Daybreak Oil and Gas (DBRM) 10-K 22 May 15 2015 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Feb. 28, 2015	20-May-15	Aug. 29, 2014
Document And Entity Information
Entity Registrant Name	Daybreak Oil & Gas, Inc.
Entity Central Index Key	1164256
Document Type	10-K
Document Period End Date	28-Feb-15
Amendment Flag	FALSE
Current Fiscal Year End Date	-26
Is Entity a Well-known Seasoned Issuer?	No
Is Entity a Voluntary Filer?	No
Is Entity's Reporting Status Current?	Yes
Entity Filer Category	Smaller Reporting Company
Entity Public Float			$9,351,491
Entity Common Stock, Shares Outstanding		51,487,373
Document Fiscal Period Focus	FY
Document Fiscal Year Focus	2015

Balance_Sheets

Balance Sheets (USD $)	Feb. 28, 2015	Feb. 28, 2014
CURRENT ASSETS:
Cash and cash equivalents	$496,772	$500,431
Accounts receivable:
Oil and natural gas sales	202,732	330,343
Joint interest participants	51,382	338,950
Other receivables, net	160,996	30,039
Production revenue receivable - current	120,000	120,000
Prepaid expenses and other current assets	201,693	29,397
Note receivable - current	1,320,944	793,727
Total current assets	2,554,519	2,142,887
OIL AND NATURAL GAS PROPERTIES, successful efforts method, net
Proved properties	4,379,606	2,914,965
Unproved properties	733,478	1,261,156
PREPAID DRILLING COSTS	16,452	14,915
PRODUCTION REVENUE RECEIVABLE - NON-CURRENT	35,000	155,000
DEFERRED FINANCING COSTS, NET	1,058,751	1,326,600
NOTE RECEIVABLE - NON-CURRENT	3,429,056	2,756,273
OTHER ASSETS	106,199	106,114
Total assets	12,313,061	10,677,910
CURRENT LIABILITIES:
Accounts payable and other accrued liabilities	1,435,677	2,158,546
Accounts payable - related parties	905,891	952,652
Accrued interest	158,797	1,587
Notes payable, related party	250,100	250,100
Debt - current portion, net	4,691,211	2,024,417
Line of credit	869,865	882,369
Total current liabilities	8,311,541	6,269,671
LONG TERM LIABILITIES:
12% Notes payable, net	315,000	327,871
12% Notes payable - related party, net	250,000	237,395
Debt - non-current, net	8,591,507	6,629,638
Asset retirement obligation	29,603	22,079
Total liabilities	17,497,651	13,486,654
COMMITMENTS AND CONTINGENCIES
STOCKHOLDERS' DEFICIT:
Preferred stock	0	0
Common stock	51,457	55,509
Additional paid-in capital	22,968,734	24,607,582
Accumulated deficit	-28,205,516	-27,472,573
Total stockholders' deficit	-5,184,590	-2,808,744
Total liabilities and stockholders' deficit	12,313,061	10,677,910
Series A Convertible Preferred Stock
STOCKHOLDERS' DEFICIT:
Preferred stock	$735	$738

Balance_Sheets_Parenthetical

Balance Sheets (Parenthetical) (USD $)	Feb. 28, 2015	Feb. 28, 2014
Preferred stock, par value in dollars	$0.00	$0.00
Preferred stock, shares authorized	10,000,000	10,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Common stock, par value in dollars	$0.00	$0.00
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	51,457,373	55,509,411
Common stock, shares outstanding	51,457,373	55,509,411
Series A Convertible Preferred Stock
Preferred stock, par value in dollars	$0.00	$0.00
Preferred stock, shares authorized	2,400,000	2,400,000
Preferred stock, shares issued	734,565	737,565
Preferred stock, shares outstanding	734,565	737,565
Preferred stock, cumulative dividend rate	6.00%	6.00%

Statements_of_Operations

Statements of Operations (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
REVENUE:
Oil and natural gas sales	$3,083,797	$1,802,791
OPERATING EXPENSES:
Production	329,917	216,771
Exploration and drilling	42,997	251,543
Depreciation, depletion, amortization and impairment	570,110	308,097
Loss on asset write down	0	39,446
General and administrative	1,103,042	1,264,272
Total operating expenses	2,046,066	2,080,129
OPERATING INCOME (LOSS)	1,037,731	-277,338
OTHER INCOME (EXPENSE):
Interest income	1,081,214	318,695
Interest expense	-2,795,369	-1,439,709
Loss on debt extinguishment	-56,519	0
Total other income (expense)	-1,770,674	-1,121,014
NET LOSS	-732,943	-1,398,352
Cumulative convertible preferred stock dividend requirement	-132,634	-151,323
NET LOSS AVAILABLE TO COMMON SHAREHOLDERS	($865,577)	($1,549,675)
NET LOSS PER COMMON SHARE, Basic and diluted	($0.02)	($0.03)
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING - Basic and diluted	54,126,721	52,044,497

Statements_of_Changes_in_Stock

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, 2013	$889	$48,838	$22,663,103	($26,074,221)	($3,361,391)
Beginning balance, shares at Feb. 28, 2013	888,565	48,837,939
Issuance of common stock for Kentucky oil project, value		3,498	556,279		559,777
Issuance of common stock for Kentucky oil project, shares		3,498,601
Issuance of common stock for debt financing , value		2,624	417,208		419,832
Issuance of common stock for debt financing, shares		2,623,951
Issuance of common stock for company stock plan, value			12,426		12,426
Cancellation of stock plan issuances, value		-4	-750		-754
Cancellation of stock plan issuances, shares		-4,080
Conversion of preferred stock, value	-151	453	-302		0
Conversion of preferred stock, shares	-151,000	453,000
Issuance of common stock for warrant excercise, value		100	13,900		14,000
Issuance of common stock for warrant exercise, shares		100,000
Warrants issued in connection with Kentucky oil project			513,314		513,314
Warrants issued in connection with debt financing			432,404		432,404
Net loss				-1,398,352	-1,398,352
Ending balance, value at Feb. 28, 2014	738	55,509	24,607,582	-27,472,573	-2,808,744
Ending balance, shares at Feb. 28, 2014	737,565	55,509,411
Issuance of common stock for company stock plan, value			2,515		2,515
Cancellation of stock plan issuances, value		-2	-488		-490
Cancellation of stock plan issuances, shares		-2,040
Conversion of preferred stock, value	-3	9	-6		0
Conversion of preferred stock, shares	-3,000	9,000
Transfer agent balancing adjustment, value		140	-140		0
Transfer agent balancing adjustment, shares		140,000
Shares purchase and cancellation, value		-5,695	-1,702,752		-1,708,447
Shares purchase and cancellation, shares		-5,694,823
Share-for-warrant exchange, value		-428	428		0
Share-for-warrant exchange, shares		-427,729
Issuance of common stock for warrant excercise, value		1,924	5,076		7,000
Issuance of common stock for warrant exercise, shares		1,923,554
Extension of Note warrants			56,519		56,519
Net loss				-732,943	-732,943
Ending balance, value at Feb. 28, 2015	$735	$51,457	$22,968,734	($28,205,516)	($5,184,590)
Ending balance, shares at Feb. 28, 2015	734,565	51,457,373

Statements_of_Cash_Flows

Statements of Cash Flows (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
CASH FLOWS FROM OPERATING ACTIVITIES:
NET LOSS	($732,943)	($1,398,352)
Adjustments to reconcile net loss to net cash provided by operating activities:
Stock compensation	2,515	12,426
Depreciation, depletion, impairment and ARO expense	570,110	308,097
Loss on asset write down	0	39,446
Amortization of debt discount	168,722	159,378
Amortization of deferred financing costs	422,408	223,772
Loss on debt extinguishment	56,519	0
Non-cash interest income	-85	-190
Changes in assets and liabilities:
Accounts receivable, oil and gas sales	127,611	-162,418
Accounts receivable - joint interest participants	287,568	-255,365
Accounts receivable - other	-11,447	61,276
Prepaid expenses and other current assets	-172,296	-944
Accounts payable and other accrued liabilities	-515,776	-1,280,564
Accounts payable - related parties	-46,761	158,449
Accrued interest	156,555	-43,075
Net cash provided by (used in) operating activities	312,700	-2,178,064
CASH FLOWS FROM INVESTING ACTIVITIES:
Prepaid drilling costs	-1,537	-14,915
Additions to note receivable	-4,762,500	-2,958,368
Collections of note receivable	3,562,500	50,000
Deferred interest	655	0
Additions to oil and natural gas properties	-1,516,201	-1,838,775
Net cash used in investing activities	-2,717,083	-4,762,058
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from non-current debt	5,700,000	7,076,885
Proceeds from warrant conversion	7,000	14,000
Payment of deferred financing fees	-345,000	0
Deferred financing fees	0	892,138
Payments on line of credit	-12,504	0
Principal payments on non-current debt	-2,948,772	-622,466
Net cash provided by financing activities	2,400,724	7,360,557
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS	-3,659	420,435
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	500,431	79,996
CASH AND CASH EQUIVALENTS AT END OF PERIOD	496,772	500,431
Cash paid for Interest	2,077,418	1,067,068
Cash paid for Income taxes	0	0
SUPPLEMENTAL CASH FLOW INFORMATION:
Unpaid additions to oil and natural gas properties	16,652	155,289
Interest converted to principal	0	31,911
Note paid directly from proceeds of note	0	362,816
Increase in note receivable for deferred interest	0	317,816
Increase in note payable for stock acquisition and subsequent retirement	1,708,447	0
ARO asset and liability increase due to timing differences	5,337	40,140
Share-to-warrant exchange	428	0
Shares and warrants issued for oil and gas properties and deferred financing costs	0	1,925,327
Conversion of warrants	1,874	0
Unpaid deferred financing fees	0	1,253,225
Repurchase of stock through payment of payroll taxes	490	754
Conversion of preferred stock to common stock	$9	$453

Organization_and_Basis_of_Pres

Organization and Basis of Presentation	12 Months Ended
	Feb. 28, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and Basis of Presentation	NOTE 1 — ORGANIZATION:
	Originally incorporated as Daybreak Uranium, Inc., (“Daybreak Uranium”) under the laws of the State of Washington on March 11, 1955, Daybreak Uranium was organized to explore for, acquire, and develop mineral properties in the Western United States. During 2005, management of the Company decided to enter the oil and natural gas exploration and production industry. On October 25, 2005, the Company’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 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, 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 oil and gas, the establishment of and compliance with production quotas by oil-exporting countries, the relative strength of the U.S. dollar, weather conditions, the price and availability of alternative fuels, and overall economic conditions, both foreign and domestic.

Going_Concern

Going Concern	12 Months Ended
	Feb. 28, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Going Concern	NOTE 2 — GOING CONCERN:
	Financial Condition
	Daybreak’s financial statements for the year ended February 28, 2015 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 $28,205,516 and a working capital deficit of $5,757,022, which raises substantial doubt about the Company’s ability to continue as a going concern.
	Management Plans to Continue as a Going Concern
	The Company continues to implement plans to enhance its ability to continue as a going concern. Daybreak currently has a net revenue interest in 20 producing wells in its East Slopes Project located in Kern County, California (the “East Slopes Project”). The revenue from these wells has created a steady and reliable source of revenue. The Company’s average working interest in these wells is 36.6% and the average net revenue interest is 28.4% for these same wells.
	Additionally, the Company has become involved in a shallow oil play in an existing natural gas field in Lawrence County, Kentucky, through its acquisition of a 25% working interest in approximately 7,300 acres in two large contiguous blocks in the Twin Bottoms Field in Lawrence County, Kentucky. Daybreak currently has a net revenue interest in 13 producing horizontal oil wells in the Twin Bottoms Field. The Company’s average working interest in these 13 horizontal oil wells is 22.4% and the average net revenue interest is 19.6% in these same wells.
	The Company anticipates revenues will continue to increase as it participates in the drilling of more wells in California and Kentucky. Daybreak plans to continue its development drilling programs in both California and Kentucky at a rate that is compatible with its cash flow; funding opportunities; and, hydrocarbon prices.
	The Company’s sources of funds in the past have included the debt or equity markets and the sale of assets. While the Company has experienced revenue growth which has resulted in positive cash flow from its 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, 2015 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_Account

