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, 2012
 OR
 [ ] 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: 000-54452
 
 BUCKEYE OIL & GAS, INC.
 (Exact name of registrant as specified in its charter)
 
 Florida
27-2565276(State or Other Jurisdiction of Incorporation or Organization
I.R.S. Employer Identification No.
 
 8275 S. Eastern Avenue, Suite 200
 Las Vegas, Nevada 89123
 (Address of principal executive offices) (Zip Code)
 
 702-938-0491
 (Registrant's telephone number, including area code)
 
 _____________________________________________________________
 (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.
 [X] 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  [X]         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 [  ]
Smaller reporting company  [X](Do not check if a smaller reporting company)
 
 Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  Yes  [   ]  No [X]
 
 Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date: 61,750,000 shares of common stock, $0.0001 par value, were issued and outstanding as of October 15, 2012.
 
  1
  
 
 TABLE OF CONTENTS
 
 PagePART I  - Financial Information
3Item 1. Financial Statements
3Balance Sheets August 31, 2012 (unaudited), and May 31, 2012
3Statements of Operations (unaudited) for the three-month periods endedAugust 31, 2012 and 2011, and for the period from inceptionon May 11, 2010 to August 31, 2012
4Statements of Cash Flows (unaudited) for the three-month periods endedAugust 31, 2012 and 2011, and for the period from inceptionon May 11, 2010 to August 31, 2012
5Notes to the Financial Statements
7Item 2.  Management’s Discussion and Analysis of Financial Condition and Results of Operations.
13Item 3 Quantitative and Qualitative Disclosures About Market Risk
14Item 4  Controls and Procedures
15PART II – Other Information
15Item 1.  Legal Proceedings
15Item 1A.  Risk Factors
15Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
15Item 3. Defaults Upon Senior Securities
15Item 4. Mine Safety Disclosures
15Item 5. Other Information
15Item 6. Exhibits
16
 
  2
  
 Item 1.  Financial Statements
 BUCKEYE OIL & GAS, INC.
 (An Exploration Stage Company)
 CONSOLIDATED BALANCE SHEETS
 
 (Unaudited)August 31,


May 31,2012


2012ASSETSCurrent AssetsCash

$
24,205


$
61,654Accounts Receivable


2,246



2,199Prepaid Expenses


5,304



1,883Total Current Assets


31,755



65,736Oil and Gas Property Interests (note 4)


970,856



970,856Total Assets

$
1,002,611


$
1,036,592LIABILITIES & STOCKHOLDERS’ EQUITYCurrent LiabilitiesAccounts Payable and Accrued Liabilities

$
33,826


$
49,354Total Current Liabilities


33,826



49,354Long Term LiabilitiesAsset Retirement Obligations (note 5)


10,394



9,565Total Long Term Liabilities


10,394



9,565Total Liabilities


44,220



58,919Stockholders' Equity (Deficit)Common Stock, Par Value $.0001Authorized 500,000,000 shares,61,750,000 shares issued and outstanding at August 31, 2012(61,750,000 shares issued at May 31, 2012)


6,175



6,175Paid-In Capital


1,164,825



1,164,825Deficit Accumulated During Exploration Stage


(212,609
)


(193,327
)Total Stockholders' Equity (Deficit)


958,391



977,673Total Liabilities and Stockholders' Equity

$
1,002,611


$
1,036,592
 
 The accompanying notes are an integral part of these financial statements.
  3
  BUCKEYE OIL & GAS, INC.
 (An Exploration Stage Company)
 CONSOLIDATED STATEMENTS OF OPERATIONS
 (Unaudited)
 
 CumulativeSinceFor the Three-Months Ended


May 11, 2010August 31,


(Inception) to2012


2011


August 31, 2012RevenuesOil and gas revenues

$
–


$
–


$
8,401ExpensesOperating Expenses


4,450



–



73,156Accretion


362



–



1,205Professional Fees


750



5,800



38,935Office and Sundry


3,468



2,533



60,176Rent


450



900



2,550Management and Directors’ Fees


8,670



1,022



42,437Total Expenses


(18,150
)


(10,255
)


(218,459
)Net Loss from Operations


(18,150
)


(10,255
)


(210,058
)Other Income (Expenses)Foreign Exchange Gain (Loss)


(1,132
)


(1,391
)


(2,551
)Net Other Income (Expenses)


(1,132
)


(1,391
)


(2,551
)Net Loss

$
(19,282
)

$
(11,646
)

$
(212,609
)Basic and Diluted loss per share

$
(0.00
)

$
(0.00
)Weighted Average Shares Outstanding (1)


61,750,000



61,747,826
 (1)
Reflects the 17:1 forward stock split completed on June 1, 2011.
 
