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Document and Entity Information

v2.4.0.6
Document and Entity Information
3 Months Ended
Jul. 31, 2013
Sep. 23, 2013
Document And Entity Information    
Entity Registrant Name Petro River Oil Corp.  
Entity Central Index Key 0001172298  
Document Type 10-Q  
Document Period End Date Jul. 31, 2013  
Amendment Flag false  
Current Fiscal Year End Date --04-30  
Is Entity's Reporting Status Current? Yes  
Entity Filer Category Smaller Reporting Company  
Entity Common Stock, Shares Outstanding   737,317,746
Document Fiscal Period Focus Q1  
Document Fiscal Year Focus 2014  

Condensed Consolidated Balance Sheets

v2.4.0.6
Condensed Consolidated Balance Sheets (USD $)
Jul. 31, 2013
Apr. 30, 2013
Current Assets:    
Cash and cash equivalents $ 5,038,371 $ 5,703,082
Accounts receivable 45,130 31,394
Prepaid expenses and other current assets 48,889 58,390
Total Current Assets 5,132,390 5,792,866
Oil and gas assets, net 13,706,858 13,423,089
Property, plant and equipment, net of accumulated depreciation of $311,602 and $310,700 3,636 4,538
Reclamation deposits 25,000 25,000
Other assets 6,000 5,500
Total Non-Current Assets 13,741,494 13,458,127
Total Assets 18,873,884 19,250,993
Current Liabilities:    
Accounts payable and accrued expenses 1,065,855 871,094
Related party payable 1,539,500   
Current portion of asset retirement obligations 213,302 213,302
Total Current Liabilities 2,818,657 1,084,396
Long-term liabilities:    
Asset retirement obligations, net of current portion 562,990 549,734
Total Long-Term Liabilities 562,990 549,734
Total Liabilities 3,381,647 1,634,130
Commitments and contingencies      
Stockholders' Equity:    
Preferred Shares - 5,000,000 authorized; par value $0.00001 per share, Preferred B shares - 29,500 authorized; 0 issued with a $100 stated value, par value $0.00001 per share      
Common shares - 2,250,000,000 authorized; par value $0.00001 per share; Issued and outstanding; 737,317,746 and 737,117,746 7,373 7,371
Additional paid-in capital 20,397,092 20,317,094
Accumulated deficit (4,912,228) (2,707,602)
Total Stockholders' Equity 15,492,237 17,616,863
Total Liabilities and Stockholders' Equity 18,873,884 19,250,993
Preferred B Shares [Member]
   
Stockholders' Equity:    
Preferred Shares - 5,000,000 authorized; par value $0.00001 per share, Preferred B shares - 29,500 authorized; 0 issued with a $100 stated value, par value $0.00001 per share      

Condensed Consolidated Balance Sheets (Parenthetical)

v2.4.0.6
Condensed Consolidated Balance Sheets (Parenthetical) (USD $)
Jul. 31, 2013
Apr. 30, 2013
Accumulated depreciation of Property, plant and equipment $ 311,602 $ 310,700
Preferred stock, shares authorized 5,000,000 5,000,000
Preferred stock, par value $ 0.00001 $ 0.00001
Common stock, shares authorized 2,250,000,000 2,250,000,000
Common stock, par value $ 0.00001 $ 0.00001
Common stock, shares issued 737,317,746 737,117,746
Common stock, shares outstanding 737,317,746 737,117,746
Preferred B Shares [Member]
   
Preferred stock, shares authorized 29,500 29,500
Preferred stock, par value $ 0.00001 $ 0.00001
Preferred stock, shares issued 0 0
Preferred shares, stated value per share $ 100 $ 100

Condensed Consolidated Statements of Operations (Unaudited)

v2.4.0.6
Condensed Consolidated Statements of Operations (Unaudited) (USD $)
3 Months Ended
Jul. 31, 2013
Jul. 31, 2012
Revenue and Other Income    
Oil and natural gas sales $ 104,840 $ 1,729
Total Income 104,840 1,729
Operating Expenses    
Operating 64,079 21,566
General and administrative 679,528 183,564
Officers' share based compensation 1,539,500   
Depreciation, depletion and accretion 26,354 21,950
Total Expenses 2,309,461 227,080
Operating loss (2,204,621) (225,351)
Other expenses    
Interest expense (5) (374,501)
Total other expenses (5) (374,501)
Net Loss $ (2,204,626) $ (599,852)
Net Loss per Common Share Basic and Diluted $ 0.00 $ 0.00
Weighted Average Number of Common Shares Outstanding - Basic and Diluted 737,311,224 427,574,247

Condensed Consolidated Statements of Cash Flows (Unaudited)

v2.4.0.6
Condensed Consolidated Statements of Cash Flows (Unaudited) (USD $)
3 Months Ended
Jul. 31, 2013
Jul. 31, 2012
CASH FLOWS FROM OPERATING ACTIVITIES:    
Net loss $ (2,204,626) $ (599,852)
Adjustments to reconcile net loss to net cash used in operating activities    
Depreciation, depletion and amortization 13,098 21,950
Accretion of asset retirement obligation 13,256   
Officers' share based compensation 1,539,500   
Changes in operating assets and liabilities:    
Accounts receivable (13,736) (8,935)
Prepaid expenses and other assets 9,001 (75,454)
Accounts payable and accrued liabilities 274,761 535,596
Net Cash Used in Operating Activities (368,746) (126,695)
Cash Flows From Investing Activities:    
Capitalized expenditure on oil and gas assets (295,965) (8,466,252)
Issuance of notes receivable to related party    (250,000)
Net Cash Used in Investing Activities (295,965) (8,716,252)
Cash Flows From Financing Activities:    
Proceeds from issuance of notes   11,532,483
Net Cash Provided by Financing Activities    11,532,483
Change in cash and cash equivalents (664,711) 2,689,536
Cash and cash equivalents, beginning of period 5,703,082 4,364,033
Cash and cash equivalents, end of period 5,038,371 7,053,569
Cash Paid During the Period for:    
Income taxes      
Interest paid      
Non-cash investing and financing activities:    
Conversion of accrued settlement liability into common stock $ 80,000   

Organization and Liquidity

v2.4.0.6
Organization and Liquidity
3 Months Ended
Jul. 31, 2013
Organization And Liquidity  
Organization and Liquidity

1.   Organization and Liquidity:

 

Petro River Oil Corp (the “Company”) is an enterprise engaged in the exploration and exploitation of heavy oil properties. The Company’s principal administrative office is located in Houston, Texas and its principal operations are in Kansas and Western Missouri.

 

Petro River Oil LLC (“Petro”) was incorporated under the laws of the State of Delaware on March 3, 2011.  Through proceeds received from the issuance of various promissory notes, on February 1, 2012 Petro  purchased various interests in oil and gas leases, wells, records, data and related personal property located along the Mississippi Lime play in the state of Kansas from Metro Energy Corporation (“Metro”)., a Louisiana company, and other interrelated entities, which were in financial distress. These assets were purchased by Petro from Metro through a court approved order as Metro was undergoing Chapter 11 Bankruptcy proceedings as a Debtor-In-Possession of these various oil and gas assets. Petro purchased these assets for cash consideration of $2,000,000 as well as a 25% non-managing membership interest in the Company.  Subsequent to the Metro purchase the Company engaged Energy Source Advisors to renew a number of the leases acquired in the Metro purchase and to lease additional acreage. As a result of the asset purchase from Metro and the completion of the additional lease renewals and additional acreage purchases, the Company obtained a total of 115,000 gross/85,000 net acres of leases, having unproven reserves at the time of acquisition, in the Mississippi Lime play in Southeast Kansas for total cost of $12.2 million.

