10-Q 1 v450910_10q.htm FORM 10-Q

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

FORM 10-Q

 

(MARK ONE)

 

xQUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

For the quarterly period ended August 31, 2016

 

¨TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

For the transition period from                        to

 

Commission file number 000-53520

 

DISCOVERY ENERGY CORP.

(Exact Name of Registrant as Specified in Its Charter)

 

Nevada 98-0507846
(State or other jurisdiction of incorporation or organization) (I.R.S. Employer Identification No.)

 

One Riverway Drive, Suite 1700, Houston, Texas 77056

(Address of principal executive offices)

 

713-840-6495

(Registrant’s telephone number

 

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.  Yes x    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 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 equity, as of the latest practicable date: 140,189,501 as of October 20, 2016.

 

 

 

 

PART I - FINANCIAL INFORMATION

 

Item 1. Financial Statements.

Discovery Energy Corp. and Subsidiary

Consolidated Balance Sheets

(Unaudited)

 

   August 31,   February 29, 
   2016   2016 
Assets          
Current Assets          
Cash  $804,445   $15,895 
Prepaid expenses   11,394    - 
GST receivable   245,654    17,059 
Total Current Assets   1,061,493    32,954 
Oil and gas property – not subject to amortization (successful efforts method)   2,421,415    2,421,415 
Other assets   37,570    - 
Total Assets  $3,520,478   $2,454,369 
           
Liabilities and Stockholders’ Equity (Deficit)          
Current Liabilities          
Accounts payable and accrued liabilities  $419,371   $97,277 
Accounts payable – related parties   137,419    123,508 
Other liabilities   5,700    13,623 
Promissory notes – related parties   146,353    139,953 
Promissory notes   487,724    542,294 
Total Current Liabilities   1,196,567    916,655 
Derivative liabilities   8,212,793    - 
Convertible debentures payable, net of debt discount of $3,795,681 and $0, respectively   154,319    - 
Total Liabilities   9,563,679    916,655 
           
Commitments and Contingencies          
           
Stockholders' Equity (Deficit)          
Preferred stock – 10,000,000 shares authorized, zero issued and outstanding   -    - 
Common stock – 500,000,000 shares authorized, $0.001 par value – 140,189,501 shares issued and outstanding   140,189    140,189 
Additional paid-in capital   3,952,947    3,952,947 
Accumulated other comprehensive loss   (66,162)   (11,830)
Accumulated deficit   (10,070,175)   (2,543,592)
Total Stockholders' Equity (Deficit)   (6,043,201)   1,537,714 
Total Liabilities and Stockholders' Equity (Deficit)  $3,520,478   $2,454,369 

 

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

 

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Discovery Energy Corp. and Subsidiary

Consolidated Statements of Operations and Other Comprehensive Loss

For the Three and Six Months Ended August 31, 2016 and 2015

(Unaudited)

  

   Three   Three   Six   Six 
   Months
Ended
   Months
Ended
   Months
Ended
   Months
Ended
 
   August 31,   August 31,   August 31,   August 31, 
   2016   2015   2016   2015 
Operating Expenses                    
General and administrative  $32,046   $17,868   $59,635   $43,484 
Exploration costs   2,531,704    33,747    2,542,228    36,297 
Professional fees   142,728    38,066    173,710    56,733 
Rent   2,545    3,089    5,087    8,615 
Travel   28,118    -    28,401    40,000 
Total operating expenses   2,737,141    92,770    2,809,061    185,129 
                     
Other (Income) Expenses                    
Interest expense   438,426    5,270    4,976,891    10,613 
Change in fair value of derivative liabilities   (252,049)   -    (256,984)   - 
Miscellaneous income   (2,333)   (9)   (2,385)   (25)
(Gain) loss of foreign currency transactions   (349)   (3,306)   -    (8,873)
                     
Other expenses   183,695    1,955    4,717,522    1,715 
                     
Net loss  $(2,920,836)  $(94,725)  $(7,526,583)  $(186,844)
                     
Net loss per common share – basic and diluted  $(0.02)  $(0.00)  $(0.05)  $0.00 
Weighted average number of common shares outstanding – basic and diluted   140,189,501    139,975,732    140,189,501    139,872,109 
                     
Comprehensive Income (Loss)                    
Net loss  $(2,920,836)  $(94,725)  $(7,526,583)  $(186,844)
Other comprehensive income (loss) – gain (loss) on foreign currency translation   (70,111)   (2,097)   (54,332)   9,146 
Total comprehensive loss  $(2,990,947)  $(96,822)  $(7,580,915)  $(177,698)

 

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

 

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Discovery Energy Corp. and Subsidiary

Consolidated Statements of Cash Flows

For the Six Months Ended August 31, 2016 and 2015

(Unaudited)

   Six Months
Ended
   Six Months
Ended
 
   August 31, 2016   August 31, 2015 
Cash flows used in operating activities          
Net loss  $(7,526,583)  $(186,844)
Adjustments to reconcile net loss to net cash used in operating activities:          
Amortization of debt discount   154,318    - 
Change in fair value of derivative liabilities   (256,984)   - 
Interest expense related to derivative liabilities in excess of debt   4,735,477    - 
(Gain) loss on foreign currency transactions   -    (8,873)
Changes in operating assets and liabilities:          
GST receivable   (228,595)   - 
Prepaid expenses   (11,394)   10,151 
Accounts payable and accrued liabilities   143,902    (29,324)
Accounts payable – related party   13,911    (17,228)
Net cash used in operating activities   (2,975,948)   (232,118)
           
Cash flows from investing activities          
Cash paid for oil and gas property bond   (37,570)   - 
Net cash flows used in investing activities   (37,570)   - 
           
Cash flows from financing activities          
Proceeds from promissory notes – related party   6,400    7,000 
Repayments on promissory notes – related party   -    (64,000)
Repayments on promissory notes   (100,000)   - 
Proceeds from convertible debentures   3,950,000    - 
Stock subscription proceeds   -    50,000 
Proceeds from issuance of common stock   -    250,000 
Net cash flows from financing activities   3,856,400    243,000 
           
Effect of foreign currency translation on cash   (54,332)   9,146 
           
Change in cash during the period   788,550    20,028 
           
Cash beginning of the period   15,895    859 
           
Cash end of the period  $804,445   $20,887 
           
Supplemental disclosures          
Interest paid in the period  $-   $- 
Income taxes paid in the period  $-   $- 
           
Noncash investing and financing activities          
Debt discount on convertible debentures  $215,699   $- 
Derivative liabilities debt discount  $3,734,000   $- 
Interest payable converted to principal on outstanding promissory notes  $45,430   $- 

 

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

 

 4 

 

 

Discovery Energy Corp. and Subsidiary

Notes to the Unaudited Consolidated Financial Statements

 

1.Nature of Operations and Basis of Presentation

 

The principal business of Discovery Energy, Inc. (the “Company”) is the proposed exploration and development of the 584,651 gross acres (the “Prospect”) in the State of South Australia covered by Petroleum Exploration License (PEL) 512 (the “License”). The Prospect involves a 100% working interest in the preceding acreage, which overlies portions of the Cooper and Eromanga basins. The Company has not presently determined whether the Prospect contains any crude oil and natural gas reserves that are economically recoverable. While the Company’s present focus is on the Prospect, the Company may consider the acquisition of other attractive oil and gas properties under the right circumstances.

 

In May 2012, the Company incorporated a wholly-owned Australian subsidiary, Discovery Energy SA Ltd. (the “Subsidiary”) for purposes of acquiring the License. On May 25, 2016 the Subsidiary changed its status from a public company to private company (as those forms of entities are provided under applicable Australian law) and, accordingly changed its name to Discovery Energy SA Pty Ltd.