 
 The accompanying notes are an integral part of these financial statements.
  4
  BUCKEYE OIL & GAS, INC.
 (An Exploration Stage Company)
 CONSOLIDATED STATEMENTS OF CASH FLOWS
 (Unaudited)
 CumulativeSinceMay 11, 2010For the Three-Months Ended


(Inception) toAugust 31,


August 31,2012


2011


2012CASH FLOWS FROM OPERATING ACTIVITIESNet Loss

$
(19,282
)

$
(11,646
)

$
(212,609
)Adjustments to Reconcile Net Loss to NetCash Used in Operating ActivitiesAccretion Expense


362



-



1,205Change in Operating Assets and LiabilitiesDecrease (Increase) In Accounts Receivable


(47
)


(7
)


(2,246
)Decrease (Increase) in Prepaid Expenses


(3,421
)


(1,198
)


(5,304
)Increase (Decrease) in Accounts Payable


(15,528
)


8,782



33,826Net Cash Used in Operating Activities


(37,916
)


(4,069
)


(185,128
)CASH FLOWS FROM INVESTING ACTIVITIESAcquisition of Oil and Gas Property Interests


-



(392,604
)


(802,295
)Cash Acquired on Business Combination


-



240,161



240,161Net Cash Used in Investing Activities


-



(152,443
)


(562,134
)CASH FLOWS FROM FINANCING ACTIVITIESProceeds from the Sale of Common Stock


-



450,000



771,000Net Cash Provided by Financing Activities


-



450,000



771,000Foreign Exchange Effect on Cash


467



-



467Net (Decrease) Increase in Cash and Cash Equivalents


(37,449
)


293,488



24,205Cash and Cash Equivalents at Beginning of Period


61,654



2,515



-Cash and Cash Equivalents at End of Period

$
24,205


$
296,003


$
24,205
 
 
 The accompanying notes are an integral part of these financial statements.
  5
  BUCKEYE OIL & GAS, INC.
 (An Exploration Stage Company)
 CONSOLIDATED STATEMENTS OF CASH FLOWS
 (Unaudited)
 (Continued)
 CumulativeSinceMay 11, 2010For the Three-Months Ended


(inception) toAugust 31,


August 31,


August 31,2012


2011


2012SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATIONCash paid during the year for:Interest

$
—


$
—


$
—Income taxes

$
—


$
—


$
—
 
 SUPPLEMENTAL DISCLOSURE OF NON-CASH INVESTING INFORMATIONLong Term Liabilities - Asset Retirement Obligation

$
—


$
—


$
9,696Shares issued on acquisition of Buckeye Oil & Gas (Canada), Inc.

$
—


$
—


$
400,000
 
 The accompanying notes are an integral part of these financial statements.
 
 
  6
  BUCKEYE OIL & GAS, INC.
 (An Exploration Stage Company)
 NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
 
 NOTE 1 – NATURE OF BUSINESS AND OPERATIONS
 
 Organization and Basis of Presentation
 
 Buckeye Oil & Gas, Inc. (an exploration stage company) (the “Company”) was incorporated in the state of Florida on May 11, 2010 under the name Benefit Solutions Outsourcing Corp. On May 19, 2011 the Board of Directors and majority shareholder of the Company approved a change to the Company’s Articles of Incorporation which affected a name change of the company to “Buckeye Oil & Gas, Inc.”, and changed the business of the Company to oil and gas exploration.  The changes became effective at the close of business on June 1, 2011.
 
 On June 23, 2011 the Company entered into a Stock Purchase Agreement to acquire all of the issued and outstanding shares of a private Canadian business owned by the Company’s principal executive officer called Buckeye Oil & Gas (Canada) Inc. (“Buckeye Canada”), a company incorporated in Alberta, Canada. The purchase price paid for the shares of Buckeye Canada was $400,000, which was paid by the issuance to Pol Brisset, the Company's principal officer and a director, of 1,000,000 shares of common stock of the Company.  As a result of the acquisition, Buckeye Canada became a wholly-owned subsidiary of the Company.
 
