Daybreak Oil and Gas, Inc.

0001515971-15-000370.txt : 20151015 0001515971-15-000370.hdr.sgml : 20151015 20151014190036 ACCESSION NUMBER: 0001515971-15-000370 CONFORMED SUBMISSION TYPE: 10-Q PUBLIC DOCUMENT COUNT: 9 CONFORMED PERIOD OF REPORT: 20150831 FILED AS OF DATE: 20151015 DATE AS OF CHANGE: 20151014 FILER: COMPANY DATA: COMPANY CONFORMED NAME: Daybreak Oil & Gas, Inc. CENTRAL INDEX KEY: 0001164256 STANDARD INDUSTRIAL CLASSIFICATION: CRUDE PETROLEUM & NATURAL GAS [1311] IRS NUMBER: 910626366 STATE OF INCORPORATION: WA FISCAL YEAR END: 0228 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 000-50107 FILM NUMBER: 151158948 BUSINESS ADDRESS: STREET 1: 601 W. MAIN AVE STREET 2: SUITE 1012 CITY: SPOKANE STATE: WA ZIP: 99201 BUSINESS PHONE: (509) 232-7674 MAIL ADDRESS: STREET 1: 601 W. MAIN AVE STREET 2: SUITE 1012 CITY: SPOKANE STATE: WA ZIP: 99201 FORMER COMPANY: FORMER CONFORMED NAME: DAYBREAK OIL & GAS INC DATE OF NAME CHANGE: 20051212 FORMER COMPANY: FORMER CONFORMED NAME: DAYBREAK MINES INC DATE OF NAME CHANGE: 20011231 10-Q 1 dbrm10q083115.htm 10-Q Daybreak Oil and Gas, Inc.

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended August 31, 2015

o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ______________ to _______________

Commission File Number: 000-50107

DAYBREAK OIL AND GAS, INC.

(Exact name of registrant as specified in its charter)


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

1101 N. Argonne Road, Suite A 211, Spokane Valley, WA		99212
(Address of principal executive offices)		(Zip code)

(509) 232-7674

(Registrant’s telephone number, including area code)


601 W. Main Ave., Suite 1017, Spokane, WA		99201

(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. þ Yes ¨ No

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.


Large accelerated filer ¨		Accelerated filer ¨

Non-accelerated filer ¨	(Do not check if a smaller reporting company)	Smaller reporting company þ

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

At October 13, 2015 the registrant had 51,487,373 outstanding shares of $0.001 par value common stock.

TABLE OF CONTENTS

PART I - FINANCIAL INFORMATION


ITEM 1.	FINANCIAL STATEMENTS	3
	Balance Sheets at August 31, 2015 and February 28, 2015 (Unaudited)	3
	Statements of Operations for the Three and Six Months Ended August 31, 2015 and August 31, 2014 (Unaudited)	4
	Statements of Cash Flows for the Six Months Ended August 31, 2015 and August 31, 2014 (Unaudited)	5
	NOTES TO UNAUDITED FINANCIAL STATEMENTS	6
ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	15
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	31
ITEM 4.	CONTROLS AND PROCEDURES	31

	PART II - OTHER INFORMATION

ITEM 1.	LEGAL PROCEEDINGS	32
ITEM 1A.	RISK FACTORS	32
ITEM 5.	OTHER INFORMATION	32
ITEM 6.	EXHIBITS	33
Signatures		34

PART I

FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DAYBREAK OIL AND GAS, INC.

Balance Sheets – Unaudited


	As of August 31,		As of February 28,
	2015		2015
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	122,492	$	496,772
Accounts receivable:
Oil and natural gas sales		123,763		202,732
Joint interest participants		53,686		51,382
Other receivables, net		141,754		160,996
Production revenue receivable – current		95,000		120,000
Prepaid expenses and other current assets		216,700		201,693
Note receivable – current		281,457		1,320,944
Total current assets		1,034,852		2,554,519
OIL AND GAS PROPERTIES, successful efforts method, net
Proved properties		4,259,275		4,379,606
Unproved properties		737,218		733,478
PREPAID DRILLING COSTS		16,452		16,452
PRODUCTION REVENUE RECEIVABLE – NON-CURRENT		-		35,000
DEFERRED FINANCING COSTS, NET		846,187		1,058,751
NOTE RECEIVABLE – NON-CURRENT		3,841,043		3,429,056
OTHER ASSETS		106,241		106,199
Total assets	$	10,841,268	$	12,313,061

LIABILITIES AND STOCKHOLDERS’ DEFICIT
CURRENT LIABILITIES:
Accounts payable and other accrued liabilities	$	1,497,010	$	1,435,677
Accounts payable – related parties		948,826		905,891
Accrued interest		168,612		158,797
Notes payable – related party		250,100		250,100
Debt – current portion, net		2,720,612		4,691,211
Line of credit		855,333		869,865
Total current liabilities		6,440,493		8,311,541
LONG TERM LIABILITIES:
12% Notes payable, net		315,000		315,000
12% Notes payable – related party, net		250,000		250,000
Debt – non-current portion, net		10,041,871		8,591,507
Asset retirement obligation		31,148		29,603
Total liabilities		17,078,512		17,497,651
COMMITMENTS AND CONTINGENCIES
STOCKHOLDERS’ DEFICIT:
Preferred stock – 10,000,000 shares authorized, $0.001 par value;		-		-
Series A Convertible Preferred stock – 2,400,000 shares authorized, $0.001 par value, 6% cumulative dividends; 724,565 and 734,565 shares issued and outstanding, respectively		725		735
Common stock – 200,000,000 shares authorized; $0.001 par value, 51,487,373 and 51,457,373 shares issued and outstanding, respectively		51,487		51,457
Additional paid-in capital		22,968,714		22,968,734
Accumulated deficit		(29,258,170)		(28,205,516)
Total stockholders’ deficit		(6,237,244)		(5,184,590)
Total liabilities and stockholders’ deficit	$	10,841,268	$	12,313,061

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

DAYBREAK OIL AND GAS, INC.

Statements of Operations – Unaudited


	For the Three Months Ended August 31,				For the Six Months Ended August 31,
	2015		2014		2015		2014
REVENUE:
Oil and natural gas sales	$	369,834	$	1,044,296	$	811,118	$	1,854,725

OPERATING EXPENSES:
Production expenses		70,001		79,955		145,606		165,485
Exploration and drilling		8,400		6,027		20,067		12,810
Depreciation, depletion, amortization, and impairment		118,889		171,516		257,729		291,493
General and administrative		248,855		265,105		534,503		619,924
Total operating expenses		446,145		522,603		957,905		1,089,712
OPERATING INCOME (LOSS)		(76,311)		521,693		(146,787)		765,013

OTHER INCOME (EXPENSE):
Interest income		201,851		290,008		424,604		454,846
Interest expense		(661,604)		(697,187)		(1,330,471)		(1,363,004)
Total other income (expense)		(459,753)		(407,179)		(905,867)		(908,158)

NET INCOME (LOSS)		(536,064)		114,514		(1,052,654)		(143,145)

Cumulative convertible preferred stock dividend requirement		(32,872)		(33,462)		(65,896)		(66,923)

NET INCOME (LOSS) AVAILABLE TO COMMON SHAREHOLDERS	$	(568,936)	$	81,052	$	(1,118,550)	$	(210,068)
NET INCOME (LOSS) PER COMMON SHARE
Basic	$	0.01	$	(0.00)	$	(0.02)	$	(0.00)
Diluted	$	0.01	$	(0.00)	$	(0.02)	$	(0.00)
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING
Basic		51,487,373		56,422,568		51,482,273		56,819,345
Diluted		51,487,373		61,376,698		51,482,273		56,819,345

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

DAYBREAK OIL AND GAS, INC.

Statements of Cash Flows – Unaudited


	Six Months Ended
	August 31 2015		August 31, 2014
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(1,052,654)	$	(143,145)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Stock compensation		-		2,515
Depreciation, depletion, accretion and impairment expense		257,730		291,493
Amortization of debt discount		68,196		84,635
Amortization of deferred financing costs		212,564		209,844
Interest income		(42)		(42)
Changes in assets and liabilities:
Accounts receivable – oil and natural gas sales		78,969		(72,706)
Accounts receivable – joint interest participants		(2,304)		187,216
Accounts receivable – other		79,242		(38,197)
Prepaid expenses and other current assets		(15,007)		11,791
Accounts payable and other accrued liabilities		57,453		(346,262)
Accounts payable – related parties		42,935		(89,685)
Accrued interest		9,815		72
Net cash provided by (used in) operating activities		(263,103)		97,529

CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and natural gas properties		(135,714)		(667,633)
Prepaid drilling costs		-		(646,938)
Additions to note receivable		-		(4,200,000)
Collections of note receivable		627,500		1,483,960
Deferred interest		-		655
Net cash provided by (used in) investing activities		491,786		(4,029,956)

CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term debt		-		5,700,000
Payments on long-term debt		(588,431)		(1,693,348)
Proceeds from warrant conversion		-		7,000
Payment of deferred financing fees		-		(345,000)
Payments on line of credit		(14,532)		(2,359)
Net cash provided by (used in) financing activities		(602,963)		3,666,293

NET DECREASE IN CASH AND CASH EQUIVALENTS		(374,280)		(266,134)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD		496,772		500,431
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	122,492	$	234,297

CASH PAID FOR:
Interest	$	1,039,896	$	1,083,825
Income taxes	$	-	$	-

SUPPLEMENTAL CASH FLOW INFORMATION:
Unpaid additions to oil and gas properties	$	3,880	$	2,426
Conversion of warrants	$	-	$	1,874
Share-to-warrant exchange	$	-	$	428
ARO asset and liability increase	$	140	$	1,906
Increase in note payable for stock acquisition and subsequent retirement	$	-	$	1,708,447
Conversion of preferred stock to common stock	$	30	$	-
Repurchase of stock through payment of payroll taxes	$	-	$	490

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

DAYBREAK OIL AND GAS, INC.

NOTES TO UNAUDITED FINANCIAL STATEMENTS

NOTE 1 — ORGANIZATION AND BASIS OF PRESENTATION:

Organization

Originally incorporated as Daybreak Uranium, Inc., (“Daybreak Uranium”) 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 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 gas production is sold under contracts which are market-sensitive. Accordingly, the Company’s financial condition, results of operations, and capital resources are highly dependent upon prevailing market prices of, and demand for, 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 natural 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.

Basis of Presentation

The accompanying unaudited interim financial statements and notes for the Company have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial information and with the instructions to Form 10-Q for quarterly reports under Section 13 or 15(d) of the Securities Exchange Act of 1934 (the “Exchange Act”). Accordingly, they do not include all of the information and footnote disclosures normally required by accounting principles generally accepted in the United States of America for complete financial statements.

In the opinion of management, all adjustments considered necessary for a fair presentation of the financial statements have been included and such adjustments are of a normal recurring nature. Operating results for the six months ended August 31, 2015 are not necessarily indicative of the results that may be expected for the fiscal year ending February 29, 2016.

These financial statements should be read in conjunction with the audited financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the fiscal year ended February 28, 2015.

Use of Estimates

In preparing financial statements in conformity with accounting principles generally accepted in the United States of America, management is required to make estimates and assumptions. These estimates and assumptions may affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, and revenues and expenses during the reporting period. Actual results could differ materially from those estimates. The accounting policies most affected by management’s estimates and assumptions are as follows:

The reliance on estimates of proved reserves to compute the provision for depreciation, depletion and amortization and to determine the amount of any impairment of proved properties;

The valuation of unproved acreage and proved oil and 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 abandonment obligations.

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.

NOTE 2 — GOING CONCERN:

Financial Condition

The Company’s financial statements for the six months ended August 31, 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. The Company has incurred net losses since entering the oil and natural gas exploration industry and as of August 31, 2015 has an accumulated deficit of $29,258,170 and a working capital deficit of $5,405,641 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 oil wells in its East Slopes Project located in Kern County, California (the “East Slopes Project”). The revenue from these wells has created a steady and reliable source of revenue. The Company’s average working interest in these wells is 36.6% and the average net revenue interest (“NRI”) is 28.4% for these same wells.

Additionally, the Company has become involved in a shallow oil development project in an existing natural gas field in Lawrence County, Kentucky, through its acquisition of an average 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 13 producing horizontal oil wells in the Twin Bottoms Field with some supplementary natural gas production. The Company’s average working interest in these 13 horizontal oil wells is 22.4% and the average NRI 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 Kentucky and California 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, while the Company has experienced revenue growth that has resulted in positive cash flow from its oil and natural gas properties, it has not yet established consistent positive cash flow on a company-wide basis primarily due to lower oil prices. It will be necessary for the Company to obtain additional financing 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 plan to continue as a going concern.

Daybreak’s financial statements as of August 31, 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.

NOTE 3 — RECENT ACCOUNTING PRONOUNCEMENTS:

There are no new accounting pronouncements issued or effective that have had, or are expected to have, a material impact on the Company’s financial statements.

NOTE 4 — CONCENTRATION OF CREDIT RISK:

Substantially all of the Company’s trade 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 including lower oil prices 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 August 31, 2015 and February 28, 2015, as all joint interest owners have a history of paying their obligations.

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 August 31, 2015 and February 28, 2015 these three individual customers represented 100.0% of crude oil and natural gas revenue accounts receivable. If these buyers are unable to resell their products or if they lose a significant sales contract then the Company may incur difficulties in selling its oil and natural gas production.

The Company’s accounts receivable from Kentucky and California oil and natural gas sales at August 31, 2015 and February 28, 2015 are set forth in the table below.


		August 31, 2015			February 28, 2015
Project	Customer	Revenue Receivable		Percentage	Revenue Receivable		Percentage
Kentucky – Twin Bottoms Field (Oil)	Appalachian Oil	$	46,015	37.2%	$	90,906	44.9%
Kentucky – Twin Bottoms Field (Natural gas)	Jefferson Gas		8,201	6.6%		16,676	8.2%
California – East Slopes Project (Oil)	Plains Marketing		69,547	56.2%		95,150	46.9%
		$	123,763	100.0%	$	202,732	100.0%

Other receivables balances primarily include amounts advanced to certain minority working interest partners in Kentucky and monthly principal and interest receivable on the loan to App Energy, LLC, a Kentucky limited liability company (“App Energy”). For additional information on the App Energy loan refer to the discussion in Note 8 – Note Receivable.

NOTE 5 — OIL AND GAS PROPERTIES:

Oil and gas property balances at August 31, 2015 and February 28, 2015 are set forth in the table below.


	August 31, 2015		February 28, 2015
Proved leasehold costs	$	699,417	$	695,231
Unproved leasehold costs		737,218		733,478
Costs of wells and development		678,614		542,563
Capitalized exploratory well costs		5,304,632		5,308,876
Total cost of oil and gas properties		7,419,881		7,280,148
Accumulated depletion, depreciation, amortization and impairment		(2,423,388)		(2,167,064)
Net oil and gas properties	$	4,996,493	$	5,113,084

NOTE 6 — PRODUCTION REVENUE RECEIVABLE:

Production revenue receivable balances of $95,000 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 August 31, 2015 and February 28, 2015 are set forth in the table below:


	August 31, 2015		February 28, 2015
Production revenue receivable – current	$	95,000	$	120,000
Production revenue receivable – non-current		-		35,000
	$	95,000	$	155,000

NOTE 7 — DEFERRED FINANCING COSTS:

Deferred financing costs at August 31, 2015 and February 28, 2015 relate 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:


	August 31, 2015		February 28, 2015
Deferred financing costs – loan fees	$	151,139	$	151,139
Deferred financing costs – loan commissions		630,662		630,662
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		1,732,121
Accumulated amortization		(885,934)		(673,370)
	$	846,187	$	1,058,751

The Company recognized amortization expense of $212,564 for the six months ended August 31, 2015.

NOTE 8 — NOTE RECEIVABLE:

At August 31, 2015, the Company had advanced approximately $8.3 million to App Energy through its credit facility. Note receivable balances at August 31, 2015 and February 28, 2015 are set forth in the table below:


	August 31, 2015		February 28, 2015
Note receivable – current	$	281,457	$	1,320,944
Note receivable – non-current		3,841,043		3,429,056
	$	4,122,500	$	4,750,000

NOTE 9 — ACCOUNTS PAYABLE:

On March 1, 2009, the Company became the operator for its East Slopes Project. Additionally, the Company at that time assumed certain original partners’ default liability of approximately $1.5 million representing a 25% working interest in the drilling and completion costs associated with the East Slopes Project four earning well program. The Company subsequently sold the same 25% working interest on June 11, 2009. Of the $1.5 million default, $246,349 remains unpaid and is included in the August 31, 2015 accounts payable balance.

NOTE 10 — ACCOUNTS PAYABLE- RELATED PARTIES:

The August 31, 2015 and February 28, 2015 accounts payable – related parties balances were comprised primarily of salaries of the Company’s Executive Officers and certain employees; directors’ fees; expense reimbursements; and interest to the Company’s President and Chief Executive Officer on the 12% Subordinated Notes further described in Note 11 – Short-Term and Long-Term Borrowings below. Payment of these items has been deferred until the Company’s cash flow situation improves.

NOTE 11 — SHORT-TERM AND LONG-TERM BORROWINGS:

Note Payable – Related Party

As of August 31, 2015 and February 28, 2015, the Company’s President and Chief Executive Officer had loaned the Company $250,100 in aggregate that was 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 our President and Chief Executive Officer. Interest is payable monthly at a stated reference rate of 0.249% + 337.5 basis points and totaled $15,468 for the six months ended August 31, 2015. The reference rate is based on the 30 day LIBOR (“London Interbank Offered Rate”) and is subject to change from UBS. At August 31, 2015 the Line of credit had an outstanding balance of $855,333.

Long-term Borrowings

12% Subordinated Notes

The Company’s 12% Subordinated Notes (“the Notes”) issued pursuant to a March 2010 private placement (of which $250,000 was from a related party) accrue interest at 12% per annum, payable semi-annually on January 29th and July 29th. On January 29, 2015, the Company and 12 of the 13 note holders agreed to extend the maturity date of the Notes from January 29, 2015 for an additional two years. The note principal is payable in full at the amended maturity date of the Notes, which is January 29, 2017. The outstanding balance of the 12% Notes was $565,000 at August 31, 2015 and February 28, 2015. Should the Board of Directors, on the amended 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.

Maximilian Credit Facility

On October 31, 2012, the Company entered into a loan agreement with Maximilian, 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. The relative fair value of this 10% working interest amounting to $515,638 was recognized as a discount to debt and is being amortized over the original term of the loan. Amortization expense was $68,196 for the six months ended August 31, 2015. Unamortized debt discount was $135,869 at August 31, 2015.

In 2012, 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. As of August 31, 2015, 316,617 of these warrants remain unexercised and outstanding.

Maximilian Credit Facility - Amended and Restated Loan Agreement

In connection with the Company’s acquisition of a working interest from App Energy 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 Energy, as borrower pursuant to a Loan and Security Agreement entered into between the Company and App Energy on August 28, 2013 (See Note 8 – Note Receivable).

The amended loan agreement contains customary covenants for loans 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 Energy 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; and contain an exercise blocker provision that prevents 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 Company’s currently issued and outstanding shares at the time of the exercise. The Company also granted to Maximilian a 50% net profits interest in the Company’s approximate 25% working interest, after the Company recovers it’s investment in the Kentucky acreage, pursuant to an Assignment of Net Profits Interest entered into as of August 28, 2013 by and between the Company and Maximilian.

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. 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.

On May 20, 2015, the Company entered into a Second Amendment to Amended and Restated Loan and Security Agreement (the”2^nd Amendment”) with Maximilian under its Amended and Restated Loan and Security Agreement dated as of August 28, 2013. The 2^nd Amendment modified the calculation of the required monthly payment for a three-month period ending June 30, 2015. As consideration for entering into the loan modification, the Company agreed to modify the exercise price of the warrants Maximilian currently holds from $0.10 to $0.04. No other terms of the warrant agreement were changed. The Company determined that the modification of the warrant exercise price did not result in any incremental fair value.

With the assistance of Maximilian, the Company is currently working with an investment banking firm to assist in securing refinancing of its debt with Maximilian, since the long-term commitment needed to develop the Kentucky and California projects no longer fits the Maximilian business model. Maximilian is continuing to work with the Company in modifying the credit facility terms during this period of lower hydrocarbon prices.

Current debt balances at August 31, 2015, and February 28, 2015 are set forth in the table below:


	August 31, 2015		February 28, 2015
Maximilian note	$	2,840,442	$	4,823,325
Maximilian note - discount		(119,830)		(132,114)
	$	2,720,612	$	4,691,211

Non-current debt balances at August 31, 2015 and February 28, 2015 are set forth in the table below:


	August 31, 2015		February 28, 2015
Maximilian note	$	10,057,910	$	8,663,458
Maximilian note - discount		(16,039)		(71,951)
	$	10,041,871	$	8,591,507

NOTE 12 — STOCKHOLDERS’ DEFICIT:

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. At August 31, 2015, there were 724,565 shares issued and outstanding, that had not been converted into our common stock. As of August 31, 2015, there are 43 accredited investors who have converted 675,200 Series A Preferred shares into 2,025,600 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 Preferred Converted to Common Stock	Shares of Common Stock Issued from Conversion	Number of Accredited Investors
Year Ended February 29, 2008	102,300	306,900	10
Year Ended February 28, 2009	237,000	711,000	12
Year Ended February 28, 2010	51,900	155,700	4
Year Ended February 28, 2011	102,000	306,000	4
Year Ended February 29, 2012	-	-	-
Year Ended February 28, 2013	18,000	54,000	2
Year Ended February 28, 2014	151,000	453,000	9
Year Ended February 28, 2015	3,000	9,000	1
Six Months Ended August 31, 2015	10,000	30,000	1
Totals	675,200	2,025,600	43

Holders of Series A Preferred shall be paid dividends, in the amount of 6% of the original purchase price per annum. 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. As of August 31, 2015, no dividends have been paid. Dividends earned since issuance for each fiscal year and the six months ended August 31, 2015 are set forth in the table below:


Fiscal Period	Shareholders at Period End	Earned Dividends
Year Ended February 28, 2007	100	$	155,311
Year Ended February 29, 2008	90		242,126
Year Ended February 28, 2009	78		209,973
Year Ended February 28, 2010	74		189,973
Year Ended February 28, 2011	70		173,707
Year Ended February 29, 2012	70		163,624
Year Ended February 28, 2013	68		161,906
Year Ended February 28, 2014	59		151,323
Year Ended February 28, 2015	58		132,634
Six Months Ended August 31, 2015	57		65,897
Total Accumulated Dividends		$	1,646,474

Common Stock

The Company is authorized to issue up to 200,000,000 shares of $0.001 par value common stock of which 51,487,373 shares were issued and outstanding as of August 31, 2015. In comparison, at February 28, 2015, a total of 51,457,373 shares were issued and outstanding. The increase of 30,000 shares was attributable as shown below:


	Common Stock Balance	Par Value
Common stock, Issued and Outstanding, February 28, 2015	51,457,373
Conversion of Series A Convertible Preferred Stock to Common Stock	30,000	$	30
Common stock, Issued and Outstanding, August 31, 2015	51,487,373

NOTE 13 — WARRANTS:

Warrants outstanding and exercisable as of August 31, 2015 are set forth in the table below:


	Warrants	Exercise Price	Remaining Life (Years)	Exercisable Warrants Remaining
12% Subordinated notes	1,190,000	$0.14	1.42	980,000
Warrants issued in 2012 for debt financing	2,435,517	$0.044	2.17	316,617
Warrants issued for Kentucky oil project	3,498,601	$0.04	1.00	3,498,601
Warrants issued for Kentucky debt financing	2,623,951	$0.04	1.00	2,623,951
Warrants issued for Kentucky debt financing	309,503	$0.214	3.00	309,503
Warrants issued in share-for-warrant exchange	427,729	$0.04	1.00	427,729
	10,485,301			8,156,401

There were 150,000 warrants issued in 2010 for services that expired during the six months ended August 31, 2015. During the six months ended August 31, 2015 there were no warrants issued or exercised. The remaining outstanding warrants as of August 31, 2015, have a weighted average exercise price of $0.06, a weighted average remaining life of 1.17 years, and an intrinsic value of -$0-.

NOTE 14 — 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 rates to income from continuing operations before income taxes is set forth in the table below:


	August 31, 2015		February 28, 2015
Computed at U.S. and state statutory rates (40%)	$	(421,059)	$	(293,176)
Permanent differences		58,737		142,925
Changes in valuation allowance		362,322		150,251
	$	-	$	-

Tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred liabilities are set forth in the table below:


	August 31, 2015		February 28, 2015
Deferred tax assets:
Net operating loss carryforwards	$	9,595,165	$	9,188,905
Oil and gas properties		(1,429,835)		(1,436,249)
Stock based compensation		88,723		88,723
Other		(153,251)		(102,899)
Less valuation allowance		(8,100,802)		(7,738,480)
	$	-	$	-

At August 31, 2015, Daybreak had estimated net operating loss (“NOL”) carryforwards for federal and state income tax purposes of approximately $23,987,913 which will begin to expire, if unused, beginning in 2024. The valuation allowance increased $362,322 for the six months ended August 31, 2015 and increased by $150,251 for the year ended February 28, 2015. Section 382 of the Internal Revenue Code places annual limitations on the Company’s NOL carryforward.

The above estimates are based on management’s decisions concerning elections which could change the relationship between net income and taxable income. Management decisions are made annually and could cause estimates to vary significantly.

NOTE 15 — COMMITMENTS AND CONTINGENCIES:

Various lawsuits, claims and other contingencies arise in the ordinary course of the Company’s business activities. While the ultimate outcome of any future contingency is not determinable at this time, management believes that any liability or loss resulting therefrom will not materially affect the financial position, results of operations or cash flows of the Company.