 

2.Summary of Significant Accounting Policies

 

Basis of Presentation

 

The accompanying unaudited interim financial statements of the Company have been prepared in accordance with accounting principles generally accepted in the United States of America and the rules of the Securities and Exchange Commission, and should be read in conjunction with the audited financial statements and notes thereto contained in the Company’s February 29, 2016 Annual Report on Form 10-K filed with the SEC. In the opinion of management, all adjustments, consisting of normal recurring adjustments, necessary for a fair presentation of financial position and the results of operations for the interim periods presented have been reflected herein. The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year. Notes to the financial statements, which would substantially duplicate the disclosure contained in the audited financial statements for the most recent fiscal year end February 29, 2016, as reported on Form 10-K, have been omitted.

 

Principles of Consolidation

 

The consolidated financial statements include the accounts of the Company and its wholly owned subsidiaries. Intercompany transactions and balances have been eliminated upon consolidation.

 

Use of Estimates

 

The preparation of financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at 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.

 

Basic and Diluted Net Income (Loss) Per Share

 

The Company computes net income (loss) per share in accordance with FASB accounting standards for "Earnings per Share", which requires presentation of both basic and diluted earnings per share (EPS) on the face of the income statement. Basic EPS is computed by dividing net income (loss) available to common shareholders (numerator) by the weighted average number of shares outstanding (denominator) during the period. Diluted EPS gives effect to all dilutive potential common shares outstanding during the period using the treasury stock method and convertible preferred stock using the if-converted method. If investors exercise their debenture conversion rights and purchase warrant rights, the Company would issue 24,687,500 and 13,875,000 common shares respectively. In computing diluted EPS, the average stock price for the period would be used in determining the number of shares assumed to be purchased from the exercise of stock options or warrants. Diluted EPS excludes all dilutive potential shares if their effect is anti-dilutive.

 

Comprehensive Loss

 

FASB accounting standard for "Reporting Comprehensive Income," establishes standards for the reporting and display of comprehensive loss and its components in the financial statements. As of August 31, 2016, the Company recognized Currency translation adjustments as a component of Comprehensive loss.

 

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Cash and Cash Equivalents

 

The Company considers all highly liquid instruments with maturity of three months or less at the time of acquisition to be cash equivalents.

 

Oil and Gas Property and Exploration Costs

 

The Company is in the exploration stage and has not yet realized any revenue from its planned operations. It is primarily engaged in the proposed exploration and development of the Prospect and the extraction of crude oil and natural gas located there under. The Company applies the successful efforts method of accounting for oil and gas properties. Under this method, exploration costs such as exploratory geological and geophysical costs, delay rentals and exploratory overhead are expensed as incurred. Costs to acquire mineral interests in crude oil and natural gas properties, drill and equip exploratory wells that find proved reserves, and drill and equip development wells are capitalized. Acquisition costs of unproved leaseholds are assessed for impairment during the holding period and transferred to proved oil and gas properties to the extent associated with successful exploration activities. Significant undeveloped leases are assessed individually for impairment, based on the Company’s current exploration plans, and a valuation allowance is provided if impairment is indicated. Capitalized costs of producing crude oil and natural gas properties, along with support equipment and facilities, are amortized to expense by the unit-of-production method based on proved crude oil and natural gas reserves on a field-by-field basis, as estimated by qualified petroleum engineers.

 

Long-lived Assets

 

In accordance with FASB accounting standard "Accounting for the Impairment or Disposal of Long-Lived Assets", the carrying value of long-lived assets is reviewed on a regular basis for the existence of facts or circumstances that may suggest impairment. The Company recognizes impairment when the sum of the expected undiscounted future cash flows is less than the carrying amount of the asset. Impairment losses, if any, are measured as the excess of the carrying amount of the asset over its estimated fair value.

 

Fair Value of Financial Instruments and Derivative Financial Instruments

 

The Company has adopted FASB’s accounting standards for Disclosure about Derivative Financial Instruments and Fair Value of Financial Instruments. The carrying amounts of cash, receivables, accounts payable and accrued liabilities, and shareholder loan approximate their fair values because of the short maturity of these items. Certain fair value estimates may be subject to and involve uncertainties and matters of significant judgment, and, therefore, cannot be determined with precision. Changes in assumptions could significantly affect these estimates. The Company does not hold or issue financial instruments for trading purposes, nor does it utilize derivative instruments in the management of its foreign exchange, commodity price, or interest rate market risks.

 

Income Taxes

 

Deferred income taxes are reported for timing differences between items of income or expense reported in the financial statements and those reported for income tax purposes in accordance with FASB’s accounting standard for income taxes, which requires the use of the asset/liability method of accounting for income taxes. Deferred income taxes and tax benefits are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases, and for tax loss and credit carry-forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The Company provides a valuation allowance for deferred taxes for the estimated future tax effects attributable to temporary differences and carry-forwards when realization is not more likely than not.

 

The Company accounts for uncertain income tax positions in accordance with FASB’s accounting standard for Accounting for Uncertainty in Income Taxes, which requires that the Company recognize in the financial statements, the impact of a tax position, if that position is more likely than not of being sustained on examination by taxation authorities, based on the technical merits of the position.

 

Foreign Currency Translation

 

The Company's functional and reporting currency is the United States dollar. Monetary assets and liabilities denominated in foreign currencies are translated in accordance with FASB’s accounting standard for "Foreign Currency Translation", using the exchange rate prevailing at the balance sheet date. Non-monetary assets are translated at historical exchange rates, and revenue and expense items at the average rate of exchange prevailing during the period. Differences resulting from translation are presented in equity as Accumulated Other Comprehensive Income. Gains and losses arising on settlement of foreign currency denominated transactions or balances are included in the determination of income. Foreign currency transactions are primarily undertaken in Canadian and Australian dollars. The Company has not, to the date of these financial statements, entered into derivative instruments to offset the impact of foreign currency fluctuations.

 

Recent Accounting Pronouncements

 

The Company does not expect the adoption of any recently issued accounting pronouncements to have a significant effect on its financial statements.

 

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Fair Value Considerations

  

The Company follows ASC 820, “Fair Value Measurements and Disclosures,” as amended by Financial Accounting Standards Board (FASB) Financial Staff Position (FSP) No. 157 and related guidance. Those provisions relate to the Company’s financial assets and liabilities carried at fair value and the fair value disclosures related to financial assets and liabilities. ASC 820 defines fair value, expands related disclosure requirements, and specifies a hierarchy of valuation techniques based on the nature of the inputs used to develop the fair value measures. Fair value is defined as 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, assuming the transaction occurs in the principal or most advantageous market for that asset or liability.

 

There are three levels of inputs to fair value measurements - Level 1, meaning the use of quoted prices for identical instruments in active markets; Level 2, meaning the use of quoted prices for similar instruments in active markets or quoted prices for identical or similar instruments in markets that are not active or are directly or indirectly observable; and Level 3, meaning the use of unobservable inputs. The Company uses Level 1 inputs for its fair value measurements whenever there is an active market, with actual quotes, market prices, and observable inputs on the measurement date. The Company uses Level 2 inputs for fair value measurements whenever there are quoted prices for similar securities in an active market or quoted prices for identical securities in an inactive market. The Company uses observable market data whenever available.

 

Derivative Liabilities

 

In accordance with ASC 815-40-25 and ASC 815-10-15 Derivatives and Hedging and ASC 480-10-25 Liabilities-Distinguishing Liabilities from Equity, the embedded derivate associated with the convertible debenture payable and warrant are accounted for as liabilities during the term of the related note payable and warrant.

 

3.Going Concern

 

The accompanying financial statements have been prepared on a going concern basis, which implies the Company will continue to realize its assets and discharge its liabilities in the normal course of business. The Company has not generated revenues since inception and has never paid dividends and is unlikely to pay dividends or generate earnings in the immediate or foreseeable future. The continuation of the Company as a going concern is dependent upon the ability of the Company to obtain necessary equity or debt financing to continue operations, the successful development of the Prospect or one or more alternative oil and gas properties, and the attainment of profitable operations. As of August 31, 2016, the Company has not generated any revenues and has an accumulated loss of $10,070,175 since inception. These factors raise substantial doubt regarding the Company's ability to continue as a going concern. The accompanying financial statements do not include any adjustments to the recoverability and classification of recorded asset amounts and classification of liabilities that might be necessary should the Company be unable to continue as a going concern.