 The accompanying financial statements have been prepared in U.S. dollars and in accordance with accounting principles generally accepted in the United States on a going concern basis.
 
 Nature of Operations
 
 The Company has had limited production from its properties as of August 31, 2012. We are engaged in the acquisition, exploration and if warranted and feasible, the development of oil and gas properties.  We currently have a 28% working interest in two properties located in Alberta, Canada.  We have drilled an exploration well on each respective property had but neither well is currently in production.
 
 Interim Reporting
 
 The unaudited financial information furnished herein reflects all adjustments, which in the opinion of management are necessary to fairly state the financial position of Buckeye Oil & Gas, Inc. and the results of its operations for the periods presented.  This report on Form 10-Q should be read in conjunction with the Company’s financial statements and notes thereto included in the Company’s Form 10-K for the fiscal year ended May 31, 2012.  The Company assumes that the users of the interim financial information herein have read or have access to the audited financial statements for the preceding fiscal year and that the adequacy of additional disclosure needed for a fair presentation may be determined in that context.  Accordingly, footnote disclosure, which would substantially duplicate the disclosure contained in the Company’s Form 10-K for the fiscal year ended May 31, 2012 has been omitted.  The results of operations for the three-month period ended August 31, 2012 are not necessary indicative of results for the entire year ending May 31, 2013.
  NOTE 2 – ABILITY TO CONTINUE AS A GOING CONCERN
 
 The accompanying financial statements have been prepared in US dollars and in accordance with accounting principles generally accepted in the United States (GAAP) on a going concern basis, which contemplates the realization of assets and the satisfaction of liabilities and commitments in the normal course of business.  The Company only commenced its oil and gas exploration activities in June 2011.  The Company has realized only limited revenue from its present operations.  During the three-months ended August 31, 2012, the Company incurred a net loss of $19,282.  Since inception on May 11, 2010 the Company has an accumulated deficit of $212,609 to August 31, 2012.  These conditions raise substantial doubt about the Company's ability to continue as a going concern.
 
  7
  The Company's ability to continue as a going concern is dependent on its ability to develop its oil and gas properties and ultimately achieve profitable operations and to generate sufficient cash flow from financing and operations to meet its obligations as they become payable. The Company expects that it will need approximately $484,000 to fund its operations during the next twelve months which will include capital payments under its property agreement (note 4) and the costs associated with maintaining an office.  Management may seek additional capital through a private placement and public offering of its common stock.  Although there are no assurances that management’s plans will be realized, management believes that the Company will be able to continue operations in the future.  Accordingly, no adjustment relating to the recoverability and classification of recorded asset amounts and the classification of liabilities has been made to the accompanying financial statements in anticipation of the Company not being able to continue as a going concern.
  NOTE 3 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
 
 Management’s Estimates and Assumptions
 
 The preparation of financial statements in conformity with generally accepted accounting principles requires the Company’s management to make estimates and assumptions that affect the amounts reported in these financial statements and notes. Significant areas requiring the use of estimates relate to accrued liabilities, asset retirement obligation, and the impairment of long-lived assets.  Management believes the estimates utilized in preparing these financial statements are reasonable and prudent and are based on management’s best knowledge of current events and actions the Company may undertake in the future. Actual results could differ from those estimates.
 
 Cash and Cash Equivalents
  For purposes of the statement of cash flows, the Company considers all highly liquid debt instruments purchased with a maturity of three months or less to be cash equivalents to the extent the funds are not being held for investment purposes.
 
 Foreign Currency
 
 The Company has oil and gas property interests in Canada and as a result incurs transactions in Canadian dollars.  The Company translates its Canadian dollar balances to US dollars in the following manner:  assets and liabilities have been translated using the rate of exchange at the balance sheet date.  The Company’s results of operations have been translated using average rates.
  Concentration of Credit Risk
  The Company has no off-balance-sheet concentrations of credit risk such as foreign exchange contracts, options contracts or other foreign hedging arrangements. The Company maintains all of its cash balances with one financial institution in the form of a demand deposit.
  Loss per Share
  Net income (loss) per share is computed by dividing the net income by the weighted average number of shares outstanding during the period. The Company did not have any dilutive instruments outstanding at August 31, 2012.
  Comprehensive Income
  The Company has adopted ASC 220 (formerly SFAS No. 130, “Reporting Comprehensive Income”), which establishes standards for reporting and display of comprehensive income, its components and accumulated balances. The Company has disclosed this information on its Statement of Operations. Comprehensive income is comprised of net income (loss) and all changes to capital deficit except those resulting from investments by owners and distribution to owners.
 
