UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549



FORM 20-F



 ̈REGISTRATION
STATEMENT PURSUANT TO SECTION 12(b) OR (g) OF THE SECURITIES EXCHANGE ACT OF 1934



OR



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



For the fiscal year ended August 31, 2014



OR



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



OR



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



Date of event requiring this shell company
report ____________________________



For the transition period from_________________to______________



Commission File Number: 0-53646



EAGLEFORD ENERGY CORP.

(Formerly: Eagleford Energy Inc.)

(Exact name of Registrant as specified
in its charter)



Ontario, Canada

(Jurisdiction of incorporation or organization)



1 King Street West, Suite 1505

Toronto, Ontario, Canada, M5H 1A1

(Address of principal executive offices)



James Cassina, Telephone (416) 364-4039,
Fax (416) 364-8244

1 King Street West, Suite 1505, Toronto,
Ontario, Canada, M5H 1A1

(Name, telephone, e-mail and/or facsimile
number and address of company contact person)



Securities registered or to be registered pursuant to section
12(b) of the Act:   None



Securities registered or to be registered pursuant to Section
12(g) of the Act:   Common Stock, no par value

(Title of Class)



Securities for which there is a reporting obligation pursuant
to Section 15(d) of the Act:   None

(Title of Class)



The number of outstanding shares of the issuer’s common
stock as of August 31, 2014 was 27,671,541 shares.



Indicate by check mark if the registrant is a well-known seasoned
issuer, as defined in Rule 405 of the Securities Act.  Yes  ̈  No
x



If this report is an annual or a transition report, indicate
by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act
of 1934.     Yes  ̈  No x



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, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer”
in Rule 12b-2 of the Exchange Act. (Check one):



|Large accelerated filer  ̈ | Accelerated filer  ̈ | Non-accelerated filer x
|------------------------- | ------------------- | -----------------------



Indicate by check mark which basis of accounting the registrant
has used to prepare the financial statements included in this filing:



|U.S. GAAP  ̈ | International Financial Reporting
        Standards
        by
        the International Accounting Standards Board x | Other   ̈
|----------- | --------------------------------------------------------------------------------------------------------------------- | --------



If “Other” has been checked in response to the
previous question, indicate by check mark which financial statement item the registrant has elected to follow.

Item 17  ̈    Item
18  ̈



If this is an annual report, indicate by check mark whether
the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).     Yes  ̈     No x











Table of Contents



|GENERAL                                   | 1                                                      
|----------------------------------------- | -------------------------------------------------------
|NOTE REGARDING FORWARD-LOOKING STATEMENTS | 1                                                      
|PART I                                    |                                                        
|ITEM 1                                    | IDENTITY OF DIRECTORS, SENIOR MANAGEMENT AND ADVISORS  
|A.                                        | DIRECTORS AND SENIOR MANAGEMENT                        
|B.                                        | ADVISERS                                               
|C.                                        | AUDITORS                                               
|ITEM 2                                    | OFFER STATISTICS AND EXPECTED TIMETABLE                
|A.                                        | OFFER STATISTICS                                       
|B.                                        | METHOD AND EXPECTED TIMETABLE                          
|ITEM 3                                    | KEY INFORMATION                                        
|A.                                        | SELECTED FINANCIAL DATA                                
|B.                                        | CAPITALIZATION AND INDEBTEDNESS                        
|C.                                        | REASONS FOR THE OFFER AND USE OF PROCEEDS              
|D.                                        | RISK FACTORS                                           
|ITEM 4                                    | INFORMATION ON THE COMPANY                             
|A.                                        | HISTORY AND DEVELOPMENT OF THE COMPANY                 
|B.                                        | BUSINESS OVERVIEW                                      
|C.                                        | ORGANIZATIONAL STRUCTURE                               
|D.                                        | PROPERTY, PLANTS AND EQUIPMENT                         
|ITEM 4A                                   | UNRESOLVED STAFF COMMENTS                              
|ITEM 5                                    | OPERATING AND FINANCIAL REVIEW AND PROSPECTS           
|A.                                        | OPERATING RESULTS                                      
|B.                                        | LIQUIDITY AND CAPITAL RESOURCES                        
|C.                                        | RESEARCH AND DEVELOPMENT, PATENTS AND LICENSES, ETC.   
|D.                                        | TREND INFORMATION                                      
|E.                                        | OFF-BALANCE SHEET ARRANGEMENTS                         
|F.                                        | TABULAR DISCLOSURE OF CONTRACTUAL OBLIGATIONS          
|G.                                        | SAFE HARBOR                                            
|ITEM 6.                                   | DIRECTORS, SENIOR MANAGEMENT AND EMPLOYEES             
|A.                                        | DIRECTORS AND SENIOR MANAGEMENT                        
|B.                                        | COMPENSATION                                           
|C.                                        | BOARD PRACTICES                                        
|D.                                        | EMPLOYEES                                              
|E.                                        | SHARE OWNERSHIP                                        
|ITEM 7                                    | MAJOR SHAREHOLDERS AND RELATED PARTY TRANSACTIONS      
|A.                                        | MAJOR SHAREHOLDERS                                     
|B.                                        | RELATED PARTY TRANSACTIONS                             
|C.                                        | INTERESTS OF EXPERTS AND COUNSEL                       
|ITEM 8                                    | FINANCIAL INFORMATION                                  
|A.                                        | CONSOLIDATED STATEMENTS AND OTHER FINANCIAL INFORMATION
|B.                                        | SIGNIFICANT CHANGES                                    
|ITEM 9                                    | THE OFFER AND LISTING                                  
|A.                                        | OFFER AND LISTING DETAILS                              
|B.                                        | PLAN OF DISTRIBUTION                                   



i







|C.       | MARKETS                                                                      | 72
|-------- | ---------------------------------------------------------------------------- | --
|D.       | SELLING SHAREHOLDERS                                                         | 72
|E.       | DILUTION                                                                     | 72
|F.       | EXPENSES OF THE ISSUE                                                        | 72
|ITEM 10  | ADDITIONAL INFORMATION                                                       | 72
|A.       | SHARE CAPITAL                                                                | 72
|B.       | MEMORANDUM AND ARTICLES OF ASSOCIATION                                       | 72
|C.       | MATERIAL CONTRACTS                                                           | 75
|D.       | EXCHANGE CONTROLS                                                            | 76
|E.       | TAXATION                                                                     | 77
|F.       | DIVIDENDS AND PAYING AGENTS                                                  | 80
|G.       | STATEMENT BY EXPERTS                                                         | 80
|H.       | DOCUMENTS ON DISPLAY                                                         | 80
|I.       | SUBSIDIARY INFORMATION                                                       | 80
|ITEM 11  | QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK                   | 81
|ITEM 12  | DESCRIPTION OF SECURITIES OTHER THAN EQUITY SECURITIES                       | 84
|A.       | DEBT SECURITIES                                                              | 84
|B.       | WARRANTS AND RIGHTS                                                          | 84
|C.       | OTHER SECURITIES                                                             | 84
|D.       | AMERICAN DEPOSITORY SHARES                                                   | 84
|PART II  |                                                                              | 85
|ITEM 13  | DEFAULTS, DIVIDENDS ARREARAGES AND DELINQUENCIES                             | 85
|ITEM 14  | MATERIAL MODIFICATIONS TO THE RIGHTS OF SECURITY HOLDERS AND USE OF PROCEEDS | 85
|ITEM 15  | CONTROLS AND PROCEDURES                                                      | 85
|ITEM 16  | [RESERVED]                                                                   | 86
|ITEM 16A | AUDIT COMMITTEE FINANCIAL EXPERT                                             | 86
|ITEM 16B | CODE OF ETHICS                                                               | 86
|ITEM 16C | PRINCIPAL ACCOUNTANT FEES AND SERVICES                                       | 87
|ITEM 16D | EXEMPTIONS FROM THE LISTING STANDARDS FOR AUDIT COMMITTEES                   | 87
|ITEM 16E | PURCHASES OF EQUITY SECURITIES BY THE ISSUER AND AFFILIATED PURCHASERS       | 87
|ITEM 16F | CHANGE IN REGISTRANT’S CERTIFYING ACCOUNTANT                                 | 88
|ITEM 16G | CORPORATE GOVERNANCE                                                         | 88
|ITEM 16H | MINE SAFETY DISCLOSURE                                                       |   
|PART III |                                                                              | 88
|ITEM 17  | FINANCIAL STATEMENTS                                                         | 88
|ITEM 18  | FINANCIAL STATEMENTS                                                         | 88
|ITEM 19  | EXHIBITS                                                                     | 88



ii







GENERAL



In this Annual Report, references to “we”,
“us”, “our”, the “Company”, and “Eagleford” mean Eagleford Energy Corp. (Formerly:
Eagleford Energy Inc.), and its subsidiaries, unless the context requires otherwise.