 

In May 2016, we secured $3.5 million in funding through a convertible debenture sale. In August 2016, we secured an additional $450,000 in funding by that sale of two additional convertible debentures, one in the original principal amount of $200,000 acquired by the Original Purchaser of the first $3.5 million Debenture (the “Original Purchaser”) and one in the original principal amount of $250,000 acquired by a New Purchaser (the “New Purchaser”). The New Purchaser has an obligation to acquire additional debentures (the “Rincon-Related Debentures”) not to exceed in the aggregate the lesser of $150,000 or those amounts that are paid to Rincon Energy, LLC pursuant to a geophysical consulting agreement among the Company, the New Purchaser, Rincon Energy, LLC and the Company’s subsidiary.

 

The New Purchaser also has the right but not the obligation to acquire additional Debentures (“Additional Debentures”) through September 30, 2018, provided that a cap is imposed on the aggregate principal amount of Additional Debentures that may be acquired (the “Principal Cap”). The Principal Cap is initially the difference between $1,250,000 minus the aggregate principal amount of any Rincon-Related Debentures purchased by the New Purchaser. Starting January 1, 2017, the Principal Cap will be reduced further by the aggregate principal amount of any Additional Debentures acquired or (if greater) specified dollar amounts that increase over time. The Conversion Price for Additional Debentures issued prior to January 1, 2017 will be $0.16 per share, while the Conversion Price for Additional Debentures issued after that date will be $0.20 per share.

 

In addition, the Original Purchaser of the $3.5 million convertible debentures has a right of first offer through the end of June 2017 to invest an additional $20.0 million in our company.

 

4.Oil and Gas Properties

 

On May 19, 2014, the Company received notice from the Government of South Australia that this government had issued certain modifications to the License and suspended the License for a period of six months. Such a suspension functions like an extension. Under the amended License, the Company will be required to drill 7 exploratory wells rather than 12, as originally required. These required wells must be drilled in years 3, 4, and 5 (2, 2, and 3 wells, respectively). The amount of required 2D seismic was also reduced to 100 kilometers (in year 3) from 250 kilometers (in year 2) but the total 3D seismic work guaranteed increased to 500 square kilometers from 400 square kilometers. However, the 3D seismic survey requirement is spread over years 2, 3 and 4 (100, 200 and 200 sq. km. respectively). Subsequent to this modification and suspension, the Company received two additional six-month suspensions, one in February 2015 and one in July 2015, and a one-year suspension in February 2016. In view of these modifications and suspensions, the Company’s remaining work commitment involves the following:

 

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* Year 2 ending April 27, 2017 - Conduct a new 3D seismic survey totaling at least 100 kilometers.
* Year 3 ending April 27, 2018 - Acquire new 2D seismic data totaling at least 100 kilometers, acquire 3D seismic data totaling at least 200 square kilometers and drill two wells.
* Year 4 ending April 27, 2019 - Acquire new 3D seismic data totaling at least 200 square kilometers and drill two wells.
* Year 5 ending April 27, 2020 - Drill three wells.

   

5.Related Party Transactions

 

As of August 31, 2016 and February 29, 2016, the Company owed $137,419 and $123,508, respectively, to certain Company directors for reimbursement of expenses paid on behalf of the Company.

 

In addition, as of August 31, 2016 and February 29, 2016, the Company owed $146,353 and $139,953, respectively, for promissory notes issued to various related parties.

 

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6.Promissory Notes

 

Two promissory notes were issued on October 26, 2012 to Liberty Petroleum Corporation (“Liberty”) upon delivery of the License with an aggregate principal amount of $650,000. The original terms of the note were:

 

(i)One note in the original principal amount of $500,000 was originally due on April 26, 2013.

 

(ii)The other note in the original principal amount of $150,000 was originally due on July 26, 2013.

 

(iii)Both notes accrued interest at a floating rate equal to the one-month term LIBOR rate, plus an additional 3%. Accrued interest of $6,520 and $42,065 is included in other liabilities as of August 31, 2016 and February 29, 2016, respectively.

 

These promissory notes had undergone a number of amendments, including extensions of the due dates. On September 26, 2013, these promissory notes were combined into a single consolidation promissory note (the “Consolidated Note”) in the original principal amount of $542,294, as some of the principal had been reduced and some interest had accrued.

 

On July 20, 2016, the Company and Liberty amended the Consolidated Note so that the all the previous outstanding principal ($542,294) and the interest accrued through May 5, 2016 ($45,430) were combined. The resulting new principal ($587,724) of this Note and interest that accrues on the Note after May 5, 2016 shall be due in a single balloon payment on September 20, 2016, and provided that on or prior to the Due Date of September 20, 2016, the Note can be paid in its entirety by the Company’s a) payment in cash of $300,000, plus the amount of accrued interest and b) issuance of 1,150,895 restricted shares of the Company’s common stock, which number of shares was determined by dividing $287,724 by a per-share price of $0.25.

 

On August 23, 2016, the Company made a payment to Liberty in the amount of $100,000 to reduce the principal amount ($587,724) of the Consolidated Note to $487,724. Effective August 23, 2016, the Company and Liberty further amended the Consolidated Note so that all outstanding principal of this Note and interest that accrues on the Consolidated Note after May 5, 2016 shall be due in a single balloon payment on October 31, 2016, and provided that on or prior to the new due date of October 31, 2016, the Consolidated Note can be paid in its entirety by the Company’s (a) payment in cash of $200,000, plus the amount of interest that accrues on the Consolidated Note after May 5, 2016 and (b) issuance of 1,150,895 restricted shares of the Company’s common stock, which number of shares was determined by dividing $287,724 by a per-share price of $0.25.

 

On July 16, 2016, the Company entered into an amendment of a previous unsecured corporate demand note with related party, Keith Spickelmier. The note was in the amount of $10,000 and the maximum term was amended and extended to the second anniversary from the date of the note. None of the other provisions of the original notes were changed.

 

On August 12, 2016, the Company entered into an amendment of a previous unsecured corporate demand note with related party, William Begley. The note was in the amount of $3,000 and the maximum term was amended and extended to the first anniversary from the date of the note. None of the other provisions of the original notes were changed.

 

7.Convertible Debentures Payable

 

On May 27, 2016, the Company sold a $3.5 million senior secured convertible debenture (the “Initial Debenture”) to DEC Funding LLC (the “Original Investor”). The Initial Debenture is due on May 27, 2021 and bears interest at 8% per annum. The use of these proceeds is limited to the payment of our and the Original Investor’s costs of the transaction (including legal fees), the funding of our 3D seismic survey with respect to our Prospect and the interpretation of such seismic survey, and the payment of our expenses associated with the seismic survey. The remainder of these proceeds may be used for general and administrative expenses with the Original Investor’s consent. The conversion price for the Initial Debentures is $0.16, subject to certain adjustments that are believed to be customary in transactions of this nature. The Initial Debenture is secured by virtually all of the Company’s assets owned directly or indirectly but for the License. As discussed elsewhere herein, the Company has sold, and may in the future sell, additional senior secured convertible debenture having the same terms and security as the Initial Debenture.

 

Among other provisions, the Initial Debenture sale transaction included warrants to purchase 13,125,000 shares of the Company’s common stock at $0.20 (the “Warrant”). The warrants have a three-year term. Further information regarding the details of this transaction is found in Form 8K filed with the Securities and Exchange Commission on June 3, 2016. The Company incurred legal and professional fees in the amount of $180,000 related to the sale transaction that were accounted for as debt discount.