The Company, as an owner or lessee and operator of 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 August 31, 2015. There can be no assurance, however, that current regulatory requirements will not change or that past non-compliance with environmental issues will not be discovered on the Company’s oil and gas properties.

NOTE 16 — SUBSEQUENT EVENTS:

On October 14, 2015, the Company entered into a Third Amendment to the Amended and Restated Loan and Security Agreement and Second Warrant Amendment with Maximilian, which amended the Company’s loan agreement with Maximilian (the “Maximilian Amendment”). Pursuant to the Maximilian Amendment, Maximilian agreed to a reduction in the Company’s monthly payments under the loan agreement to $50,000 per month for a period of six months ending on February 29, 2016. The reduction in monthly payments allows for additional funds to be used by the Company in drilling and completing additional wells in Kentucky. As consideration for the reduction in the monthly payment amount, the Company agreed that twenty percent of the amount by which the monthly payment was reduced would be added to the loan balance, and the portion of the monthly payment savings that constitutes savings in interest or commitment fees would be treated as an additional advance of principal under the loan agreement (the “Deemed Advances”). The Company also agreed to grant to Maximilian an overriding royalty interest in four wells it drills of 1.5% of its working interest in such wells, subject to reduction connected to the Company’s ongoing efforts to refinance its loan agreement. As part of the Maximilian Amendment, the Company also agreed to extend the expiration date of the warrants held by Maximilian to purchase up to 6,550,281 shares of common stock of the Company to August 28, 2018.

In connection with entering into the Maximilian Amendment, the Company concurrently entered into a Second Amendment to Loan and Security Agreement with App Energy (the “App Amendment”), which amended the Company’s loan agreement with App Energy in which the Company, as lender, lends to App Energy, as borrower, a portion of the advances it receives pursuant to its loan agreement with Maximilian. The App Amendment provides for a reduction in interest rate and a reduction in monthly payments to be made by App Energy to the Company for the same payment cycles as the reduced payment to be made by the Company under the Maximilian Amendment. The reduction in monthly payments by App Energy will allow App Energy to fund its share of drilling and completing additional wells in Kentucky with the Company. As consideration for the reduction in the monthly payment amount, App Energy agreed that a percentage of the Deemed Advances will be treated as additional advances under the App Energy loan agreement, and that it would fund a portion of the Company’s drilling and development expenses with respect to two wells, subject to a partial refund connected to the Company’s ongoing efforts to refinance its loan agreement. App Energy also agreed to grant to Maximilian an overriding royalty interest on the same terms as the overriding royalty interest agreed to by the Company. Finally, App Energy granted to the Company a time-limited option to purchase additional working interest in its Kentucky operations connected to the Company’s ongoing efforts to refinance its loan agreement.

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion is management’s assessment of the current and historical financial and operating results of the Company and of our financial condition. It is intended to provide information relevant to an understanding of our financial condition, changes in our financial condition and our results of operations and cash flows and should be read in conjunction with our unaudited financial statements and notes thereto included elsewhere in this Quarterly Report on Form 10-Q for the six months ended August 31, 2015 and in our Annual Report on Form 10-K for the year ended February 28, 2015. References to “Daybreak”, the “Company”, “we”, “us” or “our” mean Daybreak Oil and Gas, Inc.

Cautionary Statement Regarding Forward-Looking Statements

Certain statements contained in our Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”) are intended to be covered by the safe harbor provided for under Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Exchange Act.

All statements other than statements of historical fact contained in this MD&A report are inherently uncertain and are forward-looking statements. Statements that relate to results or developments that we anticipate will or may occur in the future are not statements of historical fact. Words such as “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “predict,” “project,” “will” and similar expressions identify forward-looking statements. Examples of forward-looking statements include, without limitation, statements about the following:

Our future operating results;

Our future capital expenditures;

Our future financing;

Our expansion and growth of operations; and

Our future investments in and acquisitions of oil and natural gas properties.

We have based these forward-looking statements on assumptions and analyses made in light of our experience and our perception of historical trends, current conditions, and expected future developments. However, you should be aware that these forward-looking statements are only our predictions and we cannot guarantee any such outcomes. Future events and actual results may differ materially from the results set forth in or implied in the forward-looking statements. Important factors that could cause actual results to differ materially from our expectations include, but are not limited to, the following risks and uncertainties:

General economic and business conditions;

Exposure to market risks in our financial instruments;

Fluctuations in worldwide prices and demand for oil and natural gas;

Our ability to find, acquire and develop oil and natural gas properties;

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

Risks associated with oil and natural gas exploration and development activities;

Competition for raw materials and customers in the oil and natural gas industry;

Technological changes and developments in the oil and natural gas industry;

Legislative and regulatory uncertainties, including proposed changes to federal tax law and climate change legislation, regulation of hydraulic fracturing and potential environmental liabilities;

Our ability to continue as a going concern;

Our ability to secure financing under any commitments as well as additional capital to fund operations; and

Other factors discussed elsewhere in our Form 10-K for the year ended February 28, 2015; in this Form 10-Q; in our other public filings and press releases; and discussions with Company management.

Our reserve estimates are determined through a subjective process and are subject to revision.

Should one or more of the risks or uncertainties described above or elsewhere in our Form 10-K for the year ended February 28, 2015 and in this Form 10-Q occur, or should any underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. We specifically undertake no obligation to publicly update or revise any information contained in any forward-looking statement or any forward-looking statement in its entirety, whether as a result of new information, future events, or otherwise, except as required by law.

All forward-looking statements attributable to us are expressly qualified in their entirety by this cautionary statement.

Introduction and Overview

We are an independent oil and natural gas exploration, development and production company. Our basic business model is to increase shareholder value by finding and developing oil and natural gas reserves through exploration and development activities, and selling the production from those reserves at a profit. To be successful, we must, over time, be able to find oil and natural gas reserves and then sell the resulting production at a price that is sufficient to cover our finding costs, operating expenses, administrative costs and interest expense, plus offer us a return on our capital investment. A secondary means of generating returns can include the sale of either producing or non-producing lease properties.

Our longer-term success depends on, among many other factors, the acquisition and drilling of commercial grade oil and natural gas properties and on the prevailing sales prices for oil and natural gas along with associated operating expenses. The volatile nature of the energy markets makes it difficult to estimate future prices of oil and natural gas; however, any prolonged period of depressed prices, such as we are now experiencing, would have a material adverse effect on our results of operations and financial condition.

Our operations are focused on identifying and evaluating prospective oil and natural gas properties and funding projects that we believe have the potential to produce oil or natural gas in commercial quantities. We conduct all of our drilling, exploration and production activities in the United States, and all of our revenues are derived from sales to customers within the United States. Currently, we are in the process of developing two multi-well oilfield projects; one in Lawrence County, Kentucky and the other in Kern County, California.

In the current fiscal year, we will continue to seek additional financing for our planned exploration and development activities in both Kentucky and California. The Company has engaged an investment banking firm to assist in securing refinancing of its debt under more favorable terms and implement its development plans in California and Kentucky. We plan to obtain financing through various methods, including issuing debt securities, equity securities, or bank debt, or combinations of these instruments, which could result in dilution to existing security holders and increased debt and leverage. No assurance can be given that we will be able to obtain funding under any loan commitments or any additional financing on favorable terms, if at all. Sales of interests in our assets may be another source of cash flow.

Our management cannot provide any assurances that Daybreak will ever operate profitably. We have not been able to generate sustained positive earnings on a Company-wide basis. As a small company, we are more susceptible to the numerous business, investment and industry risks that have been described in Item 1A. Risk Factors of our Annual Report on Form 10-K for the fiscal year ended February 28, 2015 and in Part III, Item 1A. Risk Factors of this 10-Q Report. Throughout this Quarterly Report on Form 10-Q, oil is shown in barrels (“Bbls”); natural gas is shown in thousands of cubic feet (“Mcf”) unless otherwise specified, and hydrocarbon totals are expressed in barrels of oil equivalent (“BOE”).

Below is summary of our oil and natural gas projects in Kentucky and California.

Lawrence County, Kentucky (Twin Bottoms Field)

The Twin Bottoms Field, comprising approximately 7,300 acres in two large contiguous blocks, is located in the Appalachian Basin of eastern Kentucky. Log data from existing vertical gas wells in the field indicate the existence of proved oil reserves in the Berea sandstone, located at approximately 2,000 feet. The lateral leg of each well is between 2,000 feet and 4,500 feet in length. We have an approximate 25% working interest and an approximate net revenue interest (“NRI”) of 21.9% in all horizontal oil wells in this project. The oil produced from our acreage in Kentucky is light crude oil measuring between 42° and 44° API gravity. We are not the Operator of the Twin Bottoms Field project; instead we rely on the experience of the current Operator and its knowledge of this Field.

At August 31, 2015, we had 13 producing horizontal oil wells in the Twin Bottoms Field. Our first well, the Grove H-1 was put on production in October 2013. During the year ended February 28, 2014, three additional oil wells, the Grove #H-3, Grove #H-4 and Grove #H-5, were put on production. Nine additional horizontal oil wells, the Dillon #H-6, Grove #H-7, Grove #H-8, Grove #H-9, Grove #H-10, Jackson #H-20, Lyons #H-23, Lyons #H-24 and the Dillon #H-22, were put on production during the year ended February 28, 2015. Our average working interest and NRI in these 13 producing horizontal oil wells is 22.4% and 19.6%, respectively.

In August 2015, we drilled the vertical leg portion of the Murray #H-34 well. The well was logged and data was collected for use in the drilling of the App Energy #H-33 well. The App Energy #H-33 well was drilled to a measured depth of 5,251 feet and encountered 3,913 feet of oil pay in the Berea Sandstone. The App Energy #H-33 well will be hydraulically fractured in late October to early November 2015. The horizontal portion of the Murray #H-34 well will be drilled at a later date.

Kentucky Drilling Plans

Selected wells may be drilled from time to time to maintain production and leases, however; implementation of our full development plan will not begin until there is a sustained improvement in crude oil prices and additional financing is put in place. We plan to spend approximately $250,000 in capital investments in the Twin Bottoms Field project area during the remainder of the 2015-2016 fiscal year.

Kern County, California (East Slopes Project)

The East Slopes Project is located in the southeastern part of the San Joaquin Basin near Bakersfield, California. Drilling targets are porous and permeable sandstone reservoirs which exist at depths of 1,200 feet to 4,500 feet. Since January 2009, we have participated in the drilling of 25 wells in this project. We have been the Operator at the East Slopes Project since March 2009.

Our 20 oil wells in the East Slopes Project produce from five reservoirs at our Sunday, Bear, Black, Ball and Dyer Creek locations. The Sunday property has six producing wells, while the Bear property has nine producing wells. The Black property is the smallest of all currently producing reservoirs, and currently has two producing wells at this property. The Ball property also has two producing wells while the Dyer Creek property has one producing well. Our average working interest and NRI in these 20 producing oil wells is 36.6% and 28.5%, respectively. There are several other similar prospects on trend with the Bear, Black and Dyer Creek reservoirs exhibiting the same seismic characteristics. Some of these prospects, if successful, would utilize the Company’s existing production facilities. In addition to the current field development, there are several other exploratory prospects that have been identified from the seismic data, which we plan to drill in the future.

Sunday Central Processing and Storage Facility

The oil produced from our acreage in California is considered heavy oil. The oil ranges from 14° to 16° API (American Petroleum Institute) gravity. All of the oil from our five producing properties is processed, stored and sold from the Sunday central processing and storage facility. The oil must be heated to separate and remove water to prepare it to be sold. We constructed these facilities during the summer and fall of 2009 and at the same time established electrical service for our field by constructing three miles of power lines. In 2013, we completed an upgrade to this facility including the addition of a second oil storage tank to handle the additional oil production from the wells drilled in 2013.

By utilizing the Sunday centralized production facility our average operating costs have been reduced from over $40 per barrel in 2009 to a monthly average of approximately $12 per barrel of oil for the six months ended August 31, 2015. With this centralized facility and having permanent electrical power available, we are ensuring that our operating expenses are kept to a minimum.

Exploration Properties

Bull Run Prospect

This prospect is located in the southern portion of our acreage position. The drilling targets are the Etchegoin and Santa Margarita sands located between 800 and 1,200 feet deep. Utilizing the data received from a previously drilled well that was not commercially successful, we expect to drill another exploratory well on this prospect during 2015. Future Bull Run wells will require a pilot steam flood and additional production facilities. We estimate that the Bull Run prospect is 70 acres in size. We have a 37.5% working interest in this prospect.

Sherman Prospect

This prospect is also located in the southern portion of our acreage position. The drilling targets are the Olcese and Etchegoin sands between 1,000 and 2,000 feet deep. We estimate that the Sherman Prospect is 100 acres in size. We have a 37.5% working interest in this prospect.

Tobias Prospect

This prospect is also located in the central portion of our acreage position. The drilling targets are the Vedder and Eocene sands between 2,000 and 4,500 feet deep. We estimate that the Tobias prospect is 60 acres in size. We have a 37.5% working interest in this prospect.

California Drilling Plans

Future drilling plans include a combination of both exploratory drilling and development well drilling. Planned drilling activity and implementation of our full development plan will not begin until there is a sustained improvement in crude oil prices and additional financing is put in place. We do not plan to make any capital investments in the East Slopes Project during the rest of the 2015-2016 fiscal year.

Encumbrances

The Company’s debt obligations, pursuant to a loan agreement entered into by and between Maximilian Resources LLC, a Delaware limited liability company, as lender, and the Company are secured by a perfected first priority security interest in substantially all of the personal property of the Company, and a mortgage on our leases in Kern County, California encompassing the Sunday, Bear, Black, Ball and Dyer Creek properties. For further information on the loan agreement refer to the discussion under the caption “Non-current Borrowings” in this MD&A.

Results of Operations – Six Months Ended August 31, 2015 compared to the Six Months Ended August 31, 2014

Hydrocarbon Prices

The price we receive for oil sales in both Kentucky and California is based on prices quoted on the New York Mercantile Exchange (“NYMEX”) for spot West Texas Intermediate (“WTI”) Cushing, Oklahoma delivery contracts, less deductions that vary by grade of crude oil sold and transportation costs. The price we receive for natural gas sales in Kentucky per Mcf is based on the Columbia Gas Transmission Corp. Appalachia Index (“TCO Appalachia”) whereby we will receive 76% of the TCO Appalachia price per dekatherm (DTH) less $0.25 compression cost for each Mcf of gas delivered. We do not have any natural gas revenues in California.

Since June 2014, there has been a significant decline in the WTI price of crude oil and subsequently in the realized price we receive from oil sales. This decline in the price of crude oil has had a substantial negative impact on our cash flow from both our Kentucky and California properties as shown in the table below.


	June 2014		August 2015		Percentage Decline
Monthly average WTI crude oil price	$	105.79	$	42.87	59.5%
Monthly average realized crude oil sales price (Bbl)	$	101.32	$	39.40	61.1%

Kentucky Oil Prices

For the six months ended August 31, 2015, our average realized oil sale price was $51.36 in comparison to the average WTI price of $52.57 representing a discount of $1.21 per barrel or 2.3% lower than the average WTI price. In comparison, for the six months ended August 31, 2014, the average WTI price was $101.83 and our average realized sale price was $99.90 representing a discount of $1.93 per barrel or 1.9% lower than the average WTI price.

Kentucky Natural Gas Prices

For the six months ended August 31, 2015, our average realized natural gas sale price was $1.75 per Mcf (thousand cubic feet) in comparison to the average Henry Hub price of $2.78 per million BTU representing a discount of $1.03 per Mcf or 37.0% lower than the average Henry Hub price. In comparison, for the six months ended August 31, 2014, the average realized sale price was $2.74 per Mcf in comparison to the average Henry Hub price of $4.45 per million BTU representing a discount of $1.71 or 38.3% lower than the average Henry Hub price.

California Oil Prices

For the six months ended August 31, 2015, the average WTI price was $52.57 and our average realized oil sale price was $44.95, representing a discount of $7.62 per barrel or 14.5% lower than the average WTI price. In comparison, for the six months ended August 31, 2014, the average WTI prices was $101.83 and our average realized sale price was $95.46 representing a discount of $6.37 per barrel or 6.3% lower than the average WTI price. Historically, the sale price we receive for California heavy oil has been less than the quoted WTI price because of the lower API gravity of our California oil in comparison to WTI oil API gravity.

Combined Revenue and Production

Our revenues are derived entirely from the sale of our share of oil production in Kentucky and California and natural gas sales in Kentucky. Oil and natural gas revenues for the six months ended August 31, 2015 in aggregate decreased $1,043,607 or 56.3%, to $811,118 in comparison to revenues of $1,854,725 for the six months ended August 31, 2014. Oil and natural gas sales volume decreased 1,248 BOE (barrels of oil equivalent) or 6.3% to 18,637 (BOE) in comparison to 19,885 (BOE) for the six months ended August 31, 2014. The decrease in volume was due to the natural decline in oil producing reservoir pressure. Our average realized sale price on a BOE basis for the six months ended August 31, 2015 was $43.52 in comparison to $93.32 for the six months ended August 31, 2014, representing a decline of $49.80 or 53.4% per barrel.

Kentucky Oil Revenue and Production

Production in Kentucky is from horizontal oil wells in consolidated shale sands that are characterized by large initial production volumes that decline quite rapidly to a much lower and more stable long-term production volume. Fluctuations in revenue are closely linked to both production volumes and crude oil prices. Our first oil sales in Kentucky occurred in October 2013. Oil revenue in Kentucky for the six months ended August 31, 2015 decreased $557,586 or 54.6% to $464,438 in comparison to revenue of $1,022,024 for the six months ended August 31, 2014. The average realized sale price of a barrel of oil for the six months ended August 31, 2015 was $51.36 in comparison to $99.90 for the six months ended August 31, 2014. The decrease of $48.54 or 48.62% in the average sale price of a barrel of oil was responsible for 89.1% of the decline in Kentucky oil revenue for the six months ended August 31, 2015.

Our net sales volume for the six months ended August 31, 2015 was 9,043 barrels of oil in comparison to 10,230 barrels sold for the six months ended August 31, 2014. This decrease in oil sales volume of 1,187 barrels or 11.6% was responsible for 10.9% of the decline in Kentucky oil revenue for the six months ended August 31, 2015.

The API gravity of our produced oil in Kentucky ranges between 42° API and 44° API. Production for the six months ended August 31, 2015 was from 13 wells resulting in 2,188 well days of production in comparison to 1,176 well days for the six months ended August 31, 2014. We had production from nine producing horizontal oil wells for the six months ended August 31, 2014.

Kentucky Natural Gas Revenue and Production

Natural gas production is a by-product from our horizontal oil wells and the volume varies on a well-to-well basis. Our first natural gas sales in Kentucky also occurred in October 2013. Natural gas revenue for the six months ended August 31, 2015 increased $7,982 to $14,733 in comparison to revenue of $6,751 for the six months ended August 31, 2014. The average realized sale price per Mcf for the six months ended August 31, 2015 was $1.75 in comparison to $2.87 for the six months ended August 31, 2014. Our net sales volume for the six months ended August 31, 2015 was 14,733 Mcf or 2,456 BOE in comparison to 6,751 Mcf or 1,125 BOE for the six months ended August 31, 2014. The increase of 7,982 MCF or 1,330 BOE representing a 118.2% increase was due to infrastructure improvements that had previously inhibited natural gas production from existing wells.

California Revenue and Production

Production in California is from vertical oil wells that historically produce at relatively stable levels over a long period of time. Fluctuations in revenue are generally more dependent on the price of crude oil and the timing of oil sales rather than oil production volumes. Oil revenue in California for the six months ended August 31, 2015 decreased $493,297 or 60.6% to $320,876 in comparison to revenue of $814,172 for the six months ended August 31, 2014. The average realized sale price of a barrel of oil for the six months ended August 31, 2015 was $44.95 in comparison to $95.46 for the six months ended August 31, 2014. The decrease of $50.51 or 52.9% in the average realized sale price of a barrel of oil accounted for 87.3% of the decrease in California oil revenue for the six months ended August 31, 2015.

Our net sales volume for the six months ended August 31, 2015 was 7,138 barrels of oil in comparison to 8,529 barrels sold for the six months ended August 31, 2014. This decrease in oil sales volume of 1,391 barrels or 16.3% accounted for 12.7% of the decrease in California oil revenue for the six months ended August 31, 2015. The decrease in volume was due to natural decline in the oil producing reservoirs.

The gravity of our produced oil in California ranges between 14° API and 16° API. Production for the six months ended August 31, 2015 was from 20 wells resulting in 3,662 well days of production in comparison to 3,666 of production from 20 wells for the six months ended August 31, 2014.

Oil and natural gas revenues for the six months ended August 31, 2015 and 2014 are set forth in the table below:


	Six Months Ended August 31, 2015			Six Months Ended August 31, 2014
	Revenue		Percentage	Revenue		Percentage
Kentucky – Twin Bottoms Field (oil)	$	464,438	57.3%	$	1,022,024	55.1%
Kentucky – Twin Bottoms Field (natural gas)		25,804	3.2%		18,529	1.0%
California – East Slopes Project (oil)		320,876	39.5%		814,172	43.9%
Total production expenses	$	811,118	100.0%	$	1,854,725	100.0%

Operating Expenses. Total operating expenses for the six months ended August 31, 2015 decreased by $131,807 or 12.1% to $957,905 in comparison to $1,089,712 for the six months ended August 31, 2014.

Operating expenses for the six months ended August 31, 2015 and August 31, 2014 are set forth in the table below:


	Six Months Ended August 31, 2015					Six Months Ended August 31, 2014
	Expenses		Percentage	BOE Basis		Expenses		Percentage	BOE Basis
Production expenses	$	145,606	15.2%			$	165,485	15.2%
Exploration and drilling expenses		20,067	2.1%				12,810	1.2%
Depreciation, Depletion, Amortization, and Impairment (“DD&A”)		257,729	26.9%				291,493	26.7%
General and Administrative (“G&A”) expenses		534,503	55.8%				619,924	56.9%
Total operating expenses	$	957,905	100.0%	$	51.40	$	1,089,712	100.0%	$	54.80

Production expenses include expenses associated with the production of oil and natural gas. These expenses include pumper salaries, electricity, road maintenance, control of well insurance, property taxes and well workover expenses; and, relate directly to the number of wells that are in production. For the six months ended August 31, 2015, these expenses decreased by $19,879 or 12.0% to $145,606 in comparison to $165,485 for the six months ended August 31, 2014. For the six months ended August 31, 2015 we had 20 wells on production in California and 13 wells on production in Kentucky in comparison to 20 wells in California and nine wells in Kentucky for the six months ended August 31, 2014. Production expenses represented 15.2% of total operating expenses.

Production expenses in Kentucky and California for the six months ended August 31, 2015 and August 31, 2014 are set forth in the table below:


	Six Months Ended August 31, 2015			Six Months Ended August 31, 2014
	Expenses		Percentage	Expenses		Percentage
Kentucky – Twin Bottoms Field	$	58,555	40.2%	$	73,611	44.5%
California – East Slopes Project		87,051	59.8%		91,874	55.5%
Total production expenses	$	145,606	100.0%	$	165,485	100.0%

Production expenses on a BOE basis in Kentucky and California for the six months ended August 31, 2015 and August 31, 2014 are set forth in the table below:


	Six Months Ended
	August 31, 2015		August 31, 2014
Kentucky – Twin Bottoms Field (BOE)	$	5.09	$	6.48
California – East Slopes Project (BOE)	$	12.19	$	10.77
Total production expenses (BOE)	$	7.81	$	8.32

Exploration and drilling expenses include geological and geophysical (“G&G”) expenses as well as leasehold maintenance and dry hole expenses. These expenses increased $7,257 or 56.6% to $20,067 for the six months ended August 31, 2015 in comparison to $12,810 the six months ended August 31, 2014 primarily due to additional G&G work in Kentucky. Exploration and drilling expenses represented 2.1% of total operating expenses.

DD&A expenses relate to equipment, proven reserves and property costs, along with impairment and is another component of operating expenses. For the six months ended August 31, 2015, DD&A expenses decreased $33,764 or 11.6% to $257,729 in comparison to $291,493 for the six months ended August 31, 2014. The decrease in DD&A is directly related to the level of our hydrocarbon production in both Kentucky and California. On a BOE basis, DD&A and impairment represented $13.83 and $14.66 per barrel for the six months ended August 31, 2015 and 2014, respectively. DD&A expenses represented 26.9% of total operating expenses.

G&A expenses include the salaries of six full-time employees, including management. Other items included in our G&A expenses are legal and accounting expenses, director fees, stock compensation, investor relations fees, travel expenses, insurance, Sarbanes-Oxley (“SOX”) compliance expenses and other administrative expenses necessary for an operator of oil and gas properties as well as for running a public company. For the six months ended August 31, 2015, G&A expenses decreased $85,421 or 13.8% to $534,503 in comparison to $619,924 for the six months ended August 31, 2014. Legal, accounting and reserve reporting expenses decreased by $49,400 for the six months ended August 31, 2015. Travel expenses decreased $10,400 due to reduced drilling activity during the six months ended August 31, 2015 in comparison to the six months ended August 31, 2014. We received, as Operator in California, administrative overhead reimbursement of $26,644 during the six months ended August 31, 2015 for the East Slopes Project which was used to directly offset certain employee salaries. We are continuing a program of reducing all of our G&A costs wherever possible. G&A expenses represented 55.8% of total operating expenses.