Summary of Significant Accounting Policies	12 Months Ended
	Feb. 28, 2015
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	NOTE 3 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:
	Cash and Cash Equivalents
	Cash equivalents include demand deposits with banks and all highly liquid investments with original maturities of three months or less. The Company routinely maintains balances in financial institutions where deposits may exceed the Federally insured deposit limit of $250,000. The Company has not experienced any losses from such accounts and does not believe it is exposed to any significant credit risk on cash.
	Accounts Receivable
	The Company routinely assesses the recoverability of all material trade and other receivables. The Company accrues a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of any reserve may be reasonably estimated. Actual write-offs may exceed the recorded allowance. Substantially all of the Company’s trade accounts receivable result from crude oil and natural gas sales in California and Kentucky 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, 2015 and 2014.
	Oil and Gas Properties
	The Company uses the successful efforts method of accounting for oil and natural gas property acquisition, exploration, development, and production activities. Costs to acquire mineral interests in oil and natural gas properties, to drill and equip exploratory wells that find proved reserves, and to drill and equip development wells are capitalized as incurred. Costs to drill exploratory wells that are unsuccessful in finding proved reserves are expensed as incurred. In addition, the geological and geophysical costs, and costs of carrying and retaining unproved properties are expensed as incurred. Costs to operate and maintain wells and field equipment are expensed as incurred.
	Capitalized proved property acquisition costs are amortized by field using the unit-of-production method based on estimated proved reserves. Capitalized exploration well costs and development costs (plus estimated future dismantlement, surface restoration, and property abandonment costs, net of equipment salvage values) are amortized in a similar fashion (by field) based on their estimated proved developed reserves. Support equipment and other property and equipment are depreciated over their estimated useful lives.
	Pursuant to the provisions of Financial Accounting Standards Codification (“ASC”) Topic 360, “Property, Plant and Equipment” the Company reviews proved oil and natural gas properties and other long-lived assets for impairment. These reviews are predicated by events and circumstances, such as downward revision of the reserve estimates or commodity prices that indicate a decline in the recoverability of the carrying value of such properties. The Company estimates the future cash flows expected in connection with the properties and compares such future cash flows to the carrying amount of the properties to determine if the carrying amount is recoverable. When the carrying amounts of the properties exceed their estimated undiscounted future cash flows, the carrying amounts of the properties are reduced to their estimated fair value. The factors used to determine fair value include, but are not limited to, estimates of proved reserves, future commodity prices, the timing of future production, future capital expenditures and a risk-adjusted discount rate. These estimates of future product prices may differ from current market prices of oil and natural gas. Any downward revisions to management’s estimates of future production or product prices could result in an impairment of the Company’s oil and natural gas properties in subsequent periods. Unproved oil and natural gas properties that are individually significant are also periodically assessed for impairment of value. An impairment loss for unproved oil and natural gas properties is recognized at the time of impairment by providing an impairment allowance.
	The Company recognized asset impairments of $-0- and $84,929 for the years ended February 28, 2015 and 2014, respectively.
	On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated DD&A with a resulting gain or loss recognized in income.
	Property and Equipment
	Fixed assets are stated at cost. Depreciation on vehicles is provided using the straight-line method over expected useful lives of three years. Depreciation on machinery and equipment is provided using the straight-line method over expected useful life of three years. Depreciation of production facilities is recorded using the unit-of-production method based on estimated reserves.
	Long Lived Assets
	The Company reviews long-lived assets and identifiable intangibles whenever events or circumstances indicate that the carrying amounts of such assets may not be fully recoverable. The Company evaluates the recoverability of long-lived assets by measuring the carrying amounts of the assets against the estimated undiscounted cash flows associated with these assets. If this evaluation indicates that the future undiscounted cash flows of certain long-lived assets are not sufficient to recover the assets' carrying value, the assets are adjusted to their fair values (based upon discounted cash flows).
	Fair Value of Financial Instruments
	The carrying value of short-term financial instruments including cash, receivables, prepaid expenses, accounts payable, and other accrued liabilities, short-term liabilities and the line of credit approximated their fair values due to the relatively short period to maturity for these instruments. The long-term notes payable approximates fair value since the related rates of interest approximate current market rates.
	Share Based Payments
	Stock awards are accounted for under FASB ASC Topic 718, “Compensation-Stock Compensation” (“ASC 718”). Under ASC 718, compensation for all share-based payment awards is based on estimated fair value at the grant date. The value of the portion of the award that is ultimately expected to vest is recognized as expense on a straight-line basis over the requisite service periods, if any.
	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.
	Loss per Share of Common Stock
	Basic loss per share of Common Stock is calculated by dividing net loss available to common stockholders by the weighted average number of common shares issued and outstanding during the year. Diluted net loss per share is computed based on the weighted average number of common shares outstanding, increased by dilutive Common Stock equivalents. Common Stock equivalents are excluded from the calculations when their effect is anti-dilutive.
	Concentration of Credit Risk
	Substantially all of the Company’s accounts receivable result from crude oil and natural gas sales or joint interest billings to its working interest partners. This concentration of customers and joint interest owners may impact the Company’s overall credit risk as these entities could be affected by similar changes in economic conditions as well as other related factors.
	At the Company’s East Slopes project in California there is only one buyer available for the purchase of all oil production. At the Company’s Twin Bottoms Field project located in Lawrence County, Kentucky, there is only one buyer available for the purchase of its oil production and only one buyer available for the purchase of its natural gas production. At February 28, 2015 and 2014 these three individual customers represented 100.0% of crude oil and natural gas sales receivable. If these buyers are unable to resell its products or if they lose a significant sales contract then the Company may incur difficulties in selling its oil and gas production.
	The Company’s accounts receivable from California and Kentucky oil and natural gas sales at February 28, 2015 and 2014 are set forth in the table below.
			28-Feb-15			28-Feb-14
	Project	Customer	Revenue		Percentage	Revenue		Percentage
			Receivable			Receivable
	California – East Slopes Project (Oil)	Plains Marketing	$	95,150	46.90%	$	244,384	74.00%
	Kentucky – Twin Bottoms Field (Oil)	Appalachian Oil		90,906	44.90%		85,120	25.80%
	Kentucky – Twin Bottoms Field (Natural Gas)	Jefferson Gas		16,676	8.20%		839	0.20%
			$	202,732	100.00%	$	330,343	100.00%
	Revenue Recognition
	The Company uses the sales method to account for sales of crude oil and natural gas. Under this method, revenues are recognized based on actual volumes of oil and natural gas sold to purchasers. The volumes sold may differ from the volumes to which the Company is entitled based on its interests in the properties. These differences create imbalances that are recognized as a liability only when the imbalance exceeds the estimate of remaining reserves. The Company had no significant imbalances as of February 28, 2015 and 2014.
	Reclamation Bonds
	Included in other assets as of February 28, 2015, are funds that have been pledged as collateral in connection with asset retirement obligations for future plugging, abandonment and site remediation. The amount pledged for an operator bond in California is approximately $100,000 plus accrued interest. The pledging of these funds is required by any state in which the Company operates as the project Operator.
	Asset Retirement Obligation
	The Company follows the provisions of FASB ASC Topic 410, “Asset Retirement and Environmental Obligations” (“ASC 410”), which addresses financial accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs. This standard requires that the Company recognize the fair value of a liability for an asset retirement obligation (“ARO”) in the period in which it is incurred. The ARO is capitalized as part of the carrying value of the assets to which it is associated, and depreciated over the useful life of the asset. The ARO and the related asset retirement cost are recorded when an asset is first drilled, constructed or purchased. The asset retirement cost is determined and discounted to present value using a credit-adjusted risk-free rate. After initial recording, the liability is increased for the passage of time, with the increase being reflected as accretion expense in the statements of operations. Subsequent adjustments in the cost estimate are reflected in the ARO liability and the amounts continue to be amortized over the useful life of the related long-lived assets.
	Suspended Well Costs
	The Company accounts for any suspended well costs in accordance with FASB ASC Topic 932, “Extractive Activities – Oil and Gas” (“ASC 932”). ASC 932 states that exploratory well costs should continue to be capitalized if: (1) a sufficient quantity of reserves are discovered in the well to justify its completion as a producing well and (2) sufficient progress is made in assessing the reserves and the economic and operating feasibility of the well. If the exploratory well costs do not meet both of these criteria, these costs should be expensed, net of any salvage value. Additional annual disclosures are required to provide information about management’s evaluation of capitalized exploratory well costs.
	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”). As required under ASC 740, the Company accounts for income taxes using an asset and liability approach, which requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of temporary differences between the financial statements and tax bases of assets and liabilities at the applicable tax rates. A valuation allowance is utilized when it is more likely than not, that some portion of, or all of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates on the date of enactment.
	ASC 740 prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. Under ASC 740, the Company recognizes tax benefits only for tax positions that are more likely than not to be sustained upon examination by tax authorities. The amount recognized is measured as the largest amount of benefit that is greater than 50 percent likely to be realized upon settlement. A liability for “unrecognized tax benefits” is recorded for any tax benefits claimed in our tax returns that do not meet these recognition and measurement standards.
	Use of Estimates and Assumptions
	In preparing financial statements in conformity with accounting principles generally accepted in the United States of America, management is required to make estimates and assumptions. These estimates and assumptions may affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, and reported amounts of revenues and expenses during the reporting periods. Actual results could differ materially from those estimates. The accounting policies most affected by management’s estimates and assumptions are as follows:
	• The reliance on estimates of proved reserves to compute the provision for depreciation, depletion and amortization and to determine the amount of any impairment of proved properties;
	• The valuation of unproved acreage and proved oil and natural gas properties to determine the amount of any impairment of 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.
	Recent Accounting Pronouncements
	There are no new accounting pronouncements issued or effective that had, or are expected to have, a material impact on the Company’s financial statements.
	Reclassifications
	Certain reclassifications have been made to conform the prior period’s financial information to the current period’s presentation. These reclassifications had no effect on previously reported net loss or accumulated deficit.

Accounts_Receivable

Accounts Receivable	12 Months Ended
	Feb. 28, 2015
Receivables [Abstract]
Accounts Receivable	NOTE 4 — ACCOUNTS RECEIVABLE:
	Accounts receivable consists primarily of receivables from the sale of oil and natural gas production by the Company and receivables from the Company’s working interest partners in oil and natural gas projects in which the Company acts as Operator of the project.
	Oil and natural gas sales receivables balances at February 28, 2015 and 2014 primarily represent crude oil sales that occurred in February 2015 and 2014. Natural gas sales balances represent sales that occurred during the months of January and February 2015 and 2014.
	Joint interest participant receivables balances at February 28, 2015 and 2014 represent amounts due from working interest partners in California, where the Company is the Operator. There were no allowances for doubtful accounts for the Company’s trade accounts receivable at February 28, 2015 and 2014.
	Other receivables balances primarily include amounts due from third parties that were involved in arranging financing transactions for the Company that have not yet been consummated; amounts advanced to certain minority working interest partners in Kentucky; and, monthly interest receivable on the loan to App Energy. Allowances for doubtful accounts in other receivables relate to amounts due from third parties for financing transactions. Other receivables balances at February 28, 2015 and February 28, 2014 are set forth in the table below:
		28-Feb-15		28-Feb-14
	Other receivables	$	399,996	$	269,039
	Allowance for doubtful accounts		-239,000		-239,000
		$	160,996	$	30,039
	Note receivable balances (current and non-current) of $4.75 million in aggregate, represent amounts due from a third party who is the Operator of the Company’s oil and natural gas project, the Twin Bottoms field in Kentucky. Refer to the discussion in Note 8 – Note Receivable for further information on this note receivable.

Oil_and_Gas_Properties

Oil and Gas Properties	12 Months Ended
	Feb. 28, 2015
OIL AND NATURAL GAS PROPERTIES, successful efforts method, net
Oil and Gas Properties	NOTE 5 — OIL AND GAS PROPERTIES:
	Oil and gas property balances at February 28, 2015 and 2014 are set forth in the table below:
		28-Feb-15		28-Feb-14
	Proved leasehold costs	$	695,231	$	2,236
	Unproved leasehold costs		733,478		1,261,156
	Costs of wells and development		542,563		492,970
	Capitalized exploratory well costs		5,308,876		4,018,899
	Total cost of oil and gas properties		7,280,148		5,775,261
	Accumulated depletion, depreciation amortization and impairment		-2,167,064		-1,599,140
	Oil and gas properties, net	$	5,113,084	$	4,176,121
	Asset Retirement Obligation
	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 oil and natural gas properties by calculating the present value of estimated cash flows related to the liability. As of February 28, 2015 and 2014, ARO obligations were considered to be long term based on the estimated timing of the anticipated cash flows. For the years ended February 28, 2015 and 2014, the Company recognized accretion expense of $2,187 and $7,045, respectively which is included in DD&A in the statement of operations.
	Changes in the asset retirement obligations for the years ended February 28, 2015 and 2014 are set forth in the table below.
		28-Feb-15		28-Feb-14
	Asset retirement obligation, beginning of period	$	22,079	$	55,174
	Accretion expense		2,187		7,045
	Change in asset retirement estimates		5,337		-40,140
	Asset retirement obligation, end of period	$	29,603	$	22,079

Production_Revenue_Receivable

Production Revenue Receivable	12 Months Ended
	Feb. 28, 2015
Production Revenue Receivable
Production Revenue Receivable	NOTE 6 — PRODUCTION REVENUE RECEIVABLE:
	Production revenue receivable balances of $155,000 in aggregate represent amounts due the Company from a portion of the sale price of a 25% working interest in East Slopes Project in Kern County, California that was acquired through the default of certain original working interest partners in the project. Production revenue receivable balances at February 28, 2015 and 2014 are set forth in the table below:
		28-Feb-15		28-Feb-14
	Production revenue receivable – current	$	120,000	$	120,000
	Production revenue receivable – non-current		35,000		55,000
		$	155,000	$	275,000

Deferred_Financing_Costs

Deferred Financing Costs	12 Months Ended
	Feb. 28, 2015
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Deferred Financing Costs	NOTE 7 — DEFERRED FINANCING COSTS:
	Deferred financing costs at February 28, 2015 and 2014 relating to the original and the amended credit facility with Maximilian Resources LLC, a Delaware limited liability company and successor by assignment to Maximilian Investors LLC (either party, as appropriate, is referred to in these notes to the financial statements as “Maximilian”), are set forth in the table below:
		28-Feb-15		28-Feb-14
	Deferred financing costs – loan fees	$	151,139	$	151,139
	Deferred financing costs – loan commissions		630,662		476,103
	Deferred financing costs – fair value of warrants		530,488		530,488
	Deferred financing costs – fair value of common stock		419,832		419,832
			1,732,121		1,577,562
	Accumulated amortization		-673,370		-250,962
		$	1,058,751	$	1,326,600
	Amortization expense of deferred financing costs was $422,408 and $223,772 for the years ended February 28, 2015 and 2014, respectively. Deferred financing costs of $950,320 at February 28, 2015 include the fair value of common shares and warrants issued to Maximilian and to a third party that assisted in both the original and the amended financing transactions. Refer to the discussion in Note 11 – Current and Non-current Borrowings for further information on the deferred financing costs.

Note_Receivable

Note Receivable	12 Months Ended
	Feb. 28, 2015
Receivables [Abstract]
Note Receivable	NOTE 8 — NOTE RECEIVABLE:
	On August 28, 2013, the Company amended its credit facility with Maximilian as a part of a financing transaction in which the Company extended to App Energy, LLC, a Kentucky limited liability company (“App”) a credit facility for the development of a shallow oil project in an existing gas field, the Twin Bottoms Field, in Lawrence County, Kentucky. (See Note 11 – Current and Non-current Borrowings).
	The Company’s loan agreement with App, dated August 28, 2013, provides for a revolving credit facility of up to $40 million, maturing on August 28, 2017, with a minimum commitment of $2.65 million (the “Initial Advance”). All funds advanced to App, as borrower, by Daybreak, as lender, are to be borrowed by Daybreak under its amended loan agreement with Maximilian. The Initial Advance bears interest of 16.8% per annum, and subsequent loans under the loan agreement bear interest at a rate of 12% per annum. The App loan agreement also provides for a monthly commitment fee of 0.6% on the outstanding principal balance of the loans. The obligations under the App loan agreement are secured by a perfected first priority security interest in substantially all of the assets of App, including its leases (“Kentucky Acreage”) in Lawrence County, Kentucky; an indemnity provided by App’s manager, John A. Piedmonte, Jr.; and, a guarantee by certain affiliates of App.
	The App loan agreement contains customary covenants for loan of such type, including, among other things, covenants that restrict App’s ability to make capital expenditures, incur indebtedness, incur liens and dispose of property. The App loan agreement also contains various events of default, including failure to pay principal and interest when due, breach of covenants, materially incorrect representations and bankruptcy or insolvency. If an event of default occurs, all of App’s obligations under the App loan agreement could be accelerated by the Company, causing all loans outstanding (including accrued interest and fees payable thereunder) to be declared immediately due and payable.
	The proceeds of the initial borrowing by App of $2.65 million under the App revolving credit facility were primarily used to (a) pay loan fees and closing costs, (b) repay App’s indebtedness and (c) finance the drilling of three wells by App in the Kentucky Acreage. Future advances under the facility will primarily be used for oil and gas exploration and development activities.
	In connection with the App loan agreement, App also granted to the Company an average 25% working interest in the Kentucky Acreage, as described above. The fair value of the 25% working interest was determined to be $1,073,091 and was recorded as unproved oil and gas properties. Refer to Note 11 for further discussion on the related fair value.
	Note receivable balances at February 28, 2015 and 2014 are set forth in the table below:
		28-Feb-15		28-Feb-14
	Note receivable – current	$	1,320,944	$	793,727
	Note receivable – non-current		3,429,056		2,756,273
		$	4,750,000	$	3,550,000

Accounts_Payable

Accounts Payable	12 Months Ended
	Feb. 28, 2015
Payables and Accruals [Abstract]
Accounts Payable	NOTE 9 — ACCOUNTS PAYABLE:
	On March 1, 2009, the Company became the operator for the East Slopes Project located in Kern County, California. Additionally, the Company then assumed certain original defaulting partners’ approximate $1.5 million liability representing a 25% working interest in the drilling and completion costs associated with the East Slopes Project four earning wells program. The Company subsequently sold the 25% working interest on June 11, 2009. Approximately $252,349 of the $1.5 million default remains unpaid and is included in the February 28, 2015 accounts payable balance.

