program principal - related party, shares		1,222,444
Conversion of Series A preferred stock	$ (710)	$ 2,129	(1,419)
Conversion of Series A preferred stock, shares	(709,568)	2,128,704
Conversion of Series A accumulated dividend		$ 1,100	28,380	(29,480)
Conversion of Series A accumulated dividend, shares		1,100,000
Investor relations services			4,913		4,913
Debt forgiveness accrued salary - related party				53,125	53,125
Debt forgiveness production revenue program interest – related party				232,170	232,170
Settlement of receivables and payables – related party				(11,454)	(11,454)
Net Loss				(398,450)	(398,450)
Conversion of 12% Note principal and interest		79
Conversion of convertible note
Acquisition of crude oil and natural gas properties
Shares issued for financing fees
Ending balance, value at Feb. 28, 2022		$ 67,802	26,115,450	(29,530,456)	(3,347,204)
Shares outstanding at Feb. 28, 2022	0	67,802,273
Conversion of 12% Note principal and interest - related party, shares		78,934
Net Loss				(2,429,237)	(2,429,237)
Conversion of 12% Note principal and interest		$ 79	35,441		35,520
Conversion of 12% Note principal and interest, shares		78,934
Conversion of convertible note		$ 27,765	208,235		236,000
Conversion of Convertible Note, shares		27,764,706
Acquisition of crude oil and natural gas properties		$ 160,964	6,438,580		6,599,544
Acquisition of oil and gas property, shares		160,964,489
Sale of common stock		$ 125,000	1,862,500		1,987,500
Sale of common stock, shares		125,000,000
Shares issued for financing fees		$ 3,125	125,000		128,125
Shares issued for financing fees, shares		3,125,000
Adjustment to common stock		$ (1)	1
Sale of common stock, shares		(500)
Ending balance, value at Feb. 28, 2023		$ 384,734	$ 34,785,207	$ (31,959,693)	$ 3,210,248
Shares outstanding at Feb. 28, 2023	0	384,734,902

Statements of Cash Flows

Statements of Cash Flows - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$ (2,429,237)	$ (398,450)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Common stock shares issued as an incentive	128,125
Gain on forgiveness of PPP 2nd draw		(72,800)
Depreciation, depletion and amortization	504,088	49,590
Impairment of proved crude oil properties	711,873	0
Impairment of unproved crude oil properties		55,978
Amortization of debt discount	56,885	96,703
Warrants issued for investor relations services		4,913
Changes in assets and liabilities:
Accounts receivable – crude oil and natural gas sales	235,034	(8,734)
Accounts receivable - joint interest participants	(267,670)	(5,928)
Prepaid expenses and other current assets	(21,022)	68,449
Accounts payable and other accrued liabilities	784,819	52,922
Accounts payable - related parties	(27,291)	64,153
Accrued interest	(9,279)	79,848
Net cash used in operating activities	(315,117)	(13,356)
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to crude oil and natural gas properties	(417,248)	(6,772)
Acquisition of crude oil and natural gas properties	31,088
Purchase of fixed asset (used pickup truck)		(9,460)
Net cash used in investing activities	(386,160)	(16,232)
CASH FLOWS FROM FINANCING ACTIVITIES:
Payments to line of credit	(808,182)	(60,000)
Proceeds from sale of Common Stock	1,987,500
Proceeds from convertible note payable		200,000
Insurance financing repayments	(34,375)	(68,568)
Payments to note payable – related party	(8,829)	(8,599)
Proceeds from SBA PPP 2nd draw loan and 1st draw loans, respectively		72,800
Net cash provided by financing activities	1,136,114	135,633
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	434,837	106,045
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	139,573	33,528
CASH AND CASH EQUIVALENTS AT END OF PERIOD	574,410	139,573
CASH PAID FOR:
Interest	33,431	14,446
Income taxes
SUPPLEMENTAL CASH FLOW INFORMATION:
Common stock issued for conversion of 12% Subordinated Note	35,520
Common stock issued for conversion of convertible Note	236,000
Common stock issued for acquisition of crude oil and natural gas property	6,599,544
Goodwill from acquisition of O&G properties	1,415,361
ARO asset and liability increase due to acquisition of crude oil and natural gas properties	79,622
ARO asset and liability increase due to changes in estimates	159,477	10,929
Non-cash addition to line of credit due to monthly interest		27,278
Financing of insurance premiums		81,154
Forgiveness of production revenue payable interest		232,170
Settlement of accrued employee salaries credited to common stock, APIC and accumulated deficit		681,577
Settlement of accrued director fees credited to common stock and APIC		142,969
Settlement of 12% Note – related party credited to common stock and APIC		514,986
Settlement of production revenue program – related party credited to paid in capital		550,100
Settlement of Series A accumulated dividend credited to additional paid in capital		28,380
Common stock issued for conversion of Series A preferred stock		710
Common stock issued for Series A preferred accumulated dividend		1,100
Debt forgiveness of related party accrued gross salary and employer payroll taxes		53,125
Settlement of related party receivables and payables		11,454
Reclassification of related party accounts payable to accounts payable		$ 66,719

ORGANIZATION AND BASIS OF PRESE

ORGANIZATION AND BASIS OF PRESENTATION	12 Months Ended
	Feb. 28, 2023
Accounting Policies [Abstract]
ORGANIZATION AND BASIS OF PRESENTATION	NOTE 1 — ORGANIZATION AND BASIS OF PRESENTATION Originally incorporated as Daybreak Uranium, Inc., (“Daybreak Uranium”) on March 11, 1955, under the laws of the State of Washington, Daybreak Uranium was organized to explore for, acquire, and develop mineral properties in the Western United States. In August 1955, the assets of Morning Sun Uranium, Inc. were acquired by Daybreak Uranium. In May 1964, Daybreak Uranium changed its name to Daybreak Mines, Inc. In March 2005, management of the Company decided to enter the crude oil and natural gas exploration, development and production industry. On October 25, 2005, the Company’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 and natural gas 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 and natural gas. These commodity prices are subject to wide fluctuations and market uncertainties due to a variety of factors that are beyond the control of the Company. These factors include the level of global demand for petroleum products, foreign supply of crude oil and natural gas, the establishment of and compliance with production quotas by 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 or international pandemics like the coronavirus outbreak.

GOING CONCERN

GOING CONCERN	12 Months Ended
	Feb. 28, 2023
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, 2023, and February 28, 2022 have been prepared on a going concern basis, which contemplates the realization of assets and the settlement of liabilities in the normal course of business. Daybreak has incurred net losses since inception and has accumulated a deficit of approximately $ 31.96 $ 2.1 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 10 36.6 28.4 50.0 40 On May 25, 2022, the Company finalized the acquisition of Reabold California, LLC (“Reabold”) from a third party for 160,964,489 6,599,544 263,619 Approximately 82% or 51,054,229 shares of the Company’s 62,510,204 issued and outstanding shares of the Company’s Common Stock were present or represented by proxy at the meeting. The proposal for the Reabold acquisition was passed with over a 99.6% approval vote. At the special shareholders meeting held on May 20, 2022, approval was also granted to Amend and Restate the Company’s Articles of Incorporation. This allowed for the increase in the number of authorized Common Stock shares of the Company from 200,000,000 shares to 500,000,000 shares. In conjunction with the Company’s efforts to acquire Reabold, and as a condition of closing the acquisition, the Company was to secure a capital raise of $2,500,000 through the issuance of shares of the Company’s Common Stock. 128,125,000 3,125,000 The Company anticipates revenue will continue to increase as the Company participates in the drilling of more wells in the East Slopes and Reabold projects in California. Daybreak’s sources of funds in the past have included the debt or equity markets and the sale of assets. While the Company has experienced periodic revenue growth, which has resulted in positive cash flow from its crude oil and natural gas properties, it has not yet established a positive cash flow on a company-wide basis. It will be necessary for the Company to obtain additional funding from the private or public debt or equity markets in the future. However, the Company cannot offer any assurance that it will be successful in executing the aforementioned plans to continue as a going concern. Daybreak’s financial statements as of February 28, 2023, and February 28, 2022 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, 2023
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	NOTE 3 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES 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. 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. Restricted Cash Restricted cash balances include amounts posted with regulatory authorities for reclamation bonds related to the Company’s crude oil and natural gas operations in California. 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 and natural gas 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. Trade accounts receivable are generally not collateralized. There were no allowances for doubtful accounts for the Company’s trade accounts receivable at February 28, 2023 and February 28, 2022. Crude Oil and Natural Gas Properties The Company uses the successful efforts method of accounting for crude oil and natural gas property acquisition, exploration, development, and production activities. Costs to acquire mineral interests in crude oil and natural gas properties, to drill and equip exploratory wells that find proved reserves, and to drill and equip development wells are capitalized as incurred. Costs to drill exploratory wells that are unsuccessful in finding proved reserves are expensed as incurred. In addition, the geological and geophysical costs, and costs of carrying and retaining unproved properties are expensed as incurred. Costs to operate and maintain wells and field equipment are expensed as incurred. Capitalized proved property acquisition costs are amortized by field using the unit-of-production method based on estimated proved reserves. Capitalized exploration well costs and development costs (plus estimated future dismantlement, surface restoration, and property abandonment costs, net of equipment salvage values) are amortized in a similar fashion (by field) based on their estimated proved developed reserves. Support equipment and other property and equipment are depreciated over their estimated useful lives. Pursuant to the provisions of Financial Accounting Standards Codification (“ASC”) Topic 360, “Property, Plant and Equipment” For the twelve months ended February 28, 2023, the Company recognized an impairment charge of $ 711,873 For the twelve months ended February 28, 2022, the Company recognized an impairment of unproved properties in Michigan and wrote down the entire $ 55,978 On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated DD&A with a resulting gain or loss recognized in income. Property and Equipment Vehicles Machinery and Equipment Fixed assets are stated at cost. Depreciation on vehicles is provided using the straight-line method over expected useful lives of three three Long Lived Assets The Company reviews the carrying value of 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) through recognition of impairment. Fair Value Measurements ASC Topic 820, Fair Value Measurements and Disclosures, defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. Fair value is defined as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. To increase consistency and comparability in fair value measurements and related disclosures, ASC Topic 820 also established a fair value hierarchy that prioritizes the relative reliability of inputs used in fair value measurements. We are required to maximize the use of observable inputs and minimize the use of observable inputs when measuring fair value. The hierarchy describes three levels of inputs that may be used to measure fair value: Level 1 – Quoted prices in active markets for identical assets and liabilities. Level 2 - Observable inputs other than Level 1 prices, such as quoted prices for similar assets or liabilities; or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities. Level 3 – Unobservable inputs that are supported by little or no market activity and that are financial instruments whose are determined using pricing models, discounted cash flow methodologies, or similar techniques, as well as instruments for which the determination of fair value requires significant judgment or estimation. ASC Topic 820 requires that an entity give consideration to the credit risk of its counterparties, as well as its own credit risk, when measuring financial assets and liabilities at fair value. Asset acquisitions are recorded on the closing date of the transaction at their fair value, which is determined by applying market and income approached using level 3 inputs. Fair Value of Financial Instruments The Company’s carrying value of short-term financial instruments including cash, restricted cash, receivables, prepaid expenses, accounts payable, and other accrued liabilities, short-term liabilities and credit lines 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. The Company’s financial instruments consist of cash, restricted cash, accounts receivable, accounts payable, notes payable and loans. The carrying amount of these financial instruments approximates their fair value due either to length of maturity or interest rates that approximate prevailing market rates unless otherwise disclosed in these financial statements. The Company has no financial assets or liabilities that are measured at fair value on a recurring basis as of February 28, 2023. 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 The Company follows ASC Topic 260, Earnings per Share Concentration of Credit Risk Substantially all of the Company’s trade accounts receivable result from crude oil and natural gas 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 including crude oil and natural gas prices as well as other related factors. Trade accounts receivable are generally not collateralized. Customer Concentration Accounts Receivable At both the Company’s projects in California there is only one buyer for the purchase of all crude oil production. At February 28, 2023 and February 28, 2022, this one individual customer represented 100 At the Reabold project wells in Contra Costs County, California there is also natural gas production that the Company sells to a single buyer. At February 28, 2023, this one individual customer per project represented 100 The Company’s accounts receivable for California crude oil and natural gas sales at February 28, 2023 and February 28, 2022 are set forth in the table below: Summary of Significant Accounting Policies - Schedule of Concentration of Risk, by Risk Factor February 28, 2023 February 28, 2022 Project Customer Accounts Receivable Percentage Accounts Receivable Percentage California – East Slopes project (crude oil) Plains Marketing $ 55,900 42.5 % $ 117,727 100.0 % California – Reabold project (crude oil) Plains Marketing 59,614 45.3 % — — California – Reabold project (natural gas) CRC 15,996 12.2 % — — Totals $ 131,510 100.0 % $ 117,727 100.0 % Joint interest participant receivables balances of $ 353,009 85,339 Revenue Recognition The Company recognizes revenue under ASC 606, Revenue from Contracts with Customers does not include any payments for services or ancillary items other than for the sale of crude oil and natural gas. Revenue is recorded in the month crude oil and natural gas production is delivered to the purchaser. 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. 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, 2023
Receivables [Abstract]
ACCOUNTS RECEIVABLE	NOTE 4 — ACCOUNTS RECEIVABLE Accounts receivable consists primarily of receivables from the sale of crude oil and natural gas production by the Company and receivables from the Company’s working interest partners in crude oil and natural gas projects in which the Company acts as Operator of the project. Crude oil and natural gas sales receivables balances of $ 131,510 117,727 Joint interest participant receivables balances of $ 353,009 85,339 There were no allowances for doubtful accounts for the Company’s trade accounts receivable at February 28, 2023, and February 28, 2022.