Interest income for the six months ended August 31, 2015 decreased $30,242 or 6.6% to $424,604 in comparison to $454,846 for the six months ended August 31, 2014 due to reduced interest rates on the Note receivable from App Energy. For further discussion on the App Energy Note refer to the discussion of the App Loan Agreement under Capital Resources and Liquidity – Cash Flow Provided by (Used in) Financing Activities, Non-current Debt (Long-term Borrowings) in this MD&A.

Interest expense for the six months ended August 31, 2015 decreased $32,533 or 2.4% to $1,330,471 in comparison to $1,363,004 for the six months ended August 31, 2014. The decrease in interest expense is directly related to the modified loan payment terms on our credit facility with Maximilian. The credit facility activity is discussed further in the discussion of the Maximilian Credit Facility – Amended and Restated Loan Agreement in the MD&A section of this 10-Q report under Capital Resources and Liquidity – Cash Flow Provided by (Used in) Financing Activities, Non-current Debt (Long-term Borrowings) in this MD&A.

Results of Operations – Three Months Ended August 31, 2015 compared to the Three Months Ended August 31, 2014

Kentucky Oil Prices

For the three months ended August 31, 2015, our average realized oil sale price was $50.78 in comparison to the average WTI price of $51.28 representing a discount of $0.50 per barrel or 1.0% from the average WTI price. In comparison, for the three months ended August 31, 2014 the average WTI price was $101.97 and our average realized sale price was $99.86, representing a discount of $2.11 per barrel or 2.1% lower than the average WTI prices.

Kentucky Natural Gas Prices

For the three months ended August 31, 2015, our average realized natural gas sale price was $1.63 per Mcf in comparison to the average Henry Hub price of $2.80 per million BTU representing a discount of $1.17 per Mcf or 41.7% lower than the average Henry Hub price. In comparison, for the three months ended August 31, 2014, the average realized sale price was $2.80 per Mcf while the average Henry Hub price was $4.18 per million BTU representing a discount of $1.38 or 33.0% lower than the average Henry Hub price.

California Oil Prices

For the three months ended August 31, 2015, the average WTI price was $51.28 and our average realized oil sale price was $44.55 representing a discount of $6.73 per barrel or 13.1% lower than the average WTI price. In comparison, for the three months ended August 31, 2014, the average WTI price was $101.97 and our average realized sale price was $94.45, representing a discount of $7.52 per barrel or 7.4% lower than the average WTI price.

Combined Revenue and Production

Oil and natural gas revenues for the three months ended August 31, 2015 in aggregate decreased $674,462 or 64.6%, to $369,834 in comparison to revenues of $1,044,296 for the three months ended August 31, 2014. Oil and natural gas sales volume decreased 2,563 BOE (barrels of oil equivalent) or 22.8% to 8,680 (BOE) in comparison to 11,242 (BOE) for the three months ended August 31, 2014. Our average realized sale price on a BOE basis for the three months ended August 31, 2015 was $42.61 in comparison to $92.89 for the three months ended August 31, 2014, representing a decline of $50.28 or 54.1% per barrel.

Kentucky Oil Revenue and Production

Oil revenue in Kentucky for the three months ended August 31, 2015 decreased $452,798 or 69.8% to $196,054 in comparison to revenue of $648,853 for the three months ended August 31, 2014. The average realized sale price of a barrel of oil for the three months ended August 31, 2015 was $50.78 in comparison to $99.86 for the three months ended August 31, 2014. The decrease of $49.08 or 49.2% in the average sale price of a barrel of oil accounted for 70.4% of the decline in Kentucky oil revenue for the three months ended August 31, 2015.

Our net sales volume for the three months ended August 31, 2015 was 3,861 barrels of oil in comparison to 6,498 barrels sold for the three months ended August 31, 2014. This decrease in oil sales volume of 2,637 barrels or 40.6% accounted for 29.6% of the decline in Kentucky oil revenue for the three months ended August 31, 2015.

Production for the three months ended August 31, 2015 was from 13 wells resulting in 1,052 well days of production in comparison to 603 well days for the three months ended August 31, 2014. We had production from nine producing horizontal oil wells for the three months ended August 31, 2014.

Kentucky Natural Gas Revenue and Production

Natural gas revenue for the three months ended August 31, 2015 increased $130 to $11,525 in comparison to revenue of $11,395 for the three months ended August 31, 2014. The average realized sale price per Mcf for the three months ended August 31, 2015 was $1.63 in comparison to $2.80 for the three months ended August 31, 2014. Our net sales volume for the three months ended August 31, 2015 was 7,059 Mcf or 1,177 BOE in comparison to 4,071 Mcf or 679 BOE for the three months ended August 31, 2014. The increase in natural gas volume of 2,988 or 498 BOE representing a 73.4% increase was due to infrastructure improvements that had previously inhibited natural gas production from existing wells.

California Revenue and Production

Oil revenue in California for the three months ended August 31, 2015 decreased $221,793 or 57.8% to $162,255 in comparison to revenue of $384,048 for the three months ended August 31, 2014. The average realized sale price of a barrel of oil for the three months ended August 31, 2015 was $44.55 in comparison to $94.45 for the three months ended August 31, 2014. The decrease of $49.90 or 52.8% in the average realized sale price of a barrel of oil accounted for 91.5% of the decrease in California oil revenue for the three months ended August 31, 2015.

Our net sales volume for the three months ended August 31, 2015 was 3,642 barrels of oil in comparison to 4,066 barrels sold for the three months ended August 31, 2014. This decrease in oil sales volume of 424 barrels or 10.4% accounted for 8.5% of the decrease in revenue for the three months ended August 31, 2015. Production for the three months ended August 31, 2015 was from 20 wells resulting in 1,837 well days of production in comparison to 1,831 of production from 20 wells for the three months ended August 31, 2014.

Oil and natural gas revenues for the three months ended August 31, 2015 and August 31, 2014 are set forth in the table below:


	Three Months Ended August 31, 2015			Three Months Ended August 31, 2014
	Revenue		Percentage	Revenue		Percentage
Kentucky – Twin Bottoms Field (oil)	$	196,054	53.0%	$	648,853	62.1%
Kentucky – Twin Bottoms Field (natural gas)		11,525	3.1%		11,395	1.1%
California – East Slopes Project (oil)		162,255	43.9%		384,048	36.8%
Total production expenses	$	369,834	100.0%	$	1,044,296	100.0%

Operating Expenses. Total operating expenses for the three months ended August 31, 2015 decreased by $76,458 or 14.6% to $446,145 in comparison to $522,603 for the three months ended August 31, 2014.

Operating expenses for the three months ended August 31, 2015 and August 31, 2014 are set forth in the table below:


	Three Months Ended August 31, 2015					Three Months Ended August 31, 2014
	Expenses		Percentage	BOE Basis		Expenses		Percentage	BOE Basis
Production expenses	$	70,001	15.7%			$	79,955	15.3%
Exploration and drilling expenses		8,400	1.9%				6,027	1.2%
Depreciation, Depletion, Amortization, and Impairment (“DD&A”)		118,889	26.6%				171,516	32.8%
General and Administrative (“G&A”) expenses		248,855	55.8%				265,105	50.7%
Total operating expenses	$	446,145	100.0%	$	51.40	$	522,603	100.0%	$	46.48

For the three months ended August 31, 2015, production expenses decreased by $9,954 or 12.5% to $70,001 in comparison to $79,955 for the three months ended August 31, 2014. This decrease in production expenses is due to lower production expenses in Kentucky for the three months ended August 31, 2015. For the three months ended August 31, 2014 we had 20 wells on production in California and 13 wells on production in Kentucky in comparison to 20 wells in California and nine wells in Kentucky for the three months ended August 31, 2014. Production expenses represented 15.7% of total operating expenses for the three months ended August 31, 2015.

Production expenses in Kentucky and California for the three months ended August 31, 2015 and August 31, 2014 are set forth in the table below:


	Three Months Ended August 31, 2015			Three Months Ended August 31, 2014
	Expenses		Percentage	Expenses		Percentage
Kentucky – Twin Bottoms Field	$	28,847	41.2%	$	45,625	57.1%
California – East Slopes Project		41,154	58.8%		34,330	42.9%
Total production expenses	$	70,001	100.0%	$	79,955	100.0%

Production expenses on a BOE basis in Kentucky and California for the three months ended August 31, 2015 and August 31, 2014 are set forth in the table below:


	Three Months Ended
	August 31, 2015		August 31, 2014
Kentucky – Twin Bottoms Field (BOE)	$	5.73	$	6.12
California – East Slopes Project (BOE)	$	11.30	$	8.86
Total production expenses (BOE)	$	8.06	$	7.11

For the three months ended August 31, 2015, exploration and drilling expenses increased $2,373 or 39.4% to $8,400 in comparison to $6,027 for the three months ended August 31, 2014. Exploration and drilling expenses represented 1.9% of total operating expenses for the three months ended August 31, 2015.

For the three months ended August 31, 2015, DD&A expenses decreased $52,627 or 30.7% to $118,889 in comparison to $171,516 for the three months ended August 31, 2014. The decrease in DD&A is directly related to lower hydrocarbon production volumes in both Kentucky and California. On a BOE basis, DD&A and impairment represented $19.76 and $15.26 per barrel for the three months ended August 31, 2015 and 2014, respectively. DD&A expenses represented 26.6% of total operating expenses for the three months ended August 31, 2015.

For the three months ended August 31, 2015, G&A expenses decreased $16,250 or 6.1% to $248,855 in comparison to $265,105 for the three months ended August 31, 2014. Legal, accounting and reserve reporting expenses decreased by $15,300 for the three months ended August 31, 2015. We received, as Operator in California, administrative overhead reimbursement of $13,322 during the three months ended August 31, 2015 for the East Slopes Project which was used to directly offset certain employee salaries. We are continuing a program of reducing all of our G&A costs wherever possible. G&A expenses represented 55.8% of total operating expenses for the three months ended August 31, 2015.

Interest income for the three months ended August 31, 2015 decreased $88,157 or 30.4% to $201,851 in comparison to $290,008 for the three months ended August 31, 2014 due to reduced interest rates on the Note receivable from App Energy.

Interest expense for the three months ended August 31, 2015 decreased $35,583 or 5.1% to $661,604 in comparison to $697,187 for the three months ended August 31, 2014. The decrease in interest expense is directly related to the modified loan payment terms on our credit facility with Maximilian. The credit facility activity is discussed further in the discussion of the Maximilian Credit Facility – Amended and Restated Loan Agreement in the MD&A section of this 10-Q report under Capital Resources and Liquidity – Cash Flow Provided by (Used in) Financing Activities, Non-current Debt (Long-term Borrowings).

Due to the nature of our business, we expect that revenues, as well as all categories of expenses, will continue to fluctuate substantially on a quarter-to-quarter and year-to-year basis. Revenues are dependent upon both hydrocarbon production levels and the price we receive for hydrocarbon sales. Since June of 2014, there has been a significant decline in the WTI price of crude oil and subsequently in the realized price we receive from oil sales. This decline in the price of crude oil has had a substantial negative impact on our cash flow from both our Kentucky and California properties. Production expenses will fluctuate according to the number and percentage ownership of producing wells that we own. Exploration and drilling expenses will be dependent upon the amount of capital that we have to invest in future development projects, as well as the success or failure of such projects. Likewise, the amount of DD&A expense will depend upon the factors cited above including the size of our proven reserves base and the market price of energy products. G&A expenses will also fluctuate based on our current requirements, but will generally tend to increase as we expand the business operations of the Company. An ongoing goal of the Company is to improve cash flow to cover the current level of G&A expenses and to fund our development drilling programs in California and Kentucky.

Capital Resources and Liquidity

Our primary financial resource is our proven oil reserves base. Our ability to fund any future capital expenditure programs is dependent upon the prices we receive from oil sales, the success of our exploration and development program in Lawrence County, Kentucky and Kern County, California and the availability of capital resource financing.

The Company has engaged an investment banking firm to assist in securing refinancing of its debt at more favorable terms and implement our development plans in California and Kentucky.

Changes in our capital resources at August 31, 2015 in comparison to February 28, 2015 are set forth in the table below:


					Increase		Percentage
	August 31, 2015		February 28, 2015		(Decrease)		Change
Cash	$	122,492	$	496,772	$	(374,280)	(75.3%)
Current Assets	$	1,034,852	$	2,554,519	$	(1,519,667)	(59.5%)
Total Assets	$	10,841,268	$	12,313,061	$	(1,471,793)	(12.0%)
Current Liabilities	$	6,440,493	$	8,311,541	$	(1,871,048)	(22.5%)
Total Liabilities	$	17,078,512	$	17,497,651	$	(419,139)	(2.4%)
Working Capital Deficit	$	(5,405,641)	$	(5,757,022)	$	(351,381)	(6.1%)

Our working capital deficit decreased $351,381 or 6.1% to $5,405,641 at August 31, 2015 in comparison to $5,757,022 at February 28, 2015. This decrease in the working capital deficit was due to reclassification of part of the current portion of the Maximilian credit facility debt to non-current debt due to a loan modification with Maximilian during the six months ended August 31, 2015. While we have ongoing positive cash flow from our operations in California and Kentucky we have not yet been able to generate sufficient cash flow to cover all of our G&A and interest expense requirements on a consistent basis.

Our business is capital intensive. Our ability to grow is dependent upon favorably obtaining outside capital and generating cash flows from operating activities necessary to fund our investment activities. There is no assurance that we will be able to achieve profitability. Since our future operations will continue to be dependent on successful exploration and development activities and our ability to seek and secure capital from external sources, should we be unable to achieve sustainable profitability this could cause any equity investment in the Company to become worthless.

Major sources of funds in the past for us have included the debt or equity markets. While we have achieved positive cash flow from operations in Kentucky and California, we will have to rely on these capital markets to fund future operations and growth. Our business model is focused on acquiring exploration or development properties as well as existing production. Our ability to generate future revenues and operating cash flow will depend on successful exploration, and/or acquisition of oil and gas producing properties, and stabilized hydrocarbon prices, which may very likely require us to continue to raise equity or debt capital from outside sources.

Daybreak has ongoing capital commitments to develop certain leases pursuant to their underlying terms. Failure to meet such ongoing commitments may result in the loss of the right to participate in future drilling on certain leases or the loss of the lease itself. These ongoing capital commitments may also cause us to seek additional capital from sources outside of the Company. The current uncertainty in the credit and capital markets, and the decline of hydrocarbon prices, may restrict our ability to obtain needed capital.

The Company’s financial statements for the six months ended August 31, 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. Since entering the oil and gas exploration industry, we have mostly incurred quarterly net losses. As of August 31, 2015, we have an accumulated deficit of $29,258,170 and a working capital deficit of $5,405,641 which raises substantial doubt about our ability to continue as a going concern.

Cash Flows

Changes in the net funds provided by and (used in) our operating, investing and financing activities are set forth in the table below:


	Six Months		Six Months		Increase		Percentage
	August 31, 2015		August 31, 2014		(Decrease)		Change
Net cash provided by (used in) operating activities	$	(263,103)	$	97,529	$	(360,632)	(369.8%)
Net cash provided by (used in) investing activities	$	491,786	$	(4,029,956)	$	4,521,742	112.2%
Net cash provided by (used in) financing activities	$	(602,963)	$	3,666,293	$	(4,269,256)	(116.4%)

Cash Flow Provided by (Used In) Operating Activities

Cash flow from operating activities is derived from the production of our oil and natural gas reserves and changes in the balances of non-cash accounts, receivables, payables or other non-energy property asset account balances. For the six months ended August 31, 2015, we had cash flow used in operating activities of $263,103 in comparison to cash flow provided by operating activities of $97,529 for the six months ended August 31, 2014. This decline in operating cash flow of $360,632 or 369.8% is directly related to lower realized hydrocarbon revenues due to a sharp decline of over 60% in crude oil prices since June of 2014. Non-cash account balances relating to DD&A; amortization of debt discount and deferred financing costs; and stock compensation accounted for a decrease of $49,997 for the six months ended August 31, 2015. Changes in our receivables, prepaids and payables balances accounted for a net increase of approximately $600,000 in our cash flow, but were offset by the increase in the net loss of approximately $1.1 million for the six months ended August 31, 2015. Variations in cash flow from operating activities may impact our level of exploration and development expenditures.

Cash Flow Provided by (Used in) Investing Activities

Cash flow from investing activities is derived from changes in oil and gas property balances and our lending activities associated with the App Energy loan. Cash flow provided by investing activities for the six months ended August 31, 2015 was $491,786, a change of $4,521,742 from the $4,029,956 used in investing activities for the six months ended August 31, 2014. This change of $4,521,742 was due to reduced drilling activity in Kentucky for the six months ended August 31, 2015 resulting in reduced borrowing through our credit facility with Maximilian. The credit facility and our lending activity to App Energy is discussed further in the MD&A section of this 10-Q report under the caption “Long-Term Borrowings – Maximilian Credit Facility.”

Cash Flow Provided by (Used In) Financing Activities

Cash flow from financing activities is derived from changes in long-term liability account balances or in equity account balances, excluding retained earnings. Cash flow used in our financing activities was $602,963 for the six months ended August 31, 2015 in comparison to cash flow provided by our financing activities of approximately $3.7 million for the six months ended August 31, 2014. This change of $4,269,256 was due to a reduced amount of drilling activity in Kentucky for the six months ended August 31, 2015 resulting in less borrowing through our credit facility with Maximilian. The credit facility and our lending activity to App Energy is discussed further in the MD&A section of this 10-Q report discussed further in the discussion of the Maximilian Credit Facility – Amended and Restated Loan Agreement in the MD&A section of this 10-Q report under Capital Resources and Liquidity – Cash Flow Provided by (Used in) Financing Activities, Non-current Debt (Long-term Borrowings) in this MD&A.

The following discussion is a summary of cash flows provided by, and used in, the Company’s financing activities at August 31, 2015.

Current Debt (Short-Term Borrowings)

Related Party

During the years ended February 29, 2012 and February 28, 2013, the Company’s President and Chief Executive Officer loaned the Company $250,100 in aggregate that was 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 our President and Chief Executive Officer. At August 31, 2015, the Line of Credit had an outstanding balance of $855,333. Interest is payable monthly at a stated reference rate of 0.249% + 337.5 basis points and totaled $15,468 for the six months ended August 31, 2015. The reference rate is based on the 30 day LIBOR (“London Interbank Offered Rate”) and is subject to change from UBS.

Non-current Debt (Long-Term Borrowings)

12% Subordinated Notes

The Company’s 12% Subordinated Notes (“the Notes”) were issued pursuant to a March 2010 private placement (of which $250,000 was issued to a related party) and accrue interest at 12% per annum, payable semi-annually on January 29th and July 29th. On January 29, 2015, the company and 12 of the 13 holders of the Notes agreed to extend the maturity date of the Notes for an additional two years to January 29, 2017. The note principal of $565,000 is payable in full at the amended maturity of the Notes. Should the Board of Directors, on the 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.

12% Notes balances at August 31, 2015 and February 28, 2015 are set forth in the table below:


	August 31, 2015		February 28, 2015
12% Subordinated Notes	$	315,000	$	315,000
12% Subordinated Notes, related party		250,000		250,000
	$	565,000	$	565,000

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 an amended expiration date of January 29, 2017. The 12% Note warrants that have been exercised are set forth in the table below.


Fiscal Period	Warrants Exercised	Shares of Common Stock Issued	Number of Accredited Investors
Year Ended February 28, 2014	100,000	100,000	1
Year Ended February 28, 2015	50,000	50,000	1
Six Months Ended August 31, 2015	-	-	-
Totals	150,000	150,000	2

Maximilian Credit Facility

On October 31, 2012, the Company entered into a loan agreement with Maximilian, 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. 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 $68,196 for the six months ended August 31, 2015. Unamortized debt discount amounted to $135,869 at August 31, 2015.

Maximilian Credit Facility - 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; and contain an exercise blocker provision that prevents 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 Company’s currently issued and outstanding shares at the time of the exercise. 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.

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 decrease the required monthly payment made by the Company until it has paid $1,000,000 less than the principal payments required by the previous agreement. 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 our 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.

On May 20, 2015, the Company entered into a Second Amendment to Amended and Restated Loan and Security Agreement (the “2^nd Amendment”) with Maximilian under its Amended and Restated Loan and Security Agreement dated as of August 28, 2013. The 2^nd Amendment modified the calculation of the required monthly payment for a three-month period ending June 30, 2015. As consideration for entering into the loan modification, the Company agreed to lower the exercise price of the warrants Maximilian currently holds from $0.10 to $0.04. No other terms of the warrant agreement were changed.

Current debt balances at August 31, 2015 and February 28, 2015 are set forth in the table below:


	August 31, 2015		February 28, 2015
Maximilian note	$	2,840,442	$	4,823,325
Maximilian note discount		(119,830)		(132,114)
	$	2,720,612	$	4,691,211

Non-current debt balances at August 31, 2015 and February 28, 2015 are set forth in the table below:


	August 31, 2015		February 28, 2015
Maximilian note	$	10,057,910	$	8,663,458
Maximilian note discount		(16,039)		(71,951)
	$	10,041,871	$	8,591,507

App Loan Agreement

In connection with amending and restating its loan agreement with Maximilian, on August 28, 2013 the Company extended to App Energy, LLC, a Kentucky limited liability company (“App Energy”) a credit facility for the development of a shallow oil project in an existing gas field in Lawrence County, Kentucky pursuant to a Loan and Security Agreement between the Company as lender and App Energy as borrower (the “App Loan Agreement”).

The App Loan Agreement 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 Energy, as borrower, by Daybreak, as lender, are to be borrowed by Daybreak under its Amended Loan Agreement with Maximilian. The Initial Advance bears interest at a rate per annum equal to 16.8%, and subsequent loans under the Loan Agreement bear interest at a rate per annum equal to 12%. The App Loan Agreement also provides for a monthly commitment fee of 0.6% per month of 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 Energy, including the App Energy leases in Lawrence County, Kentucky.

The proceeds of the initial borrowing by App Energy of $2.65 million under the App Energy facility were primarily used to (a) pay loan fees and closing costs, (b) repay indebtedness and (c) finance the drilling of three wells by App Energy in the Twin Bottoms Field in Lawrence County, Kentucky in which the Company has a 25% working interest. Future advances under the facility will primarily be used for oil and gas exploration and development activities.

The App Loan Agreement contains customary covenants for loan of such type, including, among other things, covenants that restrict App Energy’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 Energy’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.

In connection with the App Loan Agreement, App Energy also granted to the Company a 25% working interest in approximately 6,400 acres (currently 7,300 acres) in two large contiguous blocks in the Twin Bottoms Field in Lawrence County, Kentucky and entered into a corresponding promissory note and a Mortgage, Leasehold Mortgage, Assignment of Production, Security Agreement and Financing Statement, both dated as of August 28, 2013. App Energy’s manager, John A. Piedmonte, Jr., also entered into a limited Indemnity Agreement in connection with the loan. The loans under the App Loan Agreement are also guaranteed by certain of App Energy’s affiliates.

At August 31, 2015, the Company had advanced $8.3 million to App Energy through its credit facility. Note receivable balances at August 31, 2015 and February 28, 2015 are set forth in the table below:


	August 31, 2015		February 28, 2015
Note receivable – current	$	281,457	$	1,320,944
Note receivable – non-current		3,841,043		3,429,056
	$	4,122,500	$	4,750,000

Capital Commitments

Daybreak has ongoing capital commitments to develop certain leases pursuant to their underlying terms. Failure to meet such ongoing commitments may result in the loss of the right to participate in future drilling on certain leases or the loss of the lease itself. These ongoing capital commitments may also cause us to seek additional capital from sources outside of the Company. The current uncertainty in the credit and capital markets, and the economic downturn, may restrict our ability to obtain needed capital.

Encumbrances

The Company’s debt obligations, pursuant to the loan agreement with Maximilian, are secured by a perfected first priority security interest in substantially all of the personal property of the Company, and a mortgage on our leases in Kern County, California encompassing the Sunday, Bear, Black, Ball and Dyer Creek properties. For further information on the loan agreement refer to the discussion of the Maximilian Credit Facility – Amended and Restated Loan Agreement in the MD&A section of this 10-Q report under Capital Resources and Liquidity – Cash Flow Provided by (Used in) Financing Activities, Non-current Debt (Long-term Borrowings) in this MD&A.

Restricted Stock and Restricted Stock Unit Plan

On April 6, 2009, the Board approved the Restricted Stock and Restricted Stock Unit Plan (the “2009 Plan”) allowing the executive officers, directors, consultants and employees of Daybreak and its affiliates to be eligible to receive restricted common stock and restricted common stock unit awards. Subject to adjustment, the total number of shares of Daybreak 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. We believe that awards of this type further align the interests of our employees and our shareholders by providing significant incentives for these employees to achieve and maintain high levels of performance. Restricted stock and restricted stock units also enhance our ability to attract and retain the services of qualified individuals.

At August 31, 2015, a total of 3,000,000 shares of restricted stock had been awarded and remained outstanding under the 2009 Plan, with 2,986,220 shares having fully vested. A total of 1,013,780 common stock shares remained available at August 31, 2015 for issuance pursuant to the 2009 Plan. A summary of the 2009 Plan issuances is set forth in the table below:


Grant Date	Shares Awarded	Vesting Period	Shares Vested⁽¹⁾	Shares Returned⁽²⁾	Shares Outstanding (Unvested)
4/7/2009	1,900,000	3 Years	1,900,000	-	-
7/16/2009	25,000	3 Years	25,000	-	-
7/16/2009	625,000	4 Years	619,130	5,870	-
7/22/2010	25,000	3 Years	25,000	-	-
7/22/2010	425,000	4 Years	417,090	7,910	-
	3,000,000		2,986,220⁽¹⁾	13,780⁽²⁾	-

⁽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.