 

The Company also recorded debt discount in the amount of $3,320,000 related to the conversion feature associated with this debenture.

 

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On August 16, 2016, the Company entered into a first amendment (the “Amendment”) to the securities purchase agreement (the “Agreement”) that the Company entered into on May 27, 2016 with the Original Investor. The Company first reported on the Agreement in a Current Report on Form 8-K filed with the U.S. Securities and Exchange Commission on June 2, 2016 (the “Initial 8-K”). The Initial 8-K contains a summary description of the Agreement, and a copy of the Agreement was filed as Exhibit 10.01 to the Initial 8-K. For more information about the Agreement, see the Initial 8-K.

 

The parties to the Amendment include the Company, the Original Investor and a new investor (the “New Investor”). In connection with the Amendment, the parties to the Amendment also entered into related documentation.

 

Pursuant to the Amendment, the Company sold the following securities: to the New Investor, a Senior Secured Convertible Debenture due May 27, 2021 having an original principal amount of $250,000 (singly a "Debenture" and collectively with any similar securities issued in the future, the "Debentures"), and to the Original Investor, a Debenture due May 27, 2021 having an original principal amount of $200,000 (in May 2016, the Original Investor purchased the Initial Debenture having an original principal amount of $3,500,000), and to the Original Investor, warrants (the "Warrants") to purchase up to a maximum of 750,000 shares (prior to any required adjustment) of the Company's common stock (singly a "Common Share" and collectively the "Common Shares") at an initial per-share exercise price of $0.20 (in May 2016, the Original Investor received Warrants to purchase up to a maximum of 13,125,000 Common Shares at the foregoing exercise price).

 

The Debenture and the Warrant include a reset provision whereby the investor is entitled to reset the conversion price of the Debenture and the Warrant in the event that the Company issues securities priced below the conversion price of the Debenture or the Warrant. The Company has analyzed the reset provision of the Debenture and Warrant and calculated the fair market value of the ensuing derivative liability, as discussed in Note 8.

 

In conjunction with the Amendment, the Company incurred legal costs of $35,699, which were recorded as debt discount and offset against the carrying value of the Debentures. The Company also recorded debt discount in the amount of $414,300 related to the conversion feature associated with these debentures.

 

The Company recognized $146,651 of debt discount amortization related to all of the Debentures during the three months ended August 31, 2016. The Company recognized $154,318 of debt discount amortization respectively during the six months ended August 31, 2016. There was no debt discount amortization recognized by the Company during the three and six months ended August 31, 2015.

 

8.Derivative Liabilities

 

The debentures and related warrants issued by the Company contain a price-reset provision (the “Reset Provision”) that gives rise to a derivative liability. The Company has measured its derivative liability at fair value and recognized the derivative value as a long-term liability and recorded the derivative value on its consolidated balance sheet. The derivative is valued primarily using a binomial latticed-based model based on unobservable inputs that are supported by little to no market activity. These inputs represent management’s best estimate of what market participants would use in pricing the liability at the measurement date and thus are classified as Level 3. Changes in the fair values of the derivative are recognized as earnings or losses in the current period.

 

The fair values of derivative liability related to the Reset Provision contained within the debentures as of May 27, 2016, and as of August 31, 2016 were estimated on the transaction dates and balance sheet dates under the following assumptions:

 

   May 27,
2016
   Issuances /
changes
   August 31,
2016
 
Shares of common stock issuable upon exercise of debt   21,875,000    2,812,500    24,687,500 
Estimated market value of common stock on measurement date  $0.26   $(0.01)  $0.25 
Exercise price  $0.16   $-   $0.16 
Risk free interest rate   1.37%   (0.45)%   0.92%
Expected dividend yield   0.00%   0.00%   0.00%
Expected volatility   306.96%   (7.77)%   299.19%
Expected exercise term in years   4.992    0.00    4.740 

 

The fair values of derivative liability related to the Reset Provision contained within the warrants as of May 27, 2016, the date of issuance, and as of August 31, 2016 were estimated on the transaction dates and balance sheet dates under the following assumptions:

 

   May 27,
2016
   Issuances /
changes
   August 31,
2016
 
Shares of common stock issuable upon exercise of warrant   13,125,000    750,000    13,875,000 
Estimated market value of common stock on measurement date  $0.26   $(0.01)  $0.25 
Exercise price  $0.20   $-   $0.20 
Risk free interest rate   1.37%   (0.57)%   0.80%
Expected dividend yield   0.00%   0.00%   0.00%
Expected volatility   306.96%   (7.77)%   299.19%
Expected exercise term in years   2.992    0.00    2.740 

 

 10 

 

 

The changes in fair values of the derivative liabilities related to the debentures and warrants for the six months ended August 31, 2016 are summarized as follows:

 

Fair value of derivative liabilities at February 29, 2016  $- 
Fair value of derivative liabilities on issuance date   8,469,777 
Conversion of derivative liabilities   - 
Change in fair value of derivative liabilities   (256,984)
Fair value of derivative liabilities at August 31, 2016  $8,212,793 

 

The Company recognized a change in fair value of derivative liabilities of $252,049 during the three months ended August 31, 2016. The Company recognized a change in fair value of derivative liabilities of $256,984 during the six months ended August 31, 2016. There was no change in fair value of derivative liabilities recognized by the Company during the three and six months ended August 31, 2015.

 

9.Stockholders’ Equity (Deficit)

 

As of August 31, 2016 and February 29, 2016, the Company had 140,189,501 shares of its common stock issued and outstanding.

 

Warrants

 

During the six months ended August 31, 2016, the Company issued 13,875,000 warrants to purchase shares of the Company’s common stock as a part of the convertible debentures described above in Note 7. These warrants contain a price-reset provision described above in Note 8.

 

A summary of the activity in the Company’s warrants during the six months ended August 31, 2016 is presented below:

 

   Number of
Warrants
   Weighted Average
Exercise Price
 
         
Outstanding and exercisable at February 29, 2016   -   $0.00 
Issued   13,875,000   $0.20 
Outstanding and exercisable at August 31, 2016   13,875,000   $0.20 

 

The intrinsic value of warrants outstanding at August 31, 2016 was $693,750.

 

10.Subsequent Events

 

Subsequent to period-end, the Company repaid $77,600 of the outstanding balances of promissory notes – related parties.

  

 11 

 

 

Item 2. Management’s Discussion and Analysis.

 

CAUTIONARY STATEMENT FOR FORWARD-LOOKING STATEMENTS

 

This Quarterly Report on Form 10-Q includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. We have based these forward-looking statements on our current expectations and projections about future events. These forward-looking statements are subject to known and unknown risks, uncertainties and assumptions about us that may cause our actual results, levels of activity, performance or achievements to be materially different from any future results, levels of activity, performance or achievements expressed or implied by such forward-looking statements. In some cases, you can identify forward-looking statements by terminology such as “may,” “should,” “could,” “would,” “expect,” “plan,” “anticipate,” “believe,” “estimate,” “continue,” or the negative of such terms or other similar expressions. Factors that might cause or contribute to such a discrepancy include, but are not limited to, those described in our other Securities and Exchange Commission filings. The following discussion should be read in conjunction with our Financial Statements and related Notes thereto included elsewhere in this report.

 

General

 

Our company, Discovery Energy Corp., was incorporated under the laws of the state of Nevada on May 24, 2006 under the name “Santos Resource Corp.” Our current business plan is to explore for and produce oil and gas from a tract of land comprising approximately 584,651 gross acres (the “Prospect”) covered by Petroleum Exploration License (PEL) 512 (the “License”) in the State of South Australia. We adopted this business plan near the end of our fiscal 2012, after having previously abandoned our initial business plan involving mining claims in Quebec, Canada and after we had been dormant from a business perspective for a period of time. In connection with the adoption of our current business plan, we had a change in control of our company, a change in our management, a change in our corporate name, and a change of our status from a “shell” company, as that term is defined in Rule 405 of the Securities Act of 1933 and Rule 12b-2 under the Securities Exchange Act of 1934.