Accounts_Payable_Related_Parti

Accounts Payable - Related Parties	12 Months Ended
	Feb. 28, 2015
Related Party Transactions [Abstract]
Accounts Payable - Related Parties	NOTE 10 — ACCOUNTS PAYABLE- RELATED PARTIES:
	The February 28, 2014 and 2013 accounts payable – related parties balances were comprised primarily of salaries of the Company’s Executive Officers and certain employees; directors’ fees; expense reimbursements; related party consulting fees; and interest to the Company’s Chairman, President and Chief Executive Officer on the 12% Notes. Payment of these deferred items has been delayed until the Company’s cash flow situation improves.

ShortTerm_and_LongTerm_Borrowi

Short-Term and Long-Term Borrowings	12 Months Ended
	Feb. 28, 2015
Debt Disclosure [Abstract]
Short-Term and Long-Term Borrowings	NOTE 11 — SHORT-TERM AND LONG-TERM BORROWINGS:
	Current Debt
	Note Payable – Related Party
	As of February 28, 2015 and 2014, the Company’s Chairman, President and Chief Executive Officer has loaned the Company $250,100 in aggregate that has been used for a variety of corporate purposes including an escrow requirement on a loan commitment; extension fees on third party loans; and a reduction of principal on the Company’s credit line with UBS Bank. These loans are non-interest bearing loans and repayment will be made upon a mutually agreeable date in the future.
	Line of Credit
	The Company has an existing $890,000 line of credit for working capital purposes with UBS Bank USA (“UBS”), established pursuant to a Credit Line Agreement dated October 24, 2011 that is secured by the personal guarantee of the Company’s Chairman, President and Chief Executive Officer. At February 28, 2015 and 2014, the Line of Credit had an outstanding balance of $869,865 and $882,369, respectively. Interest is payable monthly at a stated reference rate of 0.249% + 337.5 basis points and totaled $31,498 and $31,911 for the years ended February 28, 2015 and 2014, respectively. The reference rate is based on the 30 day LIBOR (“London Interbank Offered Rate”) and is subject to change from UBS.
	Non-current Debt
	12% Subordinated Notes
	The Company’s 12% Subordinated Notes (“the Notes”) issued pursuant to a March 2010 private placement, resulted in $595,000 in gross proceeds (of which $250,000 was from a related party) to the Company and accrue interest at 12% per annum, payable semi-annually on January 29th and July 29th. The note principal was payable in full at the maturity of the Notes, which was January 29, 2015. Effective January 29, 2015, 12 of the 13 noteholders agreed to extend the maturity date of the Notes to January 29, 2017. The one noteholder who chose not to extend the maturity date of his Note, received the principal of $30,000 upon returning his Note to the Company. Should the Board of Directors, on the extended maturity date, decide that the payment of the principal and any unpaid interest would impair the financial condition or operations of the Company, the Company may then elect a mandatory conversion of the unpaid principal and interest into the Company’s common stock at a conversion rate equal to 75% of the average closing price of the Company’s common stock over the 20 consecutive trading days preceding December 31, 2016.
	In conjunction with the Notes private placement, a total of 1,190,000 common stock purchase warrants were issued at a rate of two warrants for every dollar raised through the private placement. The warrants have an exercise price of $0.14 and expire on January 29, 2015. The fair value of the warrants, as determined by the Black-Scholes option pricing model, was $116,557 using the following weighted average assumptions: a risk free interest rate of 2.33%; volatility of 147.6%; and dividend yield of 0.0%. The fair value of the warrants was recognized as a discount to debt and was amortized over the initial term of the Notes using the effective interest method. Amortization expense was $29,734 and $22,934 for the years ended February 28, 2015 and 2014, respectively. At February 28, 2015, the debt discount was fully amortized.
	12% Notes balances at February 28, 2015 and 2014 are set forth in the table below:
		28-Feb-15		28-Feb-14
	12% Subordinated Notes	$	315,000	$	345,000
	12% Subordinated Notes discount		-		-17,129
		$	315,000	$	327,871
	12% Notes, related party balances at February 28, 2015 and 2014 are set forth in the table below:
		28-Feb-15		28-Feb-14
	12% Subordinated Notes, related party	$	250,000	$	250,000
	12% Subordinated Notes discount, related party		-		-12,605
		$	250,000	$	237,395
	In conjunction with the maturity date extension of the Notes, the expiration date of the warrants was also extended an additional two years to January 29, 2017 for the noteholders who agreed to extend the terms of their notes.. All other terms of the warrants remained unchained. The fair value of the warrant extension, as determined by the Black-Scholes option pricing model, was $56,519 using the following weighted average assumptions: a risk free interest rate of 0.51%; volatility of 153.4%; and dividend yield of 0.0%. The extension of the Notes qualified as a debt extinguishment under ASC-470-50-40. The incremental fair value of the warrants was recognized as a loss on debt extinguishment.
	The 12% Note warrants that have been exercised are set forth in the table below.
	Fiscal Period		Warrants	Shares of		Number of
			Exercised	Common Stock		Accredited
				Issued		Investors
	Year ended February 28, 2014		100,000	100,000		1
	Year ended February 28, 2015		50,000	50,000		1
			150,000	150,000		2
	Maximilian Loan
	On October 31, 2012, the Company entered into a loan agreement with Maximilian, a related party, which provided for a revolving credit facility of up to $20 million, maturing on October 31, 2016, with a minimum commitment of $2.5 million. The loan had annual interest of 18% and a monthly commitment fee of 0.5%. The loan is secured by a perfected first priority security interest in substantially all of the assets of the Company, including the company’s leases in Kern County, California. The Company also granted Maximilian a 10% working interest in its share of the oil and gas leases in Kern County, California. The relative fair value of this 10% working interest amounting to $515,638 was recognized as a debt discount and is being amortized over the term of the loan. Amortization expense was $138,988 and $131,963 for the years ended February 28, 2015 and 2014, respectively. Unamortized debt discount amounted to $204,065 as of February 28, 2015.
	The Company also issued 2,435,517 warrants to third parties who assisted in the closing of the loan. The warrants have an exercise price of $0.044; contain a cashless exercise provision; have piggyback registration rights; and are exercisable for a period of five years expiring on October 31, 2017. The fair value of the warrants, as determined by the Black-Scholes option pricing model, was $98,084 and included the following assumptions: a risk free interest rate of 0.72%; stock price of $0.04, volatility of 153.44%; and a dividend yield of 0.0%. The fair value of the warrants was recognized as a financing cost and is being amortized as a part of deferred financing cost over the term of the loan. On March 10, 2014, one of the third parties exercised 2,118,900 warrants resulting in the issuance of 1,873,554 shares of the Company’s common stock.
	Maximilian Loan - Amended and Restated Loan Agreement
	In connection with the Company’s acquisition of a working interest from App in the Twin Bottoms Field in Lawrence County, Kentucky, the Company amended its loan agreement with Maximilian on August 28, 2013. The amended loan agreement provided for an increase in the revolving credit facility from $20 million to $90 million and a reduction in the annual interest rate from 18% to 12%. The monthly commitment fee of 0.5% per month on the outstanding principal balance remained unchanged. Advances under the amended loan agreement will mature on August 28, 2017. The obligations under the amended loan agreement continue to be secured by a perfected first priority security interest in substantially all of the personal property of the Company, and a mortgage on the Company’s leases in Kern County, California. The amended loan agreement also provided for the revolving credit facility to be divided into two borrowing sublimits. The first borrowing sublimit is $50 million and is for borrowing by the Company, primarily for its ongoing oil and gas exploration and development activities. The second borrowing sublimit, of $40 million, is for loans to be extended by the Company, as lender, to App, as borrower pursuant to a Loan and Security Agreement entered into between the Company and App on August 28, 2013 (See Note 8 – Note Receivable).
	The amended loan agreement contains customary covenants for loan of such type, including among other things, covenants that restrict the Company’s ability to make capital expenditures, incur indebtedness, incur liens and dispose of property. The amended loan agreement also contains various events of default, including failure to pay principal and interest when due, breach of covenants, materially incorrect representations and bankruptcy or insolvency. If an event of default occurs, all of the Company’s obligations under the amended loan agreement could be accelerated by Maximilian, causing all loans outstanding (including accrued interest and fees payable thereunder) to be declared immediately due and payable.
	As consideration for Maximilian facilitating the Company’s transactions with App and entering into the amended loan agreement, the Company (a) issued to Maximilian approximately 6.1 million common shares, representing 9.99% of the Company’s outstanding common stock on a fully-diluted basis at the time of grant, and (b) issued approximately 6.1 million warrants to purchase shares of the Company’s common stock representing the right to purchase up to an additional 9.99% of the Company’s outstanding common stock on a fully-diluted basis, calculated as of the date of grant. The warrants have an exercise price of $0.10; contain a cash exercise provision and are exercisable for a period of three years expiring on August 28, 2016 shares and warrants as described in the paragraph below. The Company also granted to Maximilian a 50% net profits interest in the Company’s 25% working interest, after the Company recovers its investment, in the Company’s working interest in its Kentucky Acreage, pursuant to an Assignment of Net Profits Interest entered into as of August 28, 2013 by and between the Company and Maximilian.
	The fair value of the 6.1 million shares was determined to be $979,609 based on the Company’s stock price on the grant date of $0.16. The fair value of the warrants, as determined by the Black-Scholes option pricing model, was $898,299 and included the following assumptions: a risk free interest rate of 2.48%; stock price of $0.16, volatility of 184.53%; and a dividend yield of 0.0%. The Company determined that the common shares and warrants were issued in connection with the increase in Company’s borrowing limit and App’s $40 million revolving credit facility for which the Company was granted a 25% working interest. Consequently, the fair value of the common shares and warrants totaling $1,877,907 was allocated to deferred financing costs ($804,816) and unproved oil and gas properties ($1,073,091) based on the amount of the increase in the revolving credit facility that is attributable to Daybreak and App.
	On February 14, 2014, the Company at the request of Maximilian, amended the warrant agreement related to the above issuance of approximately 6.1 million warrants to include a warrant exercise blocker provision that would effectively prevent any exercise of the warrants if such exercise and related issuance of common stock would increase the Maximilian holdings of the Company’s common stock to more than 9.99% of the currently issued and outstanding shares at the time of the exercise. All other terms of the original warrant agreement remained unchanged.
	The Company also issued 309,503 warrants to third parties who assisted in the closing of the amended and restated loan agreement. The warrants have an exercise price of $0.214; contain a cashless exercise provision; have piggyback registration rights; and are exercisable for a period of five years expiring on August 28, 2018. The fair value of the warrants, as determined by the Black-Scholes option pricing model, was $47,420 and included the following assumptions: a risk free interest rate of 2.48%; stock price of $0.16, volatility of 184.53%; and a dividend yield of 0.0%. The fair value of the warrants was recognized as a financing cost and is being amortized as a part of deferred financing cost over the term of the revolving credit facility.
	The Company evaluated the amendment of the revolving credit facility under ASC 470-50-40 and determined that the Company’s borrowing capacity under the amended loan agreement exceeded its borrowing capacity under the old loan agreement. Consequently, the unamortized discount and deferred financing costs as of the date of amendment of approximately $400,349 and the new deferred financing costs, as mentioned above, were amortized over the term of the amended loan agreement.
	The fair value of the above warrant issuances that were recognized as a deferred financing cost are being amortized over the term of the loan. Amortization expense for the years ended February 28, 2015 and 2014 was $127,513 and $76,017, respectively. Unamortized deferred financing costs amounted to $318,783 as of February 28, 2015.
	On May 28, 2014, at Maximilian’s request, the Company finalized a share-for-warrant exchange agreement in which Maximilian returned to the Company 427,729 common shares and was in turn issued the same number of warrants containing the same provisions as the originally issued warrants. This share-for-warrant exchange occurred so that Maximilian would hold no more than 9.99% of the Company’s common shares, issued and outstanding. The Company determined that the share-for-warrant exchange did not result in any incremental fair value.
	On August 21, 2014, the Company entered into a First Amendment to Amended and Restated Loan and Security Agreement and Share Repurchase Agreement (the “Amendment”) with Maximilian under its Amended and Restated Loan and Security Agreement dated as of August 28, 2013. The Amendment secured for the Company an additional advance of $2,200,000 under its credit facility with Maximilian since the advances made by Maximilian had already exceeded its minimum funding commitment. Additionally, Maximilian agreed to temporarily reduce the required monthly payment made by the Company until it has paid $1,000,000 less than principal payments required by the previous agreement. As of February 28, 2015, the Company had recognized $700,000 of the reduced monthly principal payments program. Furthermore, Maximilian agreed to reduce the regular interest rate applicable to the loan from 12% per annum to 9% per annum and the default interest rate by 3%.
	The additional advance, the reduction in the required monthly payment and the reduction in the interest rate were facilitated through the Company’s acquisition of 5,694,823 shares of its common stock held by Maximilian. The repurchased shares were cancelled and restored to the status of authorized, but unissued stock. The Company paid for the share repurchase transaction through an advance of $1,708,447 under the existing loan agreement with Maximilian.
	During the year ended February 28, 2015, the Company received multiple advances of approximately $7.4 million in aggregate that were used to participate in the multi-well drilling program at the Twin Bottoms Field in Kentucky; to advance funds to App through a long-term note receivable; and, to fund the acquisition of the Company’s common stock from Maximilian. The Company made principal payments of approximately $2.9 million to Maximilian during the year ended February 28, 2015. The Company has recognized $154,559 during the year ended February 28, 2015 in deferred financing costs associated with these advances which are being amortized over the amended term of the revolving credit facility.
	Current debt balances at February 28, 2015 and 2014 are set forth in the table below:
		28-Feb-15		28-Feb-14
	Maximilian Note	$	4,823,325	$	2,163,405
	Maximilian Note Discount		-132,114		-138,988
		$	4,691,211	$	2,024,417
	Non-current debt balances at February 28, 2015 and 2014 are set forth in the table below:
		28-Feb-15		28-Feb-14
	Maximilian Note	$	8,663,458	$	6,833,703
	Maximilian Note Discount		-71,951		-204,065
		$	8,591,507	$	6,629,638