 

On April 23, 2013, the Company executed and consummated a securities purchase agreement by and among the Company, Petro, the holders of outstanding secured promissory notes of Petro (the “Notes”), and the members (the “Petro Members”) of Petro holding membership interests in Petro (the “Membership Interests”), and together with the Notes and the Membership Interests, the “Acquired Securities”) sold by the Company (the “Securities Purchase Agreement” and the transaction, the “Share Exchange”).  

 

In the Share Exchange, the Investors exchanged their Acquired Securities for 591,021,011 newly issued shares of common stock of the Company (“Common Stock”). As a result, upon completion of the Share Exchange, Petro became the Company’s wholly-owned subsidiary.

 

As a result of the Share Exchange, the Company acquired 100% of the member units of Petro and consequently, control of the business and operations of Petro. Under generally accepted accounting principles in the Unites States, (“U.S. GAAP”) because Petro’s former members’ and note holders held 80% of the issued and outstanding shares of the Company as a result of the Share Exchange, Petro is deemed the accounting acquirer while the Company remains the legal acquirer. Petro adopted the fiscal year of the Company and its operations for the period from February 2, 2012 (Commencement of Operations) to July 31, 2012 were not material. Prior to the Share Exchange, all historical financial statements presented are those of Petro. The equity of the Company is the historical equity of Petro, retrospectively restated to reflect the number of shares issued by the Company in the transaction.

 

Liquidity and Management Plans

 

The Company is focused on developing its recently acquired Mississippi Lime acreage in Kansas and also its heavy oil properties in Missouri and Kentucky. Early reservoir projects in Kansas were focused on establishing proved reserve potential into the Bourbon Arch geological region of the Mississippi Lime play. The production response from this region established migration and asset production potential. The Company also engaged an extensive geologic study of its leasehold position using over 26,000 producers and 60 square miles of a proprietary 3D data set.

 

Projects related to the heavy oil reservoirs were in technical review. The Company has an extensive amount of technical and reservoir information on both Missouri and Kansas positions. The data is being utilized in the understanding and test phases to develop an economic heavy oil production reserve base.

 

The ultimate goal of the management of the Company is to maximize shareholder value. Specific targets include: increasing production by developing its acreage, increasing profitability margins by evaluating and optimizing its production, and executing its business plan to increase property values, prove its reserves, and expand its asset base.

 

As of July 31, 2013, the Company has working capital of approximately $2.3 million and has incurred losses since it commenced operations and utilized cash in its operating activities to date. In addition, Petro has a limited operating history. At July 31, 2013, the Company has cash and cash equivalents of approximately $5.0 million. Management believes that the current level of working capital is sufficient to maintain operations for at least the next 12 months. Management intends to continue to raise capital through debt and equity instruments in order to achieve its business plans.

Basis of Preparation

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Basis of Preparation
3 Months Ended
Jul. 31, 2013
Organization, Consolidation and Presentation of Financial Statements [Abstract]  
Basis of Preparation

2.   Basis of Preparation:

 

The condensed consolidated financial statements and accompanying footnotes are prepared in accordance with US GAAP and include the accounts of the Company and its wholly-owned subsidiaries. All material intercompany balances and transactions have been eliminated in consolidation.

 

These condensed consolidated financial statements include the below wholly-owned subsidiaries:

 

Petro River Oil LLC, and MegaWest Energy USA Corp. and its wholly owned subsidiaries:

 

MegaWest Energy Texas Corp.
MegaWest Energy Kentucky Corp.
MegaWest Energy Missouri Corp.
MegaWest Energy Kansas Corp.
MegaWest Energy Montana Corp.

 

The unaudited financial information furnished herein reflects all adjustments, consisting solely of normal recurring items, which in the opinion of management are necessary to fairly state the financial position the Company and the results of its operations for the periods presented. This report should be read in conjunction with the Company’s consolidated financial statements and notes thereto included in the Company’s Form 10-K for the transition period from January 1, 2013 to April 30, 2013 filed with the Securities and Exchange Commission (the “SEC”) on August 28, 2013. 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 transition period from January 1, 2013 to April 30, 2013 has been omitted. The results of operations for the interim periods presented are not necessarily indicative of results for the entire year ending April 30, 2014.

Significant Accounting Policies

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Significant Accounting Policies
3 Months Ended
Jul. 31, 2013
Accounting Policies [Abstract]  
Significant Accounting Policies

3.   Significant Accounting Policies:

   

(a)   Use of Estimates

 

The preparation of condensed consolidated financial statements in conformity with US GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates include volumes of oil and natural gas reserves, abandonment obligations, impairment of oil and natural gas properties, depreciation, depletion and accretion, income taxes, fair value of derivatives liabilities and other financial instruments, and contingencies.

 

Oil and gas proven reserve estimates, which are the basis for unit-of-production depletion and the full cost ceiling test, have a number of inherent uncertainties. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing, and production subsequent to the date of the estimate may justify revision of such estimate. Accordingly, reserve estimates are often different from the quantities of oil and gas that are ultimately recovered. In addition, reserve estimates are vulnerable to changes in prices of crude oil and gas. Such prices have been volatile in the past and can be expected to be volatile in the future. As of July 31, 2013 and April 30, 2013, the Company had no estimated proven reserves.

 

(b)   Cash and Cash Equivalents:

 

Cash and cash equivalents include all highly liquid monetary instruments with original maturities of three months or less when purchased to be cash equivalents. These investments are carried at cost, which approximates fair value. Financial instruments that potentially subject the Company to concentrations of credit risk consist primarily of cash deposits. The Company maintains its cash in institutions insured by the Federal Deposit Insurance Corporation (“FDIC”). At times, the Company’s cash and cash equivalent balances may be uninsured or in amounts that exceed the FDIC insurance limits.

  

(c)   Oil and Gas Operations:

 

Oil and Gas Properties: The Company uses the full-cost method of accounting for its exploration and development activities. Under this method of accounting, the costs of both successful and unsuccessful exploration and development activities are capitalized as oil and gas property and equipment. Proceeds from the sale or disposition of oil and gas properties are accounted for as a reduction to capitalized costs unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to a country, in which case a gain or loss would be recognized in the statement of operations. All of the Company’s oil and gas properties are located within the continental United States, its sole cost center.

 

Oil and gas properties may include costs that are excluded from costs being depleted. Oil and gas costs excluded represent investments in unproved properties and major development projects in which the Company owns a direct interest. These unproved property costs include nonproducing leasehold, geological and geophysical costs associated with leasehold or drilling interests and in process exploration drilling costs. All costs excluded are reviewed at least quarterly to determine if impairment has occurred.

 

The Company accounts for its unproven long-lived assets in accordance with Accounting Standards Codification (“ASC”) Topic 360-10-05, “Accounting for the Impairment or Disposal of Long-Lived Assets.” ASC Topic 360-10-05 requires that long-lived assets be reviewed for impairment whenever events or changes in circumstances indicate that the historical cost carrying value of an asset may no longer be appropriate. The Company performed a comparable study of unproven long-lived assets as of April 30, 2013 and determined that none of its long-term assets at April 30, 2013 were impaired. No material changes have occurred from April 30, 2013 (date of last comparable study) to July 31, 2013.