 

Beginning in the second quarter of fiscal 2015 a significant decline in the price of oil has affected the oil and gas industry worldwide. This decline began in June 2014 when the price of Brent oil was above US$110 per barrel and continued to a low of US$28 per barrel in January of 2016 Since then prices have recovered somewhat with the recent Nymex Futures trading above US$46 per barrel near the end of September 2016. Current oil prices have made our ability to complete a capital raising transaction or procure a joint venture partner more difficult. As a result of the decline in oil prices, we and most other Cooper Basin exploration companies curtailed activities or reduced capital budgets until oil markets stabilize. In light of market conditions, we changed our ongoing business strategy to best position ourselves for when the markets improve.

 

After having made significant strides in our business plan during our fiscal 2013 (including the formal grant of the License), we spent the bulk of our business efforts during our fiscal years 2014, 2015 and 2016 trying to complete a major capital raising transaction or procure one or more major joint venture partners to further our business plan. We were not able to achieve these objectives, especially after the significant decline in oil prices described above. During these fiscal years, we were able to extend our five-year work commitment relating to the License, allowing us additional time to pursue capital raising transactions or procure a major joint venture partner, and perhaps benefit from a recovery in the price of oil. Moreover, so far in fiscal 2017, we have experienced a couple of significant positive developments described in the following paragraphs.

 

On May 27, 2016, we completed a debt financing transaction that provided us funds to commence our 3D seismic survey operating capital for a number of months. On August 16, 2016, we completed a second debt financing transaction that provided funds for additional geotechnical evaluation and general working capital. This financing is discussed in the section captioned “Liquidity and Capital Requirements - Financing History and Immediate, Short-Term Capital Needs” below.

 

Effective July 12, 2016, we entered into a seismic services agreement (the "Seismic Agreement") with Terrex Pty Ltd. (“Terrex”). Per the terms of the Seismic Agreement, Terrex is to conduct a 3D seismic survey (the “Survey”) comprised of approximately 180 square kilometers on the southwest portion of the Prospect. Terrex began the 3D seismic fieldwork on July 28, 2016, after regulatory approvals had been acquired and an archeological review of the survey area had been completed. It is expected the field data acquisition will be completed by October 18th, after which the data will then be processed and interpreted by other contractors. Once this Survey project has been completed and the results reported to the South Australian government, our work commitment for the second year of the License and a portion of our work commitment for the third year will have been satisfied. For Terrex’s services, we will have paid a “turnkey price” of approximately AU$3,057,000 (approximately US$2,341,000 based on the average exchange rate actually received for 90% of the turnkey price, which has already been paid).

 

The Nike 3D Seismic Survey, in combinations with the expenses associated with the pre- and post-field work, has depleted most of the funds raised in our debt financing transaction completed on May 27, 2016. Unless additional debentures are sold or other funds are raised our ongoing general working capital needs will largely deplete the funds raised in the second debt financing completed on August 16, 2016 by January 31, 2017. As a result, we continue the funding activities described in the section captioned “Liquidity and Capital Requirements.”

 

In the remainder of this Report, Australian dollar amounts are prefaced by "AU$" while United States dollar amounts are prefaced simply by "$" or (when used in close proximity to Australian dollar amounts) by "US$." When United States dollar amounts are given as equivalents of Australian dollar amounts, such United States dollar amounts are approximations only and not exact figures. During the three months ended August 31, 2016 exchange rate has varied from a low of US$1.00/AU$1.2968 to a high of US$1.00/AU$1.3814.

  

 12 

 

 

Plan of Operation

 

General

 

We intend to engage primarily in the exploration and conventional development of oil and gas on the Prospect in an effort to develop oil and gas reserves, and related natural gas liquids and condensates. Our principal products will be crude oil and natural gas. Our development strategy will be directed in the multi-pay target areas of South Australia, with principal focus on the prolific Cooper/Eromanga Basin, towards initiating and rapidly expanding production rates and proving up significant reserves primarily through exploratory drilling. Our mission will be to generate superior returns for our stockholders by working with industry partners, suppliers and the community to build a focused exploration and production company with strong development assets in the oil and gas sector.

 

In the right circumstances, we might assume the entire risk of the drilling and development of the Prospect. More likely, we will determine that the drilling and development of the Prospect can be more effectively pursued by inviting industry participants to share the risk and the reward of the Prospect by financing some or all of the costs of drilling wells. Such arrangements are frequently referred to as “farm-outs.” In such cases, we may retain a carried working interest or a reversionary interest, and we may be required to finance all or a portion of our proportional interest in the Prospect. Although this approach will reduce our potential return should the drilling operations prove successful, it will also reduce our risk and financial commitment to a particular prospect. Prospective participants regarding possible “farm-out” arrangements have already approached us, and we continue to have discussions with some of these persons.

 

There can be no assurance that we will be successful in our exploratory and production activities. The oil and gas business involves numerous risks, the principal ones of which are listed in our 2016 Annual Report on Form 10-K in “Item 1A. Risk Factors -RISKS RELATING TO OUR INDUSTRY - PARTICIPANTS IN THE OIL AND GAS INDUSTRY ARE SUBJECT TO NUMEROUS RISKS.” As we become more involved in the oil and gas exploration and production business, we will give more detail information regarding these risks.

 

Although our primary focus is on the exploration and development of the Prospect, we have received information about, and have had discussion regarding possible acquisition of or participation in, other oil or gas opportunities. None of these discussions has led to any agreement in principle. Nevertheless, given an attractive opportunity and our ability to consummate the same, we could acquire one or more other crude oil and natural gas properties, or participant in one or more other crude oil and natural gas opportunities.

 

Proposed Initial Activities

 

We are in the initial phase of our plan of operation. To date we have not commenced any drilling or other exploration activities on the Prospect, and thus we do not have any estimates of oil and gas reserves. Consequently, we have not reported any reserve estimates to any governmental authority. We cannot assure anyone that we will find commercially producible amounts of oil and gas. Moreover, at the present time, we cannot finance the initial phase of our plan of operation solely through our own current resources. Therefore, we have undertaken certain financing activities described in “Liquidity and Capital Requirements - Major Financing Efforts and Other Sources of Capital” below. The success of the initial phase of our plan of operation depends upon our ability to obtain additional capital to acquire seismic data with respect to the Prospect, and to drill exploratory and developmental wells. We cannot assure anyone that we will obtain the necessary capital.

 

The License is subject to a five-year work commitment. We have completed the first year of this work commitment and in this first year we conducted geological and geophysical studies including interpretation of existing seismic data. In management’s view, the geotechnical work completed in the first year was sufficient to satisfy this requirement, and we filed our report in this connection with the South Australian government. We have received no comments from the government relating to this report.

  

We received from the South Australian Minister for Mineral Resources and Energy three six-month extensions of the work commitment relating to the License, the first in May 2014, the second in February 2015 and the third in July 2015 and a one-year suspension in February 2016. In view of these modifications and suspensions, our remaining work commitment involves the following:

 

* Year 2 ending April 27, 2017 - Conduct a new 3D seismic survey totaling at least 100 kilometers.
* Year 3 ending April 27, 2018 - Acquire new 2D seismic data totaling at least 100 kilometers, acquire 3D seismic data totaling at least 200 square kilometers and drill two wells.
* Year 4 ending April 27, 2019 - Acquire new 3D seismic data totaling at least 200 square kilometers and drill two wells.
* Year 5 ending April 27, 2020 - Drill three wells

 

Although our remaining work commitment has been reduced and extended, we have no assurance that we will be able to extend the work commitment again or to fulfill it timely, as we need to complete capital raising transactions, or procure a joint venture partner, or both, to do so.