Stockholders_Deficit

Stockholders' Deficit	12 Months Ended
	Feb. 28, 2015
Equity [Abstract]
Stockholders' Deficit	NOTE 12 — STOCKHOLDERS’ DEFICIT:
	Preferred Stock
	The Company is authorized to issue up to 10,000,000 shares of preferred stock with a par value of $0.001. The Company’s preferred stock may be entitled to preference over the common stock with respect to the distribution of assets of the Company in the event of liquidation, dissolution, or winding-up of the Company, whether voluntarily or involuntarily, or in the event of any other distribution of assets of the Company among its shareholders for the purpose of winding-up its affairs. The authorized but unissued shares of preferred stock may be divided into and issued in designated series from time to time by one or more resolutions adopted by the Board of Directors. The directors in their sole discretion shall have the power to determine the relative powers, preferences, and rights of each series of preferred stock.
	Series A Convertible Preferred Stock
	The Company has designated 2,400,000 shares of the 10,000,000 preferred shares as Series A Convertible Preferred Stock (“Series A Preferred”), with a $0.001 par value. In July 2006, we completed a private placement of the Series A Preferred that resulted in the issuance of 1,399,765 shares to 100 accredited investors.
	The following is a summary of the rights and preferences of the Series A Preferred.
	Voluntary Conversion:
	The Series A Preferred that is currently issued and outstanding is eligible to be converted by the shareholder at any time into three shares of the Company’s common stock. During the years ended February 28, 2015 and 2014, there were one and nine conversions of 3,000 and 151,000 shares of Series A Preferred that occurred resulting in 9,000 and 453,000 shares of our common stock being issued, respectively.
	At February 28, 2015, there were 734,565 shares issued and outstanding, that had not been converted into our common stock. As of February 28, 2015, there are 42 accredited investors who have converted 665,200 Series A Preferred shares into 1,995,600 shares of Daybreak common stock. The conversions of Series A Preferred that have occurred since the Series A Preferred was first issued in July 2006 is set forth in the table below.
	Fiscal Period			Shares of Series A		Shares of	Number of
				Preferred Converted		Common Stock	Accredited
				to Common Stock		Issued from	Investors
						Conversion
	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
	Totals		665,200			1,995,600	42
	Automatic Conversion:
	The Series A Preferred shall be automatically converted into the Company’s common stock if the common stock into which the Series A Preferred are convertible the Company’s common stock closes at or above $3.00 per share for 20 out of 30 trading days.
	Dividend:
	Holders of Series A Preferred shall be paid dividends, in the amount of 6% of the original purchase price per annum. Dividends may be paid in cash or common stock at the discretion of the Company. Dividends are cumulative from the date of the final closing of the private placement, whether or not in any dividend period or periods we have assets legally available for the payment of such dividends. Accumulations of dividends on shares of Series A Preferred do not bear interest. Dividends are payable upon declaration by the Board of Directors.
	Cumulative dividends earned for each fiscal year since issuance are set forth in the table below:
	Fiscal Year Ended		Shareholders at		Accumulated
			Period End		Dividends
	28-Feb-07		100		$	155,311
	29-Feb-08		90			242,126
	28-Feb-09		78			209,973
	28-Feb-10		74			189,973
	28-Feb-11		70			173,707
	29-Feb-12		70			163,624
	28-Feb-13		68			161,906
	28-Feb-14		59			151,323
	28-Feb-15		58			132,634
					$	1,580,577
	Liquidation Preference:
	In the event of any liquidation, dissolution or winding up of the Company, either voluntary or involuntary, the holders of the Series A Preferred shall be entitled to receive, prior and in preference to any distribution of any of the assets or surplus funds of the Company to the holders of common stock by reason of their ownership thereof, and subject to the rights of any series of preferred stock that may rank on liquidation prior to the Series A Preferred, an amount equal to all accrued or declared but unpaid dividends on such shares, for each share of Series A Preferred then held by them. The remaining assets shall be distributed ratably to the holders of common stock and Series A Preferred on a common equivalent basis. Certain other events, as described in our Amended and Restated Articles of Incorporation, including a consolidation or merger of the Company or the disposition of the Company’s assets, may trigger the payment of the liquidation preference to the holders of Series A Preferred.
	Voting Rights:
	The holders of the Series A Preferred will vote together with the common stock and not as a separate class except as specifically provided or as otherwise required by law. Each share of the Series A Preferred shall have a number of votes equal to the number of shares of common stock then issuable upon conversion of such shares of Series A Preferred.
	Common Stock
	The Company is authorized to issue up to 200,000,000 shares of $0.001 par value common stock of which 51,457,373 shares were issued and outstanding as of February 28, 2015. In comparison, at February 28, 2014, a total of 55,509,411 shares were issued and outstanding. This increase of 6,671,472 shares was attributable as shown below:
		Common Stock		Par Value
		Balance
	Common stock, Issued and Outstanding, February 28, 2014	55,509,411
	Conversion of Series A Convertible Preferred Stock to common stock	9,000		$	9
	Exercise of warrants issued with 12% Subordinated Notes	50,000		$	50
	Cashless exercise of warrants	1,873,554		$	1,874
	Common stock-for-warrant exchange (Maximilian)	-427,729		$	-428
	Transfer agent balancing adjustment	140,000		$	140
	Share purchase and cancellation (Maximilian)	-5,694,823		$	-5,695
	Common stock returned to 2009 Stock Plan (tax withholding liability)	-2,040		$	-2
	Common stock, Issued and Outstanding, February 28, 2015	51,457,373
	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.
	Common Stock Issued through Restricted Stock and Restricted Stock Unit Plan
	On April 6, 2009, the Board approved the 2009 Restricted Stock and Restricted Stock Unit Plan (the “2009 Plan”) allowing the executive officers, directors, consultants and employees of the Company and its affiliates to be eligible to receive restricted stock and restricted stock unit awards. Refer to the discussion in Note 12 for the issuances made under the 2009 Plan.

Warrants

Warrants	12 Months Ended
	Feb. 28, 2015
Warrants and Rights Note Disclosure [Abstract]
Warrants	NOTE 13 — WARRANTS:
	Warrants outstanding and exercisable as of February 28, 2015 are set forth in the table below:
		Warrants	Exercise	Remaining	Exercisable
			Price	Life	Warrants
				(Years)	Remaining
	12% Subordinated notes	1,190,000	$0.14	1.92	980,000
	Warrants issued in 2010 for services	150,000	$0.14	0.13	150,000
	Warrants issued in 2012 for debt financing	2,435,517	$0.04	2.67	316,617
	Warrants issued for Kentucky oil project	3,498,601	$0.10	1.5	3,498,601
	Warrants issued for Kentucky debt financing	2,623,951	$0.10	1.5	2,623,951
	Warrants issued for Kentucky debt financing	309,503	$0.21	3.5	309,503
	Warrants issued in share-for-warrant exchange	427,729	$0.10	1.5	427,729
		10,635,301			8,306,401
	For the years ended February 28, 2015 and 2014, a total of 60,000 and 1,624,012 warrants expired, respectively. The warrants that expired for the year ended February 28, 2015 had been issued in conjunction with the 12% Subordinated Note offering in 2010. During the years ended February 28, 2015 and 2014, there were 2,168,900 and 100,000 warrants exercised, respectively. The warrants that were exercised during the year ended February 28, 2015 had been issued in conjunction with the 12% Subordinated Note offering (50,000) and the 2012 debt financing (2,118,900). For the years ended February 28, 2015 and 2014, there were 427,729 and 6,432,055 warrants issued, respectively. The warrants issued in the year ended February 28, 2015 were issued in connection with share-for-warrant exchange with Maximilian. The outstanding warrants as of February 28, 2015 and 2014, have a weighted average exercise price of $0.11 and $0.09; a weighted average remaining life of 1.64 and 2.66 years; and an intrinsic value of $14,564 and $2,577,388, respectively.
	On May 28, 2014, at Maximilian’s request, the Company finalized a share-for-warrant exchange agreement in which Maximilian returned to the Company 427,729 common shares and was in turn issued the same number of warrants containing the same provisions as the originally issued warrants. This share-for-warrant exchange occurred so that Maximilian would hold no more than 9.99% of the Company’s common shares, issued and outstanding. The Company determined that the share-for-warrant exchange did not result in any incremental fair value.

Restricted_Stock_and_Restricte

Restricted Stock and Restricted Stock Unit Plan	12 Months Ended
	Feb. 28, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Restricted Stock and Restricted Stock Unit Plan	NOTE 14 — RESTRICTED STOCK and RESTRICTED STOCK UNIT PLAN:
	On April 6, 2009, the Board approved the 2009 Plan allowing the executive officers, directors, consultants and employees of the Company and its affiliates to be eligible to receive restricted stock and restricted stock unit awards. Subject to adjustment, the total number of shares of the Company’s common stock that will be available for the grant of awards under the 2009 Plan may not exceed 4,000,000 shares; provided, that, for purposes of this limitation, any stock subject to an award that is forfeited in accordance with the provisions of the 2009 Plan will again become available for issuance under the 2009 Plan.
	The Company believes that awards of this type further align the interests of its employees and its shareholders by providing significant incentives for these employees to achieve and maintain high levels of performance. Restricted stock and restricted stock units also enhance the Company’s ability to attract and retain the services of qualified individuals.
	During the year ended February 28, 2009, the Compensation Committee of the Board awarded a total of 2,550,000 restricted shares of the Company’s common stock to members of the Board of Directors, officers and employees of the Company. These shares were granted pursuant to the 2009 Plan and fully vest equally over a period ranging from three to four years.
	On July 22, 2010, the Compensation Committee of the Board awarded 25,000 restricted shares of its common stock to the five non-employee Directors as a part of the director compensation policy. These shares were granted pursuant to the 2009 Plan and fully vest equally over a period of three years.
	On July 22, 2010, the Compensation Committee of the Board awarded 425,000 restricted shares of its common stock to five employees of Daybreak. These shares were granted pursuant to the 2009 Plan and fully vest equally over a period of four years.
	For the years ended February 28, 2015 and 2014, an aggregate of 106,250 and 270,835 shares vested, respectively. For the years ended February 28, 2015 and 2014, the number of common shares available for issuance under the Plan increased by 2,040 and 4,080 shares, respectively. This increase was attributable to the return of common shares that were withheld pursuant to the settlement of the number of shares with a fair market value equal to such tax withholding liability, to satisfy such tax liability upon vesting of a restricted award by a Plan Participant.
	At February 28, 2015, a total of 3,000,000 shares of restricted stock had been awarded and 2,986,220 of those fully vested shares remained outstanding under the 2009 Plan. A total of 1,013,780 common stock shares remained available at February 28, 2015 for issuance pursuant to the 2009 Plan. A summary of the 2009 Plan issuances is set forth in the table below:
	Grant	Shares	Vesting	Shares	Shares	Shares
	Date	Awarded	Period	Vested(1)	Returned(2)	Outstanding
						(Unvested)
	4/7/09	1,900,000	3 Years	1,900,000	-	-
	7/16/09	25,000	3 Years	25,000	-	-
	7/16/09	625,000	4 Years	619,130(3)	5,870	-
	7/22/10	25,000	3 Years	25,000(4)	-	-
	7/22/10	425,000	4 Years	417,090(5)	7,910	-
		3,000,000		2,986,220(1)	13,780	-
	(1) Does not include shares that were withheld to satisfy such tax liability upon vesting of a restricted award by a Plan Participant, and subsequently returned to the 2009 Plan.
	(2) Reflects the number of common shares that were withheld pursuant to the settlement of the number of shares with a fair market value equal to such tax withholding liability, to satisfy such tax liability upon vesting of a restricted award by a Plan Participant.
	(3) In accordance with the award, on July 16, 2013, 156,250 shares were vested with 2,040 shares being returned to the 2009 Plan.
	(4) In accordance with the award, on July 22, 2013, 8,335 shares were vested.
	(5) In accordance with the award, on July, 22, 2014, 106,250 shares were vested, with 2,040 shares being returned to the 2009 Plan.
	For the year ended February 28, 2015 and 2014, the Company recognized compensation expense related to the above restricted stock grants of $2,515 and $12,426, respectively. There was no unamortized stock compensation expense remaining as of February 28, 2015.

Income_Taxes

Income Taxes	12 Months Ended
	Feb. 28, 2015
Income Tax Disclosure [Abstract]
Income Taxes	NOTE 15 — INCOME TAXES:
	Reconciliation between actual tax expense (benefit) and income taxes computed by applying the U.S. federal income tax rate and state income tax rate to income from continuing operations before income taxes is as follows:
		28-Feb-15		28-Feb-14
	Computed at U.S. and state statutory rates (40%)	$	-293,176	$	-559,340
	Permanent differences		142,925		94,980
	Changes in valuation allowance		150,251		464,360
	Total	$	-	$	-
	Tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred liabilities are presented below:
		28-Feb-15		28-Feb-14
	Deferred tax assets:
	Net operating loss carryforwards	$	9,188,905	$	8,344,222
	Oil and gas properties		-1,436,249		-832,267
	Stock based compensation		88,723		87,716
	Other		-102,899		-11,442
	Less valuation allowance		-7,738,480		-7,588,229
	Total	$	-	$	-
	At February 28, 2015, the Company had a net operating loss (“NOL”) carryforwards for federal and state income tax purposes of approximately $22,972,263, which will begin to expire, if unused, beginning in 2024. The valuation allowances increased by $150,251 and $464,360 for the years ended February 28, 2015 and 2014, respectively. Section 382 Rule of the Internal Revenue Code will place annual limitations on the Company’s NOL carryforward.
	The above estimates are based upon management’s decisions concerning certain elections that could change the relationship between net income and taxable income. Management decisions are made annually and could cause the estimates to vary significantly.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Feb. 28, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	NOTE 16 — COMMITMENTS AND CONTINGENCIES:
	Various lawsuits, claims and other contingencies arise in the ordinary course of the Company’s business activities. While the ultimate outcome of the aforementioned contingencies are not determinable at this time, management believes that any liability or loss resulting therefrom will not materially affect the financial position, results of operations or cash flows of the Company.
	The Company, as an owner or lessee and operator of oil and gas properties, is subject to various federal, state and local laws and regulations relating to discharge of materials into, and protection of, the environment. These laws and regulations may, among other things, impose liability on the lessee under an oil and gas lease for the cost of pollution clean-up resulting from operations and subject the lessee to liability for pollution damages. In some instances, the Company may be directed to suspend or cease operations in the affected area. The Company maintains insurance coverage that is customary in the industry, although the Company is not fully insured against all environmental risks.
	The Company is not aware of any environmental claims existing as of February 28, 2015. There can be no assurance, however, that current regulatory requirements will not change, or past non-compliance with environmental issues will not be discovered on the Company’s oil and gas properties.

Subsequent_Events

Subsequent Events	12 Months Ended
	Feb. 28, 2015
Subsequent Events [Abstract]
Subsequent Events	NOTE 17 — SUBSEQUENT EVENTS:
	On May 20, 2015, the Company and Maximilian executed an amended loan agreement modifying the calculation of the required monthly payment for a three month period. The revised agreement includes a provision for a future loan payment modification if needed due to lower hydrocarbon prices. As consideration for entering into the loan modification the Company agreed to lower the exercise price of the warrants Maximilain currently holds from $0.10 to $0.04. No other terms of the warrant agreement were changed.