CRUDE OIL PROPERTIES

CRUDE OIL PROPERTIES	12 Months Ended
	Feb. 28, 2023
Extractive Industries [Abstract]
CRUDE OIL PROPERTIES	NOTE 5 — CRUDE OIL PROPERTIES Crude oil property balances at February 28, 2023, and February 28, 2022 are set forth in the table below: Crude Oil Properties - Schedule of Crude Oil Activities February 28, 2023 February 28, 2022 Proved leasehold costs $ 115,119 $ 115,119 Costs of wells and development 6,915,982 2,309,628 Capitalized exploratory well costs 1,341,494 1,341,494 Property, plant and equipment (Reabold) 320,217 — Cost of crude oil and natural gas properties 8,692,812 3,766,241 Accumulated depletion, depreciation amortization and impairment (3,566,612 ) (3,230,209 ) Total crude oil and natural gas properties, net $ 5,126,200 $ 536,032 For the twelve months ended February 28, 2023 and February 28, 2022, the Company recognized depletion expense of $ 477,089 38,125 711,873 0

ACQUISITION

ACQUISITION	12 Months Ended
	Feb. 28, 2023
Business Combination and Asset Acquisition [Abstract]
ACQUISITION	NOTE 6 – ACQUISITION On May 25, 2022, the Company finalized the acquisition of Reabold from a third party for 160,964,489 6,599,544 6,863,163 263,619 Cash $ 19,706 Restricted cash – O&G operator bonds 275,000 Accounts receivable 248,817 Crude oil and natural gas property and equipment 4,694,563 Property, plant and equipment, net 428,221 Goodwill 1,415,361 Accounts payable (152,854 ) Revenue payable (62,914 ) Other liabilities assumed (2,737 ) Purchase price, net of closing adjustments $ 6,863,163 Adjustments made to the Reabold assets are derived from a total value of $ 6,599,544 160,964,489 0.041 6,863,163 6,599,544 263,619 5,447,802 218,505 5,666,307 1,415,361 6,863,163 5,447,802 445,529

ASSET RETIREMENT OBLIGATION (_A

ASSET RETIREMENT OBLIGATION (“ARO”)	12 Months Ended
	Feb. 28, 2023
Asset Retirement Obligation Disclosure [Abstract]
ASSET RETIREMENT OBLIGATION (“ARO”)	NOTE 7 — 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, 2023 and February 28, 2022, 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, 2023, and February 28, 2022, the Company recognized accretion expense of $ 23,875 8,574 Changes in the asset retirement obligations for the twelve months ended February 28, 2023, and February 28, 2022 are set forth in the table below. Asset Retirement Obligation (“ARO”) - Schedule of Changes in the Asset Retirement Obligations February 28, 2023 February 28, 2022 Asset retirement obligation, beginning of period $ 52,565 $ 33,062 Accretion expense 23,875 8,574 Revisions to asset retirement obligation 239,069 10,929 Asset retirement obligation, end of period $ 315,509 $ 52,565

ACCOUNTS PAYABLE

ACCOUNTS PAYABLE	12 Months Ended
	Feb. 28, 2023
Payables and Accruals [Abstract]
ACCOUNTS PAYABLE	NOTE 8 — ACCOUNTS PAYABLE On March 1, 2009, the Company became the operator for the East Slopes Project located in Kern County, California. Additionally, the Company then assumed certain original defaulting partners’ approximate $ 1.5 representing a 25% working interest in the drilling and completion costs associated with the East Slopes Project four earning wells program. The Company subsequently sold the 25% working interest on June 11, 2009 244,849 1.5 63,367 76,268

ACCOUNTS PAYABLE - RELATED PART

ACCOUNTS PAYABLE - RELATED PARTIES	12 Months Ended
	Feb. 28, 2023
Accounts Payable - Related Parties
ACCOUNTS PAYABLE - RELATED PARTIES	NOTE 9 — ACCOUNTS PAYABLE - RELATED PARTIES The February 28, 2023, and February 28, 2022 accounts payable – related party balances of $ 21,937 49,228 In California at the East Slopes Project, two of the vendors that the Company uses for services are partially owned by a related party, the Company’s Chief Operating Officer. The Company’s Chief Operating Officer is 50% owner in both Great Earth Power (“Great Earth”) and ABPlus Net Holdings (“ABPlus”). Great Earth began providing a portion of the solar power electrical service for production operations in July 2020. ABPlus began providing portable tank rentals to the Company as a part of its water treatment and disposal operations in September 2020. The services provided by Great Earth and ABPlus are competitive with other vendors and save the Company significant expense. For the twelve months ended February 28, 2023, and February 28, 2022, Great Earth provided services valued at $ 15,663 20,300 11,520 613 1,400 960

SHORT-TERM AND LONG-TERM BORROW

SHORT-TERM AND LONG-TERM BORROWINGS	12 Months Ended
	Feb. 28, 2023
Debt Disclosure [Abstract]
SHORT-TERM AND LONG-TERM BORROWINGS	NOTE 10 — SHORT-TERM AND LONG-TERM BORROWINGS Note Payable In December 2018, the Company was able to settle an outstanding balance owed to one of its third-party vendors. This settlement resulted in a $ 120,000 2,000,000 6,000 January 1, 2022 10 st 26,000 38,000 Note Payable – Related Party Secured Debt Chief Executive Officer On December 22, 2020, the Company entered into a Secured Promissory Note (the “ Note Noteholder 155,548 10,929 144,619 2.25 December 21, 2035 8,829 729 The Company may prepay the Note at any time. Upon the occurrence of any Event of Default and expiration of any applicable cure period, and at any time thereafter during the continuance of such Event of Default, the Noteholder may at its option, by written notice to the Company: (a) declare the entire principal amount of the Note, together with all accrued interest thereon and all other amounts payable hereunder, immediately due and payable; (b) exercise any of its remedies with respect to the collateral set forth in the Deed of Trust; and/or (c) exercise any or all of its other rights, powers or remedies under applicable law. Current portion of note payable –related party balances at February 28, 2023, and February 28, 2022 are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Related Party Notes Payable February 28, 2023 February 28, 2022 Note payable – related party, current portion $ 9,065 $ 8,829 Unamortized debt issuance expenses (728 ) (729 ) Note payable – related party, current portion, net $ 8,337 $ 8,100 Note payable –related party long-term balances at February 28, 2023 and February 28, 2022 are set forth in the table below: February 28, 2023 February 28, 2022 Note payable – related party, non-current $ 127,645 $ 136,710 Unamortized debt issuance expenses (8,622 ) (9,350 ) Note payable – related party, non-current, net $ 119,023 $ 127,360 Future estimated payments on the outstanding note payable – related party are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Future Estimated Payments Twelve month periods ending February 28/29, 2024 9,065 2025 9,309 2026 9,558 2027 9,815 2028 10,078 Thereafter 88,885 Total $ 136,710 Short-term Convertible Note Payable Convertible Debt During the twelve months ended February 28, 2022, the Company executed a convertible promissory note with a third party for $ 200,000 18 36,000 0.0085 27,764,706 12% Subordinated Notes Private Placement Subordinated Debt The Company’s 12% Subordinated Notes (the “Notes”) issued pursuant to a January 2010 private placement offering to accredited investors, had a balance at February 28, 2023 and February 28, 2022 of $ 290,000 315,000 The original maturity date of January 29, 2015 had been extended to January 29, 2017 and then was extended to January 29, 2019. 12 The Company has informed the Note holders that the payment of principal and interest will be late and is subject to future financing being completed and the Company’s cash flow. The Notes principal of $ 290,000 159,508 135,229 During the twelve months ended February 28, 2023, one 12% Note holder chose to convert the principal balance and accrued interest into the Company’s Common Stock. The $ 25,000 10,520 0.45 78,934 12% Note balances at February 28, 2023 and February 28, 2022 are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Subordinated Notes 12% Subordinated Notes Related Party Notes February 28, 2023 February 28, 2022 12% Subordinated notes – third party $ 290,000 $ 315,000 12% subordinated notes – related party — — 12% Subordinated notes balance $ 290,000 $ 315,000 Line of Credit Line of Credit At February 28, 2022, the Company had an existing $ 890,000 secured by the personal guarantee of our President and Chief Executive Officer On May 26, 2022, the Company paid off the outstanding balance of $ 809,930 0 808,182 During the twelve months ended February 28, 2022, the Company made payments to the line of credit of $ 60,000 27,278 Production Revenue Payable During the twelve months ended February 28, 2019, and February 29, 2020, the Company conducted a fundraising program to raise $1.3 million to fund the drilling of future wells in California and to settle some of its existing historical debt. The purchasers of a production payment interest are to receive a production revenue payment interest on future wells to be drilled in California in exchange for their purchase. The Company shall pay seventy-five percent (75%) of its future net production revenue 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 purchaser group 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 the purchaser group. However, if the total raise amount is less than the target $1.3 million, then the payment will be a proportionate amount of the eight percent (8%) 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 $ 873,281 Accordingly, the Company has estimated the cash flows associated with the production revenue payments and determined a discount of $ 78,136 56,156 95,974 Production revenue payable balances at February 28, 2023 and February 28, 2022 are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Production Revenue Payable Balances February 28, 2023 February 28, 2022 Estimated payments of production revenue payable $ 913,395 $ 941,259 Less: unamortized discount (40,114 ) (124,134 ) 873,281 817,125 Less: current portion (56,915 ) (78,877 ) Net production revenue payable – long term $ 816,366 $ 738,248 Encumbrances On October 17, 2018, a working interest partner in California filed a UCC financing statement in regards to payable amounts owed to the partner by the Company. On December 22, 2020, the Company entered into a Secured Promissory Note (the “Westmoreland Note”), as borrower, with James Forrest Westmoreland and Angela Marie Westmoreland, Co-Trustees of the James and Angela Westmoreland Revocable Trust, or its assigns (the “Noteholder”), as the lender. James F. Westmoreland is the Company’s Chairman, President and Chief Executive Officer. Pursuant to the Westmoreland Note, the Noteholder loaned the Company an aggregate principal amount of $ 155,548

LEASES

LEASES	12 Months Ended
	Feb. 28, 2023
Leases
LEASES	NOTE 11 — LEASES Daybreak formally leased approximately 988 416 695 Rent expense for the twelve months ended February 28, 2023 and February 28, 2022 was $ 23,889 23,489

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	12 Months Ended
	Feb. 28, 2023
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	NOTE 12 — RELATED PARTY TRANSACTIONS In California at the East Slopes Project, two of the vendors that the Company uses for services are partially owned by a related party, the Company’s Chief Operating Officer, Bennett Anderson. Mr. Anderson is a 50% owner in both Great Earth Power (“Great Earth”) and ABPlus Net Holdings (“ABPlus”). Great Earth began providing a portion of the solar power electrical service for production operations in July 2020. ABPlus began providing portable tank rentals to the Company as a part of its water treatment and disposal operations in September 2020. The services provided by Great Earth and ABPlus are competitive with other vendors and save the Company significant expense. For the twelve months ended February 28, 2023, and February 28, 2022, Great Earth provided services valued at $ 15,663 20,300 11,520 613 1,400 960