 

 13 

 

 

The prices of the equipment and services that we must employ to fulfill the work commitment vary based on both local and international demand for such products by others involved in exploration for and production of oil and gas. Previous high worldwide energy prices had resulted in growing demand, which lent support to higher prices being charged by suppliers. Prices being charged by suppliers have declined with the decline in energy prices resulting in considerable cost savings in our exploration work programs like the Nike 3D seismic survey currently being conducted by Terrex Pty Ltd. on the PEL 512 South Block.

 

Based on our research and technical analysis to date, we believe that the License work plan can be justified. Hence, the initial phase of our plan of operation involves (among other things) conducting 3D seismic surveys totaling 300 square kilometers (approximately 115 sq. miles), conducting a 2D seismic survey of 100 kilometers (approximately 62 miles) and drilling of at least two exploration wells. We recently entered into a seismic services agreement, which we believe will satisfy our work commitment for the second year of the License and a portion of our work commitment for the third year. For more information about this agreement, see the section captioned “General” above.

 

We intend to seek a joint venture partner who or which might act as the operator to conduct seismic work and drill our wells. If we are unsuccessful in procuring such a partner, we will engage the services of a qualified seismic company to acquire additional 3D seismic data and once we have identified proposed drilling sites a third party contractor for drilling operations. Management foresees no problem in procuring the services of one or more qualified operators and drillers in connection with the initial phase of our plan of operation, although a considerable increase in drilling activities in the area of our properties could make difficult (and perhaps expensive) the procurement of operating and drilling services. In all cases, the operator will be responsible for all regulatory compliance regarding the well, including any necessary permitting for the well. In addition to regulatory compliance, the operator will be responsible for hiring the drilling contractor, geologist and petroleum engineer to make final decisions relative to the zones to be targeted, drilling specification, well design, and bore-hole drilling and logging. Should the well be successful, the operator would thereafter be responsible for completing the well, installing production facilities and interconnecting with gathering or transmission pipelines if economically appropriate. We expect to pay third party operators (i.e. not joint venture partner with us) commercially prevailing rates.

 

The operator will be the caretaker of the well once production has commenced. Additionally, the operator will formulate and deliver to all interest owners an operating agreement establishing each participant's rights and obligations in that particular well based on the location of the well and the ownership. The operator will also be responsible for paying bills related to the well, billing working interest owners for their proportionate expenses in drilling and completing the well, and selling the production from the well. Unless each interest owner sells its production separately, the operator will collect sale proceeds from oil and gas purchasers, and, once a division order has been established and confirmed by the interest owners, the operator will issue the checks to each interest owner in accordance with its appropriate interest. The operator will not perform these functions when each interest owner sells its production separately, in which case the interest owners will undertake these activities separately. After production commences on a well, the operator also will be responsible for maintaining the well and the wellhead site during the entire term of the production or until such time as the operator has been replaced.

 

The principal oil, natural gas and gas liquids transportation hub for the region of South Australia surrounding the Prospect is located in the vicinity of Moomba. This processing and transportation center is approximately 60 km (36 miles) due east of the Prospect's eastern boundary. Large diameter pipelines deliver oil and gas liquids from Moomba south to Port Bonython (Whyalla). Natural gas is also moved south to Adelaide or east to Sydney. A gas transmission pipeline also connects Moomba to Ballera, which is located northeastward in the State of Queensland. From Ballera gas can be moved to Brisbane and Gladstone, where a number of liquefied natural gas (LNG) projects are under development. The Moomba treating and transportation facilities and the southward pipelines were developed and are operated by a producer consortium led by Santos Limited (no relation to us).

 

We cannot accurately predict the costs of transporting our production until we locate our first successful well. The cost of installing infrastructure to deliver our production to Moomba or elsewhere will vary depending upon distance traversed, negotiated handling/treating fees, and pipeline tariffs. 

 

Results of Operations

 

Our results of operation for the three- and six-month periods ended August 31, 2016 and 2015 are summarized in the table below:

 

   Three Months
Ended
   Three Months
Ended
   Six Months
Ended
   Six Months
Ended
 
   August 31,
2016
   August 31,
2015
   August 31,
2016
   August 31,
2015
 
                 
Revenue  $-   $-   $-   $- 
Operating Expenses  $2,737,141   $92,770   $2,809,061   $185,129 
Other Expenses  $183,695   $1,955   $4,717,522   $1,715 
Net Loss  $(2,920,836)  $(94,725)  $(7,526,583)  $(186,844)

 

 14 

 

 

Our operating expenses for the six-month periods ended August 31, 2016 and 2015 are outlined in the table below:

 

   Three Months
Ended
   Three Months
Ended
   Six Months
Ended
   Six Months
Ended
 
   August 31,
2016
   August 31,
2015
   August 31,
2016
   August 31,
2015
 
                 
General and Administrative  $32,046   $17,868   $59,635   $43,484 
Exploration Costs   2,531,704    33,747    2,542,228    36,297 
Professional Fees   142,728    38,066    173,710    56,733 
Rent   2,545    3,089    5,086    8,615 
Travel   28,118    -    28,401    40,000 
Total Operating Expenses  $2,737,141   $92,770   $2,809,061   $185,129 

 

Results of Operations for the Three-Month Periods Ended August 31, 2016 and 2015

 

Revenues. We did not earn any revenues for either the quarter ended August 31, 2016 or the similar period in 2015. We do not anticipate earning revenues until such time as we have entered into commercial production of oil and natural gas. We are presently in the exploration stage of our business, and we can provide no assurance that we will discover commercially exploitable levels of hydrocarbons on our properties, or if such resources are discovered, that we will enter the commercial production.

 

Operating Expenses. Total operating expenses incurred during the quarter ended August 31, 2016 were approximately 2,850% higher than those incurred during the quarter ended August 31, 2015. The increase of approximately $2,644,000 reflects greater exploration costs and professional fees. The bulk of our activities during the quarter were focused on the commencement of the Nike 3D Seismic Survey (described above) and a second round of debenture placement (described below).

 

Exploration costs increased by approximately $2,498,000 compared to the similar period in 2015 as the Nike 3D Seismic Survey formally began in July 2016 and progressed substantially through August 2016. As of August 31, 2016, 90% of the turnkey price for the data acquisition by Terrex had been paid. Weather delayed the completion of project, with completion now scheduled for late October 2016. In addition to the Terrex costs, expenses were incurred during the most recent three-month period ended August 31, 2016 for survey design, regulatory permitting, environmental assessments, archeological surveying, plus health and safety procedure development and implementation.

 

Professional fees for the quarter ended August 31, 2016, increased approximately $105,000, or 275% compared to the quarter ended August 31, 2015 due primarily to costs associated with the issuance of two additional debentures.

 

We incurred travel expenses of about $28,000 for the quarter ended August 31, 2016, compared to none in the quarter ended August 31, 2015. Much of this difference relates to a difference in the timing of Australia’s major oil and gas conference, which Company representatives attend each year to meet with regulators, service providers and other oil and gas operation companies. (The 2016 conference was held in June, which is our second quarter, while last year’s gathering occurred in May, which is our first quarter.) During the quarter immediately past, extra travel expenses related to the start of the Nike 3D survey were also incurred.

 

General and administrative expenses were about $14,000 higher during the quarter ended August 31, 2016, compared to the same period last fiscal year. This increase was primarily due to an increase in SEC reporting expense, including the cost of required derivative analysis associated with our debentures.

 

Other Expenses. Other expenses increased approximately $182,000 during the quarter ended August 31, 2016 compared to the same quarter in FY 2016. This result was primarily due to the increase in interest expense of $433,156 being offset by the non-cash derivative liability gain in the amount of $252,049. The derivative liability represents the estimated settlement cost of issuing additional common shares of our common stock if the price reset provisions of the debenture and warrants are triggered. It is a non-cash liability that will be recomputed each quarter while the debenture and warrants are outstanding. Interest expense increased due to accrued interest of approximately $72,000 on the convertible debt and approximately $360,000 amortization of the debt discount and deferred financing costs.