We use the Canadian dollar as our reporting
and presentation currency and our consolidated financial statements are prepared in accordance with International Financial Reporting
Standards (“IFRS”), as issued by the International Accounting Standards Board (“IASB”). All monetary references
in this document are to Canadian dollars, unless otherwise indicated. All references in this document to “dollars”
or “$” or “CDN$” mean Canadian dollars, unless otherwise indicated, and references to “US$”
mean United States dollars.



Except as noted, the information set forth
in this Annual Report is as of November 28, 2014 and all information included in this document should only be considered accurate
as of such date. Our business, financial condition or results of operations may have changed since that date.



NOTE REGARDING FORWARD-LOOKING STATEMENTS



Much of the information included in this
Annual Report is based upon estimates, projections or other “forward-looking statements”. Such forward-looking statements
include any projections or estimates made by us and our management in connection with our business operations. These statements
relate to future events or our future financial performance. In some cases you can identify forward-looking statements by terminology
such as “may”, “should”, “expects”, “plans”, “anticipates”, “believes”,
“estimates”, “predicts”, “potential” or “continue” or the negative of those terms
or other comparable terminology. While these forward-looking statements, and any assumptions upon which they are based, are made
in good faith and reflect our current judgment regarding the direction of our business, actual results will almost always vary,
sometimes materially, from any estimates, predictions, projections, assumptions or other future performance suggested herein.
Such estimates, projections or other forward-looking statements involve various risks and uncertainties and other factors, including
the risks in the section titled “Risk Factors” below, which may cause our actual results, levels of activities, performance
or achievements to be materially different from any future results, levels of activity, performance or achievements expressed
or implied by these forward-looking statements. We caution the reader that important factors in some cases have affected and,
in the future, could materially affect actual results and cause actual results to differ materially from the results expressed
in any such estimates, projections or other forward-looking statements. Although we believe that the expectations reflected in
the forward-looking statements are reasonable, we cannot guarantee future results, levels of activity, performance or achievements.
Except as required by applicable law, including the securities laws of the United States, we do not intend to update any of the
forward-looking statements to conform those statements to actual results.



The statements contained in Item 4 –
“Information on the Company”, Item 5 – “Operating and Financial Review and Prospects” and Item 11
– “Quantitative and Qualitative Disclosures about Market Risk” are inherently subject to a variety of risks
and uncertainties that could cause actual results, performance or achievements to differ significantly.



PART I



|ITEM 1 | IDENTITY OF DIRECTORS, SENIOR MANAGEMENT AND ADVISORS
|------ | -----------------------------------------------------



A.           DIRECTORS
AND SENIOR MANAGEMENT



Not applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



B.           ADVISERS



Not applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



C.           AUDITORS



Not applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



1







|ITEM 2 | OFFER STATISTICS AND EXPECTED TIMETABLE
|------ | ---------------------------------------



A.           OFFER
STATISTICS



Not applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



B.           METHOD
AND EXPECTED TIMETABLE



Not applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



|ITEM 3 | KEY INFORMATION
|------ | ---------------



A.           SELECTED
FINANCIAL DATA



The following table presents selected
financial data derived from our Audited Consolidated Financial Statements for the fiscal years ended August 31, 2014, 2013, 2012
and 2011. You should read this information in conjunction with our Audited Consolidated Financial Statements and related
notes (See Item 18: “Financial Statements”), as well as (Item 4: “Information on the Company”
and Item 5: “Operating and Financial Review and Prospects”) of this Annual Report.



Our consolidated financial statements
have been prepared in accordance International Financial Reporting Standards (“IFRS”), as issued by the International
Accounting Standards Board (“IASB”). The selected consolidated statement of operations data set forth below for the
years ended August 31, 2014, 2013, 2012 and 2011 and the selected consolidated statement of financial position information set
forth below as of August 31, 2014, 2013, 2012 and 2011 is derived from our consolidated financial statements, which have been
audited by Schwartz Levitsky Feldman LLP, Chartered Accountants, Toronto, Canada all of which are attached to and forming part
of this Annual Report under Item 18 – Financial Statements.



EAGLEFORD ENERGY CORP.

Prepared in accordance with International
Financial Reporting Standards (“IFRS”), as issued by the International Accounting Standards Board (“IASB”)

(STATED IN CANADIAN DOLLARS)

Except share and per share data



CONSOLIDATED STATEMENT OF FINANCIAL
POSITION INFORMATION



|                                        |  | YEARS ENDED AUGUST 31, |           
|--------------------------------------- |  | ---------------------- | ----------
|                                        |  | 2014                   |           
|Cash                                    |  | $                      | 103,215   
|Total assets                            |  | $                      | 5,296,928 
|Total liabilities                       |  | $                      | 8,016,363 
|Total shareholders’ equity (deficiency) |  | $                      | (2,719,435



2







CONSOLIDATED STATEMENT OF OPERATIONS
INFORMATION



|                                                         |  | YEARS ENDED AUGUST 31, |           
|-------------------------------------------------------- |  | ---------------------- | ----------
|                                                         |  | 2014                   |           
|Revenue                                                  |  |                        |           
|Natural gas sales, net of royalties                      |  | $                      | 65,024    
|Expenses                                                 |  |                        |           
|Operating costs                                          |  |                        | 17,138    
|Depletion and accretion                                  |  |                        | 2,449     
|General and administrative                               |  |                        | 403,120   
|Marketing and public relations                           |  |                        | (14,250   
|Impairment loss on property and equipment                |  |                        | -         
|Impairment loss on exploration and evaluation            |  |                        | 1,315,276 
|Interest expense                                         |  |                        | 284,038   
|Loss (gain) loss on derivative liabilities               |  |                        | 2,735,476 
|Loss on settlement of debt                               |  |                        | 1,335,935 
|Loss (gain) on foreign exchange                          |  |                        | 101,427   
|Impairment loss on marketable securities                 |  |                        | -         
|Stock based compensation                                 |  |                        | -         
|Stock based compensation-non employees                   |  |                        | -         
|Compensation expense on re-pricing of units              |  |                        | -         
|Gain on disposal of marketable securities                |  |                        | -         
|                                                         |  |                        | 6,180,609 
|                                                         |  |                        |           
|Net loss for the period                                  |  |                        | (6,115,585
|                                                         |  |                        |           
|Foreign currency translation                             |  |                        | (199,965  
|                                                         |  |                        |           
|Total Loss and Comprehensive loss                        |  | $                      | (6,315,550
|                                                         |  |                        |           
|Loss per share, basic and diluted                        |  | $                      | (0.482    
|                                                         |  |                        |           
|Weighted average shares outstanding, basic and diluted * |  |                        | 12,675,329



*Reflects March 16, 2012 two-for-one stock split and the August
25, 2014 one-for-ten stock consolidation



3







Exchange Rate Information

The exchange rate between the Canadian
dollar and the U.S. dollar was CDN$1.00 per US$0.8574 (or US$1.00 per CDN$1.1426) as of November 28, 2014.