  8
  Income Taxes
 
 Deferred taxes are provided on a liability method whereby deferred tax assets are recognized for deductible temporary differences and operating loss and tax credit carry forwards and deferred tax liabilities are recognized for taxable temporary differences. Temporary differences are the differences between the reported amounts of assets and liabilities and their tax bases.  Deferred tax assets are  reduced by a  valuation  allowance  when,  in the opinion  of  management,  it is more  likely than not  that  some portion or all of the deferred  tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates on the date of enactment.
 
 Uncertain Tax Positions
  The Company adopted the provisions of ASC 740-10-50, formerly FIN 48, Accounting for Uncertainty in Income Taxes. The Company had no material unrecognized income tax assets or liabilities for the year ended May 31, 2012 or for the year ended May 31, 2011. The Company’s policy regarding income tax interest and penalties is to expense those items as general and administrative expense but to identify them for tax purposes. During the year ended May31, 2012 and 2011, there were no income tax, or related interest and penalty items in the income statement, or liability on the balance sheet. The Company files income tax returns in the U.S. federal jurisdiction and Florida State.  Tax years 2011 to present remain open to income tax examination.The Company is not currently involved in any income tax examinations.
  
 Fair Value of Financial Instruments
 
 The book values of cash, prepaid expenses, and accounts payable approximate their respective fair values due to the short-term nature of these instruments. The fair value hierarchy under GAAP distinguishes between assumptions based on market data (observable inputs) and an entity’s own assumptions (unobservable inputs). The hierarchy consists of three levels:
 •
Level one — Quoted market prices in active markets for identical assets or liabilities;•
Level two — Inputs other than level one inputs that are either directly or indirectly observable; and•
Level three — Unobservable inputs developed using estimates and assumptions, which are developed by the reporting entity and reflect those assumptions that a market participant would use.
 
 Determining which category an asset or liability falls within the hierarchy requires significant judgment. We evaluate our hierarchy disclosures each quarter.
 
 Oil and Gas Property Payments and Exploration Costs
 
 The Company follows the full cost method of accounting for natural gas and oil operations.  Under the full cost method all costs incurred in the acquisition, exploration and development of natural gas and oil reserves are initially capitalized into cost centers on a country-by-country basis. The Company’s current cost center is located in Canada. Such costs include land acquisition costs, geological and geophysical expenditures, carrying charges on non-producing properties, costs of drilling and overhead charges directly related to acquisition, exploration and development activities.
 
 Costs capitalized, together with the costs of production equipment, are depleted and amortized on the unit-of-production method based on the estimated net proved reserves, as determined by independent petroleum engineers.  The Company has adopted revised oil and gas reserve estimation and disclosure requirements. The primary impact of the new disclosures is to conform the definition of proved reserves with the SEC Modernization of Oil and Gas Reporting rules, which were issued by the SEC at the end of 2008. The accounting standards update revised the definition of proved oil and gas reserves to require that the average, first-day-of-the-month price during the 12-month period before the end of the year rather than the year-end price, must be used when estimating whether reserve quantities are economical to produce. This same 12-month average price is also used in calculating the aggregate amount of (and changes in) future cash inflows related to the standardized measure of discounted future net cash flows. The percentage of total reserve volumes produced during the year is multiplied by the net capitalized investment plus future estimated development costs in those reserves.  Costs of acquiring and evaluating unproved properties are initially excluded from depletion calculations. These unevaluated properties are assessed periodically to ascertain whether impairment has occurred. When proved reserves are assigned or the property is considered to be impaired, the cost of the property or the amount of the impairment is added to costs subject to depletion calculations.
  9
  
 Under full cost accounting rules, capitalized costs, less accumulated amortization and related deferred income taxes, shall not exceed an amount (the ceiling) equal to the sum of:  (i) the after tax present value of estimated future net revenues computed by applying current prices of oil and gas reserves to estimated future production of proved oil and gas reserves as of the date of the latest balance sheet presented, less estimated future expenditures (based on currents costs) to be incurred in developing and producing the proved reserves computed using a discount factor of ten percent and assuming continuation of existing economic conditions; (ii) the cost of properties not being amortized; and (iii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized.  If unamortized costs capitalized within a cost center, less related deferred income taxes, exceed the ceiling, the excess shall be charged to expense and separately disclosed during the period in which the excess occurs.  Amounts thus required to be written off shall not be reinstated for any subsequent increase in the cost center ceiling.
 