 

Proved Oil and Gas Reserves: In accordance with Rule 4-10 of SEC Regulation S-X, proved oil and gas reserves are the estimated quantities of crude oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. All the oil and gas properties with proven reserves were impaired to the salvage value prior to the merger. The price used to establish economic producibility is the average price during the 12-month period preceding the end of the entity’s fiscal year and calculated as the un-weighted arithmetic average of the first-day-of-the-month price for each month within such 12-month period.

 

Ceiling Test: Under the full-cost method of accounting, a ceiling test is performed quarterly. The full-cost ceiling test is an impairment test prescribed by SEC Regulation S-X Rule 4-10. The ceiling test determines a limit on the carrying value of oil and gas properties.  The capitalized costs of proved oil and gas properties, net of accumulated depreciation, depletion, amortization, and impairment and the related deferred income taxes, may not exceed the estimated future net cash flows from proved oil and gas reserves, excluding future cash outflows associated with settling asset retirement obligations that have been accrued on the balance sheet, generally using current prices (with consideration of price changes only to the extent provided by contractual arrangements) as of the date of the latest balance sheet presented and including the effect of derivative instruments that qualify as cash flow hedges, discounted at 10%, net of related tax effects, plus the cost of unevaluated properties and major development projects excluded from the costs being amortized. If capitalized costs exceed this limit, the excess is charged to expense and reflected as additional accumulated depreciation, depletion, amortization and impairment. In the application of the full-cost method, the term “current price” means the average price during the 12-month period prior to the end of the entity’s fiscal year determined as the un-weighted arithmetical average of the prices on the first day of each month within the 12-month period. 

  

Depletion, Depreciation and Amortization: Depletion, depreciation and amortization is provided using the unit-of-production method based upon estimates of proved oil and gas reserves with oil and gas production being converted to a common unit of measure based upon their relative energy content. For the three months ended July 31, 2013 and 2012, all oil and gas reserves were classified as unproven. Investments in unproved properties and major development projects are not amortized until proved reserves associated with the projects can be determined or until impairment occurs. If the results of an assessment indicate that the properties are impaired, the amount of the impairment is deducted from the capitalized costs to be amortized. Once the assessment of unproved properties is complete and when major development projects are evaluated, the costs previously excluded from amortization are transferred to the full cost pool and amortization begins. The amortizable base includes estimated future development costs and, where significant, dismantlement, restoration and abandonment costs, net of estimated salvage value.

 

In arriving at rates under the unit-of-production method, the quantities of recoverable oil and natural gas reserves are established based on estimates made by the Company’s geologists and engineers which require significant judgment, as does the projection of future production volumes and levels of future costs, including future development costs. In addition, considerable judgment is necessary in determining when unproved properties become impaired and in determining the existence of proved reserves once a well has been drilled. All of these judgments may have significant impact on the calculation of depletion expenses. There have been no material changes in the methodology used by the Company in calculating depletion, depreciation and amortization of oil and gas properties under the full cost method during the three months ended July 31, 2013 and 2012.

 

(d)   Asset Retirement Obligations:

 

The Company recognizes a liability for the estimated fair value of site restoration and abandonment costs when the obligations are legally incurred and the fair value can be reasonably estimated. The fair value of the obligations is based on the estimated cash flow required to settle the obligations discounted using the Company’s credit adjusted risk-free interest rate. The obligation is recorded as a liability with a corresponding increase in the carrying amount of the oil and gas assets. The capitalized amount will be depleted on a unit-of-production method. The liability is increased each period, or accretes, due to the passage of time and a corresponding amount is recorded in the statement of operations.

 

Revisions to the estimated fair value would result in an adjustment to the liability and the capitalized amount in oil and gas assets.

 

(e)   Oil and Gas Revenue:

 

Sales of oil and gas, net of any royalties, are recognized when oil has been delivered to a custody transfer point, persuasive evidence of a sales arrangement exists, the rights and responsibility of ownership pass to the purchaser upon delivery, collection of revenue from the sale is reasonably assured, and the sales price is fixed or determinable. The Company sells oil and gas on a monthly basis. Virtually all of its contracts’ pricing provisions are tied to a market index, with certain adjustments based on, among other factors, whether a well delivers to a gathering or transmission line, the quality of the oil and gas, and prevailing supply and demand conditions, so that the price of the oil and gas fluctuates to remain competitive with other available oil supplies.

 

(h)   Per Share Amounts:

 

Basic net loss per common share is computed by dividing net loss attributable to common stockholders by the weighted-average number of common shares outstanding during the period. Diluted net earnings (loss) per common share is determined using the weighted-average number of common shares outstanding during the period, adjusted for the dilutive effect of common stock equivalents. In periods when losses are reported, which is the case for the three months ended July 31, 2013 and 2012, presented in these condensed consolidated financial statements, the weighted-average number of common shares outstanding excludes common stock equivalents because their inclusion would be anti-dilutive. Common share equivalents excluded an aggregate of 520,000 and 0 shares of common stock for the three months ended July 31, 2013 and 2012, respectively. The Company had no common stock equivalents at July 31, 2012.

 

The Company had the following common stock equivalents at July 31, 2013 and 2012:

 

As at   July 31, 2013     July 31, 2012  
Stock Options     290,000       -  
Compensation Warrants     230,000       -  
      520,000       -  

 

(j)   Fair Value of Financial Instruments:

 

All financial instruments, including cash and cash equivalents, accounts receivable, prepaid expenses and accounts payable are to be recognized on the balance sheet initially at carrying value. The carrying value of these assets approximate their fair value due to their short-term maturities.

 

At each balance sheet date, the Company assesses financial assets for impairment with any impairment recorded in the consolidated statement of operations. To assess loans and receivables for impairment, the Company evaluates the probability of collection of accounts receivable and records an allowance for doubtful accounts, which reduces loans and receivables to the amount management reasonably believes will be collected. In determining the amount of the allowance, the following factors are considered: the length of the time the receivable has been outstanding, specific knowledge of each customer’s financial condition and historical experience.

 

Market risk is the risk that changes in commodity prices will affect the Company’s oil sales, cash flows or the value of its financial instruments. The objective of commodity price risk management is to manage and control market risk exposures within acceptable limits while maximizing returns.

 

The Company is exposed to changes in oil prices which impact its revenues and to changes in natural gas process which impact its operating expenses.

   

The Company does not utilize financial derivatives or other contracts to manage commodity price risks.

 

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price).

 

Fair value measurements are categorized using a valuation hierarchy for disclosure of the inputs used to measure fair value, which prioritize the inputs into three broad levels:

 

Level 1 - Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

 

Level 2 - Pricing inputs are other than quoted prices in active markets included in level 1, which are either directly or indirectly observable as of the reported date, and include those financial instruments that are valued using models or other valuation methodologies.

 

Level 3 - Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

 

(k)   Subsequent Events:

 

The Company evaluates subsequent events through the date when condensed consolidated financial statements are issued.   

 

(l)   Recent Accounting Pronouncements:

 

Management does not believe that any recently issued, but not yet effective accounting pronouncements, if adopted, would have a material effect on the accompanying consolidated financial statements. 