The average exchange rates for the periods
indicated below (based on the daily noon buying rate for cable transfers in New York City certified for customs purposes by the
Federal Reserve Bank of New York) are as follows:



|                                       |  | YEARS ENDED AUGUST 31, |       
|-------------------------------------- |  | ---------------------- | ------
|                                       |  | 2014                   |       
|Average exchange rate CDN$ per US$1.00 |  |                        | 0.9214
|Average exchange rate US$ per CDN$1.00 |  |                        | 1.0786



The high and low exchange rates between
the Canadian dollar and the U.S. dollar for each of the six months ended November 28, 2014 are as follows:



|               |  | Exchange rate CDN$ per US$1.00 |       
|-------------- |  | ------------------------------ | ------
|Month          |  | Low                            |       
|November 2014  |  |                                | 1.1236
|October 2014   |  |                                | 1.1150
|September 2014 |  |                                | 1.0862
|August 2014    |  |                                | 1.0852
|July 2014      |  |                                | 1.0633
|June 2014      |  |                                | 1.0676



B.           CAPITALIZATION
AND INDEBTEDNESS



Not Applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



C.           REASONS
FOR THE OFFER AND USE OF PROCEEDS



Not Applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



D.           RISK
FACTORS



Our securities are highly speculative
and subject to a number of risks. You should not consider an investment in our securities unless you are capable of sustaining
an economic loss of the entire investment. In addition to the other information presented in this Annual Report, the following
risk factors should be given special consideration when evaluating an investment in our securities.



General Risk Factors



We require additional capital which
may not be available to us on acceptable terms, or at all.  Both the exploration and development of oil and gas reserves
can be capital-intensive businesses. We have accumulated significant losses and negative cash flows from operations in recent
years which raises doubt as to the validity of the going concern assumption. As at August 31, 2014, we had a working capital deficiency
of $3,489,237 and an accumulated deficit of $15,328,146. We do not have sufficient funds to meet our liabilities for the ensuing
twelve months as they become due. In assessing whether the going concern assumption is appropriate, we take into account all available
information about the future, which is at least, but not limited to, twelve months from August 31, 2014. Our ability to continue
operations and fund our liabilities is dependent on our ability to secure additional financing and cash flow. We are pursuing
such additional sources of financing and cash flow to fund our operations and obligations and while we have been successful in
doing so in the past, there can be no assurance we will be able to do so in the future. We intend to satisfy any additional working
capital requirements from cash flow and by raising capital through public or private sales of debt or equity securities, debt
financing or short-term loans, or a combination of the foregoing.  We have no current arrangements for obtaining additional
capital, and may not be able to secure additional capital, or on terms which will not be objectionable to us or our shareholders.  Under
such circumstances, our failure or inability to obtain additional capital on acceptable terms or at all could have a material
adverse effect on us.



4







We have a history of losses and
a limited operating history as an oil and gas exploration and development company which makes it more difficult to evaluate our
future prospects.   To date, we have incurred significant losses. We have a limited operating history upon which
any evaluation of us and our long-term prospects might be based. We are subject to the risks inherent in the oil and gas industry,
as well as the more general risks inherent to the operation of an established business.  We and our prospects must be
considered in light of the risks, expenses and difficulties encountered by all companies engaged in the extremely volatile and
competitive oil and gas markets. Any future success we might achieve will depend upon many factors, including factors, which may
be beyond our control.  These factors may include changes in technologies, price and product competition, developments
and changes in the international oil and gas market, changes in our strategy, changes in expenses, fluctuations in foreign currency
exchange rates, general economic conditions, and economic and regulatory conditions specific to the areas in which we compete.  To
address these risks, we must, among other things, comply with environmental regulations; expand our portfolio of proven oil and
gas properties and negotiate additional working interests and prospect participations; and expand and replace depleting oil and
gas reserves.



We have a pending litigation which
could have a material effect on our financial condition or profitability. On or about September 30, 2014, Stratex Oil
& Gas Holdings, Inc. (“Stratex”) filed a petition against Zavala Inc. in the District Court of Zavala County,
Texas seeking breach of contract and actual damages of US$152,293 (the “Purported Debt”) for Zavala Inc’s alleged
non-payment of its proportionate share of minimum royalties due under the Matthews Lease. Zavala Inc. disputes the claim citing
$300,000 paid by the Company to be credited against the minimum royalties which Stratex has failed to do. Zavala Inc. paid the
$152,293 under protest and filed a Response and Cross Notice of Default against Stratex (Cause No. 14-09-13290-ZCV)



On or about October 27, 2014, the Company
filed a statement of claim in the Ontario Superior Court of Justice against Alan Gaines, a former director of the Company for
breach of fiduciary duty to the Company relating to Gaines role in the Company contracting with Stratex (Court File No.: 65-14-514935).
The Company is seeking a declaration that Gaines breached his duty to the Company, an accounting and disgorgement of profits made
by Gaines in breach of his duties or in the alternative, damages and/or restitution for breach of fiduciary duty, deceit, and
unjust enrichment in an amount to be determined before trial and $1.0 million in punitive damages.



In February 2013, a vendor of Dyami Energy
applied a lien on the Murphy #4 well and filed a claim in the District Court of Zavala County, Texas (Case No. 13-02-12941-ZCV)
seeking payment of US$169,196 for services. Dyami Energy was disputing the amount on the basis of negligence by the vendor. On
January 28, 2014 the vendor received a summary judgment against Dyami Energy in the amount of $169,196 plus interest at a rate
of 18% per annum from September 17, 2012 until paid and legal fees of $21,178 plus interest at a rate of 5% per annum from the
date of judgment until paid. During 2013 full amount of the provision had been recorded together with legal fees and interest.
The provision, legal fees and interest were transferred to trade and other payables. In addition, in December 2011, a vendor of
Dyami Energy filed a claim in the District Court of Harris County, (Case No. 2011-74035/Court: 113) seeking payment of US$62,800.
Dyami Energy disputed the claim on the basis of excessive charges. In December 2013 an agreed final judgment in favor of the vendor
was entered into court in the amount of $42,803 and post judgment interest at 5% per annum until paid in full. The provision was
transferred to trade and other payables (See - Item 8.A “Consolidated Financial Statements and Other Financial Information
– Litigation”).



We have significant shareholder
loans payable and a secured convertible note payable which may make it difficult to service our debts, adversely affect our ability
to obtain additional financing, engage in any business combinations or negatively affect our operations.At August 31,
2014we had 10% per annum shareholder loans payable on demand in the amount of US$904,250 and a 10% per annum secured
convertible promissory note payable in the amount of US$1,216,175. The note is due on the earliest to occur of: (a) August 31,
2015; (b) the closing of any subsequent financing or series of financings by the Company that results in gross proceeds of an
aggregate amount equal to or greater than US$4,400,000, excluding conversion of any existing debt into equity; (c) the date of
a sale by the Company of all of the shares in the capital stock of Zavala Inc. held by the Company from time to time; (d) the
closing of a merger, reorganization, take-over or other business combination which results in a change of control of the Company
or Zavala Inc.; or (e) an event of default (the “Note”). In the event that the Company closes any subsequent financing
or series of financings that results in gross proceeds to the Company of an aggregate amount equal to or greater than US$2,000,000,
excluding conversion of any existing debt into equity of the Company, the Company shall allocate US$0.50 of every US$1.00 exceeding
the US$2,000,000 raised from such financing to repay the Note. The Note is secured by all of the assets of the Company and Zavala
Inc. The Lender has the right but not the obligation, at any time to convert all or any portion of the unpaid principal and interest
into Units of the Company. Each Unit is comprised of one (1) common share and one (1) common share purchase warrant entitling
the holder to acquire a common share of the Company at a price equal to a 15% premium to the price of the common share acquired
under the Unit. The price of the Units be the lessor of a price equal to the 30-day volume weighted average price of the Company
as of the date of conversion, less 20% (as adjusted for any stock splits, combinations or similar events) or eight US$0.08 per
shareThe Company may, in its sole discretion, prepay any portion
of the principal amount upon seven days’ notice.