 

Net Loss. Our net loss for the quarter ended August 31, 2016 increased by approximately $2,826,000 as compared to the quarter ended August 31, 2015. While various operating cost components moved up or down, as discussed above, the net increase in the loss is mostly attributable to significantly higher exploration costs and interest expense related to derivative liabilities in excess of debt.

 

Results of Operations for the Six-Month Periods Ended August 31, 2016 and 2015

 

Revenues. We did not earn any revenues for either the six months ended August 31, 2016 or the similar period in 2015. We do not anticipate earning revenues until such time as we have entered into commercial production of oil and natural gas. We are presently in the exploration stage of our business, and we can provide no assurance that we will discover commercially exploitable levels of hydrocarbons on our properties, or if such resources are discovered, that we will enter into commercial production.

 

Operating Expenses. The total operating expenses incurred during the six months ended August 31, 2016 were about $2,624,000 (about 1,420%) more than those incurred during the six months ended August 31, 2015. Virtually all of the increase was attributable to the costs associated with activities during the three months ended August 31, 2016. The increase in that period of approximately $2,644,000 reflects greater exploration costs and professional fees. The bulk of our activities during that period were focused on the commencement of the Nike 3D Seismic Survey (described above) and a second round of debenture placement (described below).The primary driving forces behind the increases is described above. Relatively small decreases in travel and rent expenses for the six months ended August 31, 2016 mitigated slightly the substantial increases in exploration costs and professional fees compared to the six months ended August 31, 2015.

 

 15 

 

 

Other Expenses. Total other expense incurred during the six months ended August 31, 2016, increased by approximately $4,716,000. This increase was primarily related to additional interest expense recorded in the current period and related derivative liabilities in excess of the face value of convertible debentures of $4,735,477.

 

Net Loss. Our net loss for the six months ended August 31, 2016 increased significantly as compared to the same time period ended August 31, 2015. As described above, this result was primarily due to exploration expenditures associated with the Nike 3D Seismic Survey, interest expense related to derivative liabilities in excess of debt, debt discount amortization, and accrued interest on outstanding debt.

 

Off-Balance Sheet Arrangements

 

We have no off-balance sheet arrangements.

 

Liquidity and Capital Requirements

 

Financing History and Immediate, Short-Term Capital Needs

 

Until May 2016, we had financed our business since the change in our corporate direction in January 2012 primarily through private placements of common stock. Since January 2012 through the end of fiscal 2016, we had conducted several rounds of financing in which we raised total "seed" capital in the amount of $2,723,750 resulting in the issuance of 19,657,501 shares of our common stock. Since May 2016, we have been financing our business through the debenture placements described below. Moreover, from time to time, our officers and directors have advanced short-term funds. As of October 12, 2016, we had outstanding loans totaling $68,753 from two directors and an entity controlled by one officer. These loans are each evidenced by demand notes, which are non-interest bearing.

 

Effective May 27, 2016, we sold the following securities:

 

*a Senior Secured Convertible Debenture due May 27, 2021 having an original principal amount of $3,500,000 (singly a "Debenture" and collectively with any similar securities issued in the future, the "Debentures"), and

 

*warrants to purchase up to a maximum of 13,125,000 shares (prior to any required adjustment) of our common stock (at an initial per-share exercise price of $0.20.

 

Effective August 16, 2016, we sold the following additional securities:

 

*a Debenture to a new investor (the “New Investor”) having an original principal amount of $250,000, and

 

*a Debenture to the purchaser of the Debenture on May 27, 2016 (the “Original Investor”) having an original principal amount of $200,000, and

 

*warrants to purchase up to a maximum of 750,000 shares to the Original Investor (prior to any required adjustment) of our common stock (at an initial per-share exercise price of $0.20.

 

The use of the first Debenture proceeds was limited to the payment of the Debenture purchaser’s costs of the transaction (including legal fees), the funding of the Nike 3D Seismic Survey with respect to our 584,651 gross acre oil and gas prospect in the State of South Australia and the interpretation of such seismic survey, and the payment of our expenses associated with the seismic survey. The remainder of the proceeds may be used for general and administrative expenses with the Original Investor’s consent.

 

The $450,000 in proceeds from the second Debenture placement were or will be generally used to pay the Company’s and the investors’ costs of the transaction (including legal fees), general working capital purposes, and the reduction in some of the Company’s outstanding debt.

 

As of August 31, 2016, we had cash of approximately $804,000, we had drawn $5,700 in funds against our bank credit card, and we had negative working capital of about $135,000, excluding the derivative liability. Our cash on hand at the end of the most recent period was about $820,000 greater than we held at the end of the period ending August 31, 2015. The increase was primarily the result of nearly $3,900,000 derived from financings described above reduced by nearly $3,000,000 used in our operating activities and a $100,000 payment on a promissory note. As of October 20, 2016, we had the US dollar equivalent of approximately $382,500 of uncommitted cash on hand. Additionally, our Australian subsidiary has a pending sales tax return from the government having a US dollar value of about $251,000, which is associated primarily with money spend on the Nike 3D Seismic Survey.

 

The Company believes that the cash on hand and the sales tax refund will be sufficient to finance all of the Company’s other business expenses through January 2017, although the Company has no assurance of this. In the view of the preceding, the Company will need to raise more funds, and the Company is continuing efforts to raise additional working capital. It intends to do this by undertaking a private placement of Common Shares and continuing its efforts to sell more Debentures.

 

 16 

 

 

We are currently seeking to sell up to $2 million in additional Equity. Some of the net proceeds from the additional Debentures or Equity placements will be used for the following purposes:

 

*The payment of the debt that we owe to Liberty Petroleum Corporation

 

*The payment of the remaining debt owed to members of management

 

*General and administrative expenses

 

If the remaining $1,250,000 of additional Debentures are sold or a like amount of Equity is sold, or some combination of the two occurs, we believe that the related net proceeds will be sufficient to pay all remaining non-debenture debts and finance our business operations for the next year, although it has no assurance of this. We have no assurances that we will be successful in raising required additional funds. However, additional capital would need to be raised in order for us to meet the work commitments specified for License years 3, 4 and 5. If we are unsuccessful in raising required additional funds in the immediate future, we will need (among other things) to seek a further extension of the Liberty note. While Liberty has accommodated us in the past in this regard, we have no assurance that they would accommodate us again. Our failure to raise required additional funds and our subsequent failure to obtain an extension of the Liberty note and our work commitment under the License and our ultimate inability to repay the Debentures when they become due could have adverse consequences for us, including our inability to continue our business plan, which could result in a complete loss of stockholders' equity.

 

Long-Term Capital Needs

 

The five-year work commitment relating to the License imposes certain financial obligations on us. In management’s view, the geotechnical work completed in year-one was sufficient to satisfy the requirement for year-one, and we filed our report in this connection with the South Australian government. Further, we have raised the funds required to complete the second year work commitment and a portion of the following year’s 3D seismic requirement. In addition to the preceding, we will need working capital to satisfy our general and administrative expenses. Between April 2017 and the end of April 2020, we will require approximately $23.5 million in additional capital to continue operations and satisfy the obligations for the remainder of our work commitments. If the remaining Debentures are sold, the additional $2.0 million in equity is raised and the Original Investor exercises its warrants and its option to invest an additional $20.0 million in the Company, sufficient capital will be available to continue operations and meet all work commitments specified in the License. We have no assurances that any or all of these required additional funds would be raised in the manner expected or in any other manner.