STOCKHOLDERS_ EQUITY (DEFICIT)

STOCKHOLDERS’ EQUITY (DEFICIT)	12 Months Ended
	Feb. 28, 2023
Equity [Abstract]
STOCKHOLDERS’ EQUITY (DEFICIT)	NOTE 13 — STOCKHOLDERS’ EQUITY (DEFICIT) Preferred Stock With the filing of the Company’s Second Amended and Restated Articles of Incorporation with the Washington Secretary of State in May 2022, the Company no longer has any preferred stock. The Company has only one class of stock, which is Common Stock. Series A Convertible Preferred Stock At February 28, 2022, there were no issued or outstanding shares of Series A Preferred stock that had not been converted into our Common Stock. With the filing of the Company’s Second Amended and Restated Articles of Incorporation with the Washington Secretary of State in May 2022, the Company no longer had any preferred stock. The Company has only one class of stock, which is Common Stock. Conversion: At February 28, 2022, there were no shares issued and outstanding that had not been converted into our 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. Stockholders’ Deficit - Schedule of Conversions of Series A Preferred Stock Series A Preferred Stock Fiscal Period Shares of Series A Preferred Converted to Common Stock Shares of Common Stock Issued from Conversion Number of Accredited Investors Year Ended February 29, 2008 102,300 306,900 10 Year Ended February 28, 2009 237,000 711,000 12 Year Ended February 28, 2010 51,900 155,700 4 Year Ended February 28, 2011 102,000 306,000 4 Year Ended February 29, 2012 — — — Year Ended February 28, 2013 18,000 54,000 2 Year Ended February 28, 2014 151,000 453,000 9 Year Ended February 28, 2015 3,000 9,000 1 Year Ended February 29, 2016 10,000 30,000 1 Year Ended February 28, 2017 — — — Year Ended February 28, 2018 14,997 44,991 1 Year Ended February 28, 2019 — — — Year Ended February 29, 2020 — — — Year Ended February 28, 2021 — — — Year Ended February 28, 2022 709,568 2,128,704 56 Totals 1,399,765 4,199,295 100 Dividends: During the twelve months ended February 28, 2022, all accumulated dividends of $ 2,449,979 1,100,000 Cumulative dividends earned on the Series A Preferred stock for each twelve month period since issuance are set forth in the table below: Stockholders’ Deficit - Schedule of Preferred Stock Dividends Earned Fiscal Year Ended Shareholders at Period End Accumulated Dividends February 28, 2007 100 $ 155,311 February 29, 2008 90 242,126 February 28, 2009 78 209,973 February 28, 2010 74 189,973 February 28, 2011 70 173,707 February 29, 2012 70 163,624 February 28, 2013 68 161,906 February 28, 2014 59 151,323 February 28, 2015 58 132,634 February 29, 2016 57 130,925 February 28, 2017 57 130,415 February 28, 2018 56 128,231 February 28, 2019 56 127,714 February 29, 2020 56 128,063 February 28, 2021 56 127,714 February 28, 2022 — 96,340 $ 2,449,979 Common Stock The Company is authorized to issue up to 500,000,000 0.001 384,734,902 67,802,273 Common Stock Balance Par Value Common stock, Issued and Outstanding, February 28, 2021 60,491,122 Shares issued for Series A Preferred conversion 2,128,704 $ 2,129 Shares issued for Series A accumulated dividend 1,100,000 $ 1,100 Shares issued for debt conversion of accrued salaries 1,397,880 $ 1,398 Shares issued for debt conversion of accrued directors fees 317,708 $ 318 Shares issued for conversion of 12% Note principal and interest – related party 1,144,415 $ 1,144 Shares issued for investment principal in production revenue program 1,222,444 $ 1,222 Common stock, Issued and Outstanding, February 28, 2022 67,802,273 Shares issued for conversion of 12% Note principal and interest 78,934 $ 79 Shares issued for conversion of convertible note 27,764,706 $ 27,765 Shares issued for acquisition of crude oil and natural gas properties 160,964,489 $ 160,964 Shares issued for sale of stock 125,000,000 $ 125,000 Shares issued for financing fees 3,125,000 $ 3,125 Share adjustment due to recording error (500 ) $ 1 Common stock, Issued and Outstanding, February 28, 2023 384,734,902 During the twelve months ended February 28, 2023, there were 316,933,129 160,964,489 155,889,706 78,934 7,311,151 7,311,151 4,082,447 3,228,704 2,449,979 500 Subsequent Event All shares of Common Stock are equal to each other with respect to voting, liquidation, dividend and other rights. Owners of shares of Common Stock are entitled to one vote for each share of Common Stock owned at any shareholders’ meeting. Holders of shares of Common Stock are entitled to receive such dividends as may be declared by the Board of Directors out of funds legally available therefore; and upon liquidation, are entitled to participate pro rata in a distribution of assets available for such a distribution to shareholders. There are no conversion, preemptive, or other subscription rights or privileges with respect to any shares of our Common Stock. Our stock does not have cumulative voting rights, which means that the holders of more than 50% of the shares voting in an election of directors may elect all of the directors if they choose to do so. In such event, the holders of the remaining shares aggregating less than 50% would not be able to elect any directors. At a special meeting of shareholders on May 20, 2022 the Company’s shareholders approved an increase in the number of authorized Common Stock shares to 500,000,000 200,000,000

WARRANTS

WARRANTS	12 Months Ended
	Feb. 28, 2023
Warrants
WARRANTS	NOTE 14 — WARRANTS Share Based Payment Arrangement - Non-Employee During the twelve months ended February 29, 2020 there were 2.1 17,689 three 1.68 260.23 0.0 The warrant contains a vesting blocking provision that prevents the vesting of any warrants that such vesting would cause the warrant holder’s beneficial ownership (as such term is defined in Section 13d-3 of the Securities Exchange Act of 1934, as amended) to exceed more than four and ninety-nine one-hundredths percent (4.99%) of the Company’s outstanding Common Stock. The foregoing restriction may not be waived by either party. The warrants vested in equal parts over a three-year period beginning on January 2, 2020 and all warrants expired on January 2, 2024. As of February 28, 2023, and February 28, 2022, there were 2,100,000 893,333 0.01 0.83 25,200 0 4,913 Warrant activity for the twelve months ended February 28, 2023 and February 28, 2022 is set forth in the table below: Warrants - Schedule of Warrant Activity Warrants Weighted Average Exercise Price Warrants outstanding, February 28, 2021 2,100,000 $ 0.01 Changes during the twelve months ended February 28, 2022: Issued — Expired / Cancelled / Forfeited — Warrants outstanding, February 28. 2022 2,100,000 $ 0.01 Warrants exercisable, February 28, 2022 893,333 Changes during the twelve months ended February 28, 2023: Issued — $ Expired / Cancelled / Forfeited — Warrants outstanding, February 28, 2023 2,100,000 $ 0.01 Warrants exercisable, February 28, 2023 2,100,000 $ 0.01

INCOME TAXES

INCOME TAXES	12 Months Ended
	Feb. 28, 2023
Income Tax Disclosure [Abstract]
INCOME TAXES	NOTE 15 — INCOME TAXES On December 22, 2017, the federal government enacted a tax bill H.R.1, an act to provide for reconciliation pursuant to Titles II and V of the concurrent resolution on the budget for fiscal year 2018, commonly referred to as the Tax Cuts and Jobs Act. The Tax Cuts and Jobs Act contains significant changes to corporate taxation, including, but not limited to, reducing the U.S. federal corporate income tax rate from 35 21 Reconciliation between actual tax expense (benefit) and income taxes computed by applying the U.S. federal income tax rate and state income tax rate to income from continuing operations before income taxes is as follows: Income Taxes - Schedule of Reconciliation Between Actual Tax Expense Benefit and Income Taxes Computed by Applying Income Tax Rate February 28, 2023 February 28, 2022 Computed at U.S. and state statutory rates $ (724,883 ) $ (118,897 ) Permanent differences 19,156 11,157 Changes in valuation allowance 705,727 107,740 Total $ — $ — Tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred liabilities are presented below: Income Taxes - Schedule of Deferred Tax Assets and Liabilities February 28, 2023 February 28, 2022 Deferred tax assets: Net operating loss carryforwards $ 6,108,775 $ 5,670,900 Oil and gas properties 355,546 87,694 Stock based compensation 66,187 66,187 Other 27,838 27,838 Less valuation allowance (6,558,346 ) (5,852,619 ) Total $ — $ — At February 28, 2023, the Company had a net operating loss (“NOL”) carryforwards for federal and state income tax purposes of approximately $ 20,471,769 $ 340,749 339,299 416,898 279,773 of $ 107,740 705,727 $ 107,740 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, 2023
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	NOTE 16 — COMMITMENTS AND CONTINGENCIES Various lawsuits, claims, threatened legal actions, and other contingencies arise in the ordinary course of the Company’s business activities. In the opinion of management, the disposition of any such matters is not expected, individually or in the aggregate, to have a material adverse effect on the Company’s results of operations, financial condition, or cash flows. However, the results of legal actions cannot be predicted with certainty. Therefore, it is possible that the Company’s results of operations, financial condition or cash flows could be materially adversely affected in any particular period by the unfavorable resolution of one or more legal actions. 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, 2023. 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 crude oil and natural gas properties. Sunflower Lawsuit Sunflower Alliance v. California Department of Conservation, Geologic Energy Management Division. This case challenges the state agency’s compliance with the California Environmental Quality Act (CEQA) with respect to the PAL Reabold 072-00-0001 Project, for wastewater injection into an existing well. The Petition was filed on December 29, 2021 in the Alameda County Superior Court. The Petitioner seeks an order setting aside the state agency’s approval of a wastewater injection permit; damages are not sought in the lawsuit. On February 22, 2022, Real Party in Interest Reabold California, LLC filed a motion to transfer the case to the Contra Costa County Superior Court. On March 22, 2022, the Alameda County Superior Court ordered the case transferred to the Contra Costa County Superior Court. On August 15, 2022, the Contra Costa County Superior Court provided notice that the transfer has been completed and the case filed in that court. On December 22, 2022, the Superior Court issued an order finding CEQA deficiencies, and directing the state agency to rescind its approval of the project. On September 7, 2023, an appeal of the Superior Court order was filed in the California Court of Appeal, First appellate District, Division 5. The California Attorney General is defending the state agency, which disputes Petitioner’s claims. At this time, it is unclear when the litigation will be resolved. If successful, the lawsuit would prevent Reabold from injecting wastewater into an existing well until any CEQA deficiencies are addressed. The Company is not aware of any environmental claims existing as of January 23

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	12 Months Ended
	Feb. 28, 2023
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	NOTE 17 — SUBSEQUENT EVENTS Related Party Note Payable Unsecured On July 27, 2023, the Company executed an Unsecured Promissory Note (the “Note”) with James F. Westmoreland, the Company’s President and CEO, in the amount of $ 60,000 July 27, 2024