Supplementary_Information_for_

Supplementary Information for Oil and Gas Producing Activities	12 Months Ended
	Feb. 28, 2015
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Supplementary Information for Oil and Gas Producing Activities	NOTE 18 — SUPPLEMENTARY INFORMATION FOR OIL AND GAS PRODUCING ACTIVITIES (UNAUDITED)
	All of the Company’s continuing operations are directly related to oil and natural gas producing activities located in Kern County, California and Lawrence County, Kentucky.
	Capitalized Costs Relating to Oil and Gas Producing Activities
		As of		As of
		28-Feb-15		28-Feb-14
	Proved leasehold costs
	Mineral Interests	$	695,231	$	2,236
	Wells, equipment and facilities		5,851,439		4,511,869
	Total Proved Properties		6,546,670		4,514,105
	Unproved properties
	Mineral Interests		733,478		1,261,156
	Uncompleted wells, equipment and facilities		-		-
	Total unproved properties		733,478		1,261,156
	Less accumulated depreciation, depletion amortization and impairment		-2,167,064		-1,599,140
	Net capitalized costs	$	5,113,084	$	4,176,121
	Costs Incurred in Oil and Gas Producing Activities
		12 Months Ended		12 Months Ended
		28-Feb-15		28-Feb-14
	Acquisition of proved properties	$	165,317	$	-
	Acquisition of unproved properties		-		994,343
	Development costs		1,339,570		-
	Exploration costs		42,997		251,543
	Total costs incurred	$	1,547,884	$	209,398
	Results of Operations from Oil and Gas Producing Activities
		12 Months Ended		12 Months Ended
		28-Feb-15		28-Feb-14
	Oil and gas revenues	$	3,083,797	$	1,802,791
	Production costs		-329,917		-216,771
	Exploration expenses		-42,997		-251,543
	Depletion, depreciation, amortization and impairment		-570,110		-308,097
	Result of oil and gas producing operations before income taxes		2,140,773		1,026,380
	Provision for income taxes		-		-
	Results of oil and gas producing activities	$	2,140,733	$	1,026,380
	Proved Reserves
	The Company’s proved oil and natural gas reserves have been estimated by the certified independent engineering firm, PGH Petroleum and Environmental Engineers, LLC. Proved reserves are the estimated quantities that geologic and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved developed reserves are the quantities expected to be recovered through existing wells with existing equipment and operating methods when the estimates were made. Due to the inherent uncertainties and the limited nature of reservoir data, such estimates are subject to change as additional information becomes available. The reserves actually recovered and the timing of production of these reserves may be substantially different from the original estimate. Revisions result primarily from new information obtained from development drilling and production history; acquisitions of oil and natural gas properties; and changes in economic factors. Our proved reserves are summarized in the table below:
			Oil (Barrels)	Natural Gas (Mcf)		BOE (Barrels)
	Proved reserves:
	February 29, 2013		279,310	-		279,310
	Revisions(1)		-1,860	-		-1,860
	Discoveries and extensions		487,128	27,807		491,762
	Production		-18,748	-1,717		-19,034
	Purchases (sales) of minerals-in-place		-	-		-
	28-Feb-14		745,830	26,090		750,178
	Revisions(1)		49,103	192,591		88,882
	Discoveries and extensions		88,611	58,180		90,627
	Production		-37,885	-21,999		-41,551
	28-Feb-15		845,659	254,860		888,136
	(1) The revisions of previous estimates resulted from a revised increase in the estimate of reserve value after continued reservoir production offset by lower hydrocarbon prices in the energy markets.
	The Company’s proved reserves are set forth in the table below.
			Developed			Undeveloped		Total Reserves
			Oil (Bbls)	BOE (Bbls)		Oil (Bbls)	BOE (Bbls)	Oil (Bbls)	BOE (Bbls)
	28-Feb-15		278,233	294,585		567,429	593,551	845,659	888,136
	28-Feb-14		263,010	264,062		482,820	486,116	745,830	750,178
	February 29, 2013		72,320	72,320		206,990	206,990	279,310	279,310
	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, 2015 and 2014 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, 2015 and 2014 were estimated as specified by the SEC through calculation of an average price based on the 12-month unweighted arithmetic average of the first-day-of-the-month price for the period from March through February during each respective fiscal year. The resulting net cash flows are reduced to present value by applying a 10% discount factor.
		12 Months Ended
		28-Feb-15		28-Feb-14
	Future cash inflows	$	73,348,130	$	71,943,890
	Future production costs (1)		-25,378,830		-21,295,890
	Future development costs		-6,789,770		-5,560,780
	Future income tax expenses (2)		-		-
	Future net cash flows		41,179,530		45,087,220
10% annual discount for estimated timing of cash flows		-23,674,830		-23,662,780
Standardized measure of discounted future net cash flows at the end of the fiscal year	$	17,504,700	$	21,424,440
(1) Production costs include oil and gas operations expense, production ad valorem taxes, transportation costs and G&A expense supporting the Company’s oil and gas operations.
(2) The Company has sufficient tax deductions and allowances related to proved oil and gas reserves to offset future net revenues.
Average oil prices are set forth in the table below.
	Average Price
	Oil (Barrel)		Natural Gas
Year ended February 28, 2015 (1)	$	85.53	$	2.99
Year ended February 28, 2014 (1)	$	95.94	$	2.44
Year ended February 29, 2013 (1)	$	94.25	$	-
(1) Average prices were based on 12-month unweighted arithmetic average of the first-day-of-the-month prices for the period from March through February during each respective fiscal year.
Future production and development costs, which include dismantlement and restoration expense, are computed by estimating the expenditures to be incurred in developing and producing the Company’s proved crude oil and natural gas reserves at the end of the year, based on year-end costs, and assuming continuation of existing economic conditions.
Sources of Changes in Discounted Future Net Cash Flows
Principal changes in the aggregate standardized measure of discounted future net cash flows attributable to the Company’s proved crude oil and natural gas reserves, as required by ASC 932, at fiscal year-end are set forth in the table below.
	12 Months Ended
	February 28,2015		28-Feb-14
Standardized measure of discounted future net cash flows at the beginning of the year	$	21,424,440	$	13,285,134
Extensions, discoveries and improved recovery, less related costs		1,565,310		14,017,040
Revisions of previous quantity estimates		2,040,090		251,759
Net changes in prices and production costs		-3,214,934		-1,752,247
Accretion of discount		2,142,444		1,328,514
Sales of oil produced, net of production costs		-2,753,880		-1,586,020
Development costs incurred during the period		1,516,201		1,120,585
Changes in future development costs		-1,385,033		-584,992
Changes in timing of future production		-3,829,938		-4,655,333
Net changes in income taxes		-		-
Standardized measure of discounted future net cash flows at the end of the year	$	17,504,700	$	21,424,440

Accounting_Policies_Policies

Accounting Policies (Policies)	12 Months Ended
	Feb. 28, 2015
Accounting Policies [Abstract]
Cash and Cash Equivalents	Cash and Cash Equivalents
	Cash equivalents include demand deposits with banks and all highly liquid investments with original maturities of three months or less. The Company routinely maintains balances in financial institutions where deposits may exceed the Federally insured deposit limit of $250,000. The Company has not experienced any losses from such accounts and does not believe it is exposed to any significant credit risk on cash.
Accounts Receivable	Accounts Receivable
	The Company routinely assesses the recoverability of all material trade and other receivables. The Company accrues a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of any reserve may be reasonably estimated. Actual write-offs may exceed the recorded allowance. Substantially all of the Company’s trade accounts receivable result from crude oil and natural gas sales in California and Kentucky 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, 2015 and 2014.
Oil and Gas Properties	Oil and Gas Properties
	The Company uses the successful efforts method of accounting for oil and natural gas property acquisition, exploration, development, and production activities. Costs to acquire mineral interests in oil and natural gas properties, to drill and equip exploratory wells that find proved reserves, and to drill and equip development wells are capitalized as incurred. Costs to drill exploratory wells that are unsuccessful in finding proved reserves are expensed as incurred. In addition, the geological and geophysical costs, and costs of carrying and retaining unproved properties are expensed as incurred. Costs to operate and maintain wells and field equipment are expensed as incurred.
	Capitalized proved property acquisition costs are amortized by field using the unit-of-production method based on estimated proved reserves. Capitalized exploration well costs and development costs (plus estimated future dismantlement, surface restoration, and property abandonment costs, net of equipment salvage values) are amortized in a similar fashion (by field) based on their estimated proved developed reserves. Support equipment and other property and equipment are depreciated over their estimated useful lives.
	Pursuant to the provisions of Financial Accounting Standards Codification (“ASC”) Topic 360, “Property, Plant and Equipment” the Company reviews proved oil and natural gas properties and other long-lived assets for impairment. These reviews are predicated by events and circumstances, such as downward revision of the reserve estimates or commodity prices that indicate a decline in the recoverability of the carrying value of such properties. The Company estimates the future cash flows expected in connection with the properties and compares such future cash flows to the carrying amount of the properties to determine if the carrying amount is recoverable. When the carrying amounts of the properties exceed their estimated undiscounted future cash flows, the carrying amounts of the properties are reduced to their estimated fair value. The factors used to determine fair value include, but are not limited to, estimates of proved reserves, future commodity prices, the timing of future production, future capital expenditures and a risk-adjusted discount rate. These estimates of future product prices may differ from current market prices of oil and natural gas. Any downward revisions to management’s estimates of future production or product prices could result in an impairment of the Company’s oil and natural gas properties in subsequent periods. Unproved oil and natural gas properties that are individually significant are also periodically assessed for impairment of value. An impairment loss for unproved oil and natural gas properties is recognized at the time of impairment by providing an impairment allowance.
	On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated DD&A with a resulting gain or loss recognized in income.
Property and Equipment	Property and Equipment
	Fixed assets are stated at cost. Depreciation on vehicles is provided using the straight-line method over expected useful lives of three years. Depreciation on machinery and equipment is provided using the straight-line method over expected useful life of three years. Depreciation of production facilities is recorded using the unit-of-production method based on estimated reserves.
Long Lived Assets	Long Lived Assets
	The Company reviews long-lived assets and identifiable intangibles whenever events or circumstances indicate that the carrying amounts of such assets may not be fully recoverable. The Company evaluates the recoverability of long-lived assets by measuring the carrying amounts of the assets against the estimated undiscounted cash flows associated with these assets. If this evaluation indicates that the future undiscounted cash flows of certain long-lived assets are not sufficient to recover the assets' carrying value, the assets are adjusted to their fair values (based upon discounted cash flows).
Fair Value of Financial Instruments	Fair Value of Financial Instruments
	The carrying value of short-term financial instruments including cash, receivables, prepaid expenses, accounts payable, and other accrued liabilities, short-term liabilities and the line of credit approximated their fair values due to the relatively short period to maturity for these instruments. The long-term notes payable approximates fair value since the related rates of interest approximate current market rates.
Share Based Payments	Share Based Payments
	Stock awards are accounted for under FASB ASC Topic 718, “Compensation-Stock Compensation” (“ASC 718”). Under ASC 718, compensation for all share-based payment awards is based on estimated fair value at the grant date. The value of the portion of the award that is ultimately expected to vest is recognized as expense on a straight-line basis over the requisite service periods, if any.
	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.
Loss per Share of Common Stock	Loss per Share of Common Stock
	Basic loss per share of Common Stock is calculated by dividing net loss available to common stockholders by the weighted average number of common shares issued and outstanding during the year. Diluted net loss per share is computed based on the weighted average number of common shares outstanding, increased by dilutive Common Stock equivalents. Common Stock equivalents are excluded from the calculations when their effect is anti-dilutive.
Concentration of Credit Risk	Concentration of Credit Risk
	Substantially all of the Company’s accounts receivable result from crude oil and natural gas sales or joint interest billings to its working interest partners. This concentration of customers and joint interest owners may impact the Company’s overall credit risk as these entities could be affected by similar changes in economic conditions as well as other related factors.
Revenue Recognition	Revenue Recognition
	The Company uses the sales method to account for sales of crude oil and natural gas. Under this method, revenues are recognized based on actual volumes of oil and natural gas sold to purchasers. The volumes sold may differ from the volumes to which the Company is entitled based on its interests in the properties. These differences create imbalances that are recognized as a liability only when the imbalance exceeds the estimate of remaining reserves.
Reclamation Bonds	Reclamation Bonds
	Included in other assets as of February 28, 2015, are funds that have been pledged as collateral in connection with asset retirement obligations for future plugging, abandonment and site remediation. The amount pledged for an operator bond in California is approximately $100,000 plus accrued interest. The pledging of these funds is required by any state in which the Company operates as the project Operator.
Asset Retirement Obligation	Asset Retirement Obligation
	The Company follows the provisions of FASB ASC Topic 410, “Asset Retirement and Environmental Obligations” (“ASC 410”), which addresses financial accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs. This standard requires that the Company recognize the fair value of a liability for an asset retirement obligation (“ARO”) in the period in which it is incurred. The ARO is capitalized as part of the carrying value of the assets to which it is associated, and depreciated over the useful life of the asset. The ARO and the related asset retirement cost are recorded when an asset is first drilled, constructed or purchased. The asset retirement cost is determined and discounted to present value using a credit-adjusted risk-free rate. After initial recording, the liability is increased for the passage of time, with the increase being reflected as accretion expense in the statements of operations. Subsequent adjustments in the cost estimate are reflected in the ARO liability and the amounts continue to be amortized over the useful life of the related long-lived assets.
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” (“ASC 932”). ASC 932 states that exploratory well costs should continue to be capitalized if: (1) a sufficient quantity of reserves are discovered in the well to justify its completion as a producing well and (2) sufficient progress is made in assessing the reserves and the economic and operating feasibility of the well. If the exploratory well costs do not meet both of these criteria, these costs should be expensed, net of any salvage value. Additional annual disclosures are required to provide information about management’s evaluation of capitalized exploratory well costs.
	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”). As required under ASC 740, the Company accounts for income taxes using an asset and liability approach, which requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of temporary differences between the financial statements and tax bases of assets and liabilities at the applicable tax rates. A valuation allowance is utilized when it is more likely than not, that some portion of, or all of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates on the date of enactment.
	ASC 740 prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. Under ASC 740, the Company recognizes tax benefits only for tax positions that are more likely than not to be sustained upon examination by tax authorities. The amount recognized is measured as the largest amount of benefit that is greater than 50 percent likely to be realized upon settlement. A liability for “unrecognized tax benefits” is recorded for any tax benefits claimed in our tax returns that do not meet these recognition and measurement standards.
Use of Estimates and Assumptions	Use of Estimates and Assumptions
	In preparing financial statements in conformity with accounting principles generally accepted in the United States of America, management is required to make estimates and assumptions. These estimates and assumptions may affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, and reported amounts of revenues and expenses during the reporting periods. Actual results could differ materially from those estimates. The accounting policies most affected by management’s estimates and assumptions are as follows:
	• The reliance on estimates of proved reserves to compute the provision for depreciation, depletion and amortization and to determine the amount of any impairment of proved properties;
	• The valuation of unproved acreage and proved oil and natural gas properties to determine the amount of any impairment of 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.
Recent Accounting Pronouncements	Recent Accounting Pronouncements
	There are no new accounting pronouncements issued or effective that had, or are expected to have, a material impact on the Company’s financial statements.
Reclassifications	Reclassifications
	Certain reclassifications have been made to conform the prior period’s financial information to the current period’s presentation. These reclassifications had no effect on previously reported net loss or accumulated deficit.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Feb. 28, 2015
Accounting Policies [Abstract]
Schedule of Concentration of Risk by Risk Factor			28-Feb-15			28-Feb-14
	Project	Customer	Revenue		Percentage	Revenue		Percentage
			Receivable			Receivable
	California – East Slopes Project (Oil)	Plains Marketing	$	95,150	46.90%	$	244,384	74.00%
	Kentucky – Twin Bottoms Field (Oil)	Appalachian Oil		90,906	44.90%		85,120	25.80%
	Kentucky – Twin Bottoms Field (Natural Gas)	Jefferson Gas		16,676	8.20%		839	0.20%
			$	202,732	100.00%	$	330,343	100.00%