5







If in the future we are unable to service
our debt obligations we may, among other things, need to refinance all or a portion of our debt at an increased borrowing cost,
obtain additional financing, delay capital expenditures or sell material assets. If we are not able to re-finance our debt as
necessary, obtain additional financing or sell assets on commercially terms or at all, we may not be able to satisfy our debt
obligations. In the event that shareholder loans or the secured note become payable on demand we may not have sufficient funds
to re-pay all of the debt.



We have significant debt which may
make it more difficult for us to obtain future financing or engage in business combination transactions.   We
have significant debt obligations.  The degree to which this indebtedness could have consequences on our future prospects
includes the effect of such debts on our ability to obtain financing for working capital, capital expenditures or acquisitions.
The portion of available cash flow that will need to be dedicated to repayment of indebtedness will reduce funds available for
expansion.   If we are unable to meet our debt obligations through cash flow from operations, we may be required
to refinance or adopt alternative strategies to reduce or delay capital expenditures, or seek additional equity capital.



Our future operating results are
subject to fluctuation based upon factors outside of our control.   Our operating results may in the future
fluctuate significantly depending upon a number of factors including industry conditions, oil and gas prices, rate of drilling
success, rates of production from completed wells and the timing of capital expenditures.  Such variability could have
a material adverse effect on our business, financial condition and results of operations.  In addition, any failure
or delay in the realization of expected cash flows from operating activities could limit our future ability to participate in
exploration or to participate in economically attractive oil and gas projects.



Our operating results will be affected
by foreign exchange rates.   Since energy commodity prices are primarily priced in US dollars, a portion of
our revenue stream and a portion of our expenses are incurred in US dollars and they are affected by U.S./Canadian dollar exchange
rates.  We do not hedge this exposure.  While to date this exposure has not been material, it may become so in
the future.



Our inability to manage our expected
growth could have a material adverse effect on our business operations and prospects.   We may be subject to
growth-related risks including capacity constraints and pressure on our internal systems and controls. The ability to manage growth
effectively will require us to continue to implement and improve our operational and financial systems and to expend, train and
manage our employee base. The inability to deal with this growth could have a material adverse impact on our business, operations
and prospects.



To compete in our industry, we must
attract and retain qualified personnel.   Our ability to continue our business and to develop a competitive
edge in the marketplace depends, in large part, on our ability to attract and retain qualified management and personnel.  Competition
for such personnel is intense, and we may not be able to attract and retain such personnel which may negatively impact our share
price. We do not have key-man insurance on any of our employees, directors or senior officers and we do not have written employment
agreements with any of our employees, directors or senior officers.



We must continue to institute procedures
designed to avoid potential conflicts involving our officers and directors. Some of our directors and officers are or
may serve on the board of directors of other companies from time to time. Pursuant to the provisions of the Business Corporations
Act (Ontario), our directors and senior officers must disclose material interests in any contract or transaction (or proposed
contract or transaction) material to us.  To avoid the possibility of conflicts of interest which may arise out of their
fiduciary responsibilities to each of the boards, all such directors have agreed to abstain from voting with respect to a conflict
of interest between the applicable companies.  In appropriate cases, we will establish a special committee of independent
directors to review a matter in which several directors, or members of management, may have a conflict.



We rely on the expertise of certain
persons and must insure that these relationships are developed and maintained.   We are dependent on the advice
and project management skills of various consultants and joint venture partners contracted by us from time to time.  Our
failure to develop and maintain relationships with qualified consultants and joint venture partners will have a material adverse
effect on our business and operating results.



6







We must indemnify our officers and
directors against certain actions.   Our articles contain provisions that state, subject to applicable law,
we must indemnify every director or officer, subject to the limitations of the Business Corporations Act (Ontario), against
all losses or liabilities that our directors or officers may sustain or incur in the execution of their duties.  Our
articles further state that no director or officer will be liable for any loss, damage or misfortune that may happen to, or be
incurred by us in the execution of his duties if he acted honestly and in good faith with a view to our best interests. Such limitations
on liability may reduce the likelihood of litigation against our officers and directors and may discourage or deter our shareholders
from suing our officers and directors based upon breaches of their duties to us, though such an action, if successful, might otherwise
benefit us and our shareholders.



We do not currently maintain a permanent
place of business within the United States. A majority of our directors and officers are nationals or residents of countries other
than the United States, and all or a substantial portion of such persons' assets are located outside the United States. As a result,
it may be difficult for investors to enforce within the United States any judgments obtained against our company or our officers
or directors, including judgments predicated upon the civil liability provisions of the securities laws of the United States or
any state thereof.



The global financial crisis is expected
to cause petroleum and natural gas prices to remain volatile for the near future.Recent market events and conditions,
including disruptions in the international credit markets and other financial systems and the deterioration of global economic
conditions, have caused significant volatility to commodity prices. These conditions may be continuing, contributing to a loss
of confidence in the broader U.S. and global credit and financial markets and which could result in the collapse of, and government
intervention in, major banks, financial institutions and insurers and create a climate of greater volatility, less liquidity,
widening of credit spreads, a lack of price transparency, increased credit losses and tighter credit conditions. Notwithstanding
various actions by governments, concerns about the general condition of the capital markets, financial instruments, banks, investment
banks, insurers and other financial institutions caused the broader credit markets to further deteriorate and stock markets to
decline substantially. These factors have negatively impacted company valuations and will impact the performance of the global
economy going forward. Petroleum and natural gas prices are expected to remain volatile for the near future as a result of market
uncertainties over the supply and demand of these commodities due to the current state of the world economies, OPEC actions and
the ongoing global credit and liquidity concerns.



Since our sole executive officer
does not devote his full time to the performance of his Company duties, he may engage in other work activities to our detriment.  James
Cassina, our sole executive officer, devotes approximately 85% of his work time to the performance of his Company duties. Although
he has an obligation to perform his duties in a manner consistent with our best interests and through his stock ownership in the
Company, is incentivized to do so, may encounter conflicts regarding the availability and use of his work time. Although there
are no such present conflicts, the development thereof could have a material adverse effect on us.



Risks Factors Relating to Our Common
Stock



Our stockholders may have difficulty
selling shares of our common stock as there is a limited public trading market for such stock.  There is only a limited
public market for our common stock, and no assurance can be given that a broad or active public trading market will develop in
the future or, if developed, that it will be sustained. Our common stock trades on the Over-the-Counter Bulletin Board. 
In addition, our common stock has not been qualified under any applicable state blue-sky laws, and we are under no obligation
to so qualify or register our common stock, or otherwise take action to improve the public market for such securities. Our common
stock could have limited marketability due to the following factors, each of which could impair the timing, value and market for
such securities:  (i) lack of profits, (ii) need for additional capital, (ii) limited public market for such securities;
(iii) the applicability of certain resale requirements under the Securities Act; and (iv) applicable blue sky laws and the other
factors discussed in this Risk Factors section.



Possible volatility of stock price.The market price for our common stock may be volatile and is subject to significant fluctuations in response to a variety
of factors, including the liquidity of the market for the common stock, variations in our quarterly operating results, regulatory
or other changes in the oil and gas industry generally, announcements of business developments by us or our competitors, litigation,
changes in operating costs and variations in general market conditions. Because we have a limited operating history, the market
price for our common stock may be more volatile than that of a seasoned issuer. Changes in the market price of our securities
may have no connection with our operating results. No predictions or projections can be made as to what the prevailing market
price for our common stock will be at any time.