Oil and Gas Assets

v2.4.0.6
Oil and Gas Assets
3 Months Ended
Jul. 31, 2013
Extractive Industries [Abstract]  
Oil and Gas Assets

4.   Oil and Gas Assets:

 

The following table summarizes the oil and gas assets by project:

   

Cost   Missouri     Kentucky     Montana     Kansas     Other     Total  
Balance, May 1, 2013   $ 918,991     $   -     $ 75,000     $ 12,329,098     $ 100,000     $ 13,423,089  
Additions                             295,965               295,965  
Depreciation, Depletion and amortization     -       -       -       (12,196 )     -       (12,196 )
                                                 
Balance July 31, 2013   $ 918,991     $ -     $ 75,000     $ 12,612,867     $ 100,000     $ 13,706,858  

 

The following are descriptions of the Company’s oil and gas assets. The assets are disclosed based on the historical ownership of both Petro and the Company.

 

Kansas

 

Through proceeds received from the issuance of various promissory notes, on February 1, 2012 Petro  purchased various interests in oil and gas leases, wells, records, data and related personal property located along the Mississippi Lime play in the state of Kansas from Metro Energy Corporation (“Metro”)., a Louisiana company and other interrelated entities, which were in financial distress. These assets were purchased by Petro from Metro through a court approved order as Metro was undergoing Chapter 11 Bankruptcy proceedings as a Debtor-In-Possession of these various oil and gas assets. Petro purchased these assets for cash considerations of $2,000,000 as well as a 25% non-managing membership interest in the Company. Subsequent to the Metro purchase the Company engaged Energy Source Advisors to renew a number of the leases acquired in the Metro purchase and to lease additional acreage. As a result of the asset purchase from Metro and the completion of the additional lease renewals and additional acreage purchases, the Company obtained a total of 115,000 gross/85,000 net acres of leases, having unproven reserves at the time of acquisition, in the Mississippi Lime play in Southeast Kansas for total cost of $12.2 million. The Company also acquired over 60 square miles of proprietary 3D seismic data over prospective Mississippi Lime acreage in the same area. During the three months ended July 31, 2013, the Company capitalized an additional $0.3 million in Kansas oil and gas expenditures.

 

Kentucky

 

As a result of the share exchange, the Company acquired Kentucky lease holdings which include a 37.5% working interest in 27,150 unproved gross acres (10,181 net acres). The Kentucky property is mainly undeveloped land and therefore was not assigned any reserve value under the Company’s independent reserve reports. 

 

Currently, the Company is carrying these oil and gas assets at $-, the carrying value of the assets acquired through the share exchange.

  

Missouri

 

At April 30, 2013, the Company’s Missouri lease holdings totaled 22,832 gross acres with 98.4% working interest.

 

On separate pilot projects at Deerfield, the Company built two 500 barrel of oil per day steam drive production facilities (Marmaton River and Grassy Creek) comprised of 116 production wells, 39 steam injection wells and 14 service and observation wells. Throughout the Deerfield area, the Company have drilled 73 exploration/delineation wells with a 67% success rate. 

 

As of July 31, 2013, all Missouri assets were carried at salvage value, since the Company’s current business plans do not contemplate raising the necessary capital to develop these properties.

 

Montana

 

The Montana leasehold is in the Devils Basin prospect and totals 1,175 gross acres (881 net). The Company currently owns a 75% working interest in this prospect, but has no immediate plans to develop this property. On April 17, 2012 the Teton Prospect leases totaling 2,807 gross acres (1137 net) expired.

 

As of July 31, 2013, all Montana assets were carried at salvage value.

 

Other

 

Other property consists primarily of four used steam generators and related equipment that will be assigned to future projects. As of July 31, 2013, management concluded that impairment was not necessary as all other assets were carried at salvage value.

Asset Retirement Obligations

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Asset Retirement Obligations
3 Months Ended
Jul. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]  
Asset Retirement Obligations

5.   Asset Retirement Obligations:

 

The total future asset retirement obligation was estimated based on the Company’s ownership interest in all wells and facilities, the estimated legal obligations required to retire, dismantle, abandon and reclaim the wells and facilities and the estimated timing of such payments. The Company estimated the present value of its asset retirement obligations at July 31, 2013 and April 30, 2013, based on a future undiscounted liability of $1,087,292 and $1,087,292, respectively. These costs are expected to be incurred within one to 24 years. A credit-adjusted risk-free discount rate of 10% and an inflation rate of 2% were used to calculate the present value.

  

Changes to the asset retirement obligation were as follows:

 

    July 31, 2013     April 30, 2013  
Balance, beginning of period   $ 763,036     $ 143,035  
Additions     -       615,784  
Disposition     -       -  
Revisions     -       -  
Accretion     13,256       4,217  
      776,292       763,036  
Less: Current portion for cash flows expected to be incurred within one year     (213,302 )     (213,302 )
Long-term portion, end of period   $ 562,990     $ 549,734  

 

As of July 31, 2013 and April 30, 2013, the Company has $25,000 of reclamation deposits with authorities to secure certain abandonment liabilities in Missouri.

 

Expected timing of asset retirement obligations:

 

Year Ended April 30      
2014     213,302  
2015     122,222  
2016     135,556  
2017     273,181  
Thereafter     343,031  
      1,087,292  
Effect of discount     (311,000 )
Total   $ 776,292  

Related Party Transactions

v2.4.0.6
Related Party Transactions
3 Months Ended
Jul. 31, 2013
Related Party Transactions [Abstract]  
Related Party Transactions

6.   Related Party Transactions:

 

Upon completion of the Share Exchange, the Company entered into an Employment Agreement with Scot Cohen, the Company’s Executive Chairman (the “Employment Agreement”).

 

In accordance with the Employment Agreement, Mr. Cohen is entitled to an issuance of 66,340,597 shares of the Company’s common stock, or a substitute equity award with equal economic benefit as determined by the Board of Directors. As of July 31, 2013 and through the date of filing of this report, the award is yet to be issued.

 

The Company computed the economic benefit of the issuance as of the date of the agreement based on the fair value of the Company’s common stock as quoted on the Over the Counter Bulletin Board ($0.40) and recorded a related party liability of approximately $1.4 million as a result of the share-based award to Mr. Cohen for the service period ended July 31, 2013. The total grant date fair value was approximately $26.5 million. The award vests over a service period of 5 years. Management concluded liability treatment is warranted as the Board of Directors is yet to determine the type of award to be issued.

 

In addition, in June and July of 2013, the Company signed a series of agreements with Jeffrey Freedman, former Chief Executive Officer, in relation to his departure from the Company. Pursuant to these agreements, the Company has provided to Mr. Freedman the sum of $12,000 and will issue options to purchase common stock with a $100,000 aggregate fair market value (as “fair market value” is defined in the 2012 Equity Compensation Plan) as of the July 24, 2013 option grant date. These options will expire on July 23, 2016. As of July 31, 2013 and through the date of filing of this report, these options have not been granted to and the $100,000 is recorded as a related party liability.

Stock Based Compensation

v2.4.0.6
Stock Based Compensation
3 Months Ended
Jul. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]  
Stock Based Compensation

7.   Stock Based Compensation:

 

As of July 31, 2013, the Company has one equity incentive plan. The number of shares reserved for issuance in aggregate under the plan is limited to 90 million shares. The exercise price, term and vesting schedule of stock options granted are set by the board of directors at the time of grant. Stock options granted under the plan may be exercised on a cashless basis, if such exercise is approved by the Board. In a cashless exercise, the employee receives a lesser amount of shares in lieu of paying the exercise price based on the quoted market price of the shares on the trading day immediately preceding the exercise date.