Accounts_Receivable_Tables

Accounts Receivable (Tables)	12 Months Ended
	Feb. 28, 2015
Receivables [Abstract]
Schedule of Other Receivables
		28-Feb-15		28-Feb-14
	Other receivables	$	399,996	$	269,039
	Allowance for doubtful accounts		-239,000		-239,000
		$	160,996	$	30,039

Oil_and_Gas_Properties_Tables

Oil and Gas Properties (Tables)	12 Months Ended
	Feb. 28, 2015
OIL AND NATURAL GAS PROPERTIES, successful efforts method, net
Capitalized Costs Relating to Oil and Gas Activities		As of		As of
		28-Feb-15		28-Feb-14
	Proved leasehold costs
	Mineral Interests	$	695,231	$	2,236
	Wells, equipment and facilities		5,851,439		4,511,869
	Total Proved Properties		6,546,670		4,514,105
	Unproved properties
	Mineral Interests		733,478		1,261,156
	Uncompleted wells, equipment and facilities		-		-
	Total unproved properties		733,478		1,261,156
	Less accumulated depreciation, depletion amortization and impairment		-2,167,064		-1,599,140
	Net capitalized costs	$	5,113,084	$	4,176,121
Schedule of Change in Asset Retirement Obligations		28-Feb-15		28-Feb-14
	Asset retirement obligation, beginning of period	$	22,079	$	55,174
	Accretion expense		2,187		7,045
	Change in asset retirement estimates		5,337		-40,140
	Asset retirement obligation, end of period	$	29,603	$	22,079

Production_Revenue_Receivable_

Production Revenue Receivable (Tables)	12 Months Ended
	Feb. 28, 2015
Production Revenue Receivable
Schedule of Production Revenue Receivable		28-Feb-15		28-Feb-14
	Production revenue receivable – current	$	120,000	$	120,000
	Production revenue receivable – non-current		35,000		55,000
		$	155,000	$	275,000

Deferred_Financing_Costs_Table

Deferred Financing Costs (Tables)	12 Months Ended
	Feb. 28, 2015
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Schedule of Other Assets		28-Feb-15		28-Feb-14
	Deferred financing costs – loan fees	$	151,139	$	151,139
	Deferred financing costs – loan commissions		630,662		476,103
	Deferred financing costs – fair value of warrants		530,488		530,488
	Deferred financing costs – fair value of common stock		419,832		419,832
			1,732,121		1,577,562
	Accumulated amortization		-673,370		-250,962
		$	1,058,751	$	1,326,600

Note_Receivable_Tables

Note Receivable (Tables)	12 Months Ended
	Feb. 28, 2015
Receivables [Abstract]
Schedule of Note Receivables		28-Feb-15		28-Feb-14
	Note receivable – current	$	1,320,944	$	793,727
	Note receivable – non-current		3,429,056		2,756,273
		$	4,750,000	$	3,550,000

ShortTerm_and_LongTerm_Borrowi1

Short-Term and Long-Term Borrowings (Tables)	12 Months Ended
	Feb. 28, 2015
Debt Disclosure [Abstract]
Schedule of Notes Payable	Current Notes
		28-Feb-15		28-Feb-14
	12% Subordinated Notes	$	315,000	$	345,000
	12% Subordinated Notes discount		-		-17,129
		$	315,000	$	327,871
	Current Note, Related Parties
		28-Feb-15		28-Feb-14
	12% Subordinated Notes, related party	$	250,000	$	250,000
	12% Subordinated Notes discount, related party		-		-12,605
		$	250,000	$	237,395
Schedule of Warrant Activity	Fiscal Period		Warrants	Shares of		Number of
			Exercised	Common Stock		Accredited
				Issued		Investors
	Year ended February 28, 2014		100,000	100,000		1
	Year ended February 28, 2015		50,000	50,000		1
			150,000	150,000		2
Schedule of Short-Term and Long-Term Borrowings	Current
		28-Feb-15		28-Feb-14
	Maximilian Note	$	4,823,325	$	2,163,405
	Maximilian Note Discount		-132,114		-138,988
		$	4,691,211	$	2,024,417
	Non-Current
		28-Feb-15		28-Feb-14
	Maximilian Note	$	8,663,458	$	6,833,703
	Maximilian Note Discount		-71,951		-204,065
		$	8,591,507	$	6,629,638

Stockholders_Deficit_Tables

Stockholders' Deficit (Tables)	12 Months Ended
	Feb. 28, 2015
Equity [Abstract]
Schedule of Stockholder's Equity	Fiscal Period			Shares of Series A		Shares of	Number of
				Preferred Converted		Common Stock	Accredited
				to Common Stock		Issued from	Investors
						Conversion
	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
	Totals		665,200			1,995,600	42
Schedule of Dividends Payable	Fiscal Year Ended		Shareholders at		Accumulated
			Period End		Dividends
	28-Feb-07		100		$	155,311
	29-Feb-08		90			242,126
	28-Feb-09		78			209,973
	28-Feb-10		74			189,973
	28-Feb-11		70			173,707
	29-Feb-12		70			163,624
	28-Feb-13		68			161,906
	28-Feb-14		59			151,323
	28-Feb-15		58			132,634
					$	1,580,577
Schedule of Common Stock Outstanding		Common Stock		Par Value
		Balance
	Common stock, Issued and Outstanding, February 28, 2014	55,509,411
	Conversion of Series A Convertible Preferred Stock to common stock	9,000		$	9
	Exercise of warrants issued with 12% Subordinated Notes	50,000		$	50
	Cashless exercise of warrants	1,873,554		$	1,874
	Common stock-for-warrant exchange (Maximilian)	-427,729		$	-428
	Transfer agent balancing adjustment	140,000		$	140
	Share purchase and cancellation (Maximilian)	-5,694,823		$	-5,695
	Common stock returned to 2009 Stock Plan (tax withholding liability)	-2,040		$	-2
	Common stock, Issued and Outstanding, February 28, 2015	51,457,373

Warrants_Tables

Warrants (Tables)	12 Months Ended
	Feb. 28, 2015
Warrants and Rights Note Disclosure [Abstract]
Schedule of Stockholders' Equity Note Warrants and Rights		Warrants	Exercise	Remaining	Exercisable
			Price	Life	Warrants
				(Years)	Remaining
	12% Subordinated notes	1,190,000	$0.14	1.92	980,000
	Warrants issued in 2010 for services	150,000	$0.14	0.13	150,000
	Warrants issued in 2012 for debt financing	2,435,517	$0.04	2.67	316,617
	Warrants issued for Kentucky oil project	3,498,601	$0.10	1.5	3,498,601
	Warrants issued for Kentucky debt financing	2,623,951	$0.10	1.5	2,623,951
	Warrants issued for Kentucky debt financing	309,503	$0.21	3.5	309,503
	Warrants issued in share-for-warrant exchange	427,729	$0.10	1.5	427,729
		10,635,301			8,306,401

Restricted_Stock_and_Restricte1

Restricted Stock and Restricted Stock Unit Plan (Tables)	12 Months Ended
	Feb. 28, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Restricted Stock and Restricted Stock Unit Activity	Grant	Shares	Vesting	Shares	Shares	Shares
	Date	Awarded	Period	Vested(1)	Returned(2)	Outstanding
						(Unvested)
	4/7/09	1,900,000	3 Years	1,900,000	-	-
	7/16/09	25,000	3 Years	25,000	-	-
	7/16/09	625,000	4 Years	619,130(3)	5,870	-
	7/22/10	25,000	3 Years	25,000(4)	-	-
	7/22/10	425,000	4 Years	417,090(5)	7,910	-
		3,000,000		2,986,220(1)	13,780	-
	(1) Does not include shares that were withheld to satisfy such tax liability upon vesting of a restricted award by a Plan Participant, and subsequently returned to the 2009 Plan.
	(2) Reflects the number of common shares that were withheld pursuant to the settlement of the number of shares with a fair market value equal to such tax withholding liability, to satisfy such tax liability upon vesting of a restricted award by a Plan Participant.
	(3) In accordance with the award, on July 16, 2013, 156,250 shares were vested with 2,040 shares being returned to the 2009 Plan.
	(4) In accordance with the award, on July 22, 2013, 8,335 shares were vested.
	(5) In accordance with the award, on July, 22, 2014, 106,250 shares were vested, with 2,040 shares being returned to the 2009 Plan.

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Feb. 28, 2015
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense Benefit		28-Feb-15		28-Feb-14
	Computed at U.S. and state statutory rates (40%)	$	-293,176	$	-559,340
	Permanent differences		142,925		94,980
	Changes in valuation allowance		150,251		464,360
	Total	$	-	$	-
Schedule of Deferred Tax Assets and Liabilities		28-Feb-15		28-Feb-14
	Deferred tax assets:
	Net operating loss carryforwards	$	9,188,905	$	8,344,222
	Oil and gas properties		-1,436,249		-832,267
	Stock based compensation		88,723		87,716
	Other		-102,899		-11,442
	Less valuation allowance		-7,738,480		-7,588,229
	Total	$	-	$	-

Supplementary_Information_for_1

Supplementary Information for Oil and Gas Producing Activities (Tables)	12 Months Ended
	Feb. 28, 2015
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Capitalized Costs Relating to Oil and Gas Producing Activities		As of		As of
		28-Feb-15		28-Feb-14
	Proved leasehold costs
	Mineral Interests	$	695,231	$	2,236
	Wells, equipment and facilities		5,851,439		4,511,869
	Total Proved Properties		6,546,670		4,514,105
	Unproved properties
	Mineral Interests		733,478		1,261,156
	Uncompleted wells, equipment and facilities		-		-
	Total unproved properties		733,478		1,261,156
	Less accumulated depreciation, depletion amortization and impairment		-2,167,064		-1,599,140
	Net capitalized costs	$	5,113,084	$	4,176,121
Cost Incurred in Oil and Gas Producing Activities		12 Months Ended		12 Months Ended
		28-Feb-15		28-Feb-14
	Acquisition of proved properties	$	165,317	$	-
	Acquisition of unproved properties		-		994,343
	Development costs		1,339,570		-
	Exploration costs		42,997		251,543
	Total costs incurred	$	1,547,884	$	209,398
Results of Operations from Oil and Gas Producing Activities		12 Months Ended		12 Months Ended
		28-Feb-15		28-Feb-14
	Oil and gas revenues	$	3,083,797	$	1,802,791
	Production costs		-329,917		-216,771
	Exploration expenses		-42,997		-251,543
	Depletion, depreciation, amortization and impairment		-570,110		-308,097
	Result of oil and gas producing operations before income taxes		2,140,773		1,026,380
	Provision for income taxes		-		-
	Results of oil and gas producing activities	$	2,140,733	$	1,026,380
Schedule of Proved Developed and Undeveloped Oil and Gas Reserves			Oil (Barrels)	Natural Gas (Mcf)		BOE (Barrels)
	Proved reserves:
	February 29, 2013		279,310	-		279,310
	Revisions(1)		-1,860	-		-1,860
	Discoveries and extensions		487,128	27,807		491,762
	Production		-18,748	-1,717		-19,034
	Purchases (sales) of minerals-in-place		-	-		-
	28-Feb-14		745,830	26,090		750,178
	Revisions(1)		49,103	192,591		88,882
	Discoveries and extensions		88,611	58,180		90,627
	Production		-37,885	-21,999		-41,551
	28-Feb-15		845,659	254,860		888,136
	(1) The revisions of previous estimates resulted from a revised increase in the estimate of reserve value after continued reservoir production offset by lower hydrocarbon prices in the energy markets.
			Developed			Undeveloped		Total Reserves
			Oil (Bbls)	BOE (Bbls)		Oil (Bbls)	BOE (Bbls)	Oil (Bbls)	BOE (Bbls)
	28-Feb-15		278,233	294,585		567,429	593,551	845,659	888,136
	28-Feb-14		263,010	264,062		482,820	486,116	745,830	750,178
	February 29, 2013		72,320	72,320		206,990	206,990	279,310	279,310
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves		12 Months Ended
		28-Feb-15		28-Feb-14
	Future cash inflows	$	73,348,130	$	71,943,890
	Future production costs (1)		-25,378,830		-21,295,890
	Future development costs		-6,789,770		-5,560,780
	Future income tax expenses (2)		-		-
	Future net cash flows		41,179,530		45,087,220
	10% annual discount for estimated timing of cash flows		-23,674,830		-23,662,780
	Standardized measure of discounted future net cash flows at the end of the fiscal year	$	17,504,700	$	21,424,440
	(1) Production costs include oil and gas operations expense, production ad valorem taxes, transportation costs and G&A expense supporting the Company’s oil and gas operations.
	(2) The Company has sufficient tax deductions and allowances related to proved oil and gas reserves to offset future net revenues.
		Average Price
		Oil (Barrel)		Natural Gas
	Year ended February 28, 2015 (1)	$	85.53	$	2.99
	Year ended February 28, 2014 (1)	$	95.94	$	2.44
	Year ended February 29, 2013 (1)	$	94.25	$	-
	(1) Average prices were based on 12-month unweighted arithmetic average of the first-day-of-the-month prices for the period from March through February during each respective fiscal year.
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows		12 Months Ended
		February 28,2015		28-Feb-14
	Standardized measure of discounted future net cash flows at the beginning of the year	$	21,424,440	$	13,285,134
	Extensions, discoveries and improved recovery, less related costs		1,565,310		14,017,040
	Revisions of previous quantity estimates		2,040,090		251,759
	Net changes in prices and production costs		-3,214,934		-1,752,247
	Accretion of discount		2,142,444		1,328,514
	Sales of oil produced, net of production costs		-2,753,880		-1,586,020
	Development costs incurred during the period		1,516,201		1,120,585
	Changes in future development costs		-1,385,033		-584,992
	Changes in timing of future production		-3,829,938		-4,655,333
	Net changes in income taxes		-		-
	Standardized measure of discounted future net cash flows at the end of the year	$	17,504,700	$	21,424,440

Going_Concern_Details_Narrativ

Going Concern (Details Narrative) (USD $)	Feb. 28, 2015	Feb. 28, 2014
Oil and Gas Delivery Commitments and Contracts [Line Items]
Accumulated deficit	($28,205,516)	($27,472,573)
Working capital deficit	$5,757,022
East Slopes Project
Oil and Gas Delivery Commitments and Contracts [Line Items]
Number of producing wells, net revenue interest	20
Average working interest	36.60%
Average net revenue interest	28.40%
Twin Bottoms Field
Oil and Gas Delivery Commitments and Contracts [Line Items]
Number of producing wells, net revenue interest	13
Average working interest	22.40%
Average net revenue interest	19.60%
Kentucky acreage	7,300