 Impairment of Long-lived Assets
 
 In accordance with ASC 360, Property, Plant and Equipment, long lived assets such as equipment are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.  Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to estimated undiscounted future cash flows expected to be generated by the asset.  If the carrying amount of an asset exceeds its estimated future cash flows, an impairment charge is recognized by the amount by which the carrying amount of the asset exceeds the fair value of the asset.  Assets to be disposed of would be separately presented in the balance sheet and reported at the lower of the carrying amount of fair value less costs to sell, and are no longer depreciated.  The assets and liabilities of a disposed group classified as held for sale would be presented separately in the appropriate asset and liability sections of the balance sheet.
 
 Asset Retirement Obligations
 
 In accordance with ASC 410, Asset Retirement and Environmental Obligations the fair value of an asset retirement cost, and corresponding liability, should be recorded as part of the cost of the related long-lived asset and subsequently allocated to expense using a systematic and rational method.  The Company provides for future asset retirement obligations on its oil and natural gas properties based on estimates established by current legislation. The asset retirement obligation is initially measured at fair value and capitalized to capital assets as an asset retirement cost. The asset retirement obligation accretes until the time the asset retirement obligation is expected to settle while the asset retirement cost is amortized over the useful life of the underlying capital assets. The amortization of the asset retirement cost and the accretion of the asset retirement obligation are included in depletion and accretion expense.  Actual asset retirement costs are recorded against the obligation when incurred. Any difference between the recorded asset retirement obligations and the actual retirement costs incurred is recorded as a gain or loss in the period of settlement.
 
 Revenue recognition
 
 Revenue from the production of crude oil and natural gas is recognized when title passes to the customer and when collection of the revenue is reasonably assured.  The Company does not operate its wells and is reliant on the wells’ operator to market and sell its proportion of oil and gas produced from its wells.  The customers take title when the crude oil is transferred to their pipeline or collection facility.
 
 The Company has recognized only minimal revenue from its oil and gas exploration activities as of August 31, 2012.  The Company began earning revenue from its 28% working interest it has in its Valhalla Property commencing in October, 2011 and its 28% working interest in its Spirit Rycroft Property in March 2012.  Currently, neither property is in production.  Both properties are located in Alberta, Canada.
 
  10
  
 The Company reviews new accounting standards as issued. No new standards had any material effect on these financial statements. The accounting pronouncements issued subsequent to the date of these financial statements that were considered significant by management were evaluated for the potential effect on these financial statements. Management does not believe any of the subsequent pronouncements will have a material effect on these financial statements as presented and does not anticipate the need for any future restatement of these financial statements because of the retro-active application of any accounting pronouncements issued subsequent to August 31, 2012 through the date these financial statements were issued.
 
 NOTE 4 – OIL AND GAS PROPERTY INTERESTS (Unproven)
 
 
 August 31, 2012 (Cumulative)Valhalla

Sprit Rycroft

Total(unproven)

(unproven)Property acquisition costs

$
345,600


$
610,780


$
956,380Geological and geophysical


2,593



2,187



4,780Asset Retirement Obligation


4,848



4,848



9,696Total expenditures

$
353,041



617,815



970,856
 
 Farmout and Participation Agreement with Luxor
 
 The Company’s sole assets are rights acquired by Buckeye Canada pursuant to a May 12, 2011 Farmout and Participation Agreement with Luxor Oil & Gas, Inc. (“Luxor”). Under this agreement Buckeye Canada has agreed to incur 80% of the cost of drilling a well on one of Luxor’s properties in exchange for a 56% working interest in said well. In a separate agreement, on May 16, 2011 Buckeye Canada entered into a Participation Agreement whereby the Company agreed to share its obligations and rights under the agreement with Luxor with a partner on a 50% basis.  The partner is a privately-owned company called Pioneer Marketing Group, Ltd. (“Pioneer”).  The Participation Agreement requires Buckeye Canada and Pioneer to equally fund Buckeye Canada’s obligations under the Luxor agreement and to participate equally in the interest in the well.  Accordingly, Buckeye Canada and Pioneer will each pay a net 40% of the initial capital costs and earn a 28% working interest each in any wells drilled by Luxor, as long as Pioneer continues to fund its half of the required amount of expenses.
 