SUPPLEMENTARY INFORMATION FOR C

SUPPLEMENTARY INFORMATION FOR CRUDE OIL PRODUCING ACTIVITIES (UNAUDITED)	12 Months Ended
	Feb. 28, 2023
Extractive Industries [Abstract]
SUPPLEMENTARY INFORMATION FOR CRUDE OIL PRODUCING ACTIVITIES (UNAUDITED)	NOTE 18 SUPPLEMENTARY INFORMATION FOR CRUDE OIL PRODUCING ACTIVITIES (UNAUDITED) Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities Supplementary Information for Crude Oil Producing Activities - Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities As of February 28, 2023 As of February 28, 2022 Proved leasehold costs Mineral Interests $ 115,119 $ 115,119 Wells, equipment and facilities 8,577,693 3,651,122 Total Proved Properties 8,692,812 3,766,241 Unproved properties Mineral Interests — — Uncompleted wells, equipment and facilities — — Total unproved properties — — Less accumulated depreciation, depletion amortization and impairment (3,566,612 ) (3,230,209 ) Net capitalized costs $ 5,126,200 $ 536,032 Costs Incurred in Oil and Gas Producing Activities Supplementary Information for Crude Oil Producing Activities - Costs Incurred in Oil and Gas Producing Activities 12 Months Ended 12 Months Ended February 28, 2023 February 28, 2022 Acquisition of proved properties $ 4,694,563 $ — Acquisition of unproved properties — — Development costs — 6,773 Exploration costs — — Total costs incurred $ 4,694,563 $ 6,773 Results of Operations from Oil and Gas Producing Activities Supplementary Information for Crude Oil Producing Activities - Results of Operations from Oil and Gas Producing Activities 12 Months Ended 12 Months Ended February 28, 2023 February 28, 2022 Crude oil and natural gas revenues $ 1,613,286 $ 680,107 Production costs (1,103,825 ) (231,275 ) Exploration expenses — (56,213 ) Depletion, depreciation and amortization (504,118 ) (49,590 ) Impairment of crude oil and natural gas properties (711,873 ) — Result of crude oil and natural gas producing operations before income taxes (706,530 ) 343,029 Provision for income taxes — — Results of crude oil and natural gas producing activities $ (706,530 ) $ 343,029 Proved Reserves The Company’s proved oil and natural gas reserves have been estimated by two certified independent engineering firms, PGH Petroleum and Environmental Engineers, LLC, of Austin, Texas and PETROtech Resources Company of Bakersfield, California. 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, 2023, our total reserves were comprised of our working interest in the East Slopes Project located in Kern County and our working interest in the Reabold subsidiary located in Monterey and Contra Costs Counties, all in California. Under the guidance provided by Rule 4-10(a)(31)(ii) of Regulation S-X, we have no reserves that qualify to be considered proved undeveloped reserves since any proved undeveloped reserves that were previously considered to be proved undeveloped reserves have remained undeveloped for a period greater than five years. Our proved reserves are summarized in the table below: Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Oil and Gas Reserves Oil (Barrels) Natural Gas (Mcf) Oil (Barrels) Natural Gas (Mcf) BOE (Barrels) Proved reserves: February 28, 2021 434,223 — 434,223 Revisions (1) 92,545 — 92,545 Discoveries and extensions — — — Production (9,613 ) — (9,613 ) February 28, 2022 517,155 — 517,155 Purchases of minerals 277,224 62,152 287,582 Revisions (2) (393,076 ) — (393,076 ) Discoveries and extensions — — — Production (17,114 ) (3,822 ) (17,751 ) February 28, 2023 384,188 58,330 393,910 (1) The upward revision of 92,545 BOE of proved reserves in aggregate were due to an increase in the economic life of existing reserves due to an improvement in crude oil prices in the energy markets. (2) A decrease in aggregate of 393,076 BOE resulted from upward revisions of 6,235 BOE of developed reserves due to an increase in the economic life of existing reserves due to an improvement in crude oil prices in the energy markets, offset by the removal of 399,311 BOE of proved undeveloped reserves that have remained undeveloped for a period greater than five years as of February 28, 2023. The Company’s proved reserves are set forth in the table below. Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Developed and Undeveloped Reserves Developed Undeveloped Total Reserves Oil (Bbls) BOE (Bbls) Oil (Bbls) BOE (Bbls) Oil (Bbls) BOE (Bbls) February 28, 2021 95,120 95,120 339.103 339,103 495,977 495,977 February 28, 2022 117,844 117,844 47,323 47,323 165,167 165,167 February 28, 2023 384,188 393,910 — — 384,188 393,910 Under the guidance provided by Rule 4-10(a)(31)(ii) of Regulation S-X, we have no reserves that qualify to be considered proved undeveloped reserves since any proved undeveloped reserves that were previously considered to be proved undeveloped reserves have remained undeveloped for a period greater than five years. 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, 2023, and February 28, 2022 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, 2023, and February 28, 2022 were estimated as specified by the SEC through calculation of an average price based on the twelve-month unweighted arithmetic average of the first-day-of-the-month price for the period from March through February during each respective fiscal year. The resulting net cash flow are reduced to present value by applying a 10% discount factor. Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves Supplementary Information for Crude Oil Producing Activities - Standardized Measure of Discounted Future Cash Flows Relating to Proved Oil and Gas Reserves 12 Months Ended February 28, 2023 February 28, 2022 Future cash inflows $ 35,775,832 $ 35,580,251 Future production costs (1) (17,162,238 ) (16,217,379 ) Future development costs (725,938 ) (3,603,561 ) Future income tax expenses (2) — — Future net cash flows 17,887,656 15,759,311 10% annual discount for estimated timing of cash flows (6,851,692 ) (9,567,367 ) Standardized measure of discounted future net cash flows at the end of the fiscal year $ 11,035,964 $ 6,191,944 (1) Production costs include crude oil and natural gas operations expense, production ad valorem taxes, transportation expense, workover costs and G&A expense supporting the Company’s crude oil and natural gas operations. (2) The Company has sufficient tax deductions and allowances related to proved crude oil and natural gas reserves to offset future net revenues. Average hydrocarbon prices are set forth in the table below. Supplementary Information for Crude Oil Producing Activities - Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure Crude Oil Average Price Natural Natural Gas Crude Oil (Bbl) Gas (Mcf) Year ended February 28, 2021 (1) $ 36.91 $ — Year ended February 28, 2022 (1) $ 70.75 $ — Year ended February 28, 2023 (1) $ 93.67 $ 5.76 (1) Average prices were based on 12-month unweighted arithmetic average of the first-day-of-the-month prices for the period from March through February during each respective fiscal year. Future production and development costs, which include dismantlement and restoration expense, are computed by estimating the expenditures to be incurred in developing and producing the Company’s proved crude oil and natural gas reserves at the end of the year, based on year-end costs, and assuming continuation of existing economic conditions. Sources of Changes in Discounted Future Net Cash Flows Principal changes in the aggregate standardized measure of discounted future net cash flows attributable to the Company’s proved crude oil and natural gas reserves, as required by ASC 932, at fiscal year-end are set forth in the table below. Supplementary Information for Crude Oil Producing Activities - Schedule of Sources of Changes in Discounted Future Net Cash Flows 12 Months Ended February 28, 2023 February 28, 2022 Standardized measure of discounted future net cash flows at the beginning of the year $ 6,191,944 $ 1,648,418 Extensions, discoveries and improved recovery, less related costs — 906,390 Revisions of previous quantity estimates (11,442,092 ) 44,898 Purchase of minerals in place 8,990,030 — Net changes in prices and production costs 4,695,284 3,320,241 Accretion of discount 619,194 164,842 Sales of crude oil and natural gas produced, net of production costs (509,461 ) (448,832 ) Changes in future development costs 2,022,097 (267,335 ) Changes in timing of future production 468,968 823,322 Net changes in income taxes — — Standardized measure of discounted future net cash flows at the end of the year $ 11,035,964 $ 6,191,944

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Feb. 28, 2023
Accounting Policies [Abstract]
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.
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. Restricted Cash Restricted cash balances include amounts posted with regulatory authorities for reclamation bonds related to the Company’s crude oil and natural gas operations in California.
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 and natural gas 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. Trade accounts receivable are generally not collateralized. There were no allowances for doubtful accounts for the Company’s trade accounts receivable at February 28, 2023 and February 28, 2022.
Crude Oil and Natural Gas Properties	Crude Oil and Natural Gas Properties The Company uses the successful efforts method of accounting for crude oil and natural gas property acquisition, exploration, development, and production activities. Costs to acquire mineral interests in crude oil and natural gas properties, to drill and equip exploratory wells that find proved reserves, and to drill and equip development wells are capitalized as incurred. Costs to drill exploratory wells that are unsuccessful in finding proved reserves are expensed as incurred. In addition, the geological and geophysical costs, and costs of carrying and retaining unproved properties are expensed as incurred. Costs to operate and maintain wells and field equipment are expensed as incurred. Capitalized proved property acquisition costs are amortized by field using the unit-of-production method based on estimated proved reserves. Capitalized exploration well costs and development costs (plus estimated future dismantlement, surface restoration, and property abandonment costs, net of equipment salvage values) are amortized in a similar fashion (by field) based on their estimated proved developed reserves. Support equipment and other property and equipment are depreciated over their estimated useful lives. Pursuant to the provisions of Financial Accounting Standards Codification (“ASC”) Topic 360, “Property, Plant and Equipment” For the twelve months ended February 28, 2023, the Company recognized an impairment charge of $ 711,873 For the twelve months ended February 28, 2022, the Company recognized an impairment of unproved properties in Michigan and wrote down the entire $ 55,978 On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated DD&A with a resulting gain or loss recognized in income.
Property and Equipment	Property and Equipment Vehicles Machinery and Equipment Fixed assets are stated at cost. Depreciation on vehicles is provided using the straight-line method over expected useful lives of three three
Long Lived Assets	Long Lived Assets The Company reviews the carrying value of 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) through recognition of impairment.
Fair Value Measurements	Fair Value Measurements ASC Topic 820, Fair Value Measurements and Disclosures, defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. Fair value is defined as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. To increase consistency and comparability in fair value measurements and related disclosures, ASC Topic 820 also established a fair value hierarchy that prioritizes the relative reliability of inputs used in fair value measurements. We are required to maximize the use of observable inputs and minimize the use of observable inputs when measuring fair value. The hierarchy describes three levels of inputs that may be used to measure fair value: Level 1 – Quoted prices in active markets for identical assets and liabilities. Level 2 - Observable inputs other than Level 1 prices, such as quoted prices for similar assets or liabilities; or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities. Level 3 – Unobservable inputs that are supported by little or no market activity and that are financial instruments whose are determined using pricing models, discounted cash flow methodologies, or similar techniques, as well as instruments for which the determination of fair value requires significant judgment or estimation. ASC Topic 820 requires that an entity give consideration to the credit risk of its counterparties, as well as its own credit risk, when measuring financial assets and liabilities at fair value. Asset acquisitions are recorded on the closing date of the transaction at their fair value, which is determined by applying market and income approached using level 3 inputs.
Fair Value of Financial Instruments	Fair Value of Financial Instruments The Company’s carrying value of short-term financial instruments including cash, restricted cash, receivables, prepaid expenses, accounts payable, and other accrued liabilities, short-term liabilities and credit lines 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. The Company’s financial instruments consist of cash, restricted cash, accounts receivable, accounts payable, notes payable and loans. The carrying amount of these financial instruments approximates their fair value due either to length of maturity or interest rates that approximate prevailing market rates unless otherwise disclosed in these financial statements. The Company has no financial assets or liabilities that are measured at fair value on a recurring basis as of February 28, 2023.
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 The Company follows ASC Topic 260, Earnings per Share
Concentration of Credit Risk	Concentration of Credit Risk Substantially all of the Company’s trade accounts receivable result from crude oil and natural gas 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 including crude oil and natural gas prices as well as other related factors. Trade accounts receivable are generally not collateralized. Customer Concentration Accounts Receivable At both the Company’s projects in California there is only one buyer for the purchase of all crude oil production. At February 28, 2023 and February 28, 2022, this one individual customer represented 100 At the Reabold project wells in Contra Costs County, California there is also natural gas production that the Company sells to a single buyer. At February 28, 2023, this one individual customer per project represented 100 The Company’s accounts receivable for California crude oil and natural gas sales at February 28, 2023 and February 28, 2022 are set forth in the table below: Summary of Significant Accounting Policies - Schedule of Concentration of Risk, by Risk Factor February 28, 2023 February 28, 2022 Project Customer Accounts Receivable Percentage Accounts Receivable Percentage California – East Slopes project (crude oil) Plains Marketing $ 55,900 42.5 % $ 117,727 100.0 % California – Reabold project (crude oil) Plains Marketing 59,614 45.3 % — — California – Reabold project (natural gas) CRC 15,996 12.2 % — — Totals $ 131,510 100.0 % $ 117,727 100.0 % Joint interest participant receivables balances of $ 353,009 85,339
Revenue Recognition	Revenue Recognition The Company recognizes revenue under ASC 606, Revenue from Contracts with Customers does not include any payments for services or ancillary items other than for the sale of crude oil and natural gas. Revenue is recorded in the month crude oil and natural gas production is delivered to the purchaser.
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.
Recent Accounting Pronouncements	Recent Accounting Pronouncements Accounting Standards Issued and Adopted The Company does not believe that any recently issued effective pronouncements, or pronouncements issued but not yet effective, if adopted, would have a material effect on the Company’s financial statements.