7







We do not anticipate paying dividends
on our common stock.   We presently plan to retain all available funds for use in our business, and therefore
do not plan to pay any cash dividends with respect to our securities in the foreseeable future.  Hence, investors in
our common stock should not expect to receive any distribution of cash dividends with respect to such securities for the foreseeable
future.



Our shareholders may experience
dilution of their ownership interests because of our future issuance of additional shares of common stock.   Our
constating documents authorize the issuance of an unlimited number of shares of common stock, without par value. In the event
that we are required to issue additional shares of common stock or securities exercisable for or convertible into additional shares
of common stock, enter into private placements to raise financing through the sale of equity securities or acquire additional
oil and gas property interests in the future from the issuance of shares of our common stock to acquire such interests, the interests
of our existing shareholders will be diluted and existing shareholders may suffer dilution in their net book value per share depending
on the price at which such securities are sold. If we do issue additional shares, it will cause a reduction in the proportionate
ownership and voting power of all existing shareholders.As of the date of this Annual report we had outstanding
the following common share purchase warrants: 7,378,560 warrants exercisable at $0.10 per share; 1,915,000 warrants exercisable
at $0.50 per share; 641,240 warrants exercisable at US$5.00 per share; and 102,598 warrants exercisable at US$2.50. If any of
these common share purchase warrants are exercised it would generate additional capital for us. As of the date of this Annual
report we had the following share purchase options outstanding; 100,000 exercisable at $1.60 per share and 1,000,000 exercisable
at $0.12 per share. (See Item 5: “Operating and Financial Review and Prospects – Share Capital and Reserves and
Derivative Liabilities”).



Prospective investors in our Company
are urged to seek independent investment advice.   Independent legal, accounting or business advisors (i) have
not been appointed by, and have not represented or held themselves out as representing the interests of prospective investors
in connection with this Annual Report, and (ii) have not “expertized” or held themselves out as “expertizing”
any portion of this Annual Report, nor is our legal counsel providing any opinion in connection with us, our business or the completeness
or accuracy of this Annual Report.  Neither we nor any of our respective officers, directors, employees or agents, including
legal counsel, make any representation or expresses any opinion (i) with respect to the merits of an investment in our common
stock, including without limitation the proposed value of our common stock; or (ii) that this Annual Report provides a complete
or exhaustive description of us, our business or relevant risk factors which an investor may now or in the future deem pertinent
in making his, her or its investment decision.  Any prospective investor in our common stock is therefore urged to engage
independent accountants, appraisers, attorneys and other advisors to (a) conduct such due diligence review as such investor may
deem necessary and advisable, and (b) to provide such opinions with respect to the merits of an investment in our Company and
applicable risk factors upon which such investor may deem necessary and advisable to rely.  We will fully cooperate
with any investor who desires to conduct such an independent analysis so long as we determine, in our sole discretion, that such
cooperation is not unduly burdensome.



Applicable SEC rules governing the
trading of “penny stocks” will limit the trading and liquidity of our common stock and may affect the trade price
for our common stock.   The Securities and Exchange Commission (“SEC”) has adopted rules which generally
define "penny stock" to be any equity security that has a market price (as defined) of less than US$5.00 per share or
an exercise price of less than $5.00 per share, subject to certain exceptions. Our securities will be covered by the penny stock
rules, which impose additional sales practice requirements on broker-dealers who sell to persons other than established customers
and "accredited investors". The term "accredited investor" refers generally to institutions with assets in
excess of US$5,000,000 or individuals with a net worth in excess of US$1,000,000 or annual income exceeding US$200,000 or US$300,000
jointly with their spouse.



The penny stock rules require a broker-dealer,
prior to a transaction in a penny stock not otherwise exempt from the rules, to deliver a standardized risk disclosure document
in a form prepared by the SEC which provides information about penny stocks and the nature and level of risks in the penny stock
market. The broker-dealer also must provide the customer with current bid and offer quotations for the penny stock, the compensation
of the broker-dealer and its salesperson in the transaction and monthly account statements showing the market value of each penny
stock held in the customer's account. The bid and offer quotations, and the broker-dealer and salesperson compensation information,
must be given to the customer orally or in writing prior to effecting the transaction and must be given to the customer in writing
before or with the customer's confirmation.



8







In addition, the penny stock rules require
that prior to a transaction in a penny stock not otherwise exempt from these rules, the broker-dealer must make a special written
determination that the penny stock is a suitable investment for the purchaser and receive the purchaser's written agreement to
the transaction. These disclosure requirements may have the effect of reducing the level of trading activity in the secondary
market for the shares that are subject to these penny stock rules. Consequently, these penny stock rules may affect the ability
of broker-dealers to trade our securities. We expect that the penny stock rules will discourage investor interest in and limit
the marketability of our common shares.



In addition to the "penny stock"
rules described above, The Financial Industry Regulatory Authority (“FINRA”) has adopted rules that require that in
recommending an investment to a customer, a broker-dealer must have reasonable grounds for believing that the investment is suitable
for that customer. Prior to recommending speculative low priced securities to their non-institutional customers, broker-dealers
must make reasonable efforts to obtain information about the customer's financial status, tax status, investment objectives and
other information. Under interpretations of these rules, the FINRA believes that there is a high probability that speculative
low priced securities will not be suitable for at least some customers. The FINRA requirements will make it more difficult for
broker-dealers to recommend that their customers buy our common shares, which may limit your ability to buy and sell our shares
and have an adverse effect on the market for our shares.



Risks Factors Relating to Our Business



Our future success is dependent
upon our ability to locate, obtain and develop commercially viable oil and gas deposits.   Our future success
is dependent upon our ability to economically locate commercially viable oil and gas deposits. We may not be able to consistently
identify viable prospects, and such prospects, if identified, may not be commercially exploitable.  Our inability to
consistently identify and exploit commercially viable hydrocarbon deposits would have a material and adverse effect on our business
and financial position.



Exploratory drilling activities
are subject to substantial risks.   Our expected revenues and cash flows will be principally dependent upon
the success of any drilling and production from prospects in which we participate.  The success of such prospects will
be determined by the economical location, development and production of commercial quantities of hydrocarbons.  Exploratory
drilling is subject to numerous risks, including the risk that no commercially productive oil and gas reservoirs will be encountered.
The cost of drilling, completing and operating wells is often uncertain, and drilling operations may be curtailed, delayed or
canceled as a result of a variety of factors, including unexpected formation and drilling conditions, pressure or other irregularities
in formations, blowouts, equipment failures or accidents, as well as weather conditions, compliance with governmental requirements
or shortages or delays in the delivery of equipment.  Our inability to successfully locate and drill wells that will
economically produce commercial quantities of oil and gas could have a material adverse effect on our business and, financial
position.



Our drilling and exploration plans
will be subject to factors beyond our control.   A prospect is a property that has been identified based on
available geological and geophysical information that indicates the potential for hydrocarbons. Whether we ultimately drill a
property may depend on a number of factors including funding; the receipt of additional seismic data or reprocessing of existing
data; material changes in oil or gas prices; the costs and availability of drilling equipment; the success or failure of wells
drilled in similar formations or which would use the same production facilities; changes in estimates of costs to drill or complete
wells; our ability to attract industry partners to acquire a portion of our working interest to reduce exposure to drilling and
completion costs; decisions of our joint working interest owners; and restrictions under provincial or state regulators.



Our operating results are subject
to oil and natural gas price volatility.   Our profitability, cash flow and future growth will be affected by
changes in prevailing oil and gas prices.  Oil and gas prices have been subject to wide fluctuations in recent years
in response to changes in the supply and demand for oil and natural gas, market uncertainty, competition, regulatory developments
and other factors which are beyond our control.  It is impossible to predict future oil and natural gas price movements
with any certainty.  We do not engage in hedging activities.  As a result, we may be more adversely affected
by fluctuations in oil and gas prices than other industry participants that do engage in such activities.   An
extended or substantial decline in oil and gas prices would have a material adverse effect on our access to capital, and our financial
position and results of operations.