For the six months ended August 31, 2015, the Company did not recognize any stock compensation expense related to the above restricted stock grants since all issuances have been fully amortized.

Management Plans to Continue as a Going Concern

We continue to implement plans to enhance Daybreak’s ability to continue as a going concern. The Company 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% with an average net revenue interest of 28.4% for these same wells. Additionally, Daybreak currently has a net revenue interest in 13 producing horizontal oil wells in the Twin Bottoms Field in Lawrence County, Kentucky. Our average working interest in these thirteen wells is 22.4% with an average net revenue interest of 19.6%.

We anticipate revenues will continue to increase as the Company participates in the drilling of more wells in Kentucky and California. Daybreak plans to continue its development drilling program 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, while the Company has experienced revenue growth from its oil 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 the Company will be successful in executing the aforementioned plans to continue as a going concern.

Critical Accounting Policies

Refer to Daybreak’s Annual Report on Form 10-K for the fiscal year ended February 28, 2015.

Off-Balance Sheet Arrangements

As of August 31, 2015, we did not have any off-balance sheet arrangements or relationships with unconsolidated entities or financial partners that have been, or are reasonably likely to have, a material effect on our financial position or results of operations.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

As a smaller reporting company, we are not required to provide the information otherwise required by this Item.

ITEM 4. CONTROLS AND PROCEDURES

Management’s Evaluation of Disclosure Controls and Procedures

As of the end of the reporting period, August 31, 2015, an evaluation was conducted by Daybreak management, including our President and Chief Executive Officer, who is also serving as our interim principal finance and accounting officer, as to the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Rule 13a-15(e) of the Exchange Act. Such disclosure controls and procedures are designed to ensure that information required to be disclosed by a company in the reports that it files under the Exchange Act is recorded, processed, summarized and reported within required time periods specified by the SEC rules and forms. Additionally, it is vital that such information is accumulated and communicated to our management, including our President and Chief Executive Officer, in a manner to allow timely decisions regarding required disclosures. Based on that evaluation, our management concluded that our disclosure controls were effective as of August 31, 2015.

Changes in Internal Control over Financial Reporting

There have not been any changes in the Company’s internal control over financial reporting during the six months ended August 31, 2015 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

Limitations

Our management does not expect that our disclosure controls or internal controls over financial reporting will prevent all errors or all instances of fraud. A control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that the control system’s objectives will be met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs.

Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within our company have been detected. These inherent limitations include the realities that judgments in decision-making can be faulty, and that breakdowns can occur because of simple error or mistake. Controls can also be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the controls. The design of any system of controls is based in part upon certain assumptions about the likelihood of future events, and any design may not succeed in achieving its stated goals under all potential future conditions.

Over time, controls may become inadequate because of changes in conditions or deterioration in the degree of compliance with policies or procedures. Because of the inherent limitation of a cost-effective control system, misstatements due to error or fraud may occur and not be detected.

PART II

OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

None

ITEM 1A. RISK FACTORS

In addition to the other information set forth in this Form 10-Q Report, you should carefully consider the various factors discussed in Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended February 28, 2015, which could materially affect our business, financial condition or future results. Our Annual Report is available from the SEC at www.sec.gov. The risks described in this report are not the only risks we face. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial could have a material adverse effect on our business, financial condition or future results of operations.

ITEM 5. OTHER INFORMATION

ITEM 6. EXHIBITS

The following Exhibits are filed as part of the report:

Exhibit

Number

Description

31.1⁽¹⁾

Certification of principal executive and principal financial officer as required pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1⁽¹⁾

Certification of principal executive and principal financial officer as required pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101.INS⁽²⁾

XBRL Instance Document

101.SCH⁽²⁾

XBRL Taxonomy Schema

101.CAL⁽²⁾

XBRL Taxonomy Calculation Linkbase

101.DEF⁽²⁾

XBRL Taxonomy Definition Linkbase

101.LAB⁽²⁾

XBRL Taxonomy Label Linkbase

101.PRE⁽²⁾

XBRL Taxonomy Presentation Linkbase

⁽¹⁾

Filed herewith.

⁽²⁾

Furnished herewith

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.


DAYBREAK OIL AND GAS, INC.

By:	/s/ JAMES F. WESTMORELAND
	James F. Westmoreland, its
	President, Chief Executive Officer and interim
	principal finance and accounting officer
	(Principal Executive Officer, Principal Financial
	Officer and Principal Accounting Officer)

Date: October 14, 2015

EX-31 2 exhibit311.htm EXHIBIT 31.1 Exhibit 31.1

Exhibit 31.1

Certification

I, James F. Westmoreland, certify that:

(1)

I have reviewed this interim report on Form 10-Q of Daybreak Oil and Gas, Inc.

(2)

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

(3)

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

(4)

The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15(d)-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under my supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to me by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

(5)

The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: October 14, 2015

By /s/ JAMES F. WESTMORELAND

James F. Westmoreland, President, Chief Executive Officer

and interim principal finance and accounting officer

(Principal Executive Officer, Principal Financial Officer and Principal Accounting Officer)

EX-32 3 exhibit321.htm EXHIBIT 32.1 Exhibit 32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Interim Report of Daybreak Oil and Gas, Inc. on Form 10-Q for the period ending August 31, 2015, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, the undersigned, in the capacity and on the date indicated below, hereby certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: October 14, 2015

By /s/ JAMES F. WESTMORELAND

James F. Westmoreland, President, Chief Executive Officer

and interim principal finance and accounting officer

(Principal Executive Officer, Principal Financial Officer and Principal Accounting Officer)

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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.

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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.

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.

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The 2nd Amendment modified the calculation of the required monthly payment for a three-month period ending June 30, 2015. As consideration for entering into the loan modification, the Company agreed to modify the exercise price of the warrants Maximilian currently holds from $0.10 to $0.04.

The Company entered into a Third Amendment to the Amended and Restated Loan and Security Agreement and Second Warrant Amendment with Maximilian, which amended the Company’s loan agreement with Maximilian (the “Maximilian Amendment”). Pursuant to the Maximilian Amendment, Maximilian agreed to a reduction in the Company’s monthly payments under the loan agreement to $50,000 per month for a period of six months ending on February 29, 2016. The reduction in monthly payments allows for additional funds to be used by the Company in drilling and completing additional wells in Kentucky. As consideration for the reduction in the monthly payment amount, the Company agreed that twenty percent of the amount by which the monthly payment was reduced would be added to the loan balance, and the portion of the monthly payment savings that constitutes savings in interest or commitment fees would be treated as an additional advance of principal under the loan agreement (the “Deemed Advances”). The Company also agreed to grant to Maximilian an overriding royalty interest in four wells it drills of 1.5% of its working interest in such wells, subject to reduction connected to the Company’s ongoing efforts to refinance its loan agreement. As part of the Maximilian Amendment, the Company also agreed to extend the expiration date of the warrants held by Maximilian to purchase up to 6,550,281 shares of common stock of the Company to August 28, 2018.

The App Amendment provides for a reduction in interest rate and a reduction in monthly payments to be made by App Energy to the Company for the same payment cycles as the reduced payment to be made by the Company under the Maximilian Amendment. The reduction in monthly payments by App Energy will allow App Energy to fund its share of drilling and completing additional wells in Kentucky with the Company. As consideration for the reduction in the monthly payment amount, App Energy agreed that a percentage of the Deemed Advances will be treated as additional advances under the App Energy loan agreement, and that it would fund a portion of the Company’s drilling and development expenses with respect to two wells, subject to a partial refund connected to the Company’s ongoing efforts to refinance its loan agreement. App Energy also agreed to grant to Maximilian an overriding royalty interest on the same terms as the overriding royalty interest agreed to by the Company. Finally, App Energy granted to the Company a time-limited option to purchase additional working interest in its Kentucky operations connected to the Company’s ongoing efforts to refinance its loan agreement.

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NOTE 1 ORGANIZATION AND BASIS OF PRESENTATION:   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 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 Companys oil and gas production is sold under contracts which are market-sensitive. Accordingly, the Companys 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 natural 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.   Basis of Presentation   The accompanying unaudited interim financial statements and notes for the Company have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial information and with the instructions to Form 10-Q for quarterly reports under Section 13 or 15(d) of the Securities Exchange Act of 1934 (the Exchange Act). Accordingly, they do not include all of the information and footnote disclosures normally required by accounting principles generally accepted in the United States of America for complete financial statements.   In the opinion of management, all adjustments considered necessary for a fair presentation of the financial statements have been included and such adjustments are of a normal recurring nature. Operating results for the six months ended August 31, 2015 are not necessarily indicative of the results that may be expected for the fiscal year ending February 29, 2016.   These financial statements should be read in conjunction with the audited financial statements and notes thereto included in the Companys Annual Report on Form 10-K for the fiscal year ended February 28, 2015.   Use of Estimates   In preparing financial statements in conformity with accounting principles generally accepted in the United States of America, management is required to make estimates and assumptions. These estimates and assumptions may affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, and revenues and expenses during the reporting period. Actual results could differ materially from those estimates. The accounting policies most affected by managements 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 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 abandonment obligations.   Reclassifications   Certain reclassifications have been made to conform the prior periods financial information to the current periods presentation. These reclassifications had no effect on previously reported net loss or accumulated deficit.

NOTE 2 GOING CONCERN:   Financial Condition   The Companys financial statements for the six months ended August 31, 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. The Company has incurred net losses since entering the oil and natural gas exploration industry and as of August 31, 2015 has an accumulated deficit of $29,258,170 and a working capital deficit of $5,405,641 which raises substantial doubt about the Companys 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 oil wells in its East Slopes Project located in Kern County, California (the East Slopes Project). The revenue from these wells has created a steady and reliable source of revenue. The Companys average working interest in these wells is 36.6% and the average net revenue interest (NRI) is 28.4% for these same wells.   Additionally, the Company has become involved in a shallow oil development project in an existing natural gas field in Lawrence County, Kentucky, through its acquisition of an average 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 13 producing horizontal oil wells in the Twin Bottoms Field with some supplementary natural gas production. The Companys average working interest in these 13 horizontal oil wells is 22.4% and the average NRI 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 Kentucky and California at a rate that is compatible with its cash flow; funding opportunities and hydrocarbon prices.   The Companys sources of funds in the past have included the debt or equity markets and, while the Company has experienced revenue growth that has resulted in positive cash flow from its oil and natural gas properties, it has not yet established consistent positive cash flow on a company-wide basis primarily due to lower oil prices. It will be necessary for the Company to obtain additional financing 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 plan to continue as a going concern.   Daybreaks financial statements as of August 31, 2015 do not include any adjustments that might result from the inability to implement or execute Daybreaks plans to improve our ability to continue as a going concern.

NOTE 3 RECENT ACCOUNTING PRONOUNCEMENTS:   There are no new accounting pronouncements issued or effective that have had, or are expected to have, a material impact on the Companys financial statements.

NOTE 4 CONCENTRATION OF CREDIT RISK:   Substantially all of the Companys trade 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 Companys overall credit risk as these entities could be affected by similar changes in economic conditions including lower oil prices as well as other related factors. Trade accounts receivable are generally not collateralized. There were no allowances for doubtful accounts for the Companys trade accounts receivable at August 31, 2015 and February 28, 2015, as all joint interest owners have a history of paying their obligations.   At the Companys East Slopes project in California, there is only one buyer available for the purchase of all oil production. At the Companys 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 August 31, 2015 and February 28, 2015 these three individual customers represented 100.0% of crude oil and natural gas revenue accounts receivable. If these buyers are unable to resell their products or if they lose a significant sales contract then the Company may incur difficulties in selling its oil and natural gas production.   The Companys accounts receivable from Kentucky and California oil and natural gas sales at August 31, 2015 and February 28, 2015 are set forth in the table below. <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 41%"> </td> <td style="width: 1%"> </td> <td style="width: 17%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 9%"> </td> <td style="width: 1%"> </td> <td style="width: 9%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 8%"> </td> <td style="width: 1%"> </td> <td style="width: 9%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom"> </td> <td colspan="4" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td colspan="4" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="vertical-align: bottom"> <td style="border-bottom: #000000 1px solid; font-size: 8.5pt; text-align: center">Project</td> <td style="font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; font-size: 8.5pt; text-align: center">Customer</td> <td style="font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid">Revenue Receivable</td> <td style="font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; font-size: 8.5pt; text-align: center">Percentage</td> <td style="font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid">Revenue Receivable</td> <td style="font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; font-size: 8.5pt; text-align: center">Percentage</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Kentucky Twin Bottoms Field (Oil)</td> <td> </td> <td>Appalachian Oil</td> <td> </td> <td style="text-align: justify">$</td> <td style="text-align: right">46,015</td> <td> </td> <td style="text-align: right">37.2%</td> <td> </td> <td style="text-align: justify">$</td> <td style="text-align: right">90,906</td> <td> </td> <td style="text-align: right">44.9%</td></tr> <tr style="vertical-align: bottom"> <td>Kentucky Twin Bottoms Field (Natural gas)</td> <td> </td> <td>Jefferson Gas</td> <td> </td> <td> </td> <td style="text-align: right">8,201</td> <td> </td> <td style="text-align: right">6.6%</td> <td> </td> <td> </td> <td style="text-align: right">16,676</td> <td> </td> <td style="text-align: right">8.2%</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>California East Slopes Project (Oil)</td> <td> </td> <td>Plains Marketing</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">69,547</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-align: right">56.2%</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">95,150</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-align: right">46.9%</td></tr> <tr style="vertical-align: bottom"> <td> </td> <td> </td> <td> </td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: justify">$</td> <td style="border-bottom: #000000 3px double; text-align: right">123,763</td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: right">100.0%</td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: justify">$</td> <td style="border-bottom: #000000 3px double; text-align: right">202,732</td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: right">100.0%</td></tr> </table>   Other receivables balances primarily include amounts advanced to certain minority working interest partners in Kentucky and monthly principal and interest receivable on the loan to App Energy, LLC, a Kentucky limited liability company (App Energy). For additional information on the App Energy loan refer to the discussion in Note 8 Note Receivable.

NOTE 5 OIL AND GAS PROPERTIES:   Oil and gas property balances at August 31, 2015 and February 28, 2015 are set forth in the table below. <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 71%"> </td> <td style="width: 1%"> </td> <td style="width: 13%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 13%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Proved leasehold costs</td> <td>$</td> <td style="text-align: right">699,417</td> <td> </td> <td>$</td> <td style="text-align: right">695,231</td></tr> <tr style="vertical-align: bottom"> <td>Unproved leasehold costs</td> <td> </td> <td style="text-align: right">737,218</td> <td> </td> <td> </td> <td style="text-align: right">733,478</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Costs of wells and development</td> <td> </td> <td style="text-align: right">678,614</td> <td> </td> <td> </td> <td style="text-align: right">542,563</td></tr> <tr style="vertical-align: bottom"> <td>Capitalized exploratory well costs</td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">5,304,632</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">5,308,876</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Total cost of oil and gas properties</td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">7,419,881</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">7,280,148</td></tr> <tr style="vertical-align: bottom"> <td>Accumulated depletion, depreciation, amortization and impairment</td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">(2,423,388)</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">(2,167,064)</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Net oil and gas properties</td> <td style="border-bottom: #000000 3px double">$</td> <td style="border-bottom: #000000 3px double; text-align: right">4,996,493</td> <td> </td> <td style="border-bottom: #000000 3px double">$</td> <td style="border-bottom: #000000 3px double; text-align: right">5,113,084</td></tr> </table>

NOTE 6 PRODUCTION REVENUE RECEIVABLE:   Production revenue receivable balances of $95,000 in aggregate represent amounts due the Company from a portion of the sale price of a 25% working interest in East Slopes Project in Kern County, California that was acquired through the default of certain original working interest partners in the project. Production revenue receivable balances at August 31, 2015 and February 28, 2015 are set forth in the table below: <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 67%"> </td> <td style="width: 1%"> </td> <td style="width: 14%"> </td> <td style="width: 3%"> </td> <td style="width: 1%"> </td> <td style="width: 14%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: top; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Production revenue receivable current</td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">95,000</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">120,000</td></tr> <tr> <td style="vertical-align: bottom">Production revenue receivable non-current</td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">-</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">35,000</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">95,000</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">155,000</td></tr> </table>

NOTE 7 DEFERRED FINANCING COSTS:   Deferred financing costs at August 31, 2015 and February 28, 2015 relate 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: <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 69%"> </td> <td style="width: 1%"> </td> <td style="width: 13%"> </td> <td style="width: 2%"> </td> <td style="width: 1%"> </td> <td style="width: 14%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Deferred financing costs loan fees</td> <td>$</td> <td style="text-align: right">151,139</td> <td> </td> <td>$</td> <td style="text-align: right">151,139</td></tr> <tr style="vertical-align: bottom"> <td>Deferred financing costs loan commissions</td> <td> </td> <td style="text-align: right">630,662</td> <td> </td> <td> </td> <td style="text-align: right">630,662</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Deferred financing costs fair value of warrants</td> <td> </td> <td style="text-align: right">530,488</td> <td> </td> <td> </td> <td style="text-align: right">530,488</td></tr> <tr style="vertical-align: bottom"> <td>Deferred financing costs fair value of common stock</td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">419,832</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">419,832</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td> </td> <td> </td> <td style="text-align: right">1,732,121</td> <td> </td> <td> </td> <td style="text-align: right">1,732,121</td></tr> <tr style="vertical-align: bottom"> <td>Accumulated amortization</td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">(885,934)</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">(673,370)</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td> </td> <td style="border-bottom: #000000 3px double">$</td> <td style="border-bottom: #000000 3px double; text-align: right">846,187</td> <td> </td> <td style="border-bottom: #000000 3px double">$</td> <td style="border-bottom: #000000 3px double; text-align: right">1,058,751</td></tr> </table>   The Company recognized amortization expense of $212,564 for the six months ended August 31, 2015.

NOTE 8 NOTE RECEIVABLE:   At August 31, 2015, the Company had advanced approximately $8.3 million to App Energy through its credit facility. Note receivable balances at August 31, 2015 and February 28, 2015 are set forth in the table below: <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 68%"> </td> <td style="width: 1%"> </td> <td style="width: 14%"> </td> <td style="width: 2%"> </td> <td style="width: 1%"> </td> <td style="width: 14%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: top; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Note receivable current</td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">281,457</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">1,320,944</td></tr> <tr> <td style="vertical-align: bottom">Note receivable non-current</td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">3,841,043</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">3,429,056</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">4,122,500</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">4,750,000</td></tr> </table>

NOTE 9 ACCOUNTS PAYABLE:   On March 1, 2009, the Company became the operator for its East Slopes Project. Additionally, the Company at that time assumed certain original partners default liability of approximately $1.5 million representing a 25% working interest in the drilling and completion costs associated with the East Slopes Project four earning well program. The Company subsequently sold the same 25% working interest on June 11, 2009. Of the $1.5 million default, $246,349 remains unpaid and is included in the August 31, 2015 accounts payable balance.

NOTE 10 ACCOUNTS PAYABLE- RELATED PARTIES:   The August 31, 2015 and February 28, 2015 accounts payable related parties balances were comprised primarily of salaries of the Companys Executive Officers and certain employees; directors fees; expense reimbursements; and interest to the Companys President and Chief Executive Officer on the 12% Subordinated Notes further described in Note 11 Short-Term and Long-Term Borrowings below. Payment of these items has been deferred until the Companys cash flow situation improves.

NOTE 11 SHORT-TERM AND LONG-TERM BORROWINGS:   Note Payable Related Party   As of August 31, 2015 and February 28, 2015, the Companys President and Chief Executive Officer had loaned the Company $250,100 in aggregate that was 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 Companys 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 our President and Chief Executive Officer. Interest is payable monthly at a stated reference rate of 0.249% + 337.5 basis points and totaled $15,468 for the six months ended August 31, 2015. The reference rate is based on the 30 day LIBOR (London Interbank Offered Rate) and is subject to change from UBS. At August 31, 2015 the Line of credit had an outstanding balance of $855,333.   Long-term Borrowings   12% Subordinated Notes   The Companys 12% Subordinated Notes (the Notes) issued pursuant to a March 2010 private placement (of which $250,000 was from a related party) accrue interest at 12% per annum, payable semi-annually on January 29th and July 29th. On January 29, 2015, the Company and 12 of the 13 note holders agreed to extend the maturity date of the Notes from January 29, 2015 for an additional two years. The note principal is payable in full at the amended maturity date of the Notes, which is January 29, 2017. The outstanding balance of the 12% Notes was $565,000 at August 31,2015 and February 05, 2015. Should the Board of Directors, on the amended 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 Companys common stock at a conversion rate equal to 75% of the average closing price of the Companys common stock over the 20 consecutive trading days preceding December 31, 2016.   Maximilian Credit Facility   On October 31, 2012, the Company entered into a loan agreement with Maximilian, 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. 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 original term of the loan. Amortization expense was $68,196 for the six months ended August 31, 2015. Unamortized debt discount was $135,869 at August 31, 2015.   In 2012, 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. As of August 31, 2015, 316,617 of these warrants remain unexercised and outstanding.   Maximilian Credit Facility - Amended and Restated Loan Agreement   In connection with the Companys acquisition of a working interest from App Energy 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 Companys 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 Energy, as borrower pursuant to a Loan and Security Agreement entered into between the Company and App Energy on August 28, 2013 (See Note 8 Note Receivable).   The amended loan agreement contains customary covenants for loans of such type, including among other things, covenants that restrict the Companys 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 Companys 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 Companys transactions with App Energy and entering into the amended loan agreement, the Company (a) issued to Maximilian approximately 6.1 million common shares, representing 9.99% of the Companys 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 Companys common stock representing the right to purchase up to an additional 9.99% of the Companys 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; and contain an exercise blocker provision that prevents any exercise of the warrants if such exercise and related issuance of common stock would increase the Maximilian holdings of the Companys common stock to more than 9.99% of the Companys currently issued and outstanding shares at the time of the exercise. The Company also granted to Maximilian a 50% net profits interest in the Companys approximate 25% working interest, after the Company recovers its investment in the Kentucky acreage, pursuant to an Assignment of Net Profits Interest entered into as of August 28, 2013 by and between the Company and Maximilian.   On May 28, 2014 at Maximilians 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 Companys 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. 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 Companys 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.   On May 20, 2015, the Company entered into a Second Amendment to Amended and Restated Loan and Security Agreement (the2nd Amendment) with Maximilian under its Amended and Restated Loan and Security Agreement dated as of August 28, 2013. The 2nd Amendment modified the calculation of the required monthly payment for a three-month period ending June 30, 2015. As consideration for entering into the loan modification, the Company agreed to modify the exercise price of the warrants Maximilian currently holds from $0.10 to $0.04. No other terms of the warrant agreement were changed. The Company determined that the modification of the warrant exercise price did not result in any incremental fair value.   With the assistance of Maximilian, the Company is currently working with an investment banking firm to assist in securing refinancing of its debt with Maximilian, since the long-term commitment needed to develop the Kentucky and California projects no longer fits the Maximilian business model. Maximilian is continuing to work with the Company in modifying the credit facility terms during this period of lower hydrocarbon prices.   Current debt balances at August 31, 2015, and February 28, 2015 are set forth in the table below: <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 68%"> </td> <td style="width: 1%"> </td> <td style="width: 15%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 14%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: top; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Maximilian note</td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">2,840,442</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">4,823,325</td></tr> <tr> <td style="vertical-align: bottom">Maximilian note - discount</td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">(119,830)</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">(132,114)</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">2,720,612</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">4,691,211</td></tr> </table>   Non-current debt balances at August 31, 2015 and February 28, 2015 are set forth in the table below: <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 68%"> </td> <td style="width: 1%"> </td> <td style="width: 15%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 14%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: top; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Maximilian note</td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">10,057,910</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">8,663,458</td></tr> <tr> <td style="vertical-align: bottom">Maximilian note - discount</td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">(16,039)</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">(71,951)</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">10,041,871</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">8,591,507</td></tr> </table>