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Feb. 28, 2023
Accounting Policies [Abstract]
Summary of Significant Accounting Policies - Schedule of Concentration of Risk, by Risk Factor	The Company’s accounts receivable for California crude oil and natural gas sales at February 28, 2023 and February 28, 2022 are set forth in the table below: Summary of Significant Accounting Policies - Schedule of Concentration of Risk, by Risk Factor February 28, 2023 February 28, 2022 Project Customer Accounts Receivable Percentage Accounts Receivable Percentage California – East Slopes project (crude oil) Plains Marketing $ 55,900 42.5 % $ 117,727 100.0 % California – Reabold project (crude oil) Plains Marketing 59,614 45.3 % — — California – Reabold project (natural gas) CRC 15,996 12.2 % — — Totals $ 131,510 100.0 % $ 117,727 100.0 %

CRUDE OIL PROPERTIES (Tables)

CRUDE OIL PROPERTIES (Tables)	12 Months Ended
	Feb. 28, 2023
Extractive Industries [Abstract]
Crude Oil Properties - Schedule of Crude Oil Activities	Crude oil property balances at February 28, 2023, and February 28, 2022 are set forth in the table below: Crude Oil Properties - Schedule of Crude Oil Activities February 28, 2023 February 28, 2022 Proved leasehold costs $ 115,119 $ 115,119 Costs of wells and development 6,915,982 2,309,628 Capitalized exploratory well costs 1,341,494 1,341,494 Property, plant and equipment (Reabold) 320,217 — Cost of crude oil and natural gas properties 8,692,812 3,766,241 Accumulated depletion, depreciation amortization and impairment (3,566,612 ) (3,230,209 ) Total crude oil and natural gas properties, net $ 5,126,200 $ 536,032

ACQUISITION (Tables)

ACQUISITION (Tables)	12 Months Ended
	Feb. 28, 2023
Business Combination and Asset Acquisition [Abstract]
Acquisition - Schedule of Business Acquisition	Cash $ 19,706 Restricted cash – O&G operator bonds 275,000 Accounts receivable 248,817 Crude oil and natural gas property and equipment 4,694,563 Property, plant and equipment, net 428,221 Goodwill 1,415,361 Accounts payable (152,854 ) Revenue payable (62,914 ) Other liabilities assumed (2,737 ) Purchase price, net of closing adjustments $ 6,863,163

ASSET RETIREMENT OBLIGATION (_2

ASSET RETIREMENT OBLIGATION (“ARO”) (Tables)	12 Months Ended
	Feb. 28, 2023
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation (“ARO”) - Schedule of Changes in the Asset Retirement Obligations	Changes in the asset retirement obligations for the twelve months ended February 28, 2023, and February 28, 2022 are set forth in the table below. Asset Retirement Obligation (“ARO”) - Schedule of Changes in the Asset Retirement Obligations February 28, 2023 February 28, 2022 Asset retirement obligation, beginning of period $ 52,565 $ 33,062 Accretion expense 23,875 8,574 Revisions to asset retirement obligation 239,069 10,929 Asset retirement obligation, end of period $ 315,509 $ 52,565

SHORT-TERM AND LONG-TERM BORR_2

SHORT-TERM AND LONG-TERM BORROWINGS (Tables)	12 Months Ended
	Feb. 28, 2023
Debt Disclosure [Abstract]
Short-Term and Long-Term Borrowings - Schedule of Related Party Notes Payable	Current portion of note payable –related party balances at February 28, 2023, and February 28, 2022 are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Related Party Notes Payable February 28, 2023 February 28, 2022 Note payable – related party, current portion $ 9,065 $ 8,829 Unamortized debt issuance expenses (728 ) (729 ) Note payable – related party, current portion, net $ 8,337 $ 8,100 Note payable –related party long-term balances at February 28, 2023 and February 28, 2022 are set forth in the table below: February 28, 2023 February 28, 2022 Note payable – related party, non-current $ 127,645 $ 136,710 Unamortized debt issuance expenses (8,622 ) (9,350 ) Note payable – related party, non-current, net $ 119,023 $ 127,360
Short-Term and Long-Term Borrowings - Schedule of Future Estimated Payments	Future estimated payments on the outstanding note payable – related party are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Future Estimated Payments Twelve month periods ending February 28/29, 2024 9,065 2025 9,309 2026 9,558 2027 9,815 2028 10,078 Thereafter 88,885 Total $ 136,710
Short-Term and Long-Term Borrowings - Schedule of Subordinated Notes	12% Note balances at February 28, 2023 and February 28, 2022 are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Subordinated Notes 12% Subordinated Notes Related Party Notes February 28, 2023 February 28, 2022 12% Subordinated notes – third party $ 290,000 $ 315,000 12% subordinated notes – related party — — 12% Subordinated notes balance $ 290,000 $ 315,000
Short-Term and Long-Term Borrowings - Schedule of Production Revenue Payable Balances	Production revenue payable balances at February 28, 2023 and February 28, 2022 are set forth in the table below: Short-Term and Long-Term Borrowings - Schedule of Production Revenue Payable Balances February 28, 2023 February 28, 2022 Estimated payments of production revenue payable $ 913,395 $ 941,259 Less: unamortized discount (40,114 ) (124,134 ) 873,281 817,125 Less: current portion (56,915 ) (78,877 ) Net production revenue payable – long term $ 816,366 $ 738,248

STOCKHOLDERS_ EQUITY (DEFICIT)

STOCKHOLDERS’ EQUITY (DEFICIT) (Tables)	12 Months Ended
	Feb. 28, 2023
Equity [Abstract]
Stockholders’ Deficit - Schedule of Preferred Stock Dividends Earned	The conversions of Series A Preferred that have occurred since the Series A Preferred was first issued in July 2006 are set forth in the table below. Stockholders’ Deficit - Schedule of Conversions of Series A Preferred Stock Series A Preferred Stock Fiscal Period Shares of Series A Preferred Converted to Common Stock Shares of Common Stock Issued from Conversion Number of Accredited Investors Year Ended February 29, 2008 102,300 306,900 10 Year Ended February 28, 2009 237,000 711,000 12 Year Ended February 28, 2010 51,900 155,700 4 Year Ended February 28, 2011 102,000 306,000 4 Year Ended February 29, 2012 — — — Year Ended February 28, 2013 18,000 54,000 2 Year Ended February 28, 2014 151,000 453,000 9 Year Ended February 28, 2015 3,000 9,000 1 Year Ended February 29, 2016 10,000 30,000 1 Year Ended February 28, 2017 — — — Year Ended February 28, 2018 14,997 44,991 1 Year Ended February 28, 2019 — — — Year Ended February 29, 2020 — — — Year Ended February 28, 2021 — — — Year Ended February 28, 2022 709,568 2,128,704 56 Totals 1,399,765 4,199,295 100 Dividends: During the twelve months ended February 28, 2022, all accumulated dividends of $ 2,449,979 1,100,000 Cumulative dividends earned on the Series A Preferred stock for each twelve month period since issuance are set forth in the table below: Stockholders’ Deficit - Schedule of Preferred Stock Dividends Earned Fiscal Year Ended Shareholders at Period End Accumulated Dividends February 28, 2007 100 $ 155,311 February 29, 2008 90 242,126 February 28, 2009 78 209,973 February 28, 2010 74 189,973 February 28, 2011 70 173,707 February 29, 2012 70 163,624 February 28, 2013 68 161,906 February 28, 2014 59 151,323 February 28, 2015 58 132,634 February 29, 2016 57 130,925 February 28, 2017 57 130,415 February 28, 2018 56 128,231 February 28, 2019 56 127,714 February 29, 2020 56 128,063 February 28, 2021 56 127,714 February 28, 2022 — 96,340 $ 2,449,979 Common Stock The Company is authorized to issue up to 500,000,000 0.001 384,734,902 67,802,273
Stockholders’ Deficit - Schedule of Preferred Stock Dividends Earned	Cumulative dividends earned on the Series A Preferred stock for each twelve month period since issuance are set forth in the table below: Stockholders’ Deficit - Schedule of Preferred Stock Dividends Earned Fiscal Year Ended Shareholders at Period End Accumulated Dividends February 28, 2007 100 $ 155,311 February 29, 2008 90 242,126 February 28, 2009 78 209,973 February 28, 2010 74 189,973 February 28, 2011 70 173,707 February 29, 2012 70 163,624 February 28, 2013 68 161,906 February 28, 2014 59 151,323 February 28, 2015 58 132,634 February 29, 2016 57 130,925 February 28, 2017 57 130,415 February 28, 2018 56 128,231 February 28, 2019 56 127,714 February 29, 2020 56 128,063 February 28, 2021 56 127,714 February 28, 2022 — 96,340 $ 2,449,979 Common Stock The Company is authorized to issue up to 500,000,000 0.001 384,734,902 67,802,273
Stockholders' Deficit - Schedule of Common Stock Outstanding	Common Stock Balance Par Value Common stock, Issued and Outstanding, February 28, 2021 60,491,122 Shares issued for Series A Preferred conversion 2,128,704 $ 2,129 Shares issued for Series A accumulated dividend 1,100,000 $ 1,100 Shares issued for debt conversion of accrued salaries 1,397,880 $ 1,398 Shares issued for debt conversion of accrued directors fees 317,708 $ 318 Shares issued for conversion of 12% Note principal and interest – related party 1,144,415 $ 1,144 Shares issued for investment principal in production revenue program 1,222,444 $ 1,222 Common stock, Issued and Outstanding, February 28, 2022 67,802,273 Shares issued for conversion of 12% Note principal and interest 78,934 $ 79 Shares issued for conversion of convertible note 27,764,706 $ 27,765 Shares issued for acquisition of crude oil and natural gas properties 160,964,489 $ 160,964 Shares issued for sale of stock 125,000,000 $ 125,000 Shares issued for financing fees 3,125,000 $ 3,125 Share adjustment due to recording error (500 ) $ 1 Common stock, Issued and Outstanding, February 28, 2023 384,734,902

WARRANTS (Tables)

WARRANTS (Tables)	12 Months Ended
	Feb. 28, 2023
Warrants
Warrants - Schedule of Warrant Activity	Warrant activity for the twelve months ended February 28, 2023 and February 28, 2022 is set forth in the table below: Warrants - Schedule of Warrant Activity Warrants Weighted Average Exercise Price Warrants outstanding, February 28, 2021 2,100,000 $ 0.01 Changes during the twelve months ended February 28, 2022: Issued — Expired / Cancelled / Forfeited — Warrants outstanding, February 28. 2022 2,100,000 $ 0.01 Warrants exercisable, February 28, 2022 893,333 Changes during the twelve months ended February 28, 2023: Issued — $ Expired / Cancelled / Forfeited — Warrants outstanding, February 28, 2023 2,100,000 $ 0.01 Warrants exercisable, February 28, 2023 2,100,000 $ 0.01

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Feb. 28, 2023
Income Tax Disclosure [Abstract]
Income Taxes - Schedule of Reconciliation Between Actual Tax Expense Benefit and Income Taxes Computed by Applying Income Tax Rate	Reconciliation between actual tax expense (benefit) and income taxes computed by applying the U.S. federal income tax rate and state income tax rate to income from continuing operations before income taxes is as follows: Income Taxes - Schedule of Reconciliation Between Actual Tax Expense Benefit and Income Taxes Computed by Applying Income Tax Rate February 28, 2023 February 28, 2022 Computed at U.S. and state statutory rates $ (724,883 ) $ (118,897 ) Permanent differences 19,156 11,157 Changes in valuation allowance 705,727 107,740 Total $ — $ —
Income Taxes - Schedule of Deferred Tax Assets and Liabilities	Tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred liabilities are presented below: Income Taxes - Schedule of Deferred Tax Assets and Liabilities February 28, 2023 February 28, 2022 Deferred tax assets: Net operating loss carryforwards $ 6,108,775 $ 5,670,900 Oil and gas properties 355,546 87,694 Stock based compensation 66,187 66,187 Other 27,838 27,838 Less valuation allowance (6,558,346 ) (5,852,619 ) Total $ — $ —