 At the time of the acquisition of Buckeye Canada, Buckeye Canada had paid Luxor an aggregate CDN $152,876 (USD $159,839) in connection with the drilling of the well. The well, located in the Valhalla area of Alberta (“Valhalla Well”), Canada was drilled in July 2011.  In August 2011, Buckeye Canada paid an additional aggregate CDN $175,527 (USD $185,761) to Luxor for the costs to complete the Valhalla Well and acquire surface infrastructure for oil collection.  The Valhalla Well was completed in August, 2011 and initial production began in October 2011. Due to water accumulation issues, the Valhalla Well has had only limited production and is currently shut-in and not producing.  Buckeye Canada has now earned its 28% interest in the Valhalla Well as well as the entire property on which the Valhalla Well is located.
 
 Buckeye Canada also has the right of first refusal to participate on two additional properties if Luxor determines that it desires to pursue drilling on those properties. If Buckeye Canada exercises this right, it will need to pay 80% of such expenses in exchange for a 56% working interest.  On July 26, 2011 Buckeye Canada exercised its rights to participate in a second well drilled by Luxor.  The second property is called Spirit Rycroft and the well on this property was drilled in August 2011 (the “SR Well”).  The Company paid Luxor an aggregate CDN $202,706 (USD $206,422) for the drilling of the SR Well and an additional CDN $162,383 (USD $158,810) for partial completion of the well.  In February 2012, the Company paid CDN $119,540 (USD $119,888) for the construction of a pipeline to tie-in the SR Well to local infrastructure.  In April 2012, the Company paid the final amount of CDN $126,150 (USD $125,660) for the surface infrastructure.  The SR Well started producing oil and liquids in March 2012 but has had only limited production to date and is currently shut in and not producing.  It is not yet known if the SR Well will be economic.  Buckeye Canada has now earned its 28% interest in the SR Well as well as the entire property on which the SR Well is located.
  11
  The agreement with Luxor provides for Buckeye Canada to earn its working interest on the entire property and not just on the respective well.  As a result, now that Buckeye Canada has earned-in on the Valhalla and Spirit Rycroft Properties, Buckeye Canada will pay 28% of the capital costs on any new wells drilled on either property and earn a 28% working interest.  In other words, on the potentially three properties that are part of the Luxor agreement, Buckeye Canada pays 40% of the capital costs to earn a 28% working interest on the first well but pays 28% of the capital costs to earn a 28% working interest on all subsequent wells drilled on the respective property.  Luxor has not yet indicated if they will be proceeding on a third property.
 
 None of the Company’s properties currently contain any assigned reserves or resources.
 
 NOTE 5 – ASSET RETIREMENT OBLIGATION
 
 As at August 31, 2012 the Company’s asset retirement obligation was comprised of its 28% working interest in the Valhalla and SR Wells.  The Company has estimated its August 31, 2012 obligation at $10,394 which includes accretion expense of $362 for the three-months ended August 31, 2012.
 
 NOTE 6 – RELATED PARTY TRANSACTIONS
 
 Effective September 1, 2011 the Company entered into a service agreement with Pol Brisset, its principal executive officer, requiring a monthly payment of CDN $2,500.  Under the agreement the Company paid Mr. Brisset $7,225 (CDN $7,500) for the three-months ended August 31, 2012.
 
 Effective as of April 2, 2012, Michal Gnitecki was appointed as Secretary and a director of the Company and will be compensated at CDN $500 per month to serve as secretary and director.  For the three-months ended August 31, 2012, the Company paid $1,445 (CDN $1,500) to Mr. Gnitecki.
 