9







Unforeseen title defects may result
in a loss of entitlement to production and reserves.   Although we conduct title reviews in accordance with
industry practice prior to any purchase of resource assets, such reviews do not guarantee that an unforeseen defect in the chain
on title will not arise and defeat our title to the purchased assets.  If such a defect were to occur, our entitlement
to the production from such purchased assets could be jeopardized.



Estimates of reserves and predictions
of future events are subject to uncertainties.   Certain statements included in this Annual Report contain estimates
of our oil and gas reserves and the discounted future net revenues from those reserves, as prepared by independent petroleum engineers
or us.  There are numerous uncertainties inherent in such estimates including many factors beyond our control. The estimates
are based on a number of assumptions including constant oil and gas prices, and assumptions regarding future production, revenues,
taxes, operating expenses, development expenditures and quantities of recoverable oil and gas reserves.  Such estimates
are inherently imprecise indications of future net revenues, and actual results might vary substantially from the estimates based
on these assumptions.  Any significant variance in these assumptions could materially affect the estimated quantity
and value of reserves.  In addition, our reserves might be subject to revisions based upon future production, results
of future exploration and development, prevailing oil and gas prices and other factors. Moreover, estimates of the economically
recoverable oil and gas reserves, classifications of such reserves and estimates of future net cash flows prepared by independent
engineers at different times may vary substantially.  Information about reserves constitutes forward-looking statements.



The success of our business is dependent
upon our ability to replace reserves.   Our future success depends upon our ability to find, develop and acquire
oil and gas reserves that are economically recoverable.  As a result we must locate, acquire and develop new oil and
gas reserves to replace those, if any, being depleted by production.  Without successful funding for acquisitions and
exploration and development activities, our resources will decline.  We may not be able to find and develop or acquire
additional resources at an acceptable cost.



Most of our competitors have substantially
greater financial, technical, sales, marketing and other resources than we do.   We engage in the exploration
for and production of oil and gas, industries which are highly competitive. We compete directly and indirectly with oil and gas
companies in our exploration for and development of desirable oil and gas properties. Many companies and individuals are engaged
in the business of acquiring interests in and developing oil and gas properties in the United States and Canada, and the industry
is not dominated by any single competitor or a small number of competitors. Many of such competitors have substantially greater
financial, technical, sales, marketing and other resources, as well as greater historical market acceptance than we do. We will
compete with numerous industry participants for the acquisition of land and rights to prospects, and for the equipment and labor
required to operate and develop such prospects. Competition could materially and adversely affect our business, operating results
and financial condition. Such competitive disadvantages could adversely affect our ability to participate in projects with favorable
rates of return.



Shortages of supplies and equipment
could delay our operations and result in higher operating and capital costs.   Our ability to conduct operations
in a timely and cost effective manner is subject to the availability of natural gas and crude oil field supplies, rigs, equipment
and service crews. Although none are expected currently, any shortage of certain types of supplies and equipment could result
in delays in our operations as well as in higher operating and capital costs.



Our business is subject to interruption
from severe weather. Presently, our operations are conducted principally in the central region of Alberta, Canada and
in Southwest Texas. The weather in these areas and other areas in which we may operate in the future can be extreme and can cause
interruption or delays in our drilling and construction operations.



We are dependent on third-party
pipelines and would experience a material adverse effect on our operations were our access to such pipelines be curtailed or the
rates charged for use thereof materially increased.   Substantially all our sales of natural gas production
are effected through deliveries to local third-party gathering systems to processing plants.  In addition, we rely on
access to inter-provincial pipelines for the sale and distribution of substantially all of our gas. As a result, a curtailment
of our sale of natural gas by pipelines or by third-party gathering systems, an impairment of our ability to transport natural
gas on inter-provincial pipelines or a material increase in the rates charged to us for the transportation of natural gas by reason
of a change in government regulations or for any other reason, could have a material adverse effect upon us. In such event, we
would have to obtain other transportation arrangements. We may not have economical transportation alternatives and it may not
be feasible for us to construct pipelines. In the event such circumstances were to occur, our operating netbacks from the affected
wells would be suspended until, and if, such circumstances could be resolved.



10







Our business is subject to operating
hazards and uninsured risks.   The oil and gas business involves a variety of operating risks, including fire,
explosion, pipe failure, casing collapse, abnormally pressured formations, adverse weather conditions, governmental and political
actions, premature reservoir declines, and environmental hazards such as oil spills, gas leaks and discharges of toxic gases.
The occurrence of any of these events with respect to any property operated or owned (in whole or in part) by us could have a
material adverse impact on us. Insurance coverage is not always economically feasible and is not obtained to cover all types of
operational risks. The occurrence of a significant event that is not insured or insured fully could have a material adverse effect
on our financial condition.



Our business is subject to restoration,
safety and environmental risk.   Our present operations are primarily in western Canada and southwest Texas
and certain laws and regulations exist that require companies engaged in petroleum activities to obtain necessary safety and environmental
permits to operate. Such legislation may restrict or delay us from conducting operations in certain geographical areas. Further,
such laws and regulations may impose liabilities on us for remedial and clean-up costs, or for personal injuries related to safety
and environmental damages, such liabilities collectively referred to as “decommissioning obligations”. While our safety
and environmental activities have been prudent in managing such risks, we may not always be successful in protecting us from the
impact of all such risks.



The termination or expiration of
any of our licenses and leases may have a material adverse effect on our results of operations.   Our properties
are held in the form of licenses and leases and working interests in licenses and leases. If we, or the holder of the license
or lease, fail to meet the specific requirement of a license or lease, the license or lease may terminate or expire. We may not
meet the obligations required to maintain each license or lease. The termination or expiration of our licenses or leases or the
working interests relating to a license or lease may have a material adverse effect on our results of operations and business
(See Item 4.B: “Information on the Company – History and Development of the Company”).



Compliance with new or modified
environmental laws or regulations could have a materially adverse impact on us.   We are subject to various
Canadian and US laws and regulations relating to the environment.  We believe that we are currently in compliance with
such laws and regulations.  However, such laws and regulations may change in the future in a manner which will increase
the burden and cost of compliance. In addition, we could incur significant liability under such laws for damages, clean-up costs
and penalties in the event of certain discharges into the environment. In addition, environmental laws and regulations may impose
liability on us for personal injuries, clean-up costs, environmental damage and property damage as well as administrative, civil
and criminal penalties. We do not maintain insurance for the full potential liability that could be caused by such environmental
damage. Accordingly, we may be subject to significant liability, or may be required to cease production in the event of the noted
liabilities.



|ITEM 4 | INFORMATION ON THE COMPANY
|------ | --------------------------



We are amalgamated under the laws of the
Province of Ontario.  Our primary activities are investment in, exploration and development and production of oil and
gas.



We hold a 0.5% non-convertible gross overriding
royalty in a natural gas well located in the Haynes area in the Province of Alberta, Canada carried on the consolidated statement
of financial position at Nil.



We hold a 5.1975% working interest held
in trust through a joint venture partner in a natural gas unit located in the Botha area in the Province of Alberta, Canada carried
on the consolidated statement of financial position at Nil.



Through Eagleford Energy, Zavala Inc.,
we hold a 50% working interest in the 2,629 acre Matthews Lease located in Zavala County, Texas and a 33.33% working interest
before payout and 50% working interest after payout in the Matthews #1H well. (See Item 4.B: “Information on the Company
– History and Development of the Company”).