SUPPLEMENTARY INFORMATION FOR_2

SUPPLEMENTARY INFORMATION FOR CRUDE OIL PRODUCING ACTIVITIES (UNAUDITED) (Tables)	12 Months Ended
	Feb. 28, 2023
Extractive Industries [Abstract]
Supplementary Information for Crude Oil Producing Activities - Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities	Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities Supplementary Information for Crude Oil Producing Activities - Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities As of February 28, 2023 As of February 28, 2022 Proved leasehold costs Mineral Interests $ 115,119 $ 115,119 Wells, equipment and facilities 8,577,693 3,651,122 Total Proved Properties 8,692,812 3,766,241 Unproved properties Mineral Interests — — Uncompleted wells, equipment and facilities — — Total unproved properties — — Less accumulated depreciation, depletion amortization and impairment (3,566,612 ) (3,230,209 ) Net capitalized costs $ 5,126,200 $ 536,032
Supplementary Information for Crude Oil Producing Activities - Costs Incurred in Oil and Gas Producing Activities	Costs Incurred in Oil and Gas Producing Activities Supplementary Information for Crude Oil Producing Activities - Costs Incurred in Oil and Gas Producing Activities 12 Months Ended 12 Months Ended February 28, 2023 February 28, 2022 Acquisition of proved properties $ 4,694,563 $ — Acquisition of unproved properties — — Development costs — 6,773 Exploration costs — — Total costs incurred $ 4,694,563 $ 6,773
Supplementary Information for Crude Oil Producing Activities - Results of Operations from Oil and Gas Producing Activities	Results of Operations from Oil and Gas Producing Activities Supplementary Information for Crude Oil Producing Activities - Results of Operations from Oil and Gas Producing Activities 12 Months Ended 12 Months Ended February 28, 2023 February 28, 2022 Crude oil and natural gas revenues $ 1,613,286 $ 680,107 Production costs (1,103,825 ) (231,275 ) Exploration expenses — (56,213 ) Depletion, depreciation and amortization (504,118 ) (49,590 ) Impairment of crude oil and natural gas properties (711,873 ) — Result of crude oil and natural gas producing operations before income taxes (706,530 ) 343,029 Provision for income taxes — — Results of crude oil and natural gas producing activities $ (706,530 ) $ 343,029
Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Oil and Gas Reserves	Our proved reserves are summarized in the table below: Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Oil and Gas Reserves Oil (Barrels) Natural Gas (Mcf) Oil (Barrels) Natural Gas (Mcf) BOE (Barrels) Proved reserves: February 28, 2021 434,223 — 434,223 Revisions (1) 92,545 — 92,545 Discoveries and extensions — — — Production (9,613 ) — (9,613 ) February 28, 2022 517,155 — 517,155 Purchases of minerals 277,224 62,152 287,582 Revisions (2) (393,076 ) — (393,076 ) Discoveries and extensions — — — Production (17,114 ) (3,822 ) (17,751 ) February 28, 2023 384,188 58,330 393,910 (1) The upward revision of 92,545 BOE of proved reserves in aggregate were due to an increase in the economic life of existing reserves due to an improvement in crude oil prices in the energy markets. (2) A decrease in aggregate of 393,076 BOE resulted from upward revisions of 6,235 BOE of developed reserves due to an increase in the economic life of existing reserves due to an improvement in crude oil prices in the energy markets, offset by the removal of 399,311 BOE of proved undeveloped reserves that have remained undeveloped for a period greater than five years as of February 28, 2023.
Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Developed and Undeveloped Reserves	The Company’s proved reserves are set forth in the table below. Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Developed and Undeveloped Reserves Developed Undeveloped Total Reserves Oil (Bbls) BOE (Bbls) Oil (Bbls) BOE (Bbls) Oil (Bbls) BOE (Bbls) February 28, 2021 95,120 95,120 339.103 339,103 495,977 495,977 February 28, 2022 117,844 117,844 47,323 47,323 165,167 165,167 February 28, 2023 384,188 393,910 — — 384,188 393,910
Supplementary Information for Crude Oil Producing Activities - Standardized Measure of Discounted Future Cash Flows Relating to Proved Oil and Gas Reserves	Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves Supplementary Information for Crude Oil Producing Activities - Standardized Measure of Discounted Future Cash Flows Relating to Proved Oil and Gas Reserves 12 Months Ended February 28, 2023 February 28, 2022 Future cash inflows $ 35,775,832 $ 35,580,251 Future production costs (1) (17,162,238 ) (16,217,379 ) Future development costs (725,938 ) (3,603,561 ) Future income tax expenses (2) — — Future net cash flows 17,887,656 15,759,311 10% annual discount for estimated timing of cash flows (6,851,692 ) (9,567,367 ) Standardized measure of discounted future net cash flows at the end of the fiscal year $ 11,035,964 $ 6,191,944 (1) Production costs include crude oil and natural gas operations expense, production ad valorem taxes, transportation expense, workover costs and G&A expense supporting the Company’s crude oil and natural gas operations. (2) The Company has sufficient tax deductions and allowances related to proved crude oil and natural gas reserves to offset future net revenues.
Supplementary Information for Crude Oil Producing Activities - Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure	Average hydrocarbon prices are set forth in the table below. Supplementary Information for Crude Oil Producing Activities - Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure Crude Oil Average Price Natural Natural Gas Crude Oil (Bbl) Gas (Mcf) Year ended February 28, 2021 (1) $ 36.91 $ — Year ended February 28, 2022 (1) $ 70.75 $ — Year ended February 28, 2023 (1) $ 93.67 $ 5.76 (1) Average prices were based on 12-month unweighted arithmetic average of the first-day-of-the-month prices for the period from March through February during each respective fiscal year.
Supplementary Information for Crude Oil Producing Activities - Schedule of Sources of Changes in Discounted Future Net Cash Flows	Principal changes in the aggregate standardized measure of discounted future net cash flows attributable to the Company’s proved crude oil and natural gas reserves, as required by ASC 932, at fiscal year-end are set forth in the table below. Supplementary Information for Crude Oil Producing Activities - Schedule of Sources of Changes in Discounted Future Net Cash Flows 12 Months Ended February 28, 2023 February 28, 2022 Standardized measure of discounted future net cash flows at the beginning of the year $ 6,191,944 $ 1,648,418 Extensions, discoveries and improved recovery, less related costs — 906,390 Revisions of previous quantity estimates (11,442,092 ) 44,898 Purchase of minerals in place 8,990,030 — Net changes in prices and production costs 4,695,284 3,320,241 Accretion of discount 619,194 164,842 Sales of crude oil and natural gas produced, net of production costs (509,461 ) (448,832 ) Changes in future development costs 2,022,097 (267,335 ) Changes in timing of future production 468,968 823,322 Net changes in income taxes — — Standardized measure of discounted future net cash flows at the end of the year $ 11,035,964 $ 6,191,944

GOING CONCERN (Details Narrativ

GOING CONCERN (Details Narrative)	1 Months Ended
	May 31, 2022 USD ($) shares	Feb. 28, 2023 USD ($) Number	Feb. 28, 2022 USD ($)
Restructuring Cost and Reserve [Line Items]
Accumulated deficit		$ 31,959,693	$ 29,530,456
Working capital deficit		$ 2,100,000
Reabold CA, LLC
Restructuring Cost and Reserve [Line Items]
Common stock issued for acquisition | shares	160,964,489
Value of common stock issued for acquisition	$ 6,599,544
Value of common stock issued for acquisition	$ 263,619
Business acquisition, description	Approximately 82% or 51,054,229 shares of the Company’s 62,510,204 issued and outstanding shares of the Company’s Common Stock were present or represented by proxy at the meeting. The proposal for the Reabold acquisition was passed with over a 99.6% approval vote.
Business acquisition, additional information	At the special shareholders meeting held on May 20, 2022, approval was also granted to Amend and Restate the Company’s Articles of Incorporation. This allowed for the increase in the number of authorized Common Stock shares of the Company from 200,000,000 shares to 500,000,000 shares.
Business acquisition, capital raise	In conjunction with the Company’s efforts to acquire Reabold, and as a condition of closing the acquisition, the Company was to secure a capital raise of $2,500,000 through the issuance of shares of the Company’s Common Stock.
Total of common stock issued for acquisition | shares	128,125,000
Shares issued for financing fees, shares | shares	3,125,000
Kern County, California
Restructuring Cost and Reserve [Line Items]
Number of producing crude oil wells | Number		20
Average working interest		36.60%
Average net revenue interest		28.40%
Monterey and Contra Costa Counties, California
Restructuring Cost and Reserve [Line Items]
Number of producing crude oil wells | Number		10
Average working interest		50%
Average net revenue interest		40%

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Schedule of Concentration of Risk, by Risk Factor (Details) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Product Information [Line Items]
Accounts receivable	$ 131,510	$ 117,727
Customer Concentration | Accounts Receivable
Product Information [Line Items]
Accounts receivable	$ 131,510	$ 117,727
Percent of revenue	100%	100%
Customer Concentration | Accounts Receivable | Plains Marketing | California - East Slopes Project (Crude Oil)
Product Information [Line Items]
Accounts receivable	$ 55,900	$ 117,727
Percent of revenue	42.50%	100%
Customer Concentration | Accounts Receivable | Plains Marketing | California - Reabold Project (Crude Oil)
Product Information [Line Items]
Accounts receivable	$ 59,614
Percent of revenue	45.30%
Customer Concentration | Accounts Receivable | CRC
Product Information [Line Items]
Percent of revenue	100%
Customer Concentration | Accounts Receivable | CRC | California - Reabold Project (Natural Gas)
Product Information [Line Items]
Accounts receivable	$ 15,996
Percent of revenue	12.20%

SUMMARY OF SIGNIFICANT ACCOUN_5

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Product Information [Line Items]
Impairment of unproved properties	$ 711,873	$ 0
Joint interest participants	$ 353,009	$ 85,339
Customer Concentration | Accounts Receivable
Product Information [Line Items]
Concentration risk	100%	100%
Customer Concentration | Accounts Receivable | CRC
Product Information [Line Items]
Concentration risk	100%
Vehicles
Product Information [Line Items]
Expected useful lives		three
Machinery and Equipment
Product Information [Line Items]
Expected useful lives		three
Michigan (Unproved Properties)
Product Information [Line Items]
Impairment of unproved properties		$ 55,978

ACCOUNTS RECEIVABLE (Details Na

ACCOUNTS RECEIVABLE (Details Narrative) - USD ($)	Feb. 28, 2023	Feb. 28, 2022
Receivables [Abstract]
Crude oil and natural gas sales receivables	$ 131,510	$ 117,727
Joint interest participant receivables, balance	$ 353,009	$ 85,339

Crude Oil Properties - Schedule

Crude Oil Properties - Schedule of Crude Oil Activities (Details) - USD ($)	Feb. 28, 2023	Feb. 28, 2022
Extractive Industries [Abstract]
Proved leasehold costs	$ 115,119	$ 115,119
Costs of wells and development	6,915,982	2,309,628
Capitalized exploratory well costs	1,341,494	1,341,494
Property, plant and equipment (Reabold)	320,217
Cost of crude oil and natural gas properties	8,692,812	3,766,241
Accumulated depletion, depreciation amortization and impairment	(3,566,612)	(3,230,209)
Total crude oil and natural gas properties, net	$ 5,126,200	$ 536,032

CRUDE OIL PROPERTIES (Details N

CRUDE OIL PROPERTIES (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Extractive Industries [Abstract]
Depletion expense	$ 477,089	$ 38,125
Impairment of crude oil and natural gas properties	$ 711,873	$ 0

Acquisition - Schedule of Busin

Acquisition - Schedule of Business Acquisition (Details) - USD ($)	1 Months Ended	3 Months Ended
	May 31, 2022	May 31, 2022	Feb. 28, 2023	Feb. 28, 2022
Business Acquisition [Line Items]
Goodwill			$ 1,415,361
Reabold CA, LLC
Business Acquisition [Line Items]
Cash	$ 19,706	$ 19,706
Restricted cash – O&G operator bonds	275,000	275,000
Accounts receivable	248,817	248,817
Crude oil and natural gas property and equipment	4,694,563
Property, plant and equipment, net	428,221	428,221
Goodwill	1,415,361	1,415,361
Accounts payable	(152,854)	(152,854)
Revenue payable	(62,914)	(62,914)
Other liabilities assumed	$ (2,737)	(2,737)
Business Combination, Consideration Transferred, Other		$ 6,863,163

ACQUISITION (Details Narrative)