NOTE 12 STOCKHOLDERS DEFICIT:   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. At August 31, 2015, there were 724,565 shares issued and outstanding, that had not been converted into our common stock. As of August 31, 2015, there are 43 accredited investors who have converted 675,200 Series A Preferred shares into 2,025,600 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. <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 45%"> </td> <td style="width: 2%"> </td> <td style="width: 18%"> </td> <td style="width: 2%"> </td> <td style="width: 16%"> </td> <td style="width: 2%"> </td> <td style="width: 15%"> </td></tr> <tr> <td style="border-bottom: #000000 1px solid; vertical-align: bottom">  Fiscal Period</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom">Shares of Series A Preferred Converted to Common Stock</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom">Shares of Common Stock Issued from Conversion</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom">Number of Accredited Investors</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Year Ended February 29, 2008</td> <td> </td> <td style="text-align: right">102,300</td> <td> </td> <td style="text-align: right">306,900</td> <td> </td> <td style="text-indent: 37px">10</td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify">Year Ended February 28, 2009</td> <td> </td> <td style="text-align: right">237,000</td> <td> </td> <td style="text-align: right">711,000</td> <td> </td> <td style="text-indent: 37px">12</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Year Ended February 28, 2010</td> <td> </td> <td style="text-align: right">51,900</td> <td> </td> <td style="text-align: right">155,700</td> <td> </td> <td style="text-indent: 43px">4</td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify">Year Ended February 28, 2011</td> <td> </td> <td style="text-align: right">102,000</td> <td> </td> <td style="text-align: right">306,000</td> <td> </td> <td style="text-indent: 43px">4</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Year Ended February 29, 2012</td> <td> </td> <td style="text-align: right">-</td> <td> </td> <td style="text-align: right">-</td> <td> </td> <td style="text-indent: 45px">-</td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify">Year Ended February 28, 2013</td> <td> </td> <td style="text-align: right">18,000</td> <td> </td> <td style="text-align: right">54,000</td> <td> </td> <td style="text-indent: 43px">2</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Year Ended February 28, 2014</td> <td> </td> <td style="text-align: right">151,000</td> <td> </td> <td style="text-align: right">453,000</td> <td> </td> <td style="text-indent: 43px">9</td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify">Year Ended February 28, 2015</td> <td> </td> <td style="text-align: right">3,000</td> <td> </td> <td style="text-align: right">9,000</td> <td> </td> <td style="text-indent: 43px">1</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Six Months Ended August 31, 2015</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-align: right">10,000</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-align: right">30,000</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-indent: 43px">1</td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify; text-indent: 16px">Totals </td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: right">675,200</td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: right">2,025,600</td> <td> </td> <td style="border-bottom: #000000 3px double; text-indent: 37px">43</td></tr> </table>   Holders of Series A Preferred shall be paid dividends, in the amount of 6% of the original purchase price per annum. 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. As of August 31, 2015, no dividends have been paid. Dividends earned since issuance for each fiscal year and the six months ended August 31, 2015 are set forth in the table below: <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 43%"> </td> <td style="width: 2%"> </td> <td style="width: 32%"> </td> <td style="width: 2%"> </td> <td style="width: 1%"> </td> <td style="width: 20%"> </td></tr> <tr> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">Fiscal Period</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">Shareholders at Period End</td> <td style="vertical-align: top; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">Earned Dividends</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Year Ended February 28, 2007</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">100</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">155,311</td></tr> <tr> <td style="vertical-align: bottom">Year Ended February 29, 2008</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">90</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">242,126</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Year Ended February 28, 2009</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">78</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">209,973</td></tr> <tr> <td style="vertical-align: bottom">Year Ended February 28, 2010</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">74</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">189,973</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Year Ended February 28, 2011</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">70</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">173,707</td></tr> <tr> <td style="vertical-align: bottom">Year Ended February 29, 2012</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">70</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">163,624</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Year Ended February 28, 2013</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">68</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">161,906</td></tr> <tr> <td style="vertical-align: bottom">Year Ended February 28, 2014</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">59</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">151,323</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Year Ended February 28, 2015</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">58</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">132,634</td></tr> <tr> <td style="vertical-align: bottom">Six Months Ended August 31, 2015</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">58</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom; border-bottom: Black 1pt solid"> </td> <td style="vertical-align: bottom; text-align: right; border-bottom: Black 1pt solid">65,897</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Total Accumulated Dividends</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">1,646,474</td></tr> </table>   Common Stock   The Company is authorized to issue up to 200,000,000 shares of $0.001 par value common stock of which 51,487,373 shares were issued and outstanding as of August 31, 2015. In comparison, at February 28, 2015, a total of 51,457,373 shares were issued and outstanding. The increase of 30,000 shares was attributable as shown below: <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 78%"> </td> <td style="width: 12%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 8%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom">Common Stock Balance</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">Par Value</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Common stock, Issued and Outstanding, February 28, 2015</td> <td style="text-align: right">51,457,373</td> <td> </td> <td> </td> <td> </td></tr> <tr style="vertical-align: bottom"> <td>Conversion of Series A Convertible Preferred Stock to Common Stock</td> <td style="text-align: right; border-bottom: Black 1pt solid">30,000</td> <td> </td> <td>$</td> <td style="text-align: right">30</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Common stock, Issued and Outstanding, August 31, 2015</td> <td style="border-bottom: #000000 3px double; text-align: right">51,487,373</td> <td> </td> <td> </td> <td> </td></tr> </table>

NOTE 13 WARRANTS:   Warrants outstanding and exercisable as of August 31, 2015 are set forth in the table below: <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 47%"> </td> <td style="width: 1%"> </td> <td style="width: 12%"> </td> <td style="width: 1%"> </td> <td style="width: 11%"> </td> <td style="width: 1%"> </td> <td style="width: 13%"> </td> <td style="width: 1%"> </td> <td style="width: 13%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">Warrants</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom">Exercise Price</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom">Remaining Life (Years)</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom">Exercisable Warrants Remaining</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>12% Subordinated notes</td> <td> </td> <td style="text-align: right">1,190,000</td> <td> </td> <td style="text-indent: 27px">$0.14</td> <td> </td> <td style="text-align: center">1.42</td> <td> </td> <td style="text-align: right">980,000</td></tr> <tr style="vertical-align: bottom"> <td>Warrants issued in 2012 for debt financing</td> <td> </td> <td style="text-align: right">2,435,517</td> <td> </td> <td style="text-indent: 27px">$0.044</td> <td> </td> <td style="text-align: center">2.17</td> <td> </td> <td style="text-align: right">316,617</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Warrants issued for Kentucky oil project</td> <td> </td> <td style="text-align: right">3,498,601</td> <td> </td> <td style="text-indent: 27px">$0.04</td> <td> </td> <td style="text-align: center">1.00</td> <td> </td> <td style="text-align: right">3,498,601</td></tr> <tr style="vertical-align: bottom"> <td>Warrants issued for Kentucky debt financing</td> <td> </td> <td style="text-align: right">2,623,951</td> <td> </td> <td style="text-indent: 27px">$0.04</td> <td> </td> <td style="text-align: center">1.00</td> <td> </td> <td style="text-align: right">2,623,951</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Warrants issued for Kentucky debt financing</td> <td> </td> <td style="text-align: right">309,503</td> <td> </td> <td style="text-indent: 27px">$0.214</td> <td> </td> <td style="text-align: center">3.00</td> <td> </td> <td style="text-align: right">309,503</td></tr> <tr style="vertical-align: bottom"> <td>Warrants issued in share-for-warrant exchange</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-align: right">427,729</td> <td> </td> <td style="text-indent: 27px">$0.04</td> <td> </td> <td style="text-align: center">1.00</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-align: right">427,729</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td> </td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: right">10,485,301</td> <td> </td> <td> </td> <td> </td> <td> </td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: right">8,156,401</td></tr> </table>   There were 150,000 warrants issued in 2010 for services that expired during the six months ended August 31, 2015. During the six months ended August 31, 2015 there were no warrants issued or exercised. The remaining outstanding warrants as of August 31, 2015, have a weighted average exercise price of $0.06, a weighted average remaining life of 1.17 years, and an intrinsic value of -$0-.

NOTE 14 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 rates to income from continuing operations before income taxes is set forth in the table below: <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 64%"> </td> <td style="width: 1%"> </td> <td style="width: 16%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 17%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Computed at U.S. and state statutory rates (40%)</td> <td>$</td> <td style="text-align: right">(421,059)</td> <td> </td> <td style="text-align: justify">$</td> <td style="text-align: right">(293,176)</td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify">Permanent differences</td> <td> </td> <td style="text-align: right">58,737</td> <td> </td> <td> </td> <td style="text-align: right">142,925</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Changes in valuation allowance</td> <td> </td> <td style="text-align: right">362,322</td> <td> </td> <td> </td> <td style="text-align: right">150,251</td></tr> <tr style="vertical-align: bottom"> <td> </td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid">$</td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid; text-align: right">-</td> <td> </td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid; text-align: justify">$</td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid; text-align: right">-</td></tr> </table>   Tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred liabilities are set forth in the table below: <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 64%"> </td> <td style="width: 1%"> </td> <td style="width: 16%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 17%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Deferred tax assets:</td> <td> </td> <td> </td> <td> </td> <td> </td> <td> </td></tr> <tr style="vertical-align: bottom"> <td style="text-indent: 14px">Net operating loss carryforwards</td> <td>$</td> <td style="text-align: right">9,595,165</td> <td> </td> <td>$</td> <td style="text-align: right">9,188,905</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Oil and gas properties</td> <td> </td> <td style="text-align: right">(1,429,835)</td> <td> </td> <td> </td> <td style="text-align: right">(1,436,249)</td></tr> <tr style="vertical-align: bottom"> <td>Stock based compensation</td> <td> </td> <td style="text-align: right">88,723</td> <td> </td> <td> </td> <td style="text-align: right">88,723</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Other</td> <td> </td> <td style="text-align: right">(153,251)</td> <td> </td> <td> </td> <td style="text-align: right">(102,899)</td></tr> <tr style="vertical-align: bottom"> <td>Less valuation allowance</td> <td> </td> <td style="text-align: right">(8,100,802)</td> <td> </td> <td> </td> <td style="text-align: right">(7,738,480)</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td> </td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid">$</td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid; text-align: right">-</td> <td> </td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid">$</td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid; text-align: right">-</td></tr> </table>   At August 31, 2015, Daybreak had estimated net operating loss (NOL) carryforwards for federal and state income tax purposes of approximately $23,987,913 which will begin to expire, if unused, beginning in 2024. The valuation allowance increased $362,322 for the six months ended August 31, 2015 and increased by $150,251 for the year ended February 28, 2015. Section 382 of the Internal Revenue Code places annual limitations on the Companys NOL carryforward.   The above estimates are based on managements decisions concerning elections which could change the relationship between net income and taxable income. Management decisions are made annually and could cause estimates to vary significantly.

NOTE 15 COMMITMENTS AND CONTINGENCIES:   Various lawsuits, claims and other contingencies arise in the ordinary course of the Companys business activities. While the ultimate outcome of any future contingency is not determinable at this time, management believes that any liability or loss resulting therefrom will not materially affect the financial position, results of operations or cash flows of the Company.   The Company, as an owner or lessee and operator of 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 August 31, 2015. There can be no assurance, however, that current regulatory requirements will not change or that past non-compliance with environmental issues will not be discovered on the Companys oil and gas properties.

NOTE 16 SUBSEQUENT EVENTS:   On October 14, 2015, the Company entered into a Third Amendment to the Amended and Restated Loan and Security Agreement and Second Warrant Amendment with Maximilian, which amended the Companys loan agreement with Maximilian (the Maximilian Amendment). Pursuant to the Maximilian Amendment, Maximilian agreed to a reduction in the Companys monthly payments under the loan agreement to $50,000 per month for a period of six months ending on February 29, 2016. The reduction in monthly payments allows for additional funds to be used by the Company in drilling and completing additional wells in Kentucky. As consideration for the reduction in the monthly payment amount, the Company agreed that twenty percent of the amount by which the monthly payment was reduced would be added to the loan balance, and the portion of the monthly payment savings that constitutes savings in interest or commitment fees would be treated as an additional advance of principal under the loan agreement (the Deemed Advances). The Company also agreed to grant to Maximilian an overriding royalty interest in four wells it drills of 1.5% of its working interest in such wells, subject to reduction connected to the Companys ongoing efforts to refinance its loan agreement. As part of the Maximilian Amendment, the Company also agreed to extend the expiration date of the warrants held by Maximilian to purchase up to 6,550,281 shares of common stock of the Company to August 28, 2018.   In connection with entering into the Maximilian Amendment, the Company concurrently entered into a Second Amendment to Loan and Security Agreement with App Energy (the App Amendment), which amended the Companys loan agreement with App Energy in which the Company, as lender, lends to App Energy, as borrower, a portion of the advances it receives pursuant to its loan agreement with Maximilian. The App Amendment provides for a reduction in interest rate and a reduction in monthly payments to be made by App Energy to the Company for the same payment cycles as the reduced payment to be made by the Company under the Maximilian Amendment. The reduction in monthly payments by App Energy will allow App Energy to fund its share of drilling and completing additional wells in Kentucky with the Company. As consideration for the reduction in the monthly payment amount, App Energy agreed that a percentage of the Deemed Advances will be treated as additional advances under the App Energy loan agreement, and that it would fund a portion of the Companys drilling and development expenses with respect to two wells, subject to a partial refund connected to the Companys ongoing efforts to refinance its loan agreement. App Energy also agreed to grant to Maximilian an overriding royalty interest on the same terms as the overriding royalty interest agreed to by the Company. Finally, App Energy granted to the Company a time-limited option to purchase additional working interest in its Kentucky operations connected to the Companys ongoing efforts to refinance its loan agreement.

Basis of Presentation   The accompanying unaudited interim financial statements and notes for the Company have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial information and with the instructions to Form 10-Q for quarterly reports under Section 13 or 15(d) of the Securities Exchange Act of 1934 (the Exchange Act). Accordingly, they do not include all of the information and footnote disclosures normally required by accounting principles generally accepted in the United States of America for complete financial statements.   In the opinion of management, all adjustments considered necessary for a fair presentation of the financial statements have been included and such adjustments are of a normal recurring nature. Operating results for the six months ended August 31, 2015 are not necessarily indicative of the results that may be expected for the fiscal year ending February 29, 2016.   These financial statements should be read in conjunction with the audited financial statements and notes thereto included in the Companys Annual Report on Form 10-K for the fiscal year ended February 28, 2015.

Use of Estimates   In preparing financial statements in conformity with accounting principles generally accepted in the United States of America, management is required to make estimates and assumptions. These estimates and assumptions may affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, and revenues and expenses during the reporting period. Actual results could differ materially from those estimates. The accounting policies most affected by managements 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 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 abandonment obligations.

Reclassifications   Certain reclassifications have been made to conform the prior periods financial information to the current periods presentation. These reclassifications had no effect on previously reported net loss or accumulated deficit.

<table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom"> </td> <td colspan="4" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td colspan="4" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="vertical-align: bottom"> <td style="border-bottom: #000000 1px solid; font-size: 8.5pt; text-align: center">Project</td> <td style="font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; font-size: 8.5pt; text-align: center">Customer</td> <td style="font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid">Revenue Receivable</td> <td style="font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; font-size: 8.5pt; text-align: center">Percentage</td> <td style="font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid">Revenue Receivable</td> <td style="font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; font-size: 8.5pt; text-align: center">Percentage</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="width: 41%">Kentucky Twin Bottoms Field (Oil)</td> <td style="width: 1%"> </td> <td style="width: 17%">Appalachian Oil</td> <td style="width: 1%"> </td> <td style="text-align: justify; width: 1%">$</td> <td style="text-align: right; width: 9%">46,015</td> <td style="width: 1%"> </td> <td style="text-align: right; width: 9%">37.2%</td> <td style="width: 1%"> </td> <td style="text-align: justify; width: 1%">$</td> <td style="text-align: right; width: 8%">90,906</td> <td style="width: 1%"> </td> <td style="text-align: right; width: 9%">44.9%</td></tr> <tr style="vertical-align: bottom"> <td>Kentucky Twin Bottoms Field (Natural gas)</td> <td> </td> <td>Jefferson Gas</td> <td> </td> <td> </td> <td style="text-align: right">8,201</td> <td> </td> <td style="text-align: right">6.6%</td> <td> </td> <td> </td> <td style="text-align: right">16,676</td> <td> </td> <td style="text-align: right">8.2%</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>California East Slopes Project (Oil)</td> <td> </td> <td>Plains Marketing</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">69,547</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-align: right">56.2%</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">95,150</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-align: right">46.9%</td></tr> <tr style="vertical-align: bottom"> <td> </td> <td> </td> <td> </td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: justify">$</td> <td style="border-bottom: #000000 3px double; text-align: right">123,763</td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: right">100.0%</td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: justify">$</td> <td style="border-bottom: #000000 3px double; text-align: right">202,732</td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: right">100.0%</td></tr> </table>

<table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="width: 71%">Proved leasehold costs</td> <td style="width: 1%">$</td> <td style="text-align: right; width: 13%">699,417</td> <td style="width: 1%"> </td> <td style="width: 1%">$</td> <td style="text-align: right; width: 13%">695,231</td></tr> <tr style="vertical-align: bottom"> <td>Unproved leasehold costs</td> <td> </td> <td style="text-align: right">737,218</td> <td> </td> <td> </td> <td style="text-align: right">733,478</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Costs of wells and development</td> <td> </td> <td style="text-align: right">678,614</td> <td> </td> <td> </td> <td style="text-align: right">542,563</td></tr> <tr style="vertical-align: bottom"> <td>Capitalized exploratory well costs</td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">5,304,632</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">5,308,876</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Total cost of oil and gas properties</td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">7,419,881</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">7,280,148</td></tr> <tr style="vertical-align: bottom"> <td>Accumulated depletion, depreciation, amortization and impairment</td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">(2,423,388)</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">(2,167,064)</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Net oil and gas properties</td> <td style="border-bottom: #000000 3px double">$</td> <td style="border-bottom: #000000 3px double; text-align: right">4,996,493</td> <td> </td> <td style="border-bottom: #000000 3px double">$</td> <td style="border-bottom: #000000 3px double; text-align: right">5,113,084</td></tr> </table>

<table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: top; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom; width: 67%">Production revenue receivable current</td> <td style="vertical-align: bottom; width: 1%">$</td> <td style="vertical-align: bottom; text-align: right; width: 14%">95,000</td> <td style="vertical-align: top; width: 3%"> </td> <td style="vertical-align: bottom; width: 1%">$</td> <td style="vertical-align: bottom; text-align: right; width: 14%">120,000</td></tr> <tr> <td style="vertical-align: bottom">Production revenue receivable non-current</td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">-</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">35,000</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">95,000</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">155,000</td></tr> </table>

<table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="width: 69%">Deferred financing costs loan fees</td> <td style="width: 1%">$</td> <td style="text-align: right; width: 13%">151,139</td> <td style="width: 2%"> </td> <td style="width: 1%">$</td> <td style="text-align: right; width: 14%">151,139</td></tr> <tr style="vertical-align: bottom"> <td>Deferred financing costs loan commissions</td> <td> </td> <td style="text-align: right">630,662</td> <td> </td> <td> </td> <td style="text-align: right">630,662</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Deferred financing costs fair value of warrants</td> <td> </td> <td style="text-align: right">530,488</td> <td> </td> <td> </td> <td style="text-align: right">530,488</td></tr> <tr style="vertical-align: bottom"> <td>Deferred financing costs fair value of common stock</td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">419,832</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">419,832</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td> </td> <td> </td> <td style="text-align: right">1,732,121</td> <td> </td> <td> </td> <td style="text-align: right">1,732,121</td></tr> <tr style="vertical-align: bottom"> <td>Accumulated amortization</td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">(885,934)</td> <td> </td> <td style="border-bottom: #000000 1px solid"> </td> <td style="border-bottom: #000000 1px solid; text-align: right">(673,370)</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td> </td> <td style="border-bottom: #000000 3px double">$</td> <td style="border-bottom: #000000 3px double; text-align: right">846,187</td> <td> </td> <td style="border-bottom: #000000 3px double">$</td> <td style="border-bottom: #000000 3px double; text-align: right">1,058,751</td></tr> </table>

<table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: top; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom; width: 68%">Note receivable current</td> <td style="vertical-align: bottom; width: 1%">$</td> <td style="vertical-align: bottom; text-align: right; width: 14%">281,457</td> <td style="vertical-align: top; width: 2%"> </td> <td style="vertical-align: bottom; width: 1%">$</td> <td style="vertical-align: bottom; text-align: right; width: 14%">1,320,944</td></tr> <tr> <td style="vertical-align: bottom">Note receivable non-current</td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">3,841,043</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">3,429,056</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">4,122,500</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">4,750,000</td></tr> </table>

<table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 68%">Current</td> <td style="width: 1%"> </td> <td style="width: 15%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 14%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: top; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Maximilian note</td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">2,840,442</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">4,823,325</td></tr> <tr> <td style="vertical-align: bottom">Maximilian note - discount</td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">(119,830)</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">(132,114)</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">2,720,612</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">4,691,211</td></tr> </table>   <table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr style="font-size: 1pt"> <td style="width: 68%"> Non-Current</td> <td style="width: 1%"> </td> <td style="width: 15%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 14%"> </td></tr> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: top; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Maximilian note</td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">10,057,910</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom">$</td> <td style="vertical-align: bottom; text-align: right">8,663,458</td></tr> <tr> <td style="vertical-align: bottom">Maximilian note - discount</td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">(16,039)</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; text-align: right">(71,951)</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">10,041,871</td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">8,591,507</td></tr> </table>

<table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; width: 45%">  Fiscal Period</td> <td style="vertical-align: bottom; font-size: 8.5pt; width: 2%"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; width: 18%">Shares of Series A Preferred Converted to Common Stock</td> <td style="vertical-align: bottom; font-size: 8.5pt; width: 2%"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; width: 16%">Shares of Common Stock Issued from Conversion</td> <td style="vertical-align: bottom; font-size: 8.5pt; width: 2%"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; width: 15%">Number of Accredited Investors</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Year Ended February 29, 2008</td> <td> </td> <td style="text-align: right">102,300</td> <td> </td> <td style="text-align: right">306,900</td> <td> </td> <td style="text-indent: 37px">10</td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify">Year Ended February 28, 2009</td> <td> </td> <td style="text-align: right">237,000</td> <td> </td> <td style="text-align: right">711,000</td> <td> </td> <td style="text-indent: 37px">12</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Year Ended February 28, 2010</td> <td> </td> <td style="text-align: right">51,900</td> <td> </td> <td style="text-align: right">155,700</td> <td> </td> <td style="text-indent: 43px">4</td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify">Year Ended February 28, 2011</td> <td> </td> <td style="text-align: right">102,000</td> <td> </td> <td style="text-align: right">306,000</td> <td> </td> <td style="text-indent: 43px">4</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Year Ended February 29, 2012</td> <td> </td> <td style="text-align: right">-</td> <td> </td> <td style="text-align: right">-</td> <td> </td> <td style="text-indent: 45px">-</td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify">Year Ended February 28, 2013</td> <td> </td> <td style="text-align: right">18,000</td> <td> </td> <td style="text-align: right">54,000</td> <td> </td> <td style="text-indent: 43px">2</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Year Ended February 28, 2014</td> <td> </td> <td style="text-align: right">151,000</td> <td> </td> <td style="text-align: right">453,000</td> <td> </td> <td style="text-indent: 43px">9</td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify">Year Ended February 28, 2015</td> <td> </td> <td style="text-align: right">3,000</td> <td> </td> <td style="text-align: right">9,000</td> <td> </td> <td style="text-indent: 43px">1</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Six Months Ended August 31, 2015</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-align: right">10,000</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-align: right">30,000</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-indent: 43px">1</td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify; text-indent: 16px">Totals </td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: right">675,200</td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: right">2,025,600</td> <td> </td> <td style="border-bottom: #000000 3px double; text-indent: 37px">43</td></tr> </table>

<table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">Fiscal Period</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">Shareholders at Period End</td> <td style="vertical-align: top; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">Earned Dividends</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom; width: 43%">Year Ended February 28, 2007</td> <td style="vertical-align: bottom; width: 2%"> </td> <td style="vertical-align: bottom; text-align: center; width: 32%">100</td> <td style="vertical-align: top; width: 2%"> </td> <td style="vertical-align: bottom; width: 1%">$</td> <td style="vertical-align: bottom; text-align: right; width: 20%">155,311</td></tr> <tr> <td style="vertical-align: bottom">Year Ended February 29, 2008</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">90</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">242,126</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Year Ended February 28, 2009</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">78</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">209,973</td></tr> <tr> <td style="vertical-align: bottom">Year Ended February 28, 2010</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">74</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">189,973</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Year Ended February 28, 2011</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">70</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">173,707</td></tr> <tr> <td style="vertical-align: bottom">Year Ended February 29, 2012</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">70</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">163,624</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Year Ended February 28, 2013</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">68</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">161,906</td></tr> <tr> <td style="vertical-align: bottom">Year Ended February 28, 2014</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">59</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">151,323</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Year Ended February 28, 2015</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">58</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: right">132,634</td></tr> <tr> <td style="vertical-align: bottom">Six Months Ended August 31, 2015</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom; text-align: center">58</td> <td style="vertical-align: top"> </td> <td style="vertical-align: bottom; border-bottom: Black 1pt solid"> </td> <td style="vertical-align: bottom; text-align: right; border-bottom: Black 1pt solid">65,897</td></tr> <tr style="background-color: #ebebff"> <td style="vertical-align: bottom">Total Accumulated Dividends</td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: bottom"> </td> <td style="vertical-align: top"> </td> <td style="border-bottom: #000000 3px double; vertical-align: bottom">$</td> <td style="border-bottom: #000000 3px double; vertical-align: bottom; text-align: right">1,646,474</td></tr> </table>

<table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr> <td style="vertical-align: bottom"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom">Common Stock Balance</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">Par Value</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify; width: 78%">Common stock, Issued and Outstanding, February 28, 2015</td> <td style="text-align: right; width: 12%">51,457,373</td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 8%"> </td></tr> <tr style="vertical-align: bottom"> <td>Conversion of Series A Convertible Preferred Stock to Common Stock</td> <td style="text-align: right; border-bottom: Black 1pt solid">30,000</td> <td> </td> <td>$</td> <td style="text-align: right">30</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Common stock, Issued and Outstanding, August 31, 2015</td> <td style="border-bottom: #000000 3px double; text-align: right">51,487,373</td> <td> </td> <td> </td> <td> </td></tr> </table>