Our registered office and management office
is located at 1 King Street West, Suite 1505, Toronto, Ontario, M5H 1A1, Telephone (416) 364-4039, Facsimile (416) 364-8244. Our
books and financial records are located in the registered office and management office.  Our Canadian public filings
can be accessed and viewed via the System for Electronic Data Analysis and Retrieval (“SEDAR”) at www.sedar.com. Readers
can also access and view our Canadian public insider trading reports via the System for Electronic Disclosure by Insiders at www.sedi.ca.
Our Registrar and Transfer Agent is Equity Financial Trust Company located at Suite 400, 200 University Avenue, Toronto, Ontario,
M5H 4H1. Our U.S. public filings are available at the public reference room of the U.S. Securities and Exchange Commission (“SEC”)
located at 100 F Street, N.E., Room 1580, Washington, DC 20549 and at the website maintained by the SEC at www.sec.gov.



11







A.           HISTORY
AND DEVELOPMENT OF THE COMPANY



We were incorporated in Ontario, Canada
on September 22, 1978, under the Business Corporations Act (Ontario), under the name Bonanza Red Lake Explorations Inc.
(“Bonanza Red Lake”).  By prospectus dated November 20, 1978 and a further amendment to the Prospectus dated
January 10, 1979 we became a reporting issuer in the Province of Ontario and raised $250,000 to acquire interests in and to explore
and develop certain mineral lands located near the Town of Red Lake, Ontario, Canada. In 1987, we optioned our mineral lands in
Red Lake, Ontario to Pure Gold Resources Inc., who expended sufficient funds during 1988 and 1989 to earn an 85% interest in our
eight patented mineral claims, and then discontinued its exploration program on the property. Bonanza Red Lake had subsequently
written the carrying amount of these mineral claims down to $1.



On March 29, 2000, Bonanza Red Lake entered
into a Share Exchange Agreement with 1406768 Ontario Inc. (“1406768 Ontario”).  1406768 Ontario is a company
incorporated under the laws of the Province of Ontario by articles of incorporation dated effective March 13, 2000. The purpose
of the transaction was to allow Bonanza Red Lake to acquire a company, 1406768 Ontario, which resulted in our owning part of an
operating business.  At an Annual and Special Meeting of shareholders held on May 10, 2000 we received shareholder approval
for the acquisition of 1406768 Ontario; the consolidation of Bonanza Red Lake’s issued and outstanding common shares on
a one new common share for every three old common shares basis;  a name change from Bonanza Red Lake to Eugenic Corp;
a new stock option plan (the “Plan”) authorizing 1,275,000 common shares to be set aside for issuance under the Plan;
and authorizing the directors to determine or vary the number of directors of the Company from time to time which pursuant to
our Articles provide for a minimum of three and a maximum of ten.



By Articles of Amendment dated August
15, 2000, Bonanza Red Lake consolidated its issued and outstanding common shares on a one new common share for every three old
common shares basis and changed the name of the company to Eugenic Corp.



We completed the acquisition of 1406768
Ontario on October 12, 2000 and acquired all of the issued and outstanding shares of 1406768 Ontario for $290,000. The purchase
price was satisfied by our issuance of 5,800,000 company units at $0.05 per unit.  Each unit consisted of one common
share and one common share purchase warrant entitling the holder to purchase one common share of ours at an exercise price of
$0.25 per common share until October 12, 2003. As a result of this transaction, the original shareholders of 1406768 Ontario owned
90.7% of our issued shares. The acquisition resulted in a change in business and an introduction of new management for us. The
acquisition was accounted for as a reverse take-over of us by 1406768 Ontario. Our net assets acquired at fair value as at October
12, 2000 resulted in a deficiency of assets over liabilities in the amount of $123,170 which was charged to share capital. All
of the 5,800,000 outstanding warrants expired on October 12, 2003.



On February 5, 2009, we completed a non-brokered
private placement of 2,600,000 units (each a “Unit”) at a purchase price of $0.05 per Unit for gross proceeds of $130,000.
Each Unit was comprised of one common share (each a “Unit Share”) and one purchase warrant (each a “Warrant”).  Each
Warrant is exercisable until February 5, 2014 to purchase one additional share of our common stock (each a “Warrant Share”)
at a purchase price of $0.07 per share. 1407271 Ontario Inc. purchased 1,600,000 units. 1407271 Ontario Inc. is owned 100% by
our former President, Ms. Sandra Hall.  Ms. Hall is also the sole director and officer of 1407271.



On February 25, 2009, we completed a non-brokered
private placement of 1,000,256 units (each a “Unit”) at a purchase price of $0.05 per Unit for gross proceeds of approximately
$50,013. Each Unit was comprised of one common share (each a “Unit Share”) and one purchase warrant (each a “Warrant”).  Each
Warrant is exercisable until February 25, 2014 to purchase one additional share of our common stock (each a “Warrant Share”)
at a purchase price of $0.07 per share. Sandra Hall, our former president and former director, and Milton Klyman, a director,
purchased 600,000 Units and 50,000 Units, respectively.



On February 27, 2009, we purchased all
of the issued and outstanding shares issued in the capital stock of 1354166 Alberta Ltd. (“1354166 Alberta”),
a company incorporated on October 3, 2007 in the Province of Alberta Canada (the "Transaction") under the Business Corporations
Act (Alberta).  In connection therewith, we issued to the shareholders of 1354166 an aggregate of 8,910,564 units (each
a "Unit") at $0.05 per unit or an aggregate of $445,528 and following the closing repaid $118,000 of shareholders’
loans in 1354166 by cash payment. . Each unit is comprised of one share of our common stock (each a "Share") and one
purchase warrant (each a "Warrant").  Each Warrant is exercisable until February 27, 2014 to purchase one
additional share of our common stock at a purchase price of $0.07 per share. 1354166 is a private company that has a 5.1975% working
interest held in trust through a joint venture partner in a natural gas unit located in the Botha area of Alberta, Canada.



12







On February 27, 2009, we entered into
an agreement with a non-related party, to convert debt in the amount of $62,500 through the issuance of a total of 1,250,000 units
at an attributed value of $0.05 per unit (the "Debt Settlement").  Each Unit was comprised of one common share
(each a “Unit Share”) and one purchase warrant (each a “Warrant”).  Each Warrant is exercisable
until February 27, 2014 to purchase one additional share of our common stock (each a “Warrant Share”) at a purchase
price of $0.07 per share.



By Articles of Amendment dated November
12, 2009, 1406768 Ontario changed its name to Eagleford Energy Inc. By Articles of Amalgamation dated November 30, 2009 we amalgamated
with Eagleford Energy Inc. and upon the amalgamation the amalgamated entity's name became Eagleford Energy Inc.



Effective June 10, 2010, we retained Gar
Wood Securities, LLC (“Gar Wood”) to act as Investment Banker/Financial Advisor to the Company for a period of two
years. Under the terms of the Gar Wood engagement, we agreed to pay a fee of 6% of the gross proceeds raised and issue 1,500,000
common share purchase warrants. On November 5, 2010 we terminated the agreement with Gar Wood dated June 10, 2010. As a result
36,430 warrants were cancelled out of the 333,333 warrants issued exercisable at $1.00 expiring December 10, 2011 and 18,215 warrants
were cancelled out of the 166,667 warrants issued exercisable at $1.50 expiring June 10, 2012. On December 10, 2011 296,903 warrants
exercisable at US $1.00 expired. During the year ended August 31, 2012 all of the remaining warrants expired unexercised.



During the fiscal year ended August 31,
2010, 1,100,000 of our common share purchase warrants were exercised at $0.07 expiring February 5, 2014 for proceeds of $77,000
and 1,000,000 of our common share purchase warrants were exercised at $0.07 expiring February 27, 2014 for proceeds of $70,000.



On August 31, 2010 we acquired a 10% working
interest before payout and a 7.5% working interest after payout of production revenue of $15 million in the Matthews lease comprising
approximately 2,629 gross acres of land in Zavala County, Texas (the “Lease Interest”). As consideration for the Lease
Interest we paid on closing $212,780 (US$200,000), satisfied by US$25,000 in cash and $186,183 (US$175,000) satisfied by the issuance
of a 5% secured promissory note.US$100,000 of principal together with accrued interest was due and payable on February 28, 2011(paid)
and US$75,000 of principal together with accrued interest was due and payable on August 31, 2011 (paid). The note was secured
by the Lease Interest.