ACQUISITION (Details Narrative) - USD ($)	1 Months Ended	3 Months Ended
	May 31, 2022	May 31, 2022	Feb. 28, 2023	Feb. 28, 2022
Business Acquisition [Line Items]
Goodwill			$ 1,415,361
Reabold CA, LLC
Business Acquisition [Line Items]
Common stock issued for acquisition	160,964,489
Value of common stock issued for acquisition	$ 6,599,544	$ 6,599,544
The common stock valuation of acquisition transaction		$ 6,863,163
Reimbursement as a purchase price adjustment	$ 263,619
Business acquisition, share price	$ 0.041	$ 0.041
Net assets acquired	$ 5,447,802	$ 5,447,802
Liabilities assumed	218,505	218,505
Assets acquired	5,666,307	5,666,307
Goodwill	$ 1,415,361	1,415,361
Transaction expense		$ 445,529

Asset Retirement Obligation (_3

Asset Retirement Obligation (“ARO”) - Schedule of Changes in the Asset Retirement Obligations (Details) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligation, beginning of period	$ 52,565	$ 33,062
Accretion expense	23,875	8,574
Revisions to asset retirement obligation	239,069	10,929
Asset retirement obligation, end of period	$ 315,509	$ 52,565

ASSET RETIREMENT OBLIGATION (_4

ASSET RETIREMENT OBLIGATION (“ARO”) (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Asset Retirement Obligation Disclosure [Abstract]
Accretion expense	$ 23,875	$ 8,574

ACCOUNTS PAYABLE (Details Narra

ACCOUNTS PAYABLE (Details Narrative) - USD ($)	1 Months Ended	3 Months Ended
	Mar. 31, 2009	Jun. 11, 2009	Feb. 28, 2023	Feb. 28, 2022
Deferred Compensation Arrangement with Individual, Excluding Share-Based Payments and Postretirement Benefits [Line Items]
Assumed liabilities	$ 1,500,000
Assumed liabilities, additional information		representing a 25% working interest in the drilling and completion costs associated with the East Slopes Project four earning wells program. The Company subsequently sold the 25% working interest on June 11, 2009
Accounts payable				$ 244,849
Working Interest Partner, California
Deferred Compensation Arrangement with Individual, Excluding Share-Based Payments and Postretirement Benefits [Line Items]
Accounts payable			$ 63,367	$ 76,268

ACCOUNTS PAYABLE - RELATED PA_2

ACCOUNTS PAYABLE - RELATED PARTIES (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Defined Benefit Plan Disclosure [Line Items]
Accounts payable	$ 21,937	$ 49,228
Great Earth Power
Defined Benefit Plan Disclosure [Line Items]
Accounts payable	613	1,400
Related party expense	15,663	20,300
ABPlus Net Holdings
Defined Benefit Plan Disclosure [Line Items]
Accounts payable	960	960
Related party expense	$ 11,520	$ 11,520

Short-Term and Long-Term Borr_3

Short-Term and Long-Term Borrowings - Schedule of Related Party Notes Payable (Details) - USD ($)	Feb. 28, 2023	Feb. 28, 2022
Debt Disclosure [Abstract]
Note payable – related party, current portion	$ 9,065	$ 8,829
Unamortized debt issuance expenses	(728)	(729)
Note payable – related party, current portion, net	8,337	8,100
Note payable – related party, non-current	127,645	136,710
Unamortized debt issuance expenses	(8,622)	(9,350)
Note payable – related party, non-current, net	$ 119,023	$ 127,360

Short-Term and Long-Term Borr_4

Short-Term and Long-Term Borrowings - Schedule of Future Estimated Payments (Details)	Feb. 28, 2023 USD ($)
Debt Disclosure [Abstract]
2024	$ 9,065
2025	9,309
2026	9,558
2027	9,815
2028	10,078
Thereafter	88,885
Total	$ 136,710

Short-Term and Long-Term Borr_5

Short-Term and Long-Term Borrowings - Schedule of Subordinated Notes (Details) - Subordinated Debt - USD ($)	Feb. 28, 2023	Feb. 28, 2022
Debt Instrument [Line Items]
12% Subordinated notes balance	$ 290,000	$ 315,000
Related Party Notes
Debt Instrument [Line Items]
12% Subordinated notes balance	0	0
Third Party
Debt Instrument [Line Items]
12% Subordinated notes balance	$ 290,000	$ 315,000

Short-Term and Long-Term Borr_6

Short-Term and Long-Term Borrowings - Schedule of Production Revenue Payable Balances (Details) - USD ($)	Feb. 28, 2023	Feb. 28, 2022
Debt Disclosure [Abstract]
Estimated payments of production revenue payable	$ 913,395	$ 941,259
Less: unamortized discount	(40,114)	(124,134)
Production revenue payable, net	873,281	817,125
Less: current portion	(56,915)	(78,877)
Net production revenue payable – long term	$ 816,366	$ 738,248

SHORT-TERM AND LONG-TERM BORR_7

SHORT-TERM AND LONG-TERM BORROWINGS (Details Narrative) - USD ($)		1 Months Ended				9 Months Ended	12 Months Ended
	Oct. 24, 2011	May 26, 2022	Dec. 22, 2020	Dec. 31, 2018	Jan. 31, 2010	Feb. 28, 2023	Feb. 28, 2023	Feb. 28, 2022	Feb. 29, 2020
Line of Credit Facility [Line Items]
Amortization of debt discount							$ 56,885	$ 96,703
Proceeds from Convertible Debt								200,000
12% Note payable						$ 290,000	290,000	315,000
Line of Credit | UBS Bank USA
Line of Credit Facility [Line Items]
Interest converted to principal								27,278
Line of Credit Facility, Maximum Borrowing Capacity	$ 890,000
Line of Credit Facility, Collateral	secured by the personal guarantee of our President and Chief Executive Officer
Repayment of lines of credit		$ 809,930						60,000
Line of credit, outstanding balance						0	$ 0	$ 808,182
Convertible Debt | Third Party
Line of Credit Facility [Line Items]
Interest rate								18%
Proceeds from Convertible Debt								$ 200,000
Interest converted to principal						$ 36,000
Conversion rate, per share						$ 0.0085	$ 0.0085
Conversion of convertible note, shares							27,764,706
Secured Debt | Chief Executive Officer
Line of Credit Facility [Line Items]
Proceeds from issuance of secured debt			$ 155,548
Loan fees			10,929
Net proceeds from loan			$ 144,619
Interest rate			2.25%
Maturity date			Dec. 21, 2035
Principal payments							$ 8,829
Amortization of debt discount							729
12% Subordinated Notes
Line of Credit Facility [Line Items]
Interest converted to principal							$ 10,520
Conversion rate, per share						$ 0.45	$ 0.45
Conversion of convertible note, shares							78,934
Subordinated note						$ 25,000	$ 25,000
12% Subordinated Notes | Private Placement
Line of Credit Facility [Line Items]
Interest rate					12%
12% Note payable						290,000	290,000	315,000
Maturity date, description					The original maturity date of January 29, 2015 had been extended to January 29, 2017 and then was extended to January 29, 2019.
Accrued interest						159,508	159,508	135,229
Third-Party Vendors
Line of Credit Facility [Line Items]
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
Maturity date				Jan. 01, 2022
Interest rate				10%
Accrued interest						26,000	26,000	38,000
Production Payment Program
Line of Credit Facility [Line Items]
Amortization of debt discount							56,156	$ 95,974
Fundraising program, description									the Company conducted a fundraising program to raise $1.3 million to fund the drilling of future wells in California and to settle some of its existing historical debt. The purchasers of a production payment interest are to receive a production revenue payment interest on future wells to be drilled in California in exchange for their purchase. The Company shall pay seventy-five percent (75%) of its future net production revenue 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 purchaser group 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 the purchaser group. However, if the total raise amount is less than the target $1.3 million, then the payment will be a proportionate amount of the eight percent (8%)
Production revenue payable, balance						$ 873,281	873,281
Interest expense on production revenue payments							$ 78,136

LEASES (Details Narrative)

LEASES (Details Narrative)	12 Months Ended
	Feb. 28, 2023 USD ($) ft²	Feb. 28, 2022 USD ($)
Lease expense | $	$ 23,889	$ 23,489
Spokane Valley, Washington
Leased properties, square feet	988
Friendswood, Texas
Leased properties, square feet	416
Wallace, Idaho
Leased properties, square feet	695

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Related Party Transaction [Line Items]
Accounts payable	$ 21,937	$ 49,228
Great Earth Power
Related Party Transaction [Line Items]
Related party expense	15,663	20,300
Accounts payable	613	1,400
ABPlus Net Holdings
Related Party Transaction [Line Items]
Related party expense	11,520	11,520
Accounts payable	$ 960	$ 960

Stockholders_ Deficit - Schedul

Stockholders’ Deficit - Schedule of Preferred Stock Dividends Earned (Details)	12 Months Ended
	Feb. 28, 2022 USD ($) Number shares	Feb. 28, 2021 USD ($) Number shares	Feb. 29, 2020 USD ($) Number shares	Feb. 28, 2019 USD ($) Number shares	Feb. 28, 2018 USD ($) Number shares	Feb. 28, 2017 USD ($) Number shares	Feb. 29, 2016 USD ($) Number shares	Feb. 28, 2015 USD ($) Number shares	Feb. 28, 2014 USD ($) Number shares	Feb. 28, 2013 USD ($) Number shares	Feb. 29, 2012 USD ($) Number shares	Feb. 28, 2011 USD ($) Number shares	Feb. 28, 2010 USD ($) Number shares	Feb. 28, 2009 USD ($) Number shares	Feb. 29, 2008 USD ($) Number shares	Feb. 28, 2007 USD ($) Number
Class of Stock [Line Items]
Shares of common stock issued from conversion	4,199,295
Shares of Series A Preferred converted to Common Stock	1,399,765
Shareholders at Period End | Number		56	56	56	56	57	57	58	59	68	70	70	74	78	90	100
Dividends, Preferred Stock | $	$ 96,340	$ 127,714	$ 128,063	$ 127,714	$ 128,231	$ 130,415	$ 130,925	$ 132,634	$ 151,323	$ 161,906	$ 163,624	$ 173,707	$ 189,973	$ 209,973	$ 242,126	$ 155,311
Accumulated dividends | $	$ 2,449,979
Series A Preferred Stock
Class of Stock [Line Items]
Shares of common stock issued from conversion	2,128,704	0	0	0	44,991	0	30,000	9,000	453,000	54,000	0	306,000	155,700	711,000	306,900
Number of Accredited Investors | Number	56	0	0	0	1	0	1	1	9	2	0	4	4	12	10
Shares of Series A Preferred converted to Common Stock	709,568				14,997		10,000	3,000	151,000	18,000		102,000	51,900	237,000	102,300

Stockholders' Deficit - Schedul

Stockholders' Deficit - Schedule of Common Stock Outstanding (Details) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Accumulated Other Comprehensive Income (Loss) [Line Items]
Conversion of Series A preferred stock
Conversion of accrued employee salaries		681,577
Conversion of accrued director fees		142,969
Conversion of 12% Note principal and interest - related party		514,986
Conversion of production revenue program principal - related party		550,100
Conversion of 12% Note principal and interest - related party	$ 35,520
Shares issued for conversion of convertible note	236,000
Shares issued for acquisition of crude oil and natural gas properties	6,599,544
Adjustment to common stock
Common Stock
Accumulated Other Comprehensive Income (Loss) [Line Items]
Shares outstanding	67,802,273	60,491,122
Conversion of Series A preferred stock, shares		2,128,704
Conversion of Series A preferred stock		$ 2,129
Conversion of Series A accumulated dividend, shares		1,100,000
Conversion of Series A accumulated dividend		$ 1,100
Conversion of accrued employee salaries, shares		1,397,880
Conversion of accrued employee salaries		$ 1,398
Conversion of accrued director fees, shares		317,708
Conversion of accrued director fees		$ 318
Conversion of 12% Note principal and interest - related party, shares	78,934	1,144,415
Conversion of 12% Note principal and interest - related party		$ 1,144
Conversion of production revenue program principal - related party, shares		1,222,444
Conversion of production revenue program principal - related party		$ 1,222
Conversion of 12% Note principal and interest - related party	$ 79	$ 79
Shares issued for conversion of convertible note, shares	27,764,706
Shares issued for conversion of convertible note	$ 27,765
Shares issued for acquisition of crude oil and natural gas properties, shares	160,964,489
Shares issued for acquisition of crude oil and natural gas properties	$ 160,964
Sale of common stock, shares	125,000,000
Sale of common stock	$ 125,000
Sale of common stock, shares	3,125,000
Shares issued for financing fees, par value	$ 3,125
Adjustment to common stock, shares	(500)
Adjustment to common stock	$ 1
Shares outstanding	384,734,902	67,802,273