Summary_of_Significant_Account2

Summary of Significant Accounting Policies - Concentration of Credit Risk (Details) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Concentration Risk [Line Items]
Revenue receivable	$202,732	$330,343
Plains Marketing (California - East Slopes Project (Oil))
Concentration Risk [Line Items]
Revenue receivable	95,150	244,384
Percent of revenue	46.90%	74.00%
Appalachian Oil (Kentucky - Twin Bottoms Field (Oil))
Concentration Risk [Line Items]
Revenue receivable	90,906	85,120
Percent of revenue	44.90%	25.80%
Jefferson Gas (Kentucky - Twin Bottoms Field (Gas))
Concentration Risk [Line Items]
Revenue receivable	$16,676	$839
Percent of revenue	8.20%	0.20%

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details Narrative) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Oil and Gas Properties
Asset impairment of oil and gas properties	$0	$84,929
Property and Equipment
Expected useful lives		3 years
Asset Retirement Obligation
Reclamation bond	$100,000

Accounts_Receivable_Accounts_R

Accounts Receivable - Accounts Receivable and Allowances (Details) (USD $)	Feb. 28, 2015	Feb. 28, 2014
Receivables [Abstract]
Other receivables	$399,996	$269,039
Allowance for doubtful accounts	-239,000	-239,000
Other receivables, net	$160,996	$30,039

Accounts_Receivable_Details_Na

Accounts Receivable (Details Narrative) (USD $)	Feb. 28, 2015	Feb. 28, 2014
Receivables [Abstract]
Note receivable, balance	$4,750,000	$3,550,000

Oil_and_Gas_Properties_Capital

Oil and Gas Properties - Capitalized Costs Relating to Oil and Gas Activities (Details) (USD $)	Feb. 28, 2015	Feb. 28, 2014
OIL AND NATURAL GAS PROPERTIES, successful efforts method, net
Proved leasehold costs	$695,231	$2,236
Unproved leasehold costs	733,478	1,261,156
Costs of wells and development	542,563	492,970
Capitalized exploratory well costs	5,308,876	4,018,899
Total cost of oil and gas properties	7,280,148	5,775,261
Accumulated depletion, depreciation, amortization and impairment	-2,167,064	-1,599,140
Net oil and gas properties	$5,113,084	$4,176,121

Oil_and_Gas_Properties_Schedul

Oil and Gas Properties - Schedule of Change in Asset Retirement Obligations (Details) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Asset Retirement Obligation Roll Forward Analysis [Roll Forward]
Asset retirement obligation, beginning of period	$22,079	$55,174
Accretion expense	2,187	7,045
Change in asset retirement estimates	5,337	-40,140
Asset retirement obligation, end of period	$29,603	$22,079

Oil_and_Gas_Properties_Details

Oil and Gas Properties (Details Narrative) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
OIL AND NATURAL GAS PROPERTIES, successful efforts method, net
Accretion expense	$2,187	$7,045

Production_Revenue_Receivable_1

Production Revenue Receivable - Schedule of Production Revenue Receivable (Details) (USD $)	Feb. 28, 2015	Feb. 28, 2014
Production Revenue Receivable
Production revenue receivable, current	$120,000	$120,000
Production revenue receivable, non-current	35,000	155,000
Production revenue receivables	$155,000	$275,000

Production_Revenue_Receivable_2

Production Revenue Receivable (Details Narrative) (USD $)	Feb. 28, 2015	Feb. 28, 2014
Production Revenue Receivable
Production revenue receivables	$155,000	$275,000

Deferred_Financing_Costs_Sched

Deferred Financing Costs - Schedule of Deferred Financing Costs (Details) (USD $)	Feb. 28, 2015	Feb. 28, 2014
Deferred financing costs, gross	$1,732,121	$1,577,562
Accumulated amortization	-673,370	-250,962
Deferred finance costs, net	1,058,751	1,326,600
Deferred Financing Expenses | Fair Value of Common Stock
Deferred financing costs, gross	419,832	419,832
Deferred Financing Expenses | Fair Value of Warrants
Deferred financing costs, gross	530,488	530,488
Deferred Financing Expenses | Loan Commissions
Deferred financing costs, gross	630,662	476,103
Deferred Financing Expenses | Loan Fees
Deferred financing costs, gross	$151,139	$151,139

Deferred_Financing_Costs_Detai

Deferred Financing Costs (Details Narrative) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Amortization expense of deferred financing costs	$422,408	$223,772
Deferred financing costs	$950,320

Note_Receivable_Schedule_of_No

Note Receivable - Schedule of Note Receivables (Details) (USD $)	Feb. 28, 2015	Feb. 28, 2014
Receivables [Abstract]
Note receivable, current	$1,320,944	$793,727
Note receivable, non-current	3,429,056	2,756,273
Note receivable	$4,750,000	$3,550,000

Note_Receivable_Details_Narrat

Note Receivable (Details Narrative) (App Note Receivable, USD $)	12 Months Ended
	Feb. 28, 2015
App Note Receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Credit facility, initiation date	28-Aug-13
Credit facility, description	The Company acquired from App a 25% working interest in the Kentucky Acreage. The fair value of the 25% working interest was determined to $1,073,091 and was recorded as unproved oil and gas reserves
Credit facility, maximum borrowing	$40,000,000
Credit facility, proceeds received	$2,650,000
Credit facility, expiration date	28-Aug-17
Credit facility, covenant terms	The App loan agreement contains customary covenants for loan of such type, including, among other things, covenants that restrict AppBs ability to make capital expenditures, incur indebtedness, incur liens and dispose of property. The App loan agreement also contains various events of default, including failure to pay principal and interest when due, breach of covenants, materially incorrect representations and bankruptcy or insolvency. If an event of default occurs, all of AppBs obligations under the App loan agreement could be accelerated by the Company, causing all loans outstanding (including accrued interest and fees payable thereunder) to be declared immediately due and payable.
Credit facility, commitment fee percentage	0.60%
Credit facility, interest rate	16.80%
Credit facility, subsequent loans, interest rate	12.00%

Accounts_Payable_Details_Narra

Accounts Payable (Details Narrative) (USD $)	4 Months Ended
	Jun. 30, 2009	Feb. 28, 2015
Payables and Accruals [Abstract]
Acquisition and disposition of East Slopes Project	On March 1, 2009, the Company became the operator for the East Slopes Project. The Company assumed certain original defaulting partners' approximate $1.5 million liability representing a 25% working interest in the drilling and completion costs associated with the East Slopes Project four earning well program. The Company subsequently sold the 25% working interest on June 11, 2009.
Accounts payable balance		$252,349

ShortTerm_and_LongTerm_Borrowi2

Short-Term and Long-Term Borrowings - Subordinated Notes (Details) (12% Subordinated Notes, USD $)	Feb. 28, 2015	Feb. 28, 2014
Debt Instrument [Line Items]
Notes payable	$315,000	$345,000
Notes payable discount	0	-17,129
Note payable balance	315,000	327,871
Related Party
Debt Instrument [Line Items]
Notes payable	250,000	250,000
Notes payable discount	0	-12,605
Note payable balance	$250,000	$237,395

ShortTerm_and_LongTerm_Borrowi3

Short-Term and Long-Term Borrowings - Schedule of Warrant Activity (Details)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Warrants exercised	2,168,900	100,000
12% Subordinated Notes | Warrants
Warrants exercised	50,000	100,000
Shares of common stock issued	50,000	100,000
Accredited investors	1	1

ShortTerm_and_LongTerm_Borrowi4

Short-Term and Long-Term Borrowings - Credit Facility - Maximilian Loan (Details) (Line of Credit, USD $)	Feb. 28, 2015	Feb. 28, 2014
Line of Credit
Line of Credit Facility [Line Items]
Current debt, note	$4,823,325	$2,163,405
Current debt, note discount	-132,114	-138,988
Current debt, note balance	4,691,211	2,024,417
Non-current debt, note	8,663,458	6,833,703
Non-current debt, note discount	-71,951	-204,065
Non-current debt, note balance	$8,591,507	$6,629,638

ShortTerm_and_LongTerm_Borrowi5

Short-Term and Long-Term Borrowings (Details Narrative) (USD $)	12 Months Ended		1 Months Ended	6 Months Ended	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014	Oct. 31, 2012	Aug. 31, 2013	Feb. 28, 2010
Debt Instrument [Line Items]
Notes payable, related party	$250,100	$250,100
Warrant exercise price	$0.11	$0.09
Fair value of stocks and warrants		513,314
Amortization of debt discount	168,722	159,378
Credit facility, payments	12,504	0
Deferred finance costs	950,320
Unamortized deferred financing costs	1,058,751	1,326,600
Common stock issued, shares	51,457,373	55,509,411
Common stock issued, value	51,457	55,509
Unproved oil properties, stock and warrant value allocation	733,478	1,261,156
Stock repurchased and retired, value	-1,708,447
Maximilian Loan
Debt Instrument [Line Items]
Warrants issued			2,435,517
Warrants exercised	2,118,900
Warrant exercise price			$0.04
Warrant expiration date			31-Oct-17
Fair value of stocks and warrants			98,084
Weighted average risk free interest rate			0.72%
Weighted average volatility rate			153.44%
Stock price, fair value assumption			$0.04
Amortization of debt discount			515,638
Amortization expense	138,988	131,963
Unamortized debt discount	204,065
Credit facility, description			The Company entered into a loan agreement with Maximilian Investors LLC which provided for a revolving credit facility of up to $20 million, maturing on October 31, 2016, with a minimum commitment of $2.5 million. The loan had annual interest of 18% and a monthly commitment fee of 0.5%. The Company also granted Maximilian a 10% working interest in its share of the oil and gas leases in Kern County, California.
Maximum borrowing			20,000,000
Expiration date			31-Oct-16
Minimum commitment terms			Minimum commitment of $2,500,000
Commitment fee percentage			0.50%
Line of credit facility, interest rate			18.00%
Common stock issued, shares	1,873,554
Common Stock for warrant exchange		427,729
Maximilian - Amended and Restated Loan Agreement
Debt Instrument [Line Items]
Credit facility, description				The Company's revolving credit facility was increased from $20 million to $90 million. The first borrowing sublimit is $50 million and is for borrowing by the Company, primarily for its ongoing oil and gas exploration and development activities. The second borrowing sublimit, of $40 million, is for loans to be extended by the Company, as lender, to App, as borrower pursuant to a Loan and Security Agreement entered into between the Company and App.
Maximum borrowing				90,000,000
Expiration date				28-Aug-17
Commitment fee percentage				0.50%
Line of credit facility, interest rate				12.00%
Maximilian- First Amendment to Amended and Restated Loan Agreement
Debt Instrument [Line Items]
Credit facility, advances	2,200,000
Credit facility, reduction to required monthly payments	Maximilian agreed to temporarily reduce the required monthly payment made by the Company until it has paid $1,000,000 less than principal payments required by the previous agreement. As of February 28, 2015, the Company recognized $700,000 of the reduced monthly principal payments program. Maximilian agreed to reduce the regular interest rate applicable to the loan from 12% per annum to 9% per annum and the default interest rate by 3%.
Deferred finance costs	154,559
Stock repurchased and retired, shares	5,694,823
Stock repurchased and retired, value	1,708,447
Proceeds from long term debt	7,400,000
Repayments of long term debt principal	2,900,000
Maximilian/App Loan Agreement - Stock and Warrants
Debt Instrument [Line Items]
Warrants issued	6,100,000
Warrant exercise price	$0.10
Warrant exercisable date	28-Aug-13
Warrant expiration date	28-Aug-16
Fair value of stocks and warrants	1,877,907
Weighted average risk free interest rate	2.48%
Weighted average volatility rate	184.53%
Stock price, fair value assumption	$0.16
Deferred finance costs	804,816
Common stock issued, shares	6,100,000
Unproved oil properties, stock and warrant value allocation	-1,073,091
Warrants Issued to Third Party
Debt Instrument [Line Items]
Warrants issued		309,503
Warrant exercise price		$0.21
Warrant exercisable date		28-Aug-13
Warrant expiration date		28-Aug-18
Fair value of stocks and warrants		47,420
Weighted average risk free interest rate		2.48%
Weighted average volatility rate		184.53%
Stock price, fair value assumption		$0.16
Amortization expense	127,513	76,017
Deferred finance costs		400,349
Unamortized deferred financing costs	318,783
12% Subordinated Notes
Debt Instrument [Line Items]
Interest rate					12.00%
Expiration period					29-Jan-17
Payment terms					Payable semi-annually on January 29th and July 29th. Should the Board of Directors, on the extended maturity date, decide that the payment of the principal and any unpaid interest would impair the financial condition or operations of the Company, the Company may then elect a mandatory conversion of the unpaid principal and interest into the CompanyBs common stock at a conversion rate equal to 75% of the average closing price of the CompanyBs common stock over the 20 consecutive trading days preceding December 31, 2016.
Warrants issued					1,190,000
Warrant exercise price					$0.14
Warrant expiration date	29-Jan-17
Fair value of stocks and warrants	56,519				116,557
Weighted average risk free interest rate	0.51%				2.33%
Weighted average volatility rate	153.40%				147.60%
Amortization of debt discount	29,734	22,934
Unamortized debt discount	0	17,129
Repayments of long term debt	30,000
Line of Credit
Debt Instrument [Line Items]
Unamortized debt discount	132,114	138,988
Maximum borrowing	890,000
Line of credit, amount outstanding	869,865	882,369
Line of credit, interest expense	$31,498	$31,911
Line of credit, interest rate	Payable monthly at a stated reference rate of 0.249% + 337.5 basis points. The reference rate is based on the 30 day LIBOR ("London Interbank Offered Rate") and is subject to change from UBS.