 

As of July 31, 2013 and April 30, 2013, the Company had 290,000 options outstanding and exerciseable with a weighted average exercise price of $0.50. No options were granted, forfeited or cancelled during the three months ended July 31, 2013.

 

During the three months ended July 31, 2013 and 2012, the Company had no stock based compensation expense. The options were fully vested at the time of the share exchange.

 

As of July 31, 2013, the Company has no compensation costs related to non-vested stock options not yet recognized.

 

The following table summarizes information about the options outstanding and exercisable at July 31, 2013:

 

      Options Outstanding     Options Exercisable  
Exercise Price     Options     Weighted Avg.
Life Remaining
  Weighted Avg.
Exercise Price
    Options     Weighted Avg.
Exercise Price
 
$ 0.50       290,000     0.76 years   $ 0.50       290,000     $ 0.50  
                                         
Aggregate Intrinsic Value                 $ -             $ -  

 

Intrinsic value is the Company’s current per share fair value as quoted on the Over the Counter Bulletin Board on the balance sheet date ($0.22) less the current exercise price.

 

As of July 31, 2013 and April 30, 2013, the Company had 230,000 warrants outstanding and exercisable with a weighted average exercise price of $0.50 and a weighted average remaining life of 0.15 and 0.65 years. No warrants were granted, forfeited or cancelled during the three months ended July 31, 2013. The aggregate intrinsic value of the warrants was $0. Intrinsic value is the Company’s current per share fair value as quoted on the Over the Counter Bulletin Board on the balance sheet date ($0.22) less the current exercise price.

Contingency and Contractual Obligations

v2.4.0.6
Contingency and Contractual Obligations
3 Months Ended
Jul. 31, 2013
Commitments and Contingencies Disclosure [Abstract]  
Contingency and Contractual Obligations

8.   Contingency and Contractual Obligations:

 

As a result of the Share Exchange, the Company inherited the following contingencies:

   

(a) In January 2010, the Company experienced a flood in its Calgary office premises as a result of a broken water pipe. There was significant damage to the premises rendering them unusable until remediation had been completed by the landlord. Pursuant to the lease contract, the Company has asserted that rent should be abated during the remediation process and accordingly, the Company has not paid rent since December 2009. During the remediation process, the Company engaged an independent environmental testing company to test for air quality and for the existence of other potentially hazardous conditions. The testing revealed the existence of potentially hazardous mold and the consultant provided specific written instructions for the effective remediation of the premises. During the remediation process, the landlord did not follow the consultant’s instructions and correct the potentially hazardous mold situation and subsequently in June 2010 gave notice and declared the premises to be ready for occupancy. The Company re-engaged the consultant to re-test the premises and the testing results again revealed the presence of potentially hazardous mold. The Company has determined that the premises are not fit for re-occupancy and considers the landlord to be in default of the lease and the lease terminated.

 

The landlord disputes the Company’s position and has given notice that it considers the Company to be in default of the lease for failure to re-occupy the premises.

 

In addition, the landlord has claimed that the Company owes monthly rent for the premises from January 2010 to June 30, 2010 in the amount of $247,348 and has claimed that, as a result of the alleged default, pursuant to the terms of the lease, the Company owes three months accelerated rent in the amount of $114,837. The landlord has also asserted that the Company would be liable for an amount up to the full lease obligation of $1,596,329 which otherwise would have been due as follows:

 

Year Ended April 30        
2011     $ 473,055  
2012       473,055  
2013       473,055  
2014       177,164  
Thereafter       -  
Total     $ 1,596,329  

 

To date, no legal action has been commenced by the landlord and the cost, if any, to the Company is not determinable. Accordingly, no amounts related to rent or the disputed lease obligation have been recorded in these financial statements.

 

(b) On March 15, 2013, a former employee of the Company (VP-Operations) commenced an action in the Court of Queen’s Bench of Alberta claiming wrongful termination and seeking severance in an amount approximating US$185,000. On May 3, 2013, the Company reached a settlement with the former employee and entered into a formal settlement and release of claims agreement. As consideration for full settlement and mutual release, the Company issued the former employee 200,000 shares of common stock of the Company, valued at $0.40/share or $80,000, and paid $50,000 during the three months ended July 31, 2013.

 

(c) Upon completion of the Share Exchange, the Company entered into an Employment Agreement with Scot Cohen. Under the terms of the Employment Agreement, Mr. Cohen will be entitled to all earned but unpaid salary, expense reimbursements, bonuses (if applicable), and any vested benefits, upon termination of the Employment Agreement by the Company for cause, by Mr. Cohen without good reason, or upon the Employment Agreement’s expiration date in the event Mr. Cohen does not choose to renew his contract. In the event Mr. Cohen’s employment is terminated by the Company without cause, upon a change in control of the company, or by Mr. Cohen for good reason, he shall be entitled to any accrued obligations (detailed in the preceding sentence), severance in a single lump sum installment in an amount equal to twice the sum of the base salary in effect on the termination date plus two times the maximum annual bonus for which Mr. Cohen was eligible in the fiscal year in which the termination date occurred, a pro-rata portion of Mr. Cohen’s annual bonus for the fiscal year in which the termination occurred, and a full vesting in the initial grant and in any and all previously granted outstanding equity-based incentive awards subject to time-based vesting criteria. In addition, Mr. Cohen is entitled to a share based payment (See Note 6).

Significant Accounting Policies (Policies)

v2.4.0.6
Significant Accounting Policies (Policies)
3 Months Ended
Jul. 31, 2013
Accounting Policies [Abstract]  
Use of Estimates

(a)   Use of Estimates

 

The preparation of condensed consolidated financial statements in conformity with US GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Significant estimates include volumes of oil and natural gas reserves, abandonment obligations, impairment of oil and natural gas properties, depreciation, depletion and accretion, income taxes, fair value of derivatives liabilities and other financial instruments, and contingencies.

 

Oil and gas proven reserve estimates, which are the basis for unit-of-production depletion and the full cost ceiling test, have a number of inherent uncertainties. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing, and production subsequent to the date of the estimate may justify revision of such estimate. Accordingly, reserve estimates are often different from the quantities of oil and gas that are ultimately recovered. In addition, reserve estimates are vulnerable to changes in prices of crude oil and gas. Such prices have been volatile in the past and can be expected to be volatile in the future. As of July 31, 2013 and April 30, 2013, the Company had no estimated proven reserves.

Cash and Cash Equivalents

(b)   Cash and Cash Equivalents:

 

Cash and cash equivalents include all highly liquid monetary instruments with original maturities of three months or less when purchased to be cash equivalents. These investments are carried at cost, which approximates fair value. Financial instruments that potentially subject the Company to concentrations of credit risk consist primarily of cash deposits. The Company maintains its cash in institutions insured by the Federal Deposit Insurance Corporation (“FDIC”). At times, the Company’s cash and cash equivalent balances may be uninsured or in amounts that exceed the FDIC insurance limits.

Oil and Gas Operations

(c)   Oil and Gas Operations:

 

Oil and Gas Properties: The Company uses the full-cost method of accounting for its exploration and development activities. Under this method of accounting, the costs of both successful and unsuccessful exploration and development activities are capitalized as oil and gas property and equipment. Proceeds from the sale or disposition of oil and gas properties are accounted for as a reduction to capitalized costs unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to a country, in which case a gain or loss would be recognized in the statement of operations. All of the Company’s oil and gas properties are located within the continental United States, its sole cost center.