<table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr> <td style="vertical-align: bottom; width: 47%"> </td> <td style="vertical-align: bottom; width: 1%"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center; width: 12%">Warrants</td> <td style="vertical-align: bottom; font-size: 8.5pt; width: 1%"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; width: 11%">Exercise Price</td> <td style="vertical-align: bottom; font-size: 8.5pt; width: 1%"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; width: 13%">Remaining Life (Years)</td> <td style="vertical-align: bottom; font-size: 8.5pt; width: 1%"> </td> <td style="border-bottom: #000000 1px solid; vertical-align: bottom; width: 13%">Exercisable Warrants Remaining</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>12% Subordinated notes</td> <td> </td> <td style="text-align: right">1,190,000</td> <td> </td> <td style="text-indent: 27px">$0.14</td> <td> </td> <td style="text-align: center">1.42</td> <td> </td> <td style="text-align: right">980,000</td></tr> <tr style="vertical-align: bottom"> <td>Warrants issued in 2012 for debt financing</td> <td> </td> <td style="text-align: right">2,435,517</td> <td> </td> <td style="text-indent: 27px">$0.044</td> <td> </td> <td style="text-align: center">2.17</td> <td> </td> <td style="text-align: right">316,617</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Warrants issued for Kentucky oil project</td> <td> </td> <td style="text-align: right">3,498,601</td> <td> </td> <td style="text-indent: 27px">$0.04</td> <td> </td> <td style="text-align: center">1.00</td> <td> </td> <td style="text-align: right">3,498,601</td></tr> <tr style="vertical-align: bottom"> <td>Warrants issued for Kentucky debt financing</td> <td> </td> <td style="text-align: right">2,623,951</td> <td> </td> <td style="text-indent: 27px">$0.04</td> <td> </td> <td style="text-align: center">1.00</td> <td> </td> <td style="text-align: right">2,623,951</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Warrants issued for Kentucky debt financing</td> <td> </td> <td style="text-align: right">309,503</td> <td> </td> <td style="text-indent: 27px">$0.214</td> <td> </td> <td style="text-align: center">3.00</td> <td> </td> <td style="text-align: right">309,503</td></tr> <tr style="vertical-align: bottom"> <td>Warrants issued in share-for-warrant exchange</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-align: right">427,729</td> <td> </td> <td style="text-indent: 27px">$0.04</td> <td> </td> <td style="text-align: center">1.00</td> <td> </td> <td style="border-bottom: #000000 1px solid; text-align: right">427,729</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td> </td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: right">10,485,301</td> <td> </td> <td> </td> <td> </td> <td> </td> <td> </td> <td style="border-bottom: #000000 3px double; text-align: right">8,156,401</td></tr> </table>

<table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify; width: 64%">Computed at U.S. and state statutory rates (40%)</td> <td style="width: 1%">$</td> <td style="text-align: right; width: 16%">(421,059)</td> <td style="width: 1%"> </td> <td style="text-align: justify; width: 1%">$</td> <td style="text-align: right; width: 17%">(293,176)</td></tr> <tr style="vertical-align: bottom"> <td style="text-align: justify">Permanent differences</td> <td> </td> <td style="text-align: right">58,737</td> <td> </td> <td> </td> <td style="text-align: right">142,925</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify">Changes in valuation allowance</td> <td> </td> <td style="text-align: right">362,322</td> <td> </td> <td> </td> <td style="text-align: right">150,251</td></tr> <tr style="vertical-align: bottom"> <td> </td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid">$</td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid; text-align: right">-</td> <td> </td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid; text-align: justify">$</td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid; text-align: right">-</td></tr> </table>

<table cellspacing="0" cellpadding="0" style="width: 100%; margin-top: 0px; font-size: 9pt"> <tr> <td style="vertical-align: bottom"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">August 31, 2015</td> <td style="vertical-align: bottom; font-size: 8.5pt"> </td> <td colspan="2" style="border-bottom: #000000 1px solid; vertical-align: bottom; font-size: 8.5pt; text-align: center">February 28, 2015</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td style="text-align: justify; width: 64%">Deferred tax assets:</td> <td style="width: 1%"> </td> <td style="width: 16%"> </td> <td style="width: 1%"> </td> <td style="width: 1%"> </td> <td style="width: 17%"> </td></tr> <tr style="vertical-align: bottom"> <td style="text-indent: 14px">Net operating loss carryforwards</td> <td>$</td> <td style="text-align: right">9,595,165</td> <td> </td> <td>$</td> <td style="text-align: right">9,188,905</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Oil and gas properties</td> <td> </td> <td style="text-align: right">(1,429,835)</td> <td> </td> <td> </td> <td style="text-align: right">(1,436,249)</td></tr> <tr style="vertical-align: bottom"> <td>Stock based compensation</td> <td> </td> <td style="text-align: right">88,723</td> <td> </td> <td> </td> <td style="text-align: right">88,723</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td>Other</td> <td> </td> <td style="text-align: right">(153,251)</td> <td> </td> <td> </td> <td style="text-align: right">(102,899)</td></tr> <tr style="vertical-align: bottom"> <td>Less valuation allowance</td> <td> </td> <td style="text-align: right">(8,100,802)</td> <td> </td> <td> </td> <td style="text-align: right">(7,738,480)</td></tr> <tr style="vertical-align: bottom; background-color: #ebebff"> <td> </td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid">$</td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid; text-align: right">-</td> <td> </td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid">$</td> <td style="border-bottom: #000000 3px double; border-top: #000000 1px solid; text-align: right">-</td></tr> </table>

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Deferred Financing Costs (Details Narrative)	6 Months Ended
Deferred Financing Costs (Details Narrative)	Aug. 31, 2015 USD ($)
Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]
Amortization expense of deferred financing costs	$ 212,564

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Subsequent Events (Details Narrative) - Subsequent Event	Oct. 14, 2015
App Energy - Second Amendment to Loan and Security Agreement
Subsequent Event [Line Items]
Credit facility, reduction to required monthly payments	The App Amendment provides for a reduction in interest rate and a reduction in monthly payments to be made by App Energy to the Company for the same payment cycles as the reduced payment to be made by the Company under the Maximilian Amendment. The reduction in monthly payments by App Energy will allow App Energy to fund its share of drilling and completing additional wells in Kentucky with the Company. As consideration for the reduction in the monthly payment amount, App Energy agreed that a percentage of the Deemed Advances will be treated as additional advances under the App Energy loan agreement, and that it would fund a portion of the Company’s drilling and development expenses with respect to two wells, subject to a partial refund connected to the Company’s ongoing efforts to refinance its loan agreement. App Energy also agreed to grant to Maximilian an overriding royalty interest on the same terms as the overriding royalty interest agreed to by the Company. Finally, App Energy granted to the Company a time-limited option to purchase additional working interest in its Kentucky operations connected to the Company’s ongoing efforts to refinance its loan agreement.
Maximilian - Third Amendment to Amended and Restated Loan Agreement
Subsequent Event [Line Items]
Credit facility, reduction to required monthly payments	The Company entered into a Third Amendment to the Amended and Restated Loan and Security Agreement and Second Warrant Amendment with Maximilian, which amended the Company’s loan agreement with Maximilian (the “Maximilian Amendment”). Pursuant to the Maximilian Amendment, Maximilian agreed to a reduction in the Company’s monthly payments under the loan agreement to $50,000 per month for a period of six months ending on February 29, 2016. The reduction in monthly payments allows for additional funds to be used by the Company in drilling and completing additional wells in Kentucky. As consideration for the reduction in the monthly payment amount, the Company agreed that twenty percent of the amount by which the monthly payment was reduced would be added to the loan balance, and the portion of the monthly payment savings that constitutes savings in interest or commitment fees would be treated as an additional advance of principal under the loan agreement (the “Deemed Advances”). The Company also agreed to grant to Maximilian an overriding royalty interest in four wells it drills of 1.5% of its working interest in such wells, subject to reduction connected to the Company’s ongoing efforts to refinance its loan agreement. As part of the Maximilian Amendment, the Company also agreed to extend the expiration date of the warrants held by Maximilian to purchase up to 6,550,281 shares of common stock of the Company to August 28, 2018.

XML 12 R48.htm IDEA: XBRL DOCUMENT

Stockholders' Deficit (Details Narrative)	6 Months Ended	12 Months Ended
Stockholders' Deficit (Details Narrative)	Aug. 31, 2015 number $ / shares shares	Feb. 28, 2015 number $ / shares shares	Feb. 28, 2014 number shares	Feb. 28, 2013 number shares	Feb. 29, 2012 number shares	Feb. 28, 2011 number shares	Feb. 28, 2010 number shares	Feb. 28, 2009 number shares	Feb. 29, 2008 number shares
Class of Stock [Line Items]
Preferred stock, par value in dollars \| $ / shares	$ 0.001	$ 0.001
Preferred stock, shares authorized	10,000,000	10,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Series A preferred shares converted to common stock	(675,200)
Shares of common stock issued from conversion	2,025,600
Accredited investors \| number	43
Common stock, par value in dollars \| $ / shares	$ 0.001	$ 0.001
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	51,487,373	51,457,373
Common stock, shares outstanding	51,487,373	51,457,373
Series A Convertible Preferred Stock
Class of Stock [Line Items]
Preferred stock, par value in dollars \| $ / shares	$ 0.001	$ 0.001
Preferred stock, shares authorized	2,400,000	2,400,000
Preferred stock, shares issued	724,565	734,565
Preferred stock, shares outstanding	724,565	734,565
Series A preferred shares converted to common stock	(10,000)	(3,000)	(151,000)	(18,000)	0	(102,000)	(51,900)	(237,000)	(102,300)
Shares of common stock issued from conversion	30,000	9,000	453,000	54,000	0	306,000	155,700	711,000	306,900
Preferred stock, cumulative dividend rate	6.00%	6.00%
Accredited investors \| number	1	1	9	2	0	4	4	12	10
Preferred Stock
Class of Stock [Line Items]
Preferred stock, par value in dollars \| $ / shares	$ 0.001
Preferred stock, shares authorized	10,000,000
Common Stock
Class of Stock [Line Items]
Shares of common stock issued from conversion	30,000
Common stock, par value in dollars \| $ / shares	$ 0.001
Common stock, shares authorized	200,000,000
Common stock, shares issued	51,487,373	51,457,373
Common stock, shares outstanding	51,487,373	51,457,373

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Stockholders' Deficit - Preferred Stock Dividends Earned (Details)	6 Months Ended	12 Months Ended
	Aug. 31, 2015 USD ($) number	Feb. 28, 2015 USD ($) number	Feb. 28, 2014 USD ($) number	Feb. 28, 2013 USD ($) number	Feb. 29, 2012 USD ($) number	Feb. 28, 2011 USD ($) number	Feb. 28, 2010 USD ($) number	Feb. 28, 2009 USD ($) number	Feb. 29, 2008 USD ($) number	Feb. 28, 2007 USD ($) number
Equity [Abstract]
Preferred shareholders at period end \| number	58	58	59	68	70	70	74	78	90	100
Earned dividends	$ 65,897	$ 132,634	$ 151,323	$ 161,906	$ 163,624	$ 173,707	$ 189,973	$ 209,973	$ 242,126	$ 155,311
Total accumulated dividends	$ 1,646,474

XML 15 R33.htm IDEA: XBRL DOCUMENT

Concentration of Credit Risk - Schedule of Concentration of Risk, by Risk Factor (Details) - USD ($)	6 Months Ended	12 Months Ended
	Aug. 31, 2015	Feb. 28, 2015
Concentration Risk [Line Items]
Revenue receivable	$ 123,763	$ 202,732
Percent of revenue	100.00%	100.00%
Customer Concentration Risk \| Accounts Receivable \| Plains Marketing (California - East Slopes Project (Oil))
Concentration Risk [Line Items]
Revenue receivable	$ 69,547	$ 95,150
Percent of revenue	56.20%	46.90%
Customer Concentration Risk \| Accounts Receivable \| Jefferson Gas (Kentucky - Twin Bottoms Field (Gas))
Concentration Risk [Line Items]
Revenue receivable	$ 8,201	$ 16,676
Percent of revenue	6.60%	8.20%
Customer Concentration Risk \| Accounts Receivable \| Appalachian Oil (Kentucky - Twin Bottoms Field (Oil))
Concentration Risk [Line Items]
Revenue receivable	$ 46,015	$ 90,906
Percent of revenue	37.20%	44.90%

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Production Revenue Receivable (Tables)
6 Months Ended

Aug. 31, 2015

Receivables [Abstract]

Schedule of Production Revenue Receivable

August 31, 2015 February 28, 2015

Production revenue receivable – current $ 95,000 $ 120,000

Production revenue receivable – non-current - 35,000

$ 95,000 $ 155,000

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Warrants (Details Narrative) - USD ($)
6 Months Ended 12 Months Ended

Aug. 31, 2015

Feb. 28, 2010

Equity [Abstract]

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Warrants issued 150,000

Outstanding warrants, weighted average exercise price $ 0.06

Weighted average remaining life 1 year 2 months

Intrinsic value $ 0

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Accounts Payable (Details Narrative) - USD ($)
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Aug. 31, 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 $ 246,349

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Production Revenue Receivable (Details Narrative) - USD ($)

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Feb. 28, 2015

Receivables [Abstract]

Production revenue receivables $ 95,000 $ 155,000

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Net operating loss carryforwards $ 9,595,165 $ 9,188,905

Oil and gas properties (1,429,835) (1,436,249)

Stock based compensation 88,723 88,723

Other (153,251) (102,899)

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Stockholders' Deficit - Schedule of Common Stock Outstanding (Details)
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Common Stock Outstanding [Roll Forward]

Common Stock, Issued and Outstanding, February 28, 2015 51,457,373

Conversion of Series A Convertible Preferred Stock to common stock 30,000

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Common Stock, Issued and Outstanding, August 31, 2015 51,487,373

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Concentration of Credit Risk
6 Months Ended

Aug. 31, 2015

Risks and Uncertainties [Abstract]

Concentration of Credit Risk
NOTE 4 — CONCENTRATION OF CREDIT RISK:

Substantially all of the Company’s trade 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 including lower oil prices 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 August 31, 2015 and February 28, 2015, as all joint interest owners have a history of paying their obligations.

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 August 31, 2015 and February 28, 2015 these three individual customers represented 100.0% of crude oil and natural gas revenue accounts receivable. If these buyers are unable to resell their products or if they lose a significant sales contract then the Company may incur difficulties in selling its oil and natural gas production.

The Company’s accounts receivable from Kentucky and California oil and natural gas sales at August 31, 2015 and February 28, 2015 are set forth in the table below.

August 31, 2015 February 28, 2015

Project Customer
Revenue

Receivable
Percentage
Revenue

Receivable
Percentage

Kentucky – Twin Bottoms Field (Oil) Appalachian Oil $ 46,015 37.2% $ 90,906 44.9%

Kentucky – Twin Bottoms Field (Natural gas) Jefferson Gas 8,201 6.6% 16,676 8.2%

California – East Slopes Project (Oil) Plains Marketing 69,547 56.2% 95,150 46.9%

$ 123,763 100.0% $ 202,732 100.0%

Other receivables balances primarily include amounts advanced to certain minority working interest partners in Kentucky and monthly principal and interest receivable on the loan to App Energy, LLC, a Kentucky limited liability company (“App Energy”). For additional information on the App Energy loan refer to the discussion in Note 8 – Note Receivable.

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Short-Term and Long-Term Borrowings - Credit Facility - Maximilian Loan (Details) - Revolving Credit Facility - USD ($)

Aug. 31, 2015

Feb. 28, 2015

Line of Credit Facility [Line Items]

Current debt, note $ 2,840,442 $ 4,823,325

Current debt, note discount (119,830) (132,114)

Current debt, note balance 2,720,612 4,691,211

Non-current debt, note 10,057,910 8,663,458

Non-current debt, note discount (16,039) (71,951)

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Stockholders' Deficit (Tables)
6 Months Ended

Aug. 31, 2015

Equity [Abstract]

Schedule of Stockholder's Equity

Fiscal Period

Shares of Series

A Preferred

Converted to

Common Stock

Shares of

Common Stock

Issued from

Conversion

Number of

Accredited

Investors

Year Ended February 29, 2008 102,300 306,900 10

Year Ended February 28, 2009 237,000 711,000 12

Year Ended February 28, 2010 51,900 155,700 4

Year Ended February 28, 2011 102,000 306,000 4

Year Ended February 29, 2012 - - -

Year Ended February 28, 2013 18,000 54,000 2

Year Ended February 28, 2014 151,000 453,000 9

Year Ended February 28, 2015 3,000 9,000 1

Six Months Ended August 31, 2015 10,000 30,000 1

Totals 675,200 2,025,600 43

Schedule of Dividends Payable

Fiscal Period Shareholders at Period End Earned Dividends

Year Ended February 28, 2007 100 $ 155,311

Year Ended February 29, 2008 90 242,126

Year Ended February 28, 2009 78 209,973

Year Ended February 28, 2010 74 189,973

Year Ended February 28, 2011 70 173,707

Year Ended February 29, 2012 70 163,624

Year Ended February 28, 2013 68 161,906

Year Ended February 28, 2014 59 151,323

Year Ended February 28, 2015 58 132,634

Six Months Ended August 31, 2015 58 65,897

Total Accumulated Dividends $ 1,646,474

Schedule of Common Stock Outstanding

Common Stock

Balance
Par Value

Common stock, Issued and Outstanding, February 28, 2015 51,457,373

Conversion of Series A Convertible Preferred Stock to Common Stock 30,000 $ 30

Common stock, Issued and Outstanding, August 31, 2015 51,487,373

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Short-Term and Long-Term Borrowings (Tables)
6 Months Ended

Aug. 31, 2015

Debt Disclosure [Abstract]

Schedule of Debt

Current

August 31, 2015 February 28, 2015

Maximilian note $ 2,840,442 $ 4,823,325

Maximilian note - discount (119,830) (132,114)

$ 2,720,612 $ 4,691,211

Non-Current

August 31, 2015 February 28, 2015

Maximilian note $ 10,057,910 $ 8,663,458

Maximilian note - discount (16,039) (71,951)

$ 10,041,871 $ 8,591,507

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Short-Term and Long-Term Borrowings (Details Narrative) - USD ($)
1 Months Ended 3 Months Ended 6 Months Ended 12 Months Ended

Aug. 31, 2014

Oct. 31, 2012

May. 31, 2015

May. 31, 2014

Aug. 31, 2015

Aug. 31, 2014

Aug. 31, 2013

Feb. 28, 2010

May. 20, 2015

Feb. 28, 2015

Debt Instrument [Line Items]

Warrants outstanding 8,156,401

Warrants exercised 30,000

Warrants, exercise price $ 0.06

Amortization of debt discount $ 68,196 $ 84,635

Common stock issued, shares 51,487,373 51,457,373

Notes payable, related party $ 250,100 $ 250,100

Share-for-Warrant Exchange

Debt Instrument [Line Items]

Warrants issued 427,729

Stock repurchased and retired, shares 427,729

12% Subordinated Notes

Debt Instrument [Line Items]

Interest rate 12.00%

Maturity date Jan. 29, 2017

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 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.

Subordinate notes, outstanding balance $ 565,000 565,000

Warrants outstanding 980,000

Warrants, exercise price $ 0.14

Line of Credit | UBS Bank USA

Debt Instrument [Line Items]

Maximum borrowing $ 890,000

Line of credit, amount outstanding 855,333

Line of credit, interest expense $ 15,468

Line of credit, interest rate description 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.

Revolving Credit Facility

Debt Instrument [Line Items]

Unamortized debt discount $ 119,830 132,114

Revolving Credit Facility | Maximilian Loan

Debt Instrument [Line Items]

Warrants outstanding 316,617

Warrants issued 2,435,517

Warrants, exercise price $ 0.044

Warrant expiration date Oct. 31, 2017

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 $ 68,196

Unamortized debt discount 135,869

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

Credit facility, expiration date Oct. 31, 2016

Minimum commitment terms Minimum commitment of $2,500,000

Commitment fee percentage 0.50%

Line of credit facility, interest rate 18.00%

Revolving Credit Facility | Maximilian - Amended and Restated Loan Agreement

Debt Instrument [Line Items]

Warrants issued 6,100,000

Warrants, exercise price $ 0.10

Warrants, exercisable date Aug. 28, 2013

Warrant expiration date Aug. 28, 2016

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

Credit facility, expiration date Aug. 28, 2017

Commitment fee percentage 0.50%

Line of credit facility, interest rate 12.00%

Common stock issued, shares 6,100,000

Revolving Credit Facility | 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. 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%.

Stock repurchased and retired, shares 5,694,823

Stock repurchased and retired, value $ 1,708,447

Revolving Credit Facility | Maximilian- Second Amendment to Amended and Restated Loan Agreement

Debt Instrument [Line Items]

Warrants, exercise price $ 0.04

Credit facility, reduction to required monthly payments The 2nd Amendment modified the calculation of the required monthly payment for a three-month period ending June 30, 2015. As consideration for entering into the loan modification, the Company agreed to modify the exercise price of the warrants Maximilian currently holds from $0.10 to $0.04.

Chief Executive Officer

Debt Instrument [Line Items]

Notes payable, related party $ 250,100 $ 250,100

X

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Warrants (Tables)
6 Months Ended

Aug. 31, 2015

Equity [Abstract]

Schedule of Stockholders' Equity Note Warrants and Rights

Warrants
Exercise

Price

Remaining

Life

(Years)

Exercisable

Warrants

Remaining

12% Subordinated notes 1,190,000 $0.14 1.42 980,000

Warrants issued in 2012 for debt financing 2,435,517 $0.044 2.17 316,617

Warrants issued for Kentucky oil project 3,498,601 $0.04 1.00 3,498,601

Warrants issued for Kentucky debt financing 2,623,951 $0.04 1.00 2,623,951

Warrants issued for Kentucky debt financing 309,503 $0.214 3.00 309,503

Warrants issued in share-for-warrant exchange 427,729 $0.04 1.00 427,729

10,485,301 8,156,401

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Income Taxes (Tables)
6 Months Ended

Aug. 31, 2015

Income Tax Disclosure [Abstract]

Schedule of Components of Income Tax Expense Benefit

August 31, 2015 February 28, 2015

Computed at U.S. and state statutory rates (40%) $ (421,059) $ (293,176)

Permanent differences 58,737 142,925

Changes in valuation allowance 362,322 150,251

$ - $ -

Schedule of Deferred Tax Assets and Liabilities

August 31, 2015 February 28, 2015

Deferred tax assets:

Net operating loss carryforwards $ 9,595,165 $ 9,188,905

Oil and gas properties (1,429,835) (1,436,249)

Stock based compensation 88,723 88,723

Other (153,251) (102,899)

Less valuation allowance (8,100,802) (7,738,480)

$ - $ -

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Recent Accounting Pronouncements
6 Months Ended

Aug. 31, 2015

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

Recent Accounting Pronouncements
NOTE 3 — RECENT ACCOUNTING PRONOUNCEMENTS:

There are no new accounting pronouncements issued or effective that have had, or are expected to have, a material impact on the Company’s financial statements.

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Going Concern (Details Narrative)

Aug. 31, 2015

USD ($)

a

number

Feb. 28, 2015

USD ($)

Oil and Gas Delivery Commitments and Contracts [Line Items]

Accumulated deficit | $ $ 29,258,170 $ 28,205,516

Working capital deficit | $ $ 5,405,641

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 | a 7,300

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Note Receivable - Schedule of Note Receivables (Details) - USD ($)

Aug. 31, 2015

Feb. 28, 2015

Receivables [Abstract]

Note receivable, current $ 281,457 $ 1,320,944

Note receivable, non-current 3,841,043 3,429,056

Note receivable $ 4,122,500 $ 4,750,000

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Income Taxes (Details Narrative) - USD ($)
6 Months Ended 12 Months Ended

Aug. 31, 2015

Feb. 28, 2015

Income Tax Disclosure [Abstract]

Net operating loss carryforwards, federal and state, approximate $ 23,987,913

Net operating loss carryforwards, expiration date Feb. 28, 2024

Approximate increase in valuation allowance $ 362,322 $ 150,251

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Balance Sheets (Unaudited) - USD ($)

Aug. 31, 2015

Feb. 28, 2015

CURRENT ASSETS:

Cash and cash equivalents $ 122,492 $ 496,772

Accounts receivable:

Oil and natural gas sales 123,763 202,732

Joint interest participants 53,686 51,382

Other receivables, net 141,754 160,996

Production revenue receivable, current 95,000 120,000

Prepaid expenses and other current assets 216,700 201,693

Note receivable, current 281,457 1,320,944

Total current assets 1,034,852 2,554,519

OIL AND NATURAL GAS PROPERTIES, successful efforts method, net

Proved properties 4,259,275 4,379,606

Unproved properties 737,218 733,478

PREPAID DRILLING COSTS 16,452 16,452

PRODUCTION REVENUE RECEIVABLE, NON-CURRENT 0 35,000

DEFERRED FINANCING COSTS, NET 846,187 1,058,751

NOTE RECEIVABLE, NON-CURRENT 3,841,043 3,429,056

OTHER ASSETS 106,241 106,199

Total assets 10,841,268 12,313,061

CURRENT LIABILITIES:

Accounts payable and other accrued liabilities 1,497,010 1,435,677

Accounts payable, related parties 948,826 905,891

Accrued interest 168,612 158,797

Notes payable, related party 250,100 250,100

Debt, current portion, net 2,720,612 4,691,211

Line of credit 855,333 869,865

Total current liabilities 6,440,493 8,311,541

LONG TERM LIABILITIES:

12% Notes payable, net 315,000 315,000

12% Notes payable, related party, net 250,000 250,000

Debt, non-current portion, net 10,041,871 8,591,507

Asset retirement obligation 31,148 29,603

Total liabilities $ 17,078,512 $ 17,497,651

COMMITMENTS AND CONTINGENCIES

STOCKHOLDERS' DEFICIT:

Preferred stock $ 0 $ 0

Common stock 51,487 51,457

Additional paid-in capital 22,968,714 22,968,734

Accumulated deficit (29,258,170) (28,205,516)

Total stockholders' deficit (6,237,244) (5,184,590)

Total liabilities and stockholders' deficit 10,841,268 12,313,061

Series A Convertible Preferred Stock

STOCKHOLDERS' DEFICIT:

Preferred stock $ 725 $ 735

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Stockholders' Deficit - Conversions of Series A Preferred Stock (Details)
6 Months Ended 12 Months Ended

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Series A preferred shares converted to common stock (675,200)

Shares of common stock issued from conversion 2,025,600

Accredited investors | number 43

Series A Convertible Preferred Stock

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Organization and Basis of Presentation
6 Months Ended

Aug. 31, 2015

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization and Basis of Presentation
NOTE 1 — ORGANIZATION AND BASIS OF PRESENTATION:

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 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 gas production is sold under contracts which are market-sensitive. Accordingly, the Company’s financial condition, results of operations, and capital resources are highly dependent upon prevailing market prices of, and demand for, 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 natural 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.