STOCKHOLDERS_ EQUITY (DEFICIT_2

STOCKHOLDERS’ EQUITY (DEFICIT) (Details Narrative) - USD ($)	1 Months Ended	12 Months Ended
	Dec. 31, 2023	Feb. 28, 2023	Feb. 28, 2022	May 20, 2022	Feb. 28, 2021
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated dividends			$ 2,449,979
Common stock, shares authorized		500,000,000	500,000,000	500,000,000	200,000,000
Common stock, par value		$ 0.001	$ 0.001
Common stock, shares issued		384,734,902	67,802,273
Common stock, shares outstanding		384,734,902	67,802,273
Equity Exchange Agreement
Accumulated Other Comprehensive Income (Loss) [Line Items]
Shares, Issued			7,311,151
[custom:SharesIssuedToSatisfyRelatedPartyDebt-0]			4,082,447
[custom:SharesIssuedToSatisfySeriesApreferredStockConversion-0]			3,228,704
Dividends, Common Stock, Stock			$ 2,449,979
Common Stock
Accumulated Other Comprehensive Income (Loss) [Line Items]
Common stock dividend shares issued			1,100,000
Shares, Issued		316,933,129
[custom:ConversionOf12PercentNotePrincipalAndInterestRelatedPartyShares]		78,934	1,144,415
Adjustment to common stock, shares		500
Common Stock | Subsequent Event
Accumulated Other Comprehensive Income (Loss) [Line Items]
Adjustment to common stock, shares	500
Common Stock | Production Payment Program
Accumulated Other Comprehensive Income (Loss) [Line Items]
Shares, Issued		155,889,706
Common Stock | Reabold CA, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Shares, Issued		160,964,489

Warrants - Schedule of Warrant

Warrants - Schedule of Warrant Activity (Details) - $ / shares	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Warrants
Warrants outstanding	2,100,000	2,100,000
Weighted average exercise price	$ 0.01	$ 0.01
Issued	0	0
Expired / cancelled / forfeited	0	0
Warrants exercisable	2,100,000	893,333
Warrants outstanding	2,100,000	2,100,000
Weighted average exercise price	$ 0.01	$ 0.01
Weighted average exercise price, warrants exercisable	$ 0.01

WARRANTS (Details Narrative)

WARRANTS (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022	Feb. 29, 2020
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Fair value of warrants issued		$ 4,913
Warrants exercisable	2,100,000	893,333
Weighted average exercise price	$ 0.01
Weighted average remaining life	9 months 29 days
Intrinsic value	$ 25,200
Compensation Expense, Excluding Cost of Good and Service Sold	$ 0	$ 4,913
Share Based Payment Arrangement - Non-Employee
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]
Warrants issued for investor relations services			2,100,000
Fair value of warrants issued			$ 17,689
Vesting period			3 years
Risk free interest rate			1.68%
Volatility rate			260.23%
Dividend yield			0%

Income Taxes - Schedule of Reco

Income Taxes - Schedule of Reconciliation Between Actual Tax Expense Benefit and Income Taxes Computed by Applying Income Tax Rate (Details) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Income Tax Disclosure [Abstract]
Computed at U.S. and state statutory rates	$ (724,883)	$ (118,897)
Permanent differences	19,156	11,157
Changes in valuation allowance	705,727	107,740
Total

Income Taxes - Schedule of Defe

Income Taxes - Schedule of Deferred Tax Assets and Liabilities (Details) - USD ($)	Feb. 28, 2023	Feb. 28, 2022
Deferred tax assets:
Net operating loss carryforwards	$ 6,108,775	$ 5,670,900
Oil and gas properties	355,546	87,694
Stock based compensation	66,187	66,187
Other	27,838	27,838
Less valuation allowance	(6,558,346)	(5,852,619)
Total

INCOME TAXES (Details Narrative

INCOME TAXES (Details Narrative) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022	Feb. 28, 2020	Feb. 28, 2019	Feb. 28, 2021	Feb. 28, 2018
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards	$ 20,471,769
Increase in valuation allowance	705,727	$ 107,740
Tax Cuts and Jobs Act
Operating Loss Carryforwards [Line Items]
Change in corporate income tax rate			21%	35%
NOL portion not subject to expiration	$ 107,740	$ 279,773	$ 339,299		$ 416,898	$ 340,749

SUBSEQUENT EVENTS (Details Narr

SUBSEQUENT EVENTS (Details Narrative) - Subsequent Event - Unsecured - Chief Executive Officer	1 Months Ended
	Jul. 27, 2023 USD ($)
Subsequent Event [Line Items]
Proceeds from related party debt	$ 60,000
Maturity date	Jul. 27, 2024

Supplementary Information for_3

Supplementary Information for Crude Oil Producing Activities - Capitalized Costs Relating to Crude Oil and Natural Gas Producing Activities (Details) - USD ($)	Feb. 28, 2023	Feb. 28, 2022
Proved leasehold costs
Mineral Interests	$ 115,119	$ 115,119
Wells, equipment and facilities	8,577,693	3,651,122
Total Proved Properties	8,692,812	3,766,241
Unproved properties
Mineral Interests
Uncompleted wells, equipment and facilities
Total unproved properties
Less accumulated depreciation, depletion amortization and impairment	(3,566,612)	(3,230,209)
Total crude oil and natural gas properties, net	$ 5,126,200	$ 536,032

Supplementary Information for_4

Supplementary Information for Crude Oil Producing Activities - Costs Incurred in Oil and Gas Producing Activities (Details) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Extractive Industries [Abstract]
Acquisition of proved properties	$ 4,694,563
Acquisition of unproved properties
Development costs		6,773
Exploration costs
Total costs incurred	$ 4,694,563	$ 6,773

Supplementary Information for_5

Supplementary Information for Crude Oil Producing Activities - Results of Operations from Oil and Gas Producing Activities (Details) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Extractive Industries [Abstract]
Crude oil and natural gas revenues	$ 1,613,286	$ 680,107
Production costs	(1,103,825)	(231,275)
Exploration expenses		(56,213)
Depletion, depreciation and amortization	(504,118)	(49,590)
Impairment of crude oil and natural gas properties	(711,873)	0
Result of crude oil and natural gas producing operations before income taxes	(706,530)	343,029
Provision for income taxes	0	0
Results of crude oil and natural gas producing activities	$ (706,530)	$ 343,029

Supplementary Information for_6

Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Oil and Gas Reserves (Details)	12 Months Ended
	Feb. 28, 2023 Boe bbl Mcf		Feb. 28, 2022 Boe bbl Mcf
Reserve Quantities [Line Items]
Proved reserves | bbl	165,167		495,977
Proved reserves | Boe	165,167		495,977
Proved reserves | bbl	384,188		165,167
Proved reserves | Boe	393,910		165,167
Oil (Barrels)
Reserve Quantities [Line Items]
Proved reserves | bbl	517,155		434,223
Proved reserves, revisions | bbl	(393,076)	[1]	92,545	[2]
Proved reserves, discoveries and extensions | bbl	0		0
Proved reserves, production | bbl	(17,114)		(9,613)
Proved reserves, purchase of minerals | bbl	277,224
Proved reserves | bbl	384,188		517,155
Natural Gas (Mcf)
Reserve Quantities [Line Items]
Proved reserves | Mcf
Proved reserves, revisions | Mcf	0	[1]	0	[2]
Proved reserves, discoveries and extensions | Mcf	0		0
Proved reserves, production | Mcf	(3,822)		0
Proved reserves, purchase of minerals | Mcf	62,152
Proved reserves | Mcf	58,330
BOE (Barrels)
Reserve Quantities [Line Items]
Proved reserves | Boe	517,155		434,223
Proved reserves, revisions | Boe	(393,076)	[1]	92,545	[2]
Proved reserves, discoveries and extensions | Boe	0		0
Proved reserves, production | Boe	(17,751)		(9,613)
Proved reserves, purchase of minerals | Boe	287,582
Proved reserves | Boe	393,910		517,155
[1]A decrease in aggregate of 393,076 BOE resulted from upward revisions of 6,235 BOE of developed reserves due to an increase in the economic life of existing reserves due to an improvement in crude oil prices in the energy markets, offset by the removal of 399,311 BOE of proved undeveloped reserves that have remained undeveloped for a period greater than five years as of February 28, 2023.[2]The upward revision of 92,545 BOE of proved reserves in aggregate were due to an increase in the economic life of existing reserves due to an improvement in crude oil prices in the energy markets.

Supplementary Information for_7

Supplementary Information for Crude Oil Producing Activities - Schedule of Proved Developed and Undeveloped Reserves (Details)	Feb. 28, 2023 Boe bbl	Feb. 28, 2022 Boe bbl	Feb. 28, 2021 Boe bbl
Reserve Quantities [Line Items]
Proved developed and undeveloped reserves, net | bbl	384,188	165,167	495,977
Proved developed and undeveloped reserves, net - BOE | Boe	393,910	165,167	495,977
Oil (Barrels)
Reserve Quantities [Line Items]
Proved developed reserves | bbl	384,188	117,844	95,120
Proved undeveloped reserves | bbl		47,323	339.103
Proved developed and undeveloped reserves, net | bbl	384,188	517,155	434,223
BOE (Barrels)
Reserve Quantities [Line Items]
Proved developed reserves - BOE | Boe	393,910	117,844	95,120
Proved undeveloped reserve - BOE | Boe		47,323	339,103
Proved developed and undeveloped reserves, net - BOE | Boe	393,910	517,155	434,223

Supplementary Information for_8

Supplementary Information for Crude Oil Producing Activities - Standardized Measure of Discounted Future Cash Flows Relating to Proved Oil and Gas Reserves (Details) - USD ($)		Feb. 28, 2023	Feb. 28, 2022	Feb. 28, 2021
Extractive Industries [Abstract]
Future cash inflows		$ 35,775,832	$ 35,580,251
Future production costs	[1]	(17,162,238)	(16,217,379)
Future development costs		(725,938)	(3,603,561)
Future income tax expenses	[2]	0	0
Future net cash flows		17,887,656	15,759,311
10% annual discount for estimated timing of cash flows		(6,851,692)	(9,567,367)
Standardized measure of discounted future net cash flows at the end of the fiscal year		$ 11,035,964	$ 6,191,944	$ 1,648,418
[1]Production costs include crude oil and natural gas operations expense, production ad valorem taxes, transportation expense, workover costs and G&A expense supporting the Company’s crude oil and natural gas operations.[2]The Company has sufficient tax deductions and allowances related to proved crude oil and natural gas reserves to offset future net revenues.

Supplementary Information for_9

Supplementary Information for Crude Oil Producing Activities - Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure (Details) - $ / PerUnit		12 Months Ended
		Feb. 28, 2023	Feb. 28, 2022	Feb. 28, 2021
Crude Oil
Average oil and gas sales price	[1]	93.67	70.75	36.91
Natural Gas
Average oil and gas sales price	[1]	5.76	0	0
[1]Average prices were based on 12-month unweighted arithmetic average of the first-day-of-the-month prices for the period from March through February during each respective fiscal year.

Supplementary Information fo_10

Supplementary Information for Crude Oil Producing Activities - Schedule of Sources of Changes in Discounted Future Net Cash Flows (Details) - USD ($)	12 Months Ended
	Feb. 28, 2023	Feb. 28, 2022
Extractive Industries [Abstract]
Standardized measure of discounted future net cash flows at the beginning of the year	$ 6,191,944	$ 1,648,418
Extensions, discoveries and improved recovery, less related costs		906,390
Revisions of previous quantity estimates	(11,442,092)	44,898
Purchase of minerals in place	8,990,030
Net changes in prices and production costs	4,695,284	3,320,241
Accretion of discount	619,194	164,842
Sales of crude oil and natural gas produced, net of production costs	(509,461)	(448,832)
Changes in future development costs	2,022,097	(267,335)
Changes in timing of future production	468,968	823,322
Net changes in income taxes
Standardized measure of discounted future net cash flows at the end of the year	$ 11,035,964	$ 6,191,944