 

If we are successful with the early wells, we will continue with a full development plan, the scope of which is now uncertain but will be based on technical analysis of acquired seismic data collected and/or reprocessed, field drilling and log reports. However, all of the preceding plans are subject to the availability of sufficient funding and the procurement of all governmental approvals. We do not now have sufficient available funds to undertake these tasks, and will need to procure a joint venture partner or raise additional funds as described above. The failure to procure a joint venture partner or raise additional funds will preclude us from pursuing our business plan, as well as exposing us to the loss of the License, as discussed below. Moreover, if our business plan proceeds as just described, but our first wells do not prove to hold producible reserves, we could be forced to cease our exploration efforts on the Prospect.

 

Major Financing Efforts and Other Sources of Capital

 

Starting in October 2012, we have entered into engagement agreements with several financial intermediaries to assist us in completing a major capital raising transaction. None of these engagements resulted in the completion of such a transaction, and we are not now bound by any such engagement agreement. We are now pursuing our own independent capital raising initiatives, and we have several prospects in this regard.

 

Our capital strategy for most of the past two years or so has been to try to engage in a single major capital raising transaction to provide sufficient funds to satisfy our capital needs for a number of years to come. While did not completely abandon this strategy, we shifted our emphasis in an effort to try to engage in one or more smaller capital raising transactions to provide sufficient funds to satisfy our capital needs through April 2017. Effective May 27, 2016, we sold a $3,500,000 Debenture. The proceeds from this sale were sufficient to finance our seismic survey requirement for our second year license work commitment of 100 km2. Effective August 16, 2016, we sold an additional $450,000 in Debentures. We believe that the proceeds from this second round of the Debenture financing will be sufficient to finance all of our other business expenses through the end of December 2016, although we have no assurance of this. In the view of the preceding, we are continuing efforts to raise up to $2,000,000 in an approved equity raise and we could raise up to another $1,250,000 by selling additional Debentures pursuant to options to purchase the same in favor of a new investor in our second round of the Debenture financing. Moreover, in the future we will need significant additional funds to undertake the development of our oil and gas prospect in Australia, and we will need to raise these funds to do this. We have no assurance that it will be able to raise these significant additional funds or the additional funds needed for our general operation.

 

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The purchaser of our $3,500,000 Debenture has a right of first offer through the end of June 2017 to invest an additional $20.0 million in our Company. We view this arrangement as a prospect for meeting our major capital needs in the future, although we have no assurance that the purchaser will elect to invest any further amounts. However, we expect to pursue other possible sources of capital. For example, we expect to pursue smaller, equity placements for short-term needs and an alternative major capital raising transaction for long-term needs. Moreover, one source of funding being pursued is the sale of a portion of our interest in the Prospect to a joint venture partner for a cash payment and/or a work commitment. We have had preliminary discussions with several companies to become joint venture partners. To obtain the maximum combination of cash and work commitment in connection with the sale of an interest in the Prospect, we have conducted extensive geological and geophysical work, including the reprocessing of existing 3D seismic data and acquiring approximately 180 km2 of new 3D seismic data relating to a portion of the Prospect, and we may seek to add further value by completing other 3D seismic surveys over other portions of the Prospect. We have no assurance that we will secure a joint venture partner. A joint venture arrangement is unlikely to help with our immediate cash needs, but (if secured) one would help with our longer-term cash needs. Moreover, any joint venture arrangement would need to be approved by each Debenture holder.

 

Production from successful exploration and drilling efforts would provide us with cash flow. The proven reserves associated with production would increase the value of our rights in the Prospect. This, in turn, should enable us to obtain bank financing (after the wells have produced for a period of time to satisfy the related lender). Both of these results would enable us to continue with our development activities. Cash flow is a critical factor to our plan of operation in the long run. Management believes that, if our plan of operation progresses (and production is realized) as planned, sufficient cash flow and debt financing will be available for purposes of properly pursuing our plan of operation, although we can make no assurances in this regard.

 

Finally, to conserve on our cash requirements, we may try to satisfy some of our obligations by issuing shares of our common stock, which will result in dilution in the percentage ownership interests of our existing stockholders and could result in dilution of the net asset value per share of our existing stockholders.

 

Consequences of a Financing Failure

 

The amount of cash on hand, the pending maturity of the Liberty note, and the issuance of the Debentures have all heightened our need to raise a significant amount of additional capital in the near future. If required financing is not available on acceptable terms, we could be prevented from satisfying our debt or work commitment obligations (including the repayment of the Debentures, which become due in May 2021), or developing the Prospect. Our failure to pay timely the Debentures could result in the partial or total loss of our assets and properties. Our failure to pay timely the Liberty note could result in Liberty’s exercise of the rights of an unsecured creditor and possibly levy encumbrances on all or a large part of our assets. Our failure to honor our work commitment could result in our loss of the Prospect. Our failure to procure required financing on acceptable terms could prevent us from developing the Prospect. If any of the preceding events were to occur, we could be forced to cease our business plan altogether, which could result in a complete loss of stockholders’ equity. If we do not obtain additional financing through an equity or debt offering, we may be constrained to attempt to sell all or some portion of the Prospect under unfavorable circumstances and at an undesirable price. However, we cannot assure anyone that we will be able to find interested buyers or that the funds received from any such partial sale would be adequate to fund our activities. Our future liquidity will depend upon numerous factors, including the success of our business efforts and our capital raising activities.

 

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, we have evaluated the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Exchange Act Rule 13a 15(e) and Rule 15d 15(e) as of the end of the period covered by this quarterly report. Based on that evaluation, the principal executive officer and principal financial officer have identified that the lack of segregation of accounting duties as a result of limited personnel resources is a material weakness and an ineffective element of our financial procedures. Therefore, the principal executive officer and principal financial officer believe the disclosure controls and procedures are not effective to ensure that information required to be disclosed by us in the reports we file or submit 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 our disclosure and controls are designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure. There were no significant changes in our internal controls or in other factors that could significantly affect internal controls subsequent to the date of their evaluation and there were no corrective actions with regard to significant deficiencies and material weaknesses.

 

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Limitations on Effectiveness of Controls and Procedures

 

Our management, including our Chief Executive Officer and Chief Financial Officer, does not expect that our disclosure controls and procedures or our internal controls will prevent all error and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within our company have been detected. These inherent limitations include, but are not limited to, the realities that judgments in decision-making can be faulty and that breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. The design of any system of controls also is based in part upon certain assumptions about the likelihood of future events and there can be no assurance that any design will succeed in achieving our stated goals under all potential future conditions; over time, control may become inadequate because of changes in conditions, or the degree of compliance with the policies or procedures may deteriorate.

 

Changes in Internal Controls over Financial Reporting

 

There have not been any changes in our internal control over financial reporting, as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act, during the period of this report that have materially affected, or are reasonably likely to materially affect our internal control over financial reporting.

 

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PART II - OTHER INFORMATION

 

Item 6. Exhibits.

 

The following exhibits are filed with this Quarterly Report or are incorporated herein by reference:

 

Exhibit    
Number   Description
     
31.01   Certification pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934.
31.02   Certification pursuant to Rule 13a-14(a) of the Securities Exchange Act of 1934.
32.01   Certification Pursuant to 18 U.S.C. Section 1350, as pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.02   Certification Pursuant to 18 U.S.C. Section 1350, as pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS   XBRL Instance Document
101.SCH   XBRL Taxonomy Extension Schema
101.CAL   XBRL Taxonomy Extension Calculation Linkbase
101.DEF   XBRL Taxonomy Extension Definition Linkbase
101.LAB   XBRL Taxonomy Extension Labels Linkbase
101.PRE   XBRL Taxonomy Extension Presentation Linkbase

 

SIGNATURES

 

In accordance with the requirements of the Exchange Act, the Registrant has duly caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized.

 

  DISCOVERY ENERGY CORP.
  (Registrant)
     
  By: /s/ Keith J. McKenzie  
    Keith J. McKenzie,
    Chief Executive Officer
    (Principal Executive Officer)
     
  By: /s/ William E. Begley  
    William E. Begley,
    Chief Financial Officer
    (Principal Financial Officer and Principal Accounting Officer)

 

October 24, 2016

 

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