 
 
  12
  Item 2.                      Management’s Discussion and Analysis of Financial Condition and Results of Operations
 
 The following discussion should be read in conjunction with the financial statements of Buckeye Oil & Gas, Inc. (the “Company”), which are included elsewhere in this Form 10-Q.  Certain statements contained in this report, including statements regarding the anticipated development and expansion of the Company's business, the intent, belief or current expectations of the Company, its directors or its officers, primarily with respect to the future operating performance of the Company and the products it expects to offer and other statements contained herein regarding matters that are not historical facts, are "forward-looking" statements.  Future filings with the Securities and Exchange Commission, future press releases and future oral or written statements made by or with the approval of the Company, which are not statements of historical fact, may contain forward-looking statements. Because such statements include risks and uncertainties, actual results may differ materially from those expressed or implied by such forward-looking statements. For a more detailed listing of some of the risks and uncertainties facing the Company, please see the Form 10-K for the year ended May 31, 2012 filed by the Company with the Securities and Exchange Commission.
 
 All forward-looking statements speak only as of the date on which they are made. The Company undertakes no obligation to update such statements to reflect events that occur or circumstances that exist after the date on which they are made.
 
 Plan of Operations
 
 During the twelve-month period ending August 31, 2013, our objective is to continue to fund our agreement with Luxor.  Management is discussing the next steps with Luxor.  It is not known whether additional wells will be drilled on either the Valhalla Property or the Spirit Rycroft Property or if a third property will be drilled.  Regardless of the next well to be drilled, the Company will be required to fund its portion of the exploration program.
 
 We continue to rely on Luxor to provide their employees and to source appropriate contractors to undertake the drill programs on the properties subject to the Farmout Agreement. We remain focused on keeping the staff compliment, which currently consists of our two directors and one officer, at a minimum to conserve capital. Our staffing level does not currently hinder our operations, as outsourcing of necessary operations continues to be the most cost effective and efficient manner of conducting the business of the Company.
 
 Results of Operations
 
 Revenues
 
 We did not earn any revenues during the three-months ended August 31, 2012 or 2011.  We do not anticipate earning revenues until such time as we have entered into commercial production of our oil and gas properties.  We are presently in the exploration stage of our business and we can provide no assurance that we will discover commercially exploitable levels of natural resources on our properties, or if such resources are discovered, that we will enter into commercial production of our properties.
 
 Operating Expenses
 
 For the three-months ended August 31, 2012 our net loss was $19,282compared to $11,646 for the three-months ended August 31, 2011.  Expenses have increased in the current period due increased operating costs, office and sundry, and management fees partially offset by lower professional fees in the three-months ended August 31, 2012 compared to the three-months ended August 31, 2011.  The Company incurred $4,450 in operating expenses in the three-months ended August 31, 2012 while it did not have any operations for the three-months ended August 31, 2011.  Office and sundry has increased in the current year to $3,468 from $2,533 in the prior year due to higher SEC filing fees partially offset by lower transfer agent fees in 2012 compared to 2011.  Management fees increased in the current year due to the timing of the appointment of management in 2011.  The Company’s current President and CEO was appointed on September 1, 2011 resulting in no fees being paid to him for the three-months ended August 31, 2011 while for the three-months ended August 31, 2012, the Company paid $7,225 in fees.  Professional fees were $750 in the three-months ended August 31, 2012 compared to $5,800 for the three-months ended August 31, 2011.  The higher professional fees in 2011 were the result of the Company incurring legal and accounting fees associated with its acquisition of Buckeye Canada and due to the change of control that occurred in June 2011.
 
  13
  Liquidity and Capital Resources
 
 We had a cash balance of $24,205 and working capital of negative ($2,071) at August 31, 2012. We anticipate that we will incur the following expenses over the next twelve months:
 
 
 Net cash used in operating activities during the three-months ended August 31, 2012 was $37,916 compared to $4,069 during the same period in 2011.  A portion of the increase was due to an increase in the net loss for the three-months ended August 31, 2012 to $19,282 from $11,646 in 2011.  In addition, in 2012 we had a net outflow from changes in accounts payable and accrued liabilities of $15,528 compared to a net inflow of $8,782 in 2011.  There was $450,000 received from the sale of common stock in 2011 while there were no financing activities in 2012.  Investing activities for the three-months ended August 31, 2011 consisted of $392,604 used for the acquisition of oil and gas property interests and $240,161 received upon the acquisition of Buckeye Oil & Gas (Canada), Inc. There were no investing activities in 2012.
 