 

Oil and gas properties may include costs that are excluded from costs being depleted. Oil and gas costs excluded represent investments in unproved properties and major development projects in which the Company owns a direct interest. These unproved property costs include nonproducing leasehold, geological and geophysical costs associated with leasehold or drilling interests and in process exploration drilling costs. All costs excluded are reviewed at least quarterly to determine if impairment has occurred.

 

The Company accounts for its unproven long-lived assets in accordance with Accounting Standards Codification (“ASC”) Topic 360-10-05, “Accounting for the Impairment or Disposal of Long-Lived Assets.” ASC Topic 360-10-05 requires that long-lived assets be reviewed for impairment whenever events or changes in circumstances indicate that the historical cost carrying value of an asset may no longer be appropriate. The Company performed a comparable study of unproven long-lived assets as of April 30, 2013 and determined that none of its long-term assets at April 30, 2013 were impaired. No material changes have occurred from April 30, 2013 (date of last comparable study) to July 31, 2013.

 

Proved Oil and Gas Reserves: In accordance with Rule 4-10 of SEC Regulation S-X, proved oil and gas reserves are the estimated quantities of crude oil, natural gas and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. All the oil and gas properties with proven reserves were impaired to the salvage value prior to the merger. The price used to establish economic producibility is the average price during the 12-month period preceding the end of the entity’s fiscal year and calculated as the un-weighted arithmetic average of the first-day-of-the-month price for each month within such 12-month period.

 

Ceiling Test: Under the full-cost method of accounting, a ceiling test is performed quarterly. The full-cost ceiling test is an impairment test prescribed by SEC Regulation S-X Rule 4-10. The ceiling test determines a limit on the carrying value of oil and gas properties.  The capitalized costs of proved oil and gas properties, net of accumulated depreciation, depletion, amortization, and impairment and the related deferred income taxes, may not exceed the estimated future net cash flows from proved oil and gas reserves, excluding future cash outflows associated with settling asset retirement obligations that have been accrued on the balance sheet, generally using current prices (with consideration of price changes only to the extent provided by contractual arrangements) as of the date of the latest balance sheet presented and including the effect of derivative instruments that qualify as cash flow hedges, discounted at 10%, net of related tax effects, plus the cost of unevaluated properties and major development projects excluded from the costs being amortized. If capitalized costs exceed this limit, the excess is charged to expense and reflected as additional accumulated depreciation, depletion, amortization and impairment. In the application of the full-cost method, the term “current price” means the average price during the 12-month period prior to the end of the entity’s fiscal year determined as the un-weighted arithmetical average of the prices on the first day of each month within the 12-month period. 

  

Depletion, Depreciation and Amortization: Depletion, depreciation and amortization is provided using the unit-of-production method based upon estimates of proved oil and gas reserves with oil and gas production being converted to a common unit of measure based upon their relative energy content. For the three months ended July 31, 2013 and 2012, all oil and gas reserves were classified as unproven. Investments in unproved properties and major development projects are not amortized until proved reserves associated with the projects can be determined or until impairment occurs. If the results of an assessment indicate that the properties are impaired, the amount of the impairment is deducted from the capitalized costs to be amortized. Once the assessment of unproved properties is complete and when major development projects are evaluated, the costs previously excluded from amortization are transferred to the full cost pool and amortization begins. The amortizable base includes estimated future development costs and, where significant, dismantlement, restoration and abandonment costs, net of estimated salvage value.

 

In arriving at rates under the unit-of-production method, the quantities of recoverable oil and natural gas reserves are established based on estimates made by the Company’s geologists and engineers which require significant judgment, as does the projection of future production volumes and levels of future costs, including future development costs. In addition, considerable judgment is necessary in determining when unproved properties become impaired and in determining the existence of proved reserves once a well has been drilled. All of these judgments may have significant impact on the calculation of depletion expenses. There have been no material changes in the methodology used by the Company in calculating depletion, depreciation and amortization of oil and gas properties under the full cost method during the three months ended July 31, 2013 and 2012.

Asset Retirement Obligations

(d)   Asset Retirement Obligations:

 

The Company recognizes a liability for the estimated fair value of site restoration and abandonment costs when the obligations are legally incurred and the fair value can be reasonably estimated. The fair value of the obligations is based on the estimated cash flow required to settle the obligations discounted using the Company’s credit adjusted risk-free interest rate. The obligation is recorded as a liability with a corresponding increase in the carrying amount of the oil and gas assets. The capitalized amount will be depleted on a unit-of-production method. The liability is increased each period, or accretes, due to the passage of time and a corresponding amount is recorded in the statement of operations.

 

Revisions to the estimated fair value would result in an adjustment to the liability and the capitalized amount in oil and gas assets.

Oil and Gas Revenue

(e)   Oil and Gas Revenue:

 

Sales of oil and gas, net of any royalties, are recognized when oil has been delivered to a custody transfer point, persuasive evidence of a sales arrangement exists, the rights and responsibility of ownership pass to the purchaser upon delivery, collection of revenue from the sale is reasonably assured, and the sales price is fixed or determinable. The Company sells oil and gas on a monthly basis. Virtually all of its contracts’ pricing provisions are tied to a market index, with certain adjustments based on, among other factors, whether a well delivers to a gathering or transmission line, the quality of the oil and gas, and prevailing supply and demand conditions, so that the price of the oil and gas fluctuates to remain competitive with other available oil supplies.

Per Share Amounts

(h)   Per Share Amounts:

 

Basic net loss per common share is computed by dividing net loss attributable to common stockholders by the weighted-average number of common shares outstanding during the period. Diluted net earnings (loss) per common share is determined using the weighted-average number of common shares outstanding during the period, adjusted for the dilutive effect of common stock equivalents. In periods when losses are reported, which is the case for the three months ended July 31, 2013 and 2012, presented in these condensed consolidated financial statements, the weighted-average number of common shares outstanding excludes common stock equivalents because their inclusion would be anti-dilutive. Common share equivalents excluded an aggregate of 520,000 and 0 shares of common stock for the three months ended July 31, 2013 and 2012, respectively. The Company had no common stock equivalents at July 31, 2012.

 

The Company had the following common stock equivalents at July 31, 2013 and 2012:

 

As at   July 31, 2013     July 31, 2012  
Stock Options     290,000       -  
Compensation Warrants     230,000       -  
      520,000       -  

Fair Value of Financial Instruments

(j)   Fair Value of Financial Instruments:

 

All financial instruments, including cash and cash equivalents, accounts receivable, prepaid expenses and accounts payable are to be recognized on the balance sheet initially at carrying value. The carrying value of these assets approximate their fair value due to their short-term maturities.

 

At each balance sheet date, the Company assesses financial assets for impairment with any impairment recorded in the consolidated statement of operations. To assess loans and receivables for impairment, the Company evaluates the probability of collection of accounts receivable and records an allowance for doubtful accounts, which reduces loans and receivables to the amount management reasonably believes will be collected. In determining the amount of the allowance, the following factors are considered: the length of the time the receivable has been outstanding, specific knowledge of each customer’s financial condition and historical experience.

 

Market risk is the risk that changes in commodity prices will affect the Company’s oil sales, cash flows or the value of its financial instruments. The objective of commodity price risk management is to manage and control market risk exposures within acceptable limits while maximizing returns.

 

The Company is exposed to changes in oil prices which impact its revenues and to changes in natural gas process which impact its operating expenses.