Stockholders_Deficit_Conversio

Stockholders' Deficit - Conversions of Series A Preferred Stock (Details) (Series A Convertible Preferred Stock)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014	Feb. 28, 2013	Feb. 29, 2012	Feb. 28, 2011	Feb. 28, 2010	Feb. 28, 2009	Feb. 29, 2008
	Integer	Integer	Integer	Integer	Integer	Integer	Integer	Integer
Series A Convertible Preferred Stock
Series A preferred shares converted to common stock	-3,000	-151,000	-18,000	0	-102,000	-51,900	-237,000	-102,300
Shares of common stock issued from conversion	9,000	453,000	54,000	0	306,000	155,700	711,000	306,900
Accredited investors	1	9	2	0	4	4	12	10

Stockholders_Deficit_Preferred

Stockholders' Deficit - Preferred Stock Dividends Earned (Details) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014	Feb. 28, 2013	Feb. 29, 2012	Feb. 28, 2011	Feb. 28, 2010	Feb. 28, 2009	Feb. 29, 2008	Feb. 28, 2007
	Integer	Integer	Integer	Integer	Integer	Integer	Integer	Integer	Integer
Equity [Abstract]
Preferred shareholders at period end	58	59	68	70	70	74	78	90	100
Earned dividends	$132,634	$151,323	$161,906	$163,624	$173,707	$189,973	$209,973	$242,126	$155,311
Total accumulated dividends	$1,580,577

Stockholders_Deficit_Common_St

Stockholders' Deficit - Common Stock (Details) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Common Stock, Issued and Outstanding, February 28, 2014	55,509,411
Cashless exercise of warrants, par value	$7,000	$14,000
Common stock for warrant exchange, Maximilian, par value	-490	-754
Common Stock, Issued and Outstanding, February 28, 2015	51,457,373	55,509,411
Common Stock
Common Stock, Issued and Outstanding, February 28, 2014	55,509,411
Conversion of Series A Convertible Preferred Stock to common stock	9,000
Conversion of Series A Convertible Preferred Stock to common stock, par value	$9
Exercise of warrants issued with 12% Subordinated Notes	50,000
Exercise of warrants issued with 12% Subordinated Notes, par value	50
Cashless exercise of warrants	1,873,554
Cashless exercise of warrants, par value	1,874
Common stock for warrant exchange, Maximilian	-427,729
Common stock for warrant exchange, Maximilian, par value	-428
Transfer agent balancing adjustment, shares	140,000
Transfer agent balancing adjustment, par value	140
Share purchase and cancellation (Maximilian)	-5,694,823
Share purchase and cancellation (Maximilian), par value	-5,695
Common stock returned to 2009 Stock Plan (tax withholding liability)	-2,040
Common stock returned to 2009 Stock Plan (tax withholding liability), par value	($2)
Common Stock, Issued and Outstanding, February 28, 2015	51,457,373

Stockholders_Deficit_Details_N

Stockholders' Deficit (Details Narrative) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014	Jul. 31, 2006
	Integer		Integer
Class of Stock [Line Items]
Preferred stock, par value in dollars	$0.00	$0.00
Preferred stock, shares authorized	10,000,000	10,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Common stock, par value in dollars	$0.00	$0.00
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	51,457,373	55,509,411
Common stock, shares outstanding	51,457,373	55,509,411
Series A Convertible Preferred Stock
Class of Stock [Line Items]
Preferred stock, par value in dollars	$0.00
Preferred stock, shares authorized	10,000,000
Preferred stock, shares issued	0
Preferred stock, shares outstanding	0
Series A Convertible Preferred Stock
Class of Stock [Line Items]
Preferred stock, par value in dollars	$0.00	$0.00
Preferred stock, shares authorized	2,400,000	2,400,000
Preferred stock, shares issued	734,565	737,565	1,399,765
Preferred stock, shares outstanding	734,565	737,565
Series A preferred shares converted to common stock	665,200	151,000
Shares of common stock issued from conversion	1,995,600	453,000
Accredited investors	42		100
Common Stock
Class of Stock [Line Items]
Common stock, par value in dollars	$0.00
Common stock, shares authorized	200,000,000
Common stock, shares issued	51,457,373	55,509,411
Common stock, shares outstanding	51,457,373	55,509,411
Increase in issued and outstanding shares	6,671,472

Warrants_Schedule_of_Stockhold

Warrants - Schedule of Stockholders' Equity Note Warrants and Rights (Details) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Class of Warrant or Right [Line Items]
Warrants	10,635,301
Exercise price	$0.11	$0.09
Remaining life (years)	1 year 8 months	2 years 8 months
Exercisable warrants remaining	8,306,401
12% Subordinated Notes
Class of Warrant or Right [Line Items]
Warrants	1,190,000
Exercise price	$0.14
Remaining life (years)	1 year 11 months
Exercisable warrants remaining	980,000
Warrants Issued In 2010 For Services
Class of Warrant or Right [Line Items]
Warrants	150,000
Exercise price	$0.14
Remaining life (years)	2 months
Exercisable warrants remaining	150,000
Warrants Issued In 2012 For Debt Financing
Class of Warrant or Right [Line Items]
Warrants	2,435,517
Exercise price	$0.04
Remaining life (years)	2 years 8 months
Exercisable warrants remaining	316,617
Warrants Issued for Kentucky Oil Project
Class of Warrant or Right [Line Items]
Warrants	3,498,601
Exercise price	$0.10
Remaining life (years)	1 year 6 months
Exercisable warrants remaining	3,498,601
Warrants Issued for Kentucky Debt Financing #1
Class of Warrant or Right [Line Items]
Warrants	2,623,951
Exercise price	$0.10
Remaining life (years)	1 year 6 months
Exercisable warrants remaining	2,623,951
Warrants Issued for Kentucky Debt Financing #2
Class of Warrant or Right [Line Items]
Warrants	309,503
Exercise price	$0.21
Remaining life (years)	3 years 6 months
Exercisable warrants remaining	309,503
Warrants Issued in Share-for-Warrant Exchange
Class of Warrant or Right [Line Items]
Warrants	427,729
Exercise price	$0.10
Remaining life (years)	1 year 6 months
Exercisable warrants remaining	427,729

Warrants_Details_Narrative

Warrants (Details Narrative) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Warrants and Rights Note Disclosure [Abstract]
Warrants exercised	2,168,900	100,000
Warrants expired	60,000	1,624,012
Warrants issued	427,729	6,432,055
Outstanding warrants, weighted average exercise price	$0.11	$0.09
Weighted average remaining life	1 year 8 months	2 years 8 months
Intrinsic value	$14,564	$2,577,388

Restricted_Stock_and_Restricte2

Restricted Stock and Restricted Stock Unit Plan (Details)	12 Months Ended
	Feb. 28, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted shares, awarded	3,000,000
Restricted shares, vested	2,986,220	[1]
Restricted shares, returned	13,780	[2]
Grant Date - 04/07/2009
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted shares, awarded	1,900,000
Restricted shares, vesting period	3 years
Restricted shares, vested	1,900,000	[1]
Restricted shares, returned	0
Restricted shares, outstanding, unvested	0
Grant Date (A) - 07/16/2009
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted shares, awarded	25,000
Restricted shares, vesting period	3 years
Restricted shares, vested	25,000	[1]
Restricted shares, returned	0
Restricted shares, outstanding, unvested	0
Grant Date (B) - 07/16/2009
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted shares, awarded	625,000
Restricted shares, vesting period	4 years
Restricted shares, vested	619,130	[1],[3]
Restricted shares, returned	5,870	[2]
Restricted shares, outstanding, unvested	0
Grant Date (A) - 07/22/2010
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted shares, awarded	25,000
Restricted shares, vesting period	3 years
Restricted shares, vested	25,000	[1],[4]
Restricted shares, returned	0
Restricted shares, outstanding, unvested	0
Grant Date (B) - 07/22/2010
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted shares, awarded	425,000
Restricted shares, vesting period	4 years
Restricted shares, vested	417,090	[1],[5]
Restricted shares, returned	7,910	[2]
Restricted shares, outstanding, unvested	0
[1]	Does not include shares that were withheld to satisfy such tax liability upon vesting of a restricted award by a Plan Participant, and subsequently returned to the 2009 Plan.
[2]	Reflects the number of common shares that were withheld pursuant to the settlement of the number of shares with a fair market value equal to such tax withholding liability, to satisfy such tax liability upon vesting of a restricted award by a Plan Participant.
[3]	In accordance with the award, on July 16, 2013, 156,250 shares were vested with 2,040 shares being returned to the 2009 Plan.
[4]	In accordance with the award, on July 22, 2013, 8,335 shares were vested.
[5]	In accordance with the award, on July, 22, 2014, 106,250 shares were vested, with 2,040 shares being returned to the 2009 Plan.

Restricted_Stock_and_Restricte3

Restricted Stock and Restricted Stock Unit Plan (Details Narrative) (USD $)	12 Months Ended		1 Months Ended		12 Months Ended
	Feb. 28, 2015		Jul. 31, 2010	Feb. 28, 2009	Feb. 28, 2014	Apr. 30, 2009
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted shares, awarded	3,000,000
Restricted shares, outstanding	2,986,220	[1]
2009 Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock available for grant						4,000,000
2009 Plan | Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common stock available for grant	1,013,780
Restricted shares, awarded	3,000,000		425,000	2,550,000
Restricted shares, outstanding	2,986,220
Restricted shares, vested	106,250				270,835
Restricted shares returned, tax withholding liability	2,040				4,080
Recognized compensation expense	2,515				$12,426
2009 Plan | Restricted Stock | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted shares, vesting period				3 years
2009 Plan | Restricted Stock | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted shares, vesting period				4 years
2009 Plan | Restricted Stock | Directors
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted shares, awarded			25,000
[1]	Does not include shares that were withheld to satisfy such tax liability upon vesting of a restricted award by a Plan Participant, and subsequently returned to the 2009 Plan.

Income_Taxes_Income_Tax_Expens

Income Taxes - Income Tax Expense Benefit Reconciliation (Details) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Income Tax Expense Benefit Continuing Operations Income Tax Reconciliation
Computed at U.S. and state statutory rates (40%)	($293,176)	($559,340)
Permanent differences	142,925	94,980
Changes in valuation allowance	150,251	464,360
Income tax expense (benefit)	$0	$0

Income_Taxes_Deferred_Tax_Asse

Income Taxes - Deferred Tax Assets and Liabilities (Details) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Deferred tax assets:
Net operating loss carryforwards	$9,188,905	$8,344,222
Oil and gas properties	-1,436,249	-832,267
Stock based compensation	88,723	87,716
Other	-102,899	-11,442
Less valuation allowance	-7,738,480	-7,588,229
Deferred tax assets, net	$0	$0

Income_Taxes_Details_Narrative

Income Taxes (Details Narrative) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Income Tax Disclosure [Abstract]
Net operating loss carryforwards, federal and state, approximate	$22,972,263
Net operating loss carryforwards, expiration	28-Feb-24
Changes in valuation allowance	$150,251	$464,360

Supplementary_Information_Capi

Supplementary Information - Capitalized Costs Relating to Oil and Gas Producing Activities (Details) (USD $)	Feb. 28, 2015	Feb. 28, 2014
Proved leasehold costs
Mineral Interests	$695,231	$2,236
Wells, equipment and facilities	5,851,439	4,511,869
Total Proved Properties	6,546,670	4,514,105
Unproved properties
Mineral Interests	733,478	1,261,156
Uncompleted wells, equipment and facilities	0	0
Total unproved properties	733,478	1,261,156
Less accumulated depreciation, depletion amortization and impairment	-2,167,064	-1,599,140
Net capitalized costs	$5,113,084	$4,176,121

Supplementary_Information_Cost

Supplementary Information - Cost Incurred in Oil and Gas Producing Activities (Details) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Costs Incurred Acquisition Of Oil And Gas Properties
Acquisition of proved properties	$165,317	$0
Acquisition of unproved properties	0	994,343
Development costs	1,339,570	0
Exploration costs	42,997	251,543
Total costs incurred	$1,547,884	$1,245,886

Supplementary_Information_Resu

Supplementary Information - Results of Operations from Oil and Gas Producing Activities (Details) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Results Of Operations From Oil And Gas Producing Activities
Oil and gas revenues	$3,083,797	$1,802,791
Production costs	-329,917	-216,771
Exploration expenses	-42,997	-251,543
Depletion, depreciation, amortization and impairment	-570,110	-308,097
Result of oil and gas producing operations before income taxes	2,140,773	1,026,380
Provision for income taxes	0	0
Results of oil and gas producing activities	$2,140,773	$1,026,380

Supplementary_Information_Sche

Supplementary Information - Schedule of Proved Developed and Undeveloped Oil and Gas Reserves (Details)	12 Months Ended
	Feb. 28, 2015		Feb. 28, 2014		Feb. 28, 2013
	bbl		bbl		bbl
					Boe
Proved Developed and Undeveloped Reserves
Proved developed reserves	278,233		263,010		72,320
Proved developed reserves - BOE	294,585		264,062		72,320
Proved undeveloped reserves	567,429		482,820		206,990
Proved undeveloped reserves - BOE	593,551		486,116		206,990
Oil (Barrels)
Proved Developed and Undeveloped Reserves
Proved reserves - beginning balance	745,830		279,310
Proved reserves - revisions	49,103	[1]	-1,860	[1]
Proved reserves - extensions and discoveries	88,611		487,128
Proved reserves - production	-37,885		-18,748
Proved reserves - purchases (sales) of minerals-in-place	0		0
Proved reserves - ending balance	845,659		745,830
Natural Gas (Mcf)
Proved Developed and Undeveloped Reserves
Proved reserves - beginning balance	26,090		0
Proved reserves - revisions	192,591	[1]	0	[1]
Proved reserves - extensions and discoveries	58,180		27,807
Proved reserves - production	-21,999		-1,717
Proved reserves - purchases (sales) of minerals-in-place	0		0
Proved reserves - ending balance	254,860		26,090
BOE (Barrels)
Proved Developed and Undeveloped Reserves
Proved reserves - beginning balance	750,178		279,310
Proved reserves - revisions	88,882	[1]	-1,860	[1]
Proved reserves - extensions and discoveries	90,627		491,762
Proved reserves - production	-41,551		-19,034
Proved reserves - purchases (sales) of minerals-in-place	0		0
Proved reserves - ending balance	888,136		750,178
[1]	The revisions of previous estimates resulted from a revised increase in the estimate of reserve value after continued reservoir production offset by lower hydrocarbon prices in the energy markets.

Supplementary_Information_Stan

Supplementary Information - Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves (Details) (USD $)	12 Months Ended
	Feb. 28, 2015		Feb. 28, 2014		Feb. 28, 2013
Discounted Future Net Cash Flows Relating To Proved Oil And Gas Reserves Standardized Measure
Future cash inflows	$73,348,130		$71,943,890
Future production costs	-25,378,830	[1]	-21,295,890	[1]
Future development costs	-6,789,770		-5,560,780
Future income tax expenses	0	[2]	0	[2]
Future net cash flows	41,179,530		45,087,220
10% annual discount for estimated timing of cash flows	-23,674,830		-23,662,780
Standardized measure of discounted future net cash flows at the end of the fiscal year	$17,504,700		$21,424,440		$13,285,134
Oil (Barrel)
Discounted Future Net Cash Flows Relating To Proved Oil And Gas Reserves Standardized Measure
Average oil and gas sales price	85.53	[3]	95.94	[3]	94.25	[3]
Natural Gas
Discounted Future Net Cash Flows Relating To Proved Oil And Gas Reserves Standardized Measure
Average oil and gas sales price	2.99	[3]	2.44	[3]	0	[3]
[1]	Production costs include oil and gas operations expense, production ad valorem taxes, transportation costs and G&A expense supporting the Company's oil and gas operations.
[2]	The Company has sufficient tax deductions and allowances related to proved oil and gas reserves to offset future net revenues.
[3]	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_2

Supplementary Information for Oil and Gas Producing Activities (Details 6) (USD $)	12 Months Ended
	Feb. 28, 2015	Feb. 28, 2014
Sources Of Changes In Standardized Measure Of Discounted Future Net Cash Flow Relating To Proved Oil And Gas Reserves [Roll Forward]
Standardized measure of discounted future net cash flows at the beginning of the year	$21,424,440	$13,285,134
Extensions, discoveries and improved recovery, less related costs	1,565,310	14,017,040
Revisions of previous quantity estimates	2,040,090	251,759
Net changes in prices and production costs	-3,214,934	-1,752,247
Accretion of discount	2,142,444	1,328,514
Sales of oil produced, net of production costs	-2,753,880	-1,586,020
Development costs incurred during the period	1,516,201	1,120,585
Changes in future development costs	-1,385,033	-584,992
Changes in timing of future production	-3,829,938	-4,655,333
Net changes in income taxes	0	0
Standardized measure of discounted future net cash flows at the end of the year	$17,504,700	$21,424,440