 We anticipate that we will require approximately an additional $484,000 to fund our operations for the next 12 months.  We may seek to raise the additional funding that we require in the form of equity financing from the sale of our common stock.  However, we cannot provide investors with any assurance that we will be able to raise sufficient funding from the sale of our common stock to fund our operations.  We currently do not have any agreements or arrangements in place for any future equity financing.
 
 Going Concern Consideration
 
 Current cash on hand is not sufficient to fund our planned operations over the next twelve months.  Even if the wells drilled on the Valhalla and Spirit Rycroft Properties commence production in the coming months, cash flow from the wells will not be sufficient to fund all of our planned operations.  We anticipate generating losses and therefore we may be unable to continue operations in the future as a going concern. No adjustment has been made in the accompanying financial statements to the amounts and classification of assets and liabilities that could result should we be unable to continue as a going concern.
 
 We currently have no agreements, arrangements or understandings with any person to obtain funds through bank loans, lines of credit or any other sources.
 
 Accordingly, our independent auditors included an explanatory paragraph in their report on the May 31, 2012 financial statements regarding concerns about our ability to continue as a going concern. Our financial statements contain additional note disclosures describing the circumstances that lead to this disclosure by our independent auditors.
 
 Off-Balance Sheet Arrangements
 
 We have no off-balance sheet arrangements.
 
 Item 3.  Quantitative and Qualitative Disclosure About Market Risk
 
 Smaller reporting companies are not required to provide the information required by this Item.
 
  14
  Item 4.  Controls and Procedures
 
 EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES
  Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, the Company conducted an evaluation of our disclosure controls and procedures, as such term is defined under Rule 13a-15(e) and Rule 15d-15(e) promulgated under the Securities Exchange Act of 1934, as amended (Exchange Act), as of August 31, 2012. Based on this evaluation, our principal executive officer and principal financial officer have concluded that the Company’s disclosure controls and procedures were effective to ensure that information required to be disclosed by the Company in the reports filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms and that the Company’s disclosure and controls are designed to ensure that information required to be disclosed by the Company in the reports that we file or submit under the Exchange Act is accumulated and communicated to management, including our principal executive officer and principal financial officer, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.
  CHANGES IN INTERNAL CONTROL OVER FINANCIAL REPORTING
 
 There were no changes in our internal controls over financial reporting that occurred during our last fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
 PART II - OTHER INFORMATION
 
 Item 1. Legal Proceedings
 
 There are no pending legal proceedings to which the Company is a party or in which any director, officer or affiliate of the Company, any owner of record or beneficially of more than 5% of any class of voting securities of the Company, or security holder is a party adverse to the Company or has a material interest adverse to the Company.  The Company’s property is not the subject of any pending legal proceedings.
 
 Item 1A. Risk Factors
 
 Smaller reporting companies are not required to provide the information required by this Item 1A.
 
 Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
 
 None.
 
 Item 3. Defaults upon Senior Securities
 
 None.
 
 Item 4. Mining Safety Disclosures
 
 Not applicable.
 
 Item 5. Other information
 
 None.
 
  15
  Item 6. Exhibits
 
 Exhibit 31 - Certification of Principal Executive and Financial Officer pursuant to Rule 13a-14 of the Securities and Exchange Act of 1934 as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 Exhibit 32 – Certification of Principal Executive and Financial Officer Pursuant to 18 U.S.C Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
 
 
 101.INS **

XBRL Instance Document101.SCH **

XBRL Taxonomy Extension Schema Document101.CAL **

XBRL Taxonomy Extension Calculation Linkbase Document101.DEF **

XBRL Taxonomy Extension Definition Linkbase Document101.LAB **

XBRL Taxonomy Extension Label Linkbase Document101.PRE **

XBRL Taxonomy Extension Presentation Linkbase Document
 
 ** XBRL (Extensible Business Reporting Language) information is furnished and not filed or a part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, is deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise is not subject to liability under these sections.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
  16
  
 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.
 
 Date:   October 15, 2012



BUCKEYE OIL & GAS, INC.



By: /s/ Pol Brisset

Pol Brisset

President, Chief Executive Officer, Chief Financial Officer, and Treasurer

(Principal Executive, Financial, and Accounting Officer)