   

The Company does not utilize financial derivatives or other contracts to manage commodity price risks.

 

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price).

 

Fair value measurements are categorized using a valuation hierarchy for disclosure of the inputs used to measure fair value, which prioritize the inputs into three broad levels:

 

Level 1 - Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

 

Level 2 - Pricing inputs are other than quoted prices in active markets included in level 1, which are either directly or indirectly observable as of the reported date, and include those financial instruments that are valued using models or other valuation methodologies.

 

Level 3 - Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

Subsequent Events

(k)   Subsequent Events:

 

The Company evaluates subsequent events through the date when condensed consolidated financial statements are issued.   

Recent Accounting Pronouncements

(l)   Recent Accounting Pronouncements:

 

Management does not believe that any recently issued, but not yet effective accounting pronouncements, if adopted, would have a material effect on the accompanying consolidated financial statements. 

Significant Accounting Policies (Tables)

v2.4.0.6
Significant Accounting Policies (Tables)
3 Months Ended
Jul. 31, 2013
Accounting Policies [Abstract]  
Schedule of Common Stock Equivalents

The Company had the following common stock equivalents at July 31, 2013 and 2012:

 

As at   July 31, 2013     July 31, 2012  
Stock Options     290,000       -  
Compensation Warrants     230,000       -  
      520,000       -  

Oil and Gas Assets (Tables)

v2.4.0.6
Oil and Gas Assets (Tables)
3 Months Ended
Jul. 31, 2013
Extractive Industries [Abstract]  
Schedule of Oil and Gas Assets

The following table summarizes the oil and gas assets by project:

   

Cost   Missouri     Kentucky     Montana     Kansas     Other     Total  
Balance, May 1, 2013   $ 918,991     $   -     $ 75,000     $ 12,329,098     $ 100,000     $ 13,423,089  
Additions                             295,965               295,965  
Depreciation, Depletion and amortization     -       -       -       (12,196 )     -       (12,196 )
                                                 
Balance July 31, 2013   $ 918,991     $ -     $ 75,000     $ 12,612,867     $ 100,000     $ 13,706,858  

Asset Retirement Obligations (Tables)

v2.4.0.6
Asset Retirement Obligations (Tables)
3 Months Ended
Jul. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]  
Schedule of Changes to Asset Retirement Obligation

Changes to the asset retirement obligation were as follows:

 

    July 31, 2013     April 30, 2013  
Balance, beginning of period   $ 763,036     $ 143,035  
Additions     -       615,784  
Disposition     -       -  
Revisions     -       -  
Accretion     13,256       4,217  
      776,292       763,036  
Less: Current portion for cash flows expected to be incurred within one year     (213,302 )     (213,302 )
Long-term portion, end of period   $ 562,990     $ 549,734  

Schedule of Expected Timing of Asset Retirement Obligations

Expected timing of asset retirement obligations:

 

Year Ended April 30      
2014     213,302  
2015     122,222  
2016     135,556  
2017     273,181  
Thereafter     343,031  
      1,087,292  
Effect of discount     (311,000 )
Total   $ 776,292  

Stock Based Compensation (Tables)

v2.4.0.6
Stock Based Compensation (Tables)
3 Months Ended
Jul. 31, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]  
Summary of Options Outstanding and Exercisable

The following table summarizes information about the options outstanding and exercisable at July 31, 2013:

 

      Options Outstanding     Options Exercisable  
Exercise Price     Options     Weighted Avg.
Life Remaining
  Weighted Avg.
Exercise Price
    Options     Weighted Avg.
Exercise Price
 
$ 0.50       290,000     0.76 years   $ 0.50       290,000     $ 0.50  
                                         
Aggregate Intrinsic Value                 $ -             $ -  

Contingency and Contractual Obligations (Tables)

v2.4.0.6
Contingency and Contractual Obligations (Tables)
3 Months Ended
Jul. 31, 2013
Commitments and Contingencies Disclosure [Abstract]  
Schedule of Contractual Lease Obligations for Fiscal Years

The landlord has also asserted that the Company would be liable for an amount up to the full lease obligation of $1,596,329 which otherwise would have been due as follows:

 

Year Ended April 30        
2011     $ 473,055  
2012       473,055  
2013       473,055  
2014       177,164  
Thereafter       -  
Total     $ 1,596,329  

Organization and Liquidity (Details Narrative)

v2.4.0.6
Organization and Liquidity (Details Narrative) (USD $)
3 Months Ended
Jul. 31, 2013
acre
Apr. 30, 2013
Jul. 31, 2012
Apr. 30, 2012
Cash paid for purchase assets $ 2,000,000      
Non-Managing membership interest 25.00%      
Land subject to leases, gross 115,000      
Land subject to leases, net 85,000      
Value of leased land 12,200,000      
Number of stock newly issued during the period 591,021,011      
Working capital deficiency 2,300,000      
Cash and cash equivalents $ 5,038,371 $ 5,703,082 $ 7,053,569 $ 4,364,033
Petro [Member]
       
Percentage of ownership interest 100.00%      
Petro's Former's Holder [Member]
       
Percentage of ownership interest 80.00%      

Significant Accounting Policies (Details Narrative)

v2.4.0.6
Significant Accounting Policies (Details Narrative)
3 Months Ended
Jul. 31, 2013
Boe
Jul. 31, 2012
Apr. 30, 2013
Boe
Accounting Policies [Abstract]      
Estimated oil and gas proved reserves 0   0
Derivative instruments qualifying as cash flow hedges, discounted rate 10.00%    
Excluded common share equivalents 520,000 0  
Common stock equivalent shares 520,000 0  

Significant Accounting Policies - Schedule of Common Stock Equivalents (Details)

v2.4.0.6
Significant Accounting Policies - Schedule of Common Stock Equivalents (Details)
Jul. 31, 2013
Jul. 31, 2012
Common stock equivalent shares 520,000 0
Stock Options [Member]
   
Common stock equivalent shares 290,000   
Compensation Warrants [Member]
   
Common stock equivalent shares 230,000   

Oil and Gas Assets (Details Narrative)

v2.4.0.6
Oil and Gas Assets (Details Narrative) (USD $)
3 Months Ended 3 Months Ended 3 Months Ended 12 Months Ended
Jul. 31, 2013
acre
Apr. 30, 2013
Jul. 31, 2013
Kansas [Member]
acre
Apr. 30, 2013
Kansas [Member]
Jul. 31, 2013
Kentucky [Member]
acre
Apr. 30, 2013
Kentucky [Member]
Apr. 30, 2013
Missouri [Member]
wells
acre
Boe
Jul. 31, 2013
Missouri [Member]
Jul. 31, 2013
Montana [Member]
Apr. 30, 2013
Montana [Member]
Jul. 31, 2013
Montana [Member]
Devils Basin Prospect [Member]
acre
Apr. 17, 2012
Montana [Member]
Teton Prospect [Member]
acre
Cash paid for purchase assets $ 2,000,000   $ 2,000,000                  
Non-Managing membership interest 25.00%   25.00%                  
Gross acres of oil and gas leases 115,000   115,000       22,832       1,175 2,807
Land subject to leases, net 85,000   85,000               881 1,137
Value of leased land 12,200,000   12,200,000                  
Additional oil and gas expenditures     300,000                  
Percentage of working interest         37.50%   98.40%       75.00%  
Unproved gross mineral acres oil and gas leases         27,150              
Net mineral acres oil and gas leases     385   10,181              
Oil and gas assets $ 13,706,858 $ 13,423,089 $ 12,612,867 $ 12,329,098       $ 918,991 $ 918,991 $ 75,000 $ 75,000    
Number of barrel of oil built per day             500          
Number of production wells             116          
Number of steam injection wells             39          
Number of service and observation wells             14          
Number of drilled exploration or delineation wells             73          
Percentage of success rate             67.00%          