Basis of Presentation

The accompanying unaudited interim financial statements and notes for the Company have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial information and with the instructions to Form 10-Q for quarterly reports under Section 13 or 15(d) of the Securities Exchange Act of 1934 (the “Exchange Act”). Accordingly, they do not include all of the information and footnote disclosures normally required by accounting principles generally accepted in the United States of America for complete financial statements.

In the opinion of management, all adjustments considered necessary for a fair presentation of the financial statements have been included and such adjustments are of a normal recurring nature. Operating results for the six months ended August 31, 2015 are not necessarily indicative of the results that may be expected for the fiscal year ending February 29, 2016.

These financial statements should be read in conjunction with the audited financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the fiscal year ended February 28, 2015.

Use of Estimates

In preparing financial statements in conformity with accounting principles generally accepted in the United States of America, management is required to make estimates and assumptions. These estimates and assumptions may affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, and revenues and expenses during the reporting period. Actual results could differ materially from those estimates. The accounting policies most affected by management’s estimates and assumptions are as follows:

•   The reliance on estimates of proved reserves to compute the provision for depreciation, depletion and amortization and to determine the amount of any impairment of proved properties;

•   The valuation of unproved acreage and proved oil and 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 abandonment obligations.

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.

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Oil and Gas Properties - Capitalized Costs Relating to Oil and Gas Activities (Details) - USD ($)

Aug. 31, 2015

Feb. 28, 2015

Oil and Gas Exploration and Production Industries Disclosures [Abstract]

Proved leasehold costs $ 699,417 $ 695,231

Unproved leasehold costs 737,218 733,478

Costs of wells and development 678,614 542,563

Capitalized exploratory well costs 5,304,632 5,308,876

Total cost of oil and gas properties 7,419,881 7,280,148

Accumulated depletion, depreciation, amortization and impairment (2,423,388) (2,167,064)

Net oil and gas properties $ 4,996,493 $ 5,113,084

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Accounting Policies (Policies)
6 Months Ended

Aug. 31, 2015

Accounting Policies [Abstract]

Basis of Presentation
Basis of Presentation

The accompanying unaudited interim financial statements and notes for the Company have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial information and with the instructions to Form 10-Q for quarterly reports under Section 13 or 15(d) of the Securities Exchange Act of 1934 (the “Exchange Act”). Accordingly, they do not include all of the information and footnote disclosures normally required by accounting principles generally accepted in the United States of America for complete financial statements.

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These financial statements should be read in conjunction with the audited financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the fiscal year ended February 28, 2015.

Use of Estimates
Use of Estimates

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•   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 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 abandonment obligations.

Reclassifications
Reclassifications

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Production Revenue Receivable - Schedule of Production Revenue Receivable (Details) - USD ($)

Aug. 31, 2015

Feb. 28, 2015

Receivables [Abstract]

Production revenue receivable, current $ 95,000 $ 120,000

Production revenue receivable, non-current 0 35,000

Production revenue receivables $ 95,000 $ 155,000

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Oil and Gas Properties (Tables)
6 Months Ended

Aug. 31, 2015

Oil and Gas Exploration and Production Industries Disclosures [Abstract]

Capitalized Costs Relating to Oil and Gas Activities

August 31, 2015 February 28, 2015

Proved leasehold costs $ 699,417 $ 695,231

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Accumulated depletion, depreciation, amortization and impairment (2,423,388) (2,167,064)

Net oil and gas properties $ 4,996,493 $ 5,113,084

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Going Concern
6 Months Ended

Aug. 31, 2015

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Going Concern
NOTE 2 — GOING CONCERN:

Financial Condition

The Company’s financial statements for the six months ended August 31, 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. The Company has incurred net losses since entering the oil and natural gas exploration industry and as of August 31, 2015 has an accumulated deficit of $29,258,170 and a working capital deficit of $5,405,641 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 oil wells in its East Slopes Project located in Kern County, California (the “East Slopes Project”). The revenue from these wells has created a steady and reliable source of revenue. The Company’s average working interest in these wells is 36.6% and the average net revenue interest (“NRI”) is 28.4% for these same wells.

Additionally, the Company has become involved in a shallow oil development project in an existing natural gas field in Lawrence County, Kentucky, through its acquisition of an average 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 13 producing horizontal oil wells in the Twin Bottoms Field with some supplementary natural gas production. The Company’s average working interest in these 13 horizontal oil wells is 22.4% and the average NRI 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 Kentucky and California 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, while the Company has experienced revenue growth that has resulted in positive cash flow from its oil and natural gas properties, it has not yet established consistent positive cash flow on a company-wide basis primarily due to lower oil prices. It will be necessary for the Company to obtain additional financing 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 plan to continue as a going concern.

Daybreak’s financial statements as of August 31, 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.

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Balance Sheets (Parenthetical) - $ / shares

Aug. 31, 2015

Feb. 28, 2015

Preferred stock, par value in dollars $ 0.001 $ 0.001

Preferred stock, shares authorized 10,000,000 10,000,000

Preferred stock, shares issued 0 0

Preferred stock, shares outstanding 0 0

Common stock, par value in dollars $ 0.001 $ 0.001

Common stock, shares authorized 200,000,000 200,000,000

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Series A Convertible Preferred Stock

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Preferred stock, shares authorized 2,400,000 2,400,000

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Preferred stock, shares outstanding 724,565 734,565

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Stockholders' Deficit
6 Months Ended

Aug. 31, 2015

Equity [Abstract]

Stockholders' Deficit
NOTE 12 — STOCKHOLDERS’ DEFICIT:

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. At August 31, 2015, there were 724,565 shares issued and outstanding, that had not been converted into our common stock. As of August 31, 2015, there are 43 accredited investors who have converted 675,200 Series A Preferred shares into 2,025,600 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 Preferred

Converted to

Common Stock

Shares of

Common Stock

Issued from

Conversion

Number of

Accredited

Investors

Year Ended February 29, 2008 102,300 306,900 10

Year Ended February 28, 2009 237,000 711,000 12

Year Ended February 28, 2010 51,900 155,700 4

Year Ended February 28, 2011 102,000 306,000 4

Year Ended February 29, 2012 - - -

Year Ended February 28, 2013 18,000 54,000 2

Year Ended February 28, 2014 151,000 453,000 9

Year Ended February 28, 2015 3,000 9,000 1

Six Months Ended August 31, 2015 10,000 30,000 1

Totals 675,200 2,025,600 43

Holders of Series A Preferred shall be paid dividends, in the amount of 6% of the original purchase price per annum. 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. As of August 31, 2015, no dividends have been paid. Dividends earned since issuance for each fiscal year and the six months ended August 31, 2015 are set forth in the table below:

Fiscal Period Shareholders at Period End Earned Dividends

Year Ended February 28, 2007 100 $ 155,311

Year Ended February 29, 2008 90 242,126

Year Ended February 28, 2009 78 209,973

Year Ended February 28, 2010 74 189,973

Year Ended February 28, 2011 70 173,707

Year Ended February 29, 2012 70 163,624

Year Ended February 28, 2013 68 161,906

Year Ended February 28, 2014 59 151,323

Year Ended February 28, 2015 58 132,634

Six Months Ended August 31, 2015 58 65,897

Total Accumulated Dividends $ 1,646,474

Common Stock

The Company is authorized to issue up to 200,000,000 shares of $0.001 par value common stock of which 51,487,373 shares were issued and outstanding as of August 31, 2015. In comparison, at February 28, 2015, a total of 51,457,373 shares were issued and outstanding. The increase of 30,000 shares was attributable as shown below:

Common Stock

Balance
Par Value

Common stock, Issued and Outstanding, February 28, 2015 51,457,373

Conversion of Series A Convertible Preferred Stock to Common Stock 30,000 $ 30

Common stock, Issued and Outstanding, August 31, 2015 51,487,373

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6 Months Ended

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Oct. 13, 2015

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Entity Registrant Name Daybreak Oil & Gas, Inc.

Entity Central Index Key 0001164256

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Current Fiscal Year End Date --02-29

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Warrants
6 Months Ended

Aug. 31, 2015

Equity [Abstract]

Warrants
NOTE 13 — WARRANTS:

Warrants outstanding and exercisable as of August 31, 2015 are set forth in the table below:

Warrants
Exercise

Price

Remaining

Life

(Years)

Exercisable

Warrants

Remaining

12% Subordinated notes 1,190,000 $0.14 1.42 980,000

Warrants issued in 2012 for debt financing 2,435,517 $0.044 2.17 316,617

Warrants issued for Kentucky oil project 3,498,601 $0.04 1.00 3,498,601

Warrants issued for Kentucky debt financing 2,623,951 $0.04 1.00 2,623,951

Warrants issued for Kentucky debt financing 309,503 $0.214 3.00 309,503

Warrants issued in share-for-warrant exchange 427,729 $0.04 1.00 427,729

10,485,301 8,156,401

There were 150,000 warrants issued in 2010 for services that expired during the six months ended August 31, 2015. During the six months ended August 31, 2015 there were no warrants issued or exercised. The remaining outstanding warrants as of August 31, 2015, have a weighted average exercise price of $0.06, a weighted average remaining life of 1.17 years, and an intrinsic value of -$0-.

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Statements of Operations (Unaudited) - USD ($)
3 Months Ended 6 Months Ended

Aug. 31, 2015

Aug. 31, 2014

Aug. 31, 2015

Aug. 31, 2014

REVENUE:

Oil and natural gas sales $ 369,834 $ 1,044,296 $ 811,118 $ 1,854,725

OPERATING EXPENSES:

Production expenses 70,001 79,955 145,606 165,485

Exploration and drilling 8,400 6,027 20,067 12,810

Depreciation, depletion, amortization and impairment 118,889 171,516 257,729 291,493

General and administrative 248,855 265,105 534,503 619,924

Total operating expenses 446,145 522,603 957,905 1,089,712

OPERATING INCOME (LOSS) (76,311) 521,693 (146,787) 765,013

OTHER INCOME (EXPENSE):

Interest income 201,851 290,008 424,604 454,846

Interest expense (661,604) (697,187) (1,330,471) (1,363,004)

Total other income (expense) (459,753) (407,179) (905,867) (908,158)

NET INCOME (LOSS) (536,064) 114,514 (1,052,654) (143,145)

Cumulative convertible preferred stock dividend requirement (32,872) (33,462) (65,896) (66,923)

NET INCOME (LOSS) AVAILABLE TO COMMON SHAREHOLDERS $ (568,936) $ 81,052 $ (1,118,550) $ (210,068)

NET INCOME (LOSS) PER COMMON SHARE, Basic $ 0.01 $ 0.00 $ (0.02) $ 0.00

NET INCOME (LOSS) PER COMMON SHARE, Diluted $ 0.01 $ 0.00 $ (0.02) $ 0.00

WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING, Basic 51,487,373 56,422,568 51,482,273 56,819,345

WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING, Diluted 51,487,373 61,376,698 51,482,273 56,819,345

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Deferred Financing Costs
6 Months Ended

Aug. 31, 2015

Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]

Deferred Financing Costs
NOTE 7 — DEFERRED FINANCING COSTS:

Deferred financing costs at August 31, 2015 and February 28, 2015 relate 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:

August 31, 2015 February 28, 2015

Deferred financing costs – loan fees $ 151,139 $ 151,139

Deferred financing costs – loan commissions 630,662 630,662

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 1,732,121

Accumulated amortization (885,934) (673,370)

$ 846,187 $ 1,058,751

The Company recognized amortization expense of $212,564 for the six months ended August 31, 2015.

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Production Revenue Receivable
6 Months Ended

Aug. 31, 2015

Receivables [Abstract]

Production Revenue Receivable
NOTE 6 — PRODUCTION REVENUE RECEIVABLE:

Production revenue receivable balances of $95,000 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 August 31, 2015 and February 28, 2015 are set forth in the table below:

August 31, 2015 February 28, 2015

Production revenue receivable – current $ 95,000 $ 120,000

Production revenue receivable – non-current - 35,000

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Concentration of Credit Risk (Tables)
6 Months Ended

Aug. 31, 2015

Risks and Uncertainties [Abstract]

Schedule of Concentration of Risk, by Risk Factor

August 31, 2015 February 28, 2015

Project Customer
Revenue

Receivable
Percentage
Revenue

Receivable
Percentage

Kentucky – Twin Bottoms Field (Oil) Appalachian Oil $ 46,015 37.2% $ 90,906 44.9%

Kentucky – Twin Bottoms Field (Natural gas) Jefferson Gas 8,201 6.6% 16,676 8.2%

California – East Slopes Project (Oil) Plains Marketing 69,547 56.2% 95,150 46.9%

$ 123,763 100.0% $ 202,732 100.0%

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Income Taxes
6 Months Ended

Aug. 31, 2015

Income Tax Disclosure [Abstract]

Income Taxes

NOTE 14 — 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 rates to income from continuing operations before income taxes is set forth in the table below:

August 31, 2015 February 28, 2015

Computed at U.S. and state statutory rates (40%) $ (421,059) $ (293,176)

Permanent differences 58,737 142,925

Changes in valuation allowance 362,322 150,251

$ - $ -

Tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred liabilities are set forth in the table below:

August 31, 2015 February 28, 2015

Deferred tax assets:

Net operating loss carryforwards $ 9,595,165 $ 9,188,905

Oil and gas properties (1,429,835) (1,436,249)

Stock based compensation 88,723 88,723

Other (153,251) (102,899)

Less valuation allowance (8,100,802) (7,738,480)

$ - $ -

At August 31, 2015, Daybreak had estimated net operating loss (“NOL”) carryforwards for federal and state income tax purposes of approximately $23,987,913 which will begin to expire, if unused, beginning in 2024. The valuation allowance increased $362,322 for the six months ended August 31, 2015 and increased by $150,251 for the year ended February 28, 2015. Section 382 of the Internal Revenue Code places annual limitations on the Company’s NOL carryforward.

The above estimates are based on management’s decisions concerning elections which could change the relationship between net income and taxable income. Management decisions are made annually and could cause estimates to vary significantly.

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Accounts Payable - Related Parties
6 Months Ended

Aug. 31, 2015

Related Party Transactions [Abstract]

Accounts Payable - Related Parties
NOTE 10 — ACCOUNTS PAYABLE- RELATED PARTIES:

The August 31, 2015 and February 28, 2015 accounts payable – related parties balances were comprised primarily of salaries of the Company’s Executive Officers and certain employees; directors’ fees; expense reimbursements; and interest to the Company’s President and Chief Executive Officer on the 12% Subordinated Notes further described in Note 11 – Short-Term and Long-Term Borrowings below. Payment of these items has been deferred until the Company’s cash flow situation improves.

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Note Receivable
6 Months Ended

Aug. 31, 2015

Receivables [Abstract]

Note Receivable
NOTE 8 — NOTE RECEIVABLE:

At August 31, 2015, the Company had advanced approximately $8.3 million to App Energy through its credit facility. Note receivable balances at August 31, 2015 and February 28, 2015 are set forth in the table below:

August 31, 2015 February 28, 2015

Note receivable – current $ 281,457 $ 1,320,944

Note receivable – non-current 3,841,043 3,429,056

$ 4,122,500 $ 4,750,000

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Accounts Payable
6 Months Ended

Aug. 31, 2015

Payables and Accruals [Abstract]

Accounts Payable
NOTE 9 — ACCOUNTS PAYABLE:

On March 1, 2009, the Company became the operator for its East Slopes Project. Additionally, the Company at that time assumed certain original partners’ default liability of approximately $1.5 million representing a 25% working interest in the drilling and completion costs associated with the East Slopes Project four earning well program. The Company subsequently sold the same 25% working interest on June 11, 2009. Of the $1.5 million default, $246,349 remains unpaid and is included in the August 31, 2015 accounts payable balance.

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Short-Term and Long-Term Borrowings
6 Months Ended

Aug. 31, 2015

Debt Disclosure [Abstract]

Short-Term and Long-Term Borrowings
NOTE 11 — SHORT-TERM AND LONG-TERM BORROWINGS:

Note Payable – Related Party

As of August 31, 2015 and February 28, 2015, the Company’s President and Chief Executive Officer had loaned the Company $250,100 in aggregate that was 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 our President and Chief Executive Officer. Interest is payable monthly at a stated reference rate of 0.249% + 337.5 basis points and totaled $15,468 for the six months ended August 31, 2015. The reference rate is based on the 30 day LIBOR (“London Interbank Offered Rate”) and is subject to change from UBS. At August 31, 2015 the Line of credit had an outstanding balance of $855,333.

Long-term Borrowings

12% Subordinated Notes

The Company’s 12% Subordinated Notes (“the Notes”) issued pursuant to a March 2010 private placement (of which $250,000 was from a related party) accrue interest at 12% per annum, payable semi-annually on January 29th and July 29th. On January 29, 2015, the Company and 12 of the 13 note holders agreed to extend the maturity date of the Notes from January 29, 2015 for an additional two years. The note principal is payable in full at the amended maturity date of the Notes, which is January 29, 2017. The outstanding balance of the 12% Notes was $565,000 at August 31,2015 and February 05, 2015. Should the Board of Directors, on the amended 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.

Maximilian Credit Facility

On October 31, 2012, the Company entered into a loan agreement with Maximilian, 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. 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 original term of the loan. Amortization expense was $68,196 for the six months ended August 31, 2015. Unamortized debt discount was $135,869 at August 31, 2015.

In 2012, 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. As of August 31, 2015, 316,617 of these warrants remain unexercised and outstanding.

Maximilian Credit Facility - Amended and Restated Loan Agreement

In connection with the Company’s acquisition of a working interest from App Energy 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 Energy, as borrower pursuant to a Loan and Security Agreement entered into between the Company and App Energy on August 28, 2013 (See Note 8 – Note Receivable).

The amended loan agreement contains customary covenants for loans 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 Energy 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; and contain an exercise blocker provision that prevents 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 Company’s currently issued and outstanding shares at the time of the exercise. The Company also granted to Maximilian a 50% net profits interest in the Company’s approximate 25% working interest, after the Company recovers its investment in the Kentucky acreage, pursuant to an Assignment of Net Profits Interest entered into as of August 28, 2013 by and between the Company and Maximilian.

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. 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.

On May 20, 2015, the Company entered into a Second Amendment to Amended and Restated Loan and Security Agreement (the”2^nd Amendment”) with Maximilian under its Amended and Restated Loan and Security Agreement dated as of August 28, 2013. The 2^nd Amendment modified the calculation of the required monthly payment for a three-month period ending June 30, 2015. As consideration for entering into the loan modification, the Company agreed to modify the exercise price of the warrants Maximilian currently holds from $0.10 to $0.04. No other terms of the warrant agreement were changed. The Company determined that the modification of the warrant exercise price did not result in any incremental fair value.

With the assistance of Maximilian, the Company is currently working with an investment banking firm to assist in securing refinancing of its debt with Maximilian, since the long-term commitment needed to develop the Kentucky and California projects no longer fits the Maximilian business model. Maximilian is continuing to work with the Company in modifying the credit facility terms during this period of lower hydrocarbon prices.

Current debt balances at August 31, 2015, and February 28, 2015 are set forth in the table below:

August 31, 2015 February 28, 2015

Maximilian note $ 2,840,442 $ 4,823,325

Maximilian note - discount (119,830) (132,114)

$ 2,720,612 $ 4,691,211

Non-current debt balances at August 31, 2015 and February 28, 2015 are set forth in the table below:

August 31, 2015 February 28, 2015

Maximilian note $ 10,057,910 $ 8,663,458

Maximilian note - discount (16,039) (71,951)

$ 10,041,871 $ 8,591,507

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Concentration of Credit Risk (Details Narrative)
6 Months Ended

Aug. 31, 2015

Risks and Uncertainties [Abstract]

Concentration of risk, description 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 August 31, 2015 and February 28, 2015 these three individual customers represented 100.0% of crude oil and natural gas revenue accounts receivable. If these buyers are unable to resell their products or if they lose a significant sales contract then the Company may incur difficulties in selling its oil and natural gas production.

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Income Taxes - Income Tax Expense Benefit Reconciliation (Details) - USD ($)
6 Months Ended 12 Months Ended

Aug. 31, 2015

Feb. 28, 2015

Income Tax Expense Benefit Continuing Operations Income Tax Reconciliation

Computed at U.S. and state statutory rates (40%) $ (421,059) $ (293,176)

Permanent differences 58,737 142,925

Changes in valuation allowance 362,322 150,251

Income tax expense (benefit) $ 0 $ 0

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Subsequent Events
6 Months Ended

Aug. 31, 2015

Subsequent Events [Abstract]

Subsequent Events

NOTE 16 — SUBSEQUENT EVENTS:

On October 14, 2015, the Company entered into a Third Amendment to the Amended and Restated Loan and Security Agreement and Second Warrant Amendment with Maximilian, which amended the Company’s loan agreement with Maximilian (the “Maximilian Amendment”). Pursuant to the Maximilian Amendment, Maximilian agreed to a reduction in the Company’s monthly payments under the loan agreement to $50,000 per month for a period of six months ending on February 29, 2016. The reduction in monthly payments allows for additional funds to be used by the Company in drilling and completing additional wells in Kentucky. As consideration for the reduction in the monthly payment amount, the Company agreed that twenty percent of the amount by which the monthly payment was reduced would be added to the loan balance, and the portion of the monthly payment savings that constitutes savings in interest or commitment fees would be treated as an additional advance of principal under the loan agreement (the “Deemed Advances”). The Company also agreed to grant to Maximilian an overriding royalty interest in four wells it drills of 1.5% of its working interest in such wells, subject to reduction connected to the Company’s ongoing efforts to refinance its loan agreement. As part of the Maximilian Amendment, the Company also agreed to extend the expiration date of the warrants held by Maximilian to purchase up to 6,550,281 shares of common stock of the Company to August 28, 2018.

In connection with entering into the Maximilian Amendment, the Company concurrently entered into a Second Amendment to Loan and Security Agreement with App Energy (the “App Amendment”), which amended the Company’s loan agreement with App Energy in which the Company, as lender, lends to App Energy, as borrower, a portion of the advances it receives pursuant to its loan agreement with Maximilian. The App Amendment provides for a reduction in interest rate and a reduction in monthly payments to be made by App Energy to the Company for the same payment cycles as the reduced payment to be made by the Company under the Maximilian Amendment. The reduction in monthly payments by App Energy will allow App Energy to fund its share of drilling and completing additional wells in Kentucky with the Company. As consideration for the reduction in the monthly payment amount, App Energy agreed that a percentage of the Deemed Advances will be treated as additional advances under the App Energy loan agreement, and that it would fund a portion of the Company’s drilling and development expenses with respect to two wells, subject to a partial refund connected to the Company’s ongoing efforts to refinance its loan agreement. App Energy also agreed to grant to Maximilian an overriding royalty interest on the same terms as the overriding royalty interest agreed to by the Company. Finally, App Energy granted to the Company a time-limited option to purchase additional working interest in its Kentucky operations connected to the Company’s ongoing efforts to refinance its loan agreement.

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Deferred Financing Costs (Tables)
6 Months Ended

Aug. 31, 2015

Deferred Costs, Capitalized, Prepaid, and Other Assets Disclosure [Abstract]

Schedule of Deferred Costs, Capitalized, Prepaid, and Other Assets

August 31, 2015 February 28, 2015

Deferred financing costs – loan fees $ 151,139 $ 151,139

Deferred financing costs – loan commissions 630,662 630,662

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 1,732,121

Accumulated amortization (885,934) (673,370)

$ 846,187 $ 1,058,751

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Warrants - Schedule of Stockholders' Equity Note Warrants and Rights (Details)
6 Months Ended

Aug. 31, 2015

$ / shares

shares

Class of Warrant or Right [Line Items]

Warrants 10,485,301

Exercise price | $ / shares $ 0.06

Remaining life (years) 1 year 2 months

Exercisable warrants remaining 8,156,401

Kentucky Oil Project

Class of Warrant or Right [Line Items]

Warrants 3,498,601

Exercise price | $ / shares $ 0.04

Remaining life (years) 1 year

Exercisable warrants remaining 3,498,601

Share-for-Warrant Exchange

Class of Warrant or Right [Line Items]

Warrants 427,729

Exercise price | $ / shares $ 0.04

Remaining life (years) 1 year

Exercisable warrants remaining 427,729

12% Subordinated Notes

Class of Warrant or Right [Line Items]

Warrants 1,190,000

Exercise price | $ / shares $ 0.14

Remaining life (years) 1 year 5 months

Exercisable warrants remaining 980,000

Debt Financing

Class of Warrant or Right [Line Items]

Warrants 2,435,517

Exercise price | $ / shares $ 0.044

Remaining life (years) 2 years 2 months

Exercisable warrants remaining 316,617

Kentucky Debt Financing #1

Class of Warrant or Right [Line Items]

Warrants 2,623,951

Exercise price | $ / shares $ 0.04

Remaining life (years) 1 year

Exercisable warrants remaining 2,623,951

Kentucky Debt Financing #2

Class of Warrant or Right [Line Items]

Warrants 309,503

Exercise price | $ / shares $ 0.214

Remaining life (years) 3 years

Exercisable warrants remaining 309,503

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Note Receivable (Details Narrative)
6 Months Ended

Aug. 31, 2015

USD ($)

App Energy Note Receivable

Accounts, Notes, Loans and Financing Receivable [Line Items]

Advances to certain minority working interest partners $ 8,300,000

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Statements of Cash Flows (Unaudited) - USD ($)
6 Months Ended

Aug. 31, 2015

Aug. 31, 2014

CASH FLOWS FROM OPERATING ACTIVITIES:

NET LOSS $ (1,052,654) $ (143,145)

Adjustments to reconcile net loss to net cash provided by (used in) operating activities:

Stock compensation 0 2,515

Depreciation, depletion, impairment and ARO expense 257,730 291,493

Amortization of debt discount 68,196 84,635

Amortization of deferred financing costs 212,564 209,844

Interest income (42) (42)

Changes in assets and liabilities:

Accounts receivable, oil and gas sales 78,969 (72,706)

Accounts receivable, joint interest participants (2,304) 187,216

Accounts receivable, other 79,242 (38,197)

Prepaid expenses and other current assets (15,007) 11,791

Accounts payable and other accrued liabilities 57,453 (346,262)

Accounts payable, related parties 42,935 (89,685)

Accrued interest 9,815 72

Net cash provided by (used in) operating activities (263,103) 97,529

CASH FLOWS FROM INVESTING ACTIVITIES:

Additions to oil and natural gas properties (135,714) (667,633)

Prepaid drilling costs 0 (646,938)

Additions to note receivable 0 (4,200,000)

Collections of note receivable 627,500 1,483,960

Deferred interest 0 655

Net cash provided by (used in) investing activities 491,786 (4,029,956)

CASH FLOWS FROM FINANCING ACTIVITIES

Proceeds from long-term debt 0 5,700,000

Payment on long-term debt (588,431) (1,693,348)

Proceeds from warrant conversion 0 7,000

Payment of deferred financing fees 0 (345,000)

Payments on line of credit (14,532) (2,359)

Net cash provided by (used in) financing activities (602,963) 3,666,293

NET DECREASE IN CASH AND CASH EQUIVALENTS (374,280) (266,134)

CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD 496,772 500,431

CASH AND CASH EQUIVALENTS AT END OF PERIOD 122,492 234,297

Cash paid for Interest 1,039,896 1,083,825

Cash paid for Income taxes 0 0

SUPPLEMENTAL CASH FLOW INFORMATION:

Unpaid additions to oil and natural gas properties 3,880 2,426

Conversion of warrants 0 1,874

Share-to-warrant exchange 0 428

ARO asset and liability increase 140 1,906

Increase in note payable for stock acquisition and subsequent retirement 0 1,708,447

Conversion of preferred stock to common stock 30 0

Repurchase of stock through payment of payroll taxes $ 0 $ 490

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Oil and Gas Properties
6 Months Ended

Aug. 31, 2015

Oil and Gas Exploration and Production Industries Disclosures [Abstract]

Oil and Gas Properties
NOTE 5 — OIL AND GAS PROPERTIES:

Oil and gas property balances at August 31, 2015 and February 28, 2015 are set forth in the table below.

August 31, 2015 February 28, 2015

Proved leasehold costs $ 699,417 $ 695,231

Unproved leasehold costs 737,218 733,478

Costs of wells and development 678,614 542,563

Capitalized exploratory well costs 5,304,632 5,308,876

Total cost of oil and gas properties 7,419,881 7,280,148

Accumulated depletion, depreciation, amortization and impairment (2,423,388) (2,167,064)

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Note Receivable (Tables)
6 Months Ended

Aug. 31, 2015

Receivables [Abstract]

Schedule of Accounts, Notes, Loans and Financing Receivables

August 31, 2015 February 28, 2015

Note receivable – current $ 281,457 $ 1,320,944

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Aug. 31, 2015

Feb. 28, 2015

Deferred financing costs, gross $ 1,732,121 $ 1,732,121

Accumulated amortization (885,934) (673,370)

Deferred finance costs, net 846,187 1,058,751

Revolving Credit Facility | Warrant

Deferred financing costs, gross 530,488 530,488

Revolving Credit Facility | Common Stock

Deferred financing costs, gross 419,832 419,832

Revolving Credit Facility | Loan Commissions

Deferred financing costs, gross 630,662 630,662

Revolving Credit Facility | Loan Fees

Deferred financing costs, gross $ 151,139 $ 151,139

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Commitments and Contingencies
6 Months Ended

Aug. 31, 2015

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies
NOTE 15 — COMMITMENTS AND CONTINGENCIES:

Various lawsuits, claims and other contingencies arise in the ordinary course of the Company’s business activities. While the ultimate outcome of any future contingency is not determinable at this time, management believes that any liability or loss resulting therefrom will not materially affect the financial position, results of operations or cash flows of the Company.

The Company, as an owner or lessee and operator of 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 August 31, 2015. There can be no assurance, however, that current regulatory requirements will not change or that past non-compliance with environmental issues will not be discovered on the Company’s oil and gas properties.

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Warrants (Details Narrative) - USD ($)	6 Months Ended	12 Months Ended
Warrants (Details Narrative) - USD ($)	Aug. 31, 2015	Feb. 28, 2010
Equity [Abstract]
Warrants expired	150,000
Warrants issued		150,000
Outstanding warrants, weighted average exercise price	$ 0.06
Weighted average remaining life	1 year 2 months
Intrinsic value	$ 0

Accounts Payable (Details Narrative) - USD ($)	4 Months Ended
Accounts Payable (Details Narrative) - USD ($)	Jun. 30, 2009	Aug. 31, 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		$ 246,349

Production Revenue Receivable (Details Narrative) - USD ($)	Aug. 31, 2015	Feb. 28, 2015
Receivables [Abstract]
Production revenue receivables	$ 95,000	$ 155,000

Income Taxes - Deferred Tax Assets and Liabilities (Details) - USD ($)	Aug. 31, 2015	Feb. 28, 2015
Deferred tax assets:
Net operating loss carryforwards	$ 9,595,165	$ 9,188,905
Oil and gas properties	(1,429,835)	(1,436,249)
Stock based compensation	88,723	88,723
Other	(153,251)	(102,899)
Less valuation allowance	(8,100,802)	(7,738,480)
Deferred tax assets, net	$ 0	$ 0

Stockholders' Deficit - Schedule of Common Stock Outstanding (Details)	6 Months Ended
	Aug. 31, 2015 $ / shares shares
Common Stock Outstanding [Roll Forward]
Common Stock, Issued and Outstanding, February 28, 2015	51,457,373
Conversion of Series A Convertible Preferred Stock to common stock	30,000
Conversion of Series A Convertible Preferred Stock to common stock, par value \| $ / shares	$ 30
Common Stock, Issued and Outstanding, August 31, 2015	51,487,373

Short-Term and Long-Term Borrowings - Credit Facility - Maximilian Loan (Details) - Revolving Credit Facility - USD ($)	Aug. 31, 2015	Feb. 28, 2015
Line of Credit Facility [Line Items]
Current debt, note	$ 2,840,442	$ 4,823,325
Current debt, note discount	(119,830)	(132,114)
Current debt, note balance	2,720,612	4,691,211
Non-current debt, note	10,057,910	8,663,458
Non-current debt, note discount	(16,039)	(71,951)
Non-current debt, note balance	$ 10,041,871	$ 8,591,507

Short-Term and Long-Term Borrowings (Details Narrative) - USD ($)	1 Months Ended		3 Months Ended		6 Months Ended			12 Months Ended
	Aug. 31, 2014	Oct. 31, 2012	May. 31, 2015	May. 31, 2014	Aug. 31, 2015	Aug. 31, 2014	Aug. 31, 2013	Feb. 28, 2010	May. 20, 2015	Feb. 28, 2015
Debt Instrument [Line Items]
Warrants outstanding					8,156,401
Warrants exercised					30,000
Warrants, exercise price					$ 0.06
Amortization of debt discount					$ 68,196	$ 84,635
Common stock issued, shares					51,487,373					51,457,373
Notes payable, related party					$ 250,100					$ 250,100
Share-for-Warrant Exchange
Debt Instrument [Line Items]
Warrants issued				427,729
Stock repurchased and retired, shares				427,729
12% Subordinated Notes
Debt Instrument [Line Items]
Interest rate								12.00%
Maturity date								Jan. 29, 2017
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 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.
Subordinate notes, outstanding balance					$ 565,000					565,000
Warrants outstanding					980,000
Warrants, exercise price					$ 0.14
Line of Credit \| UBS Bank USA
Debt Instrument [Line Items]
Maximum borrowing					$ 890,000
Line of credit, amount outstanding					855,333
Line of credit, interest expense					$ 15,468
Line of credit, interest rate description					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.
Revolving Credit Facility
Debt Instrument [Line Items]
Unamortized debt discount					$ 119,830					132,114
Revolving Credit Facility \| Maximilian Loan
Debt Instrument [Line Items]
Warrants outstanding					316,617
Warrants issued		2,435,517
Warrants, exercise price		$ 0.044
Warrant expiration date		Oct. 31, 2017
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					$ 68,196
Unamortized debt discount					135,869
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
Credit facility, expiration date		Oct. 31, 2016
Minimum commitment terms		Minimum commitment of $2,500,000
Commitment fee percentage		0.50%
Line of credit facility, interest rate		18.00%
Revolving Credit Facility \| Maximilian - Amended and Restated Loan Agreement
Debt Instrument [Line Items]
Warrants issued							6,100,000
Warrants, exercise price							$ 0.10
Warrants, exercisable date							Aug. 28, 2013
Warrant expiration date							Aug. 28, 2016
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
Credit facility, expiration date							Aug. 28, 2017
Commitment fee percentage							0.50%
Line of credit facility, interest rate							12.00%
Common stock issued, shares							6,100,000
Revolving Credit Facility \| 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. 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%.
Stock repurchased and retired, shares	5,694,823
Stock repurchased and retired, value	$ 1,708,447
Revolving Credit Facility \| Maximilian- Second Amendment to Amended and Restated Loan Agreement
Debt Instrument [Line Items]
Warrants, exercise price									$ 0.04
Credit facility, reduction to required monthly payments			The 2nd Amendment modified the calculation of the required monthly payment for a three-month period ending June 30, 2015. As consideration for entering into the loan modification, the Company agreed to modify the exercise price of the warrants Maximilian currently holds from $0.10 to $0.04.
Chief Executive Officer
Debt Instrument [Line Items]
Notes payable, related party					$ 250,100					$ 250,100

Going Concern (Details Narrative)	Aug. 31, 2015 USD ($) a number	Feb. 28, 2015 USD ($)
Oil and Gas Delivery Commitments and Contracts [Line Items]
Accumulated deficit \| $	$ 29,258,170	$ 28,205,516
Working capital deficit \| $	$ 5,405,641
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 \| a	7,300

Note Receivable - Schedule of Note Receivables (Details) - USD ($)	Aug. 31, 2015	Feb. 28, 2015
Receivables [Abstract]
Note receivable, current	$ 281,457	$ 1,320,944
Note receivable, non-current	3,841,043	3,429,056
Note receivable	$ 4,122,500	$ 4,750,000

Income Taxes (Details Narrative) - USD ($)	6 Months Ended	12 Months Ended
Income Taxes (Details Narrative) - USD ($)	Aug. 31, 2015	Feb. 28, 2015
Income Tax Disclosure [Abstract]
Net operating loss carryforwards, federal and state, approximate	$ 23,987,913
Net operating loss carryforwards, expiration date	Feb. 28, 2024
Approximate increase in valuation allowance	$ 362,322	$ 150,251

Balance Sheets (Unaudited) - USD ($)	Aug. 31, 2015	Feb. 28, 2015
CURRENT ASSETS:
Cash and cash equivalents	$ 122,492	$ 496,772
Accounts receivable:
Oil and natural gas sales	123,763	202,732
Joint interest participants	53,686	51,382
Other receivables, net	141,754	160,996
Production revenue receivable, current	95,000	120,000
Prepaid expenses and other current assets	216,700	201,693
Note receivable, current	281,457	1,320,944
Total current assets	1,034,852	2,554,519
OIL AND NATURAL GAS PROPERTIES, successful efforts method, net
Proved properties	4,259,275	4,379,606
Unproved properties	737,218	733,478
PREPAID DRILLING COSTS	16,452	16,452
PRODUCTION REVENUE RECEIVABLE, NON-CURRENT	0	35,000
DEFERRED FINANCING COSTS, NET	846,187	1,058,751
NOTE RECEIVABLE, NON-CURRENT	3,841,043	3,429,056
OTHER ASSETS	106,241	106,199
Total assets	10,841,268	12,313,061
CURRENT LIABILITIES:
Accounts payable and other accrued liabilities	1,497,010	1,435,677
Accounts payable, related parties	948,826	905,891
Accrued interest	168,612	158,797
Notes payable, related party	250,100	250,100
Debt, current portion, net	2,720,612	4,691,211
Line of credit	855,333	869,865
Total current liabilities	6,440,493	8,311,541
LONG TERM LIABILITIES:
12% Notes payable, net	315,000	315,000
12% Notes payable, related party, net	250,000	250,000
Debt, non-current portion, net	10,041,871	8,591,507
Asset retirement obligation	31,148	29,603
Total liabilities	$ 17,078,512	$ 17,497,651
COMMITMENTS AND CONTINGENCIES
STOCKHOLDERS' DEFICIT:
Preferred stock	$ 0	$ 0
Common stock	51,487	51,457
Additional paid-in capital	22,968,714	22,968,734
Accumulated deficit	(29,258,170)	(28,205,516)
Total stockholders' deficit	(6,237,244)	(5,184,590)
Total liabilities and stockholders' deficit	10,841,268	12,313,061
Series A Convertible Preferred Stock
STOCKHOLDERS' DEFICIT:
Preferred stock	$ 725	$ 735

Stockholders' Deficit - Conversions of Series A Preferred Stock (Details)	6 Months Ended	12 Months Ended
	Aug. 31, 2015 number shares	Feb. 28, 2015 number shares	Feb. 28, 2014 number shares	Feb. 28, 2013 number shares	Feb. 29, 2012 number shares	Feb. 28, 2011 number shares	Feb. 28, 2010 number shares	Feb. 28, 2009 number shares	Feb. 29, 2008 number shares
Series A preferred shares converted to common stock	(675,200)
Shares of common stock issued from conversion	2,025,600
Accredited investors \| number	43
Series A Convertible Preferred Stock
Series A preferred shares converted to common stock	(10,000)	(3,000)	(151,000)	(18,000)	0	(102,000)	(51,900)	(237,000)	(102,300)
Shares of common stock issued from conversion	30,000	9,000	453,000	54,000	0	306,000	155,700	711,000	306,900
Accredited investors \| number	1	1	9	2	0	4	4	12	10

Oil and Gas Properties - Capitalized Costs Relating to Oil and Gas Activities (Details) - USD ($)	Aug. 31, 2015	Feb. 28, 2015
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Proved leasehold costs	$ 699,417	$ 695,231
Unproved leasehold costs	737,218	733,478
Costs of wells and development	678,614	542,563
Capitalized exploratory well costs	5,304,632	5,308,876
Total cost of oil and gas properties	7,419,881	7,280,148
Accumulated depletion, depreciation, amortization and impairment	(2,423,388)	(2,167,064)
Net oil and gas properties	$ 4,996,493	$ 5,113,084

Accounting Policies (Policies)	6 Months Ended
Accounting Policies (Policies)	Aug. 31, 2015
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The accompanying unaudited interim financial statements and notes for the Company have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial information and with the instructions to Form 10-Q for quarterly reports under Section 13 or 15(d) of the Securities Exchange Act of 1934 (the “Exchange Act”). Accordingly, they do not include all of the information and footnote disclosures normally required by accounting principles generally accepted in the United States of America for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation of the financial statements have been included and such adjustments are of a normal recurring nature. Operating results for the six months ended August 31, 2015 are not necessarily indicative of the results that may be expected for the fiscal year ending February 29, 2016. These financial statements should be read in conjunction with the audited financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the fiscal year ended February 28, 2015.
Use of Estimates	Use of Estimates In preparing financial statements in conformity with accounting principles generally accepted in the United States of America, management is required to make estimates and assumptions. These estimates and assumptions may affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements, and revenues and expenses during the reporting period. Actual results could differ materially from those estimates. The accounting policies most affected by management’s estimates and assumptions are as follows: • The reliance on estimates of proved reserves to compute the provision for depreciation, depletion and amortization and to determine the amount of any impairment of proved properties; • The valuation of unproved acreage and proved oil and 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 abandonment obligations.
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.

Balance Sheets (Parenthetical) - $ / shares	Aug. 31, 2015	Feb. 28, 2015
Preferred stock, par value in dollars	$ 0.001	$ 0.001
Preferred stock, shares authorized	10,000,000	10,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Common stock, par value in dollars	$ 0.001	$ 0.001
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	51,487,373	51,457,373
Common stock, shares outstanding	51,487,373	51,457,373
Series A Convertible Preferred Stock
Preferred stock, par value in dollars	$ 0.001	$ 0.001
Preferred stock, shares authorized	2,400,000	2,400,000
Preferred stock, shares issued	724,565	734,565
Preferred stock, shares outstanding	724,565	734,565
Preferred stock, cumulative dividend rate	6.00%	6.00%

Document and Entity Information - shares	6 Months Ended
Document and Entity Information - shares	Aug. 31, 2015	Oct. 13, 2015
Document And Entity Information
Entity Registrant Name	Daybreak Oil & Gas, Inc.
Entity Central Index Key	0001164256
Document Type	10-Q
Document Period End Date	Aug. 31, 2015
Amendment Flag	false
Current Fiscal Year End Date	--02-29
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 Common Stock, Shares Outstanding		51,487,373
Document Fiscal Period Focus	Q2
Document Fiscal Year Focus	2016

Statements of Operations (Unaudited) - USD ($)	3 Months Ended		6 Months Ended
Statements of Operations (Unaudited) - USD ($)	Aug. 31, 2015	Aug. 31, 2014	Aug. 31, 2015	Aug. 31, 2014
REVENUE:
Oil and natural gas sales	$ 369,834	$ 1,044,296	$ 811,118	$ 1,854,725
OPERATING EXPENSES:
Production expenses	70,001	79,955	145,606	165,485
Exploration and drilling	8,400	6,027	20,067	12,810
Depreciation, depletion, amortization and impairment	118,889	171,516	257,729	291,493
General and administrative	248,855	265,105	534,503	619,924
Total operating expenses	446,145	522,603	957,905	1,089,712
OPERATING INCOME (LOSS)	(76,311)	521,693	(146,787)	765,013
OTHER INCOME (EXPENSE):
Interest income	201,851	290,008	424,604	454,846
Interest expense	(661,604)	(697,187)	(1,330,471)	(1,363,004)
Total other income (expense)	(459,753)	(407,179)	(905,867)	(908,158)
NET INCOME (LOSS)	(536,064)	114,514	(1,052,654)	(143,145)
Cumulative convertible preferred stock dividend requirement	(32,872)	(33,462)	(65,896)	(66,923)
NET INCOME (LOSS) AVAILABLE TO COMMON SHAREHOLDERS	$ (568,936)	$ 81,052	$ (1,118,550)	$ (210,068)
NET INCOME (LOSS) PER COMMON SHARE, Basic	$ 0.01	$ 0.00	$ (0.02)	$ 0.00
NET INCOME (LOSS) PER COMMON SHARE, Diluted	$ 0.01	$ 0.00	$ (0.02)	$ 0.00
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING, Basic	51,487,373	56,422,568	51,482,273	56,819,345
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING, Diluted	51,487,373	61,376,698	51,482,273	56,819,345

Concentration of Credit Risk (Details Narrative)	6 Months Ended
Concentration of Credit Risk (Details Narrative)	Aug. 31, 2015
Risks and Uncertainties [Abstract]
Concentration of risk, description	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 August 31, 2015 and February 28, 2015 these three individual customers represented 100.0% of crude oil and natural gas revenue accounts receivable. If these buyers are unable to resell their products or if they lose a significant sales contract then the Company may incur difficulties in selling its oil and natural gas production.

Income Taxes - Income Tax Expense Benefit Reconciliation (Details) - USD ($)	6 Months Ended	12 Months Ended
	Aug. 31, 2015	Feb. 28, 2015
Income Tax Expense Benefit Continuing Operations Income Tax Reconciliation
Computed at U.S. and state statutory rates (40%)	$ (421,059)	$ (293,176)
Permanent differences	58,737	142,925
Changes in valuation allowance	362,322	150,251
Income tax expense (benefit)	$ 0	$ 0

Warrants - Schedule of Stockholders' Equity Note Warrants and Rights (Details)	6 Months Ended
	Aug. 31, 2015 $ / shares shares
Class of Warrant or Right [Line Items]
Warrants	10,485,301
Exercise price \| $ / shares	$ 0.06
Remaining life (years)	1 year 2 months
Exercisable warrants remaining	8,156,401
Kentucky Oil Project
Class of Warrant or Right [Line Items]
Warrants	3,498,601
Exercise price \| $ / shares	$ 0.04
Remaining life (years)	1 year
Exercisable warrants remaining	3,498,601
Share-for-Warrant Exchange
Class of Warrant or Right [Line Items]
Warrants	427,729
Exercise price \| $ / shares	$ 0.04
Remaining life (years)	1 year
Exercisable warrants remaining	427,729
12% Subordinated Notes
Class of Warrant or Right [Line Items]
Warrants	1,190,000
Exercise price \| $ / shares	$ 0.14
Remaining life (years)	1 year 5 months
Exercisable warrants remaining	980,000
Debt Financing
Class of Warrant or Right [Line Items]
Warrants	2,435,517
Exercise price \| $ / shares	$ 0.044
Remaining life (years)	2 years 2 months
Exercisable warrants remaining	316,617
Kentucky Debt Financing #1
Class of Warrant or Right [Line Items]
Warrants	2,623,951
Exercise price \| $ / shares	$ 0.04
Remaining life (years)	1 year
Exercisable warrants remaining	2,623,951
Kentucky Debt Financing #2
Class of Warrant or Right [Line Items]
Warrants	309,503
Exercise price \| $ / shares	$ 0.214
Remaining life (years)	3 years
Exercisable warrants remaining	309,503

Note Receivable (Details Narrative)	6 Months Ended
Note Receivable (Details Narrative)	Aug. 31, 2015 USD ($)
App Energy Note Receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Advances to certain minority working interest partners	$ 8,300,000

Statements of Cash Flows (Unaudited) - USD ($)	6 Months Ended
Statements of Cash Flows (Unaudited) - USD ($)	Aug. 31, 2015	Aug. 31, 2014
CASH FLOWS FROM OPERATING ACTIVITIES:
NET LOSS	$ (1,052,654)	$ (143,145)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Stock compensation	0	2,515
Depreciation, depletion, impairment and ARO expense	257,730	291,493
Amortization of debt discount	68,196	84,635
Amortization of deferred financing costs	212,564	209,844
Interest income	(42)	(42)
Changes in assets and liabilities:
Accounts receivable, oil and gas sales	78,969	(72,706)
Accounts receivable, joint interest participants	(2,304)	187,216
Accounts receivable, other	79,242	(38,197)
Prepaid expenses and other current assets	(15,007)	11,791
Accounts payable and other accrued liabilities	57,453	(346,262)
Accounts payable, related parties	42,935	(89,685)
Accrued interest	9,815	72
Net cash provided by (used in) operating activities	(263,103)	97,529
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and natural gas properties	(135,714)	(667,633)
Prepaid drilling costs	0	(646,938)
Additions to note receivable	0	(4,200,000)
Collections of note receivable	627,500	1,483,960
Deferred interest	0	655
Net cash provided by (used in) investing activities	491,786	(4,029,956)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from long-term debt	0	5,700,000
Payment on long-term debt	(588,431)	(1,693,348)
Proceeds from warrant conversion	0	7,000
Payment of deferred financing fees	0	(345,000)
Payments on line of credit	(14,532)	(2,359)
Net cash provided by (used in) financing activities	(602,963)	3,666,293
NET DECREASE IN CASH AND CASH EQUIVALENTS	(374,280)	(266,134)
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD	496,772	500,431
CASH AND CASH EQUIVALENTS AT END OF PERIOD	122,492	234,297
Cash paid for Interest	1,039,896	1,083,825
Cash paid for Income taxes	0	0
SUPPLEMENTAL CASH FLOW INFORMATION:
Unpaid additions to oil and natural gas properties	3,880	2,426
Conversion of warrants	0	1,874
Share-to-warrant exchange	0	428
ARO asset and liability increase	140	1,906
Increase in note payable for stock acquisition and subsequent retirement	0	1,708,447
Conversion of preferred stock to common stock	30	0
Repurchase of stock through payment of payroll taxes	$ 0	$ 490

Deferred Financing Costs - Schedule of Deferred Financing Costs (Details) - USD ($)	Aug. 31, 2015	Feb. 28, 2015
Deferred financing costs, gross	$ 1,732,121	$ 1,732,121
Accumulated amortization	(885,934)	(673,370)
Deferred finance costs, net	846,187	1,058,751
Revolving Credit Facility \| Warrant
Deferred financing costs, gross	530,488	530,488
Revolving Credit Facility \| Common Stock
Deferred financing costs, gross	419,832	419,832
Revolving Credit Facility \| Loan Commissions
Deferred financing costs, gross	630,662	630,662
Revolving Credit Facility \| Loan Fees
Deferred financing costs, gross	$ 151,139	$ 151,139