Oil and Gas Assets - Schedule of Oil and Gas Assets (Details)

v2.4.0.6
Oil and Gas Assets - Schedule of Oil and Gas Assets (Details) (USD $)
3 Months Ended
Jul. 31, 2013
Balance at beginning $ 13,423,089
Additions 295,965
Depreciation, Depletion and amortization (12,196)
Balance at end 13,706,858
Missouri [Member]
 
Balance at beginning 918,991
Depreciation, Depletion and amortization   
Balance at end 918,991
Kentucky [Member]
 
Balance at beginning   
Depreciation, Depletion and amortization   
Balance at end   
Montana [Member]
 
Balance at beginning 75,000
Depreciation, Depletion and amortization   
Balance at end 75,000
Kansas [Member]
 
Balance at beginning 12,329,098
Additions 295,965
Depreciation, Depletion and amortization (12,196)
Balance at end 12,612,867
Other [Member]
 
Balance at beginning 100,000
Depreciation, Depletion and amortization   
Balance at end $ 100,000

Asset Retirement Obligations (Details Narrative)

v2.4.0.6
Asset Retirement Obligations (Details Narrative) (USD $)
3 Months Ended
Jul. 31, 2013
Apr. 30, 2013
Asset Retirement Obligation Disclosure [Abstract]    
Future undiscounted liability $ 1,087,292 $ 1,087,292
Costs are expected to be incurred, minimum period 1 year  
Costs are expected to be incurred, maximum period 24 years  
Credit-adjusted risk-free discount rate 10.00%  
Percentage of inflation rate 2.00%  
Reclamation deposits $ 25,000 $ 25,000

Asset Retirement Obligations - Schedule of Changes to Asset Retirement Obligation (Details)

v2.4.0.6
Asset Retirement Obligations - Schedule of Changes to Asset Retirement Obligation (Details) (USD $)
3 Months Ended 12 Months Ended
Jul. 31, 2013
Jul. 31, 2012
Apr. 30, 2013
Asset Retirement Obligation Disclosure [Abstract]      
Balance, beginning of period $ 763,036 $ 143,035 $ 143,035
Additions      615,784
Disposition        
Revisions        
Accretion 13,256    4,217
Balance, end of period 776,292   763,036
Less: Current portion for cash flows expected to be incurred within one year (213,302)   (213,302)
Long-term portion, end of period $ 562,990   $ 549,734

Asset Retirement Obligations - Schedule of Expected Timing of Asset Retirement Obligations (Details)

v2.4.0.6
Asset Retirement Obligations - Schedule of Expected Timing of Asset Retirement Obligations (Details) (USD $)
Jul. 31, 2013
Apr. 30, 2013
Apr. 30, 2012
Jul. 31, 2013
2014 [Member]
Jul. 31, 2013
2015 [Member]
Jul. 31, 2013
2016 [Member]
Jul. 31, 2012
2017 [Member]
Jul. 31, 2013
Thereafter [Member]
Jul. 31, 2013
Total [Member]
Asset retirement obligations $ 213,302 $ 213,302   $ 213,302 $ 122,222 $ 135,556 $ 273,181 $ 343,031 $ 1,087,292
Effect of discount (311,000)                
Total $ 776,292 $ 763,036 $ 143,035            

Related Party Transactions (Details Narrative)

v2.4.0.6
Related Party Transactions (Details Narrative) (USD $)
2 Months Ended 3 Months Ended
Jul. 31, 2013
Jul. 31, 2013
Related Party Transactions [Abstract]    
Number of shares issued   66,340,597
Share based awards issued $ 1,400,000 $ 1,400,000
Total grant date fair value 26,500,000 26,500,000
Service period   5 years
Due to officers 12,000 12,000
Options to purchase common stock, aggregate fair market value 100,000  
Options expiration date Jul. 23, 2016  
Related party liability $ 100,000 $ 100,000

Stock Based Compensation (Details Narrative)

v2.4.0.6
Stock Based Compensation (Details Narrative) (USD $)
3 Months Ended 3 Months Ended 12 Months Ended
Jul. 31, 2013
Jul. 31, 2012
Apr. 30, 2013
Jul. 31, 2013
Warrant [Member]
Apr. 30, 2013
Warrant [Member]
Shares reserved for issuance under equity incentive plan 90,000,000        
Number of options, outstanding 290,000   290,000    
Number of options, exercisable 290,000   290,000    
Weighted average exercise price of options $ 0.50   $ 0.50    
Number of options, granted 0        
Number of options, forfeiture/cancelled 0        
Stock based compensation $ 0 $ 0      
Compensation cost related to non-vested stock options not yet recognized $ 0        
Stock options, exercise price $ 0.22     $ 0.22  
Number of warrants, oustanding       230,000 230,000
Number of warrants, exercisable       230,000 230,000
Warrants oustanding, weighted average exercise price       $ 0.50 $ 0.50
Warrants outstanding, weighted avg. Life remaining       1 month 24 days 7 months 24 days
Number of warrants, granted       0  
Number of warrants, forfeiture/cancelled       0  
Aggregate Intrinsic Value       0  

Stock Based Compensation - Summary of Options Outstanding and Exercisable (Details)

v2.4.0.6
Stock Based Compensation - Summary of Options Outstanding and Exercisable (Details) (USD $)
3 Months Ended
Jul. 31, 2013
Apr. 30, 2013
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]    
Exercise Price $ 0.50  
Options Outstanding 290,000 290,000
Options Outstanding, Weighted Avg. Life Remaining 9 months 4 days  
Options Outstanding, Weighted Avg. Exercise Price $ 0.50 $ 0.50
Options Outstanding, Aggregate Intrinsic Value     
Options Exercisable, Options 290,000 290,000
Options Exercisable, Weighted Avg. Exercise Price $ 0.50  
Options Exercisable, Aggregate Intrinsic Value     

Contingency and Contractual Obligations (Details Narrative)

v2.4.0.6
Contingency and Contractual Obligations (Details Narrative) (USD $)
3 Months Ended 6 Months Ended
Jul. 31, 2013
Jun. 30, 2010
Commitments and Contingencies Disclosure [Abstract]    
Landlord received claims   $ 247,348
Accrued rent 114,837  
Maximum lease obligations 1,596,329  
Approximate wrongful termination amount 185,000  
Stock issued during period for considerarion of settlement to non employee, shares 200,000  
Per share Price $ 0.40  
Stock issued during period for considerarion of Settlement to non employee 80,000  
Cash payment to non employee $ 50,000  

Contingency and Contractual Obligations - Schedule of Contractual Lease Obligations for the Fiscal Years (Details)

v2.4.0.6
Contingency and Contractual Obligations - Schedule of Contractual Lease Obligations for the Fiscal Years (Details) (USD $)
Jul. 31, 2013
Commitments and Contingencies Disclosure [Abstract]  
2011 $ 473,055
2012 473,055
2013 473,055
2014 177,164
Thereafter   
Total $ 1,596,329