On August 31, 2010, we acquired 100% of
the issued and outstanding membership interests of Dyami Energy LLC, a Texas limited liability corporation for consideration of
$4,218,812. (US$3,965,422) satisfied by (i) the issuance of 3,418,467 units of the Company. Each unit is comprised of one common
share and one-half a purchase warrant. Each full warrant is exercisable into one additional common share at US$1.00 per share
on or before August 31, 2014 (the “Units’) and (ii) the assumption of $1,021,344 (US$960,000) of Dyami Energy debt
by way of a secured promissory note payable to Benchmark Enterprises LLC (“Benchmark”). The 6% per annum note was
secured by Dyami’s interest in the Matthews and Murphy leases and was payable on December 31, 2011 or upon the Company closing
a financing or series of financings in excess of US$4,500,000. Commencing January 1, 2012 the interest rate increased from 6%
to 10% and the due date of the note was extended to August 31, 2013, or within 15 days of written demand to us, or upon us closing
of a cash financing or series of cash financings closing after the date of this agreement in excess of US$2,500,000 (Two Million,
Five Hundred Thousand USA dollars), (the “Funding Threshold”) in which case fifty cents of every one dollar exceeding
the Funding Threshold will be allocated to the Note until paid in full or upon an Event of Default. On January 3, 2012 we issued
515,406 pre forward split common shares to shares Benchmark as full settlement of interest due at December 31, 2011 in the amount
of $103,028.



Dyami Energy held a 75% working interest
before payout and a 61.50% working interest after payout of production revenue of $12.5 million in the Matthews Lease comprising
approximately 2,629 gross acres of land in Zavala County, Texas and a 100% working interest in a mineral lease comprising approximately
2,637 acres of land in Zavala County, Texas (the “Murphy Lease”) subject to a 10% carried interest on the drilling
costs from surface to base of the Austin Chalk formation, and a 3% carried interest on the drilling costs from the top of the
Eagle Ford shale formation to basement on the first well drilled into a serpentine plug and for the first well drilled into a
second serpentine plug, if discovered (collectively the “Leases”) (See Item 4.B: “Information on the Company
– History and Development of the Company”).



13







The Members of Dyami entered into lock
up agreements on closing and placed 50% of the Units in escrow (1,709,234 common shares and 854,617 purchase warrants) until such
time that we receive a National Instrument 51-101 compliant report from an independent engineering firm indicating at least
100,000 boe of proven reserves on either the Murphy Lease or any formation below the San Miguel on the Matthews Lease (the “Report”).
The Report was not received by Dyami Energy within two years of the closing date of the acquisition andthe escrow units were to
be returned to us for cancellation. On August 31, 2012 we cancelled the 50% of Units held in escrow as the conditions precedent
had not been satisfied and the time allowed for performance expired.



In connection with the Dyami Energy acquisition,
we entered into a one year employment agreement with Eric Johnson and reserved 850,000 common share purchase warrants, exercisable
on an earn-out basis, for the purchase of 850,000 common shares of our stock at a price of US$1.00 per share during a period of
five years from the date of issuance. On April 13, 2011 the employment agreement was terminated and no warrants were issued or
issuable



During the fiscal year ended August 31,
2010 we spent $10,046 on exploration expenditures related to the Matthews Lease.



On March 31, 2011 we entered into a Farmout
Agreement (the “Farmout”) from surface to the base of the San Miguel formation (the “San Miguel”) on the
Matthews Lease located in Zavala County, Texas. Under the Farmout, the farmee may spend up to US$1,050,000 on exploration and
development of the San Miguel to earn a maximum of 42.50% working interest (31.875% net revenue interest). Under the terms of
the Farmout, the farmee may earn an initial 25% of the Company’s working interest in the San Miguel by paying 100% of the
costs to drill, complete, equip and perform an injection operation on a test well to a depth of approximately 3,500 feet (the
“Initial Test Well”). After the performance of the Initial Test Well, the farmee may increase its working interest
to 50% of the Company’s working interest by spending the entire $1,050,000 on additional operations on the San Miguel in
a good faith effort to produce hydrocarbons. We received US$647,536 from the farmee against costs of $711,395 related to the drilling,
completion and injection operation of the Matthews/Dyami #3 well. As of the date of this Annual Report we have not assigned any
interest to the farmee in the San Miguel formation.



During the fiscal year ended August 31,
2011 we drilled four wells and recorded additions of $3,262,782 to exploration and evaluation assets related to the Matthews and
Murphy Leases.



During the year ended August 31, 2011,
500,000 of our common share purchase warrants were exercised at $0.07 expiring February 5, 2014 for proceeds of $35,000; 625,247
of our common share purchase warrants were exercised at $0.07 expiring February 27, 2014 for proceeds of $44,475; and 2,575,000
of our common share purchase warrants were exercised at $0.20 expiring April 14, 2011 for proceeds of $515,000.



During the year ended August 31, 2011
we received $2,878,736 and issued demand promissory notes bearing interest at 10% per annum. Interest is payable annually on the
anniversary date of the notes.



During the year ended August 31, 2011
we paid a $110,000 loan payable.



As of the close of business on March 16,
2012, we completed a two-for-one forward stock split, pursuant to which one (1) newly-issued share of the Company’s common
stock was issued to each holder of a share of common stock.



During the year ended August 31, 2012
we completed a financing of 12,575,000 units in the capital of the Company for net proceeds of $2,086,718.



During the year ended August 31, 2012,
we issued 17,150,000 units as full settlement of debt and shareholders’ loans in the amount of $857,500 and issued 3,278,392
common shares as full settlement of interest due on a secured note and shareholders’ loans in the amount of $369,885.



During the year ended August 31, 2012,
we received cash of $321,845 and US$175,000 and issued demand promissory notes bearing interest at 10% per annum.



During the twelve months ended August
31, 2012, we paid US$480,000 of shareholders’ loans.



For the twelve months ended August 31,
2012, we recorded additions of $1,559,763 to exploration and evaluation assets related to the leases in Zavala County, Texas.



14







During the year ended August 31, 2013
we completed a financing of 2,249,790 units in the capital of our Company for net proceeds of $405,650. Each unit is comprised
of one common share and one-half of one common share purchase warrant with each full warrant entitling the holder to acquire one
common share of ours at US$0.50 or a period of three years from the date of issue.



During the year ended August 31, 2013,
we issued 23,662,569 common shares as full settlement of shareholder loans and interest due on shareholders’ loans of $198,333
and $345,906 respectively.



For
the twelve months ended August 31, 2013, we recorded additions of $404,818 to exploration and evaluation assets related to the
leases in Zavala County, Texas and an impairment of $2,690,568 on
the Murphy Lease.



Matthews Lease, Zavala County, Texas

During the year ended August 31, 2013,
the Company, Dyami Energy and OGR Energy Corporation, the Lessees, were litigating a dispute with the Lessors of the Matthew’s
property. During the last quarter of fiscal year August 2013, the Company and the Lessors agreed to resolve the litigation and
continue with the development of the Matthew’s property. In order to comply with certain State legal requirements, it was
deemed necessary by the Lessors counsel to continue with the development through a newly executed lease document and the Company
formed, Zavala Inc. a new wholly owned subsidiary to execute the new lease. The new lease was signed effective September 1, 2013
and the first of two payments of US$150,000 were paid to the Lessors upon signing the new lease as required initial pre-payment
of anticipated production royalties along with a continuing development obligation under the lease to complete the previously
drilled Matthews #1H horizontal well or drill a new well on the Matthews property no later than March 30, 2014. On September 1,
2013, the Matthews lease was renewed by the Company through Zavala Inc. and based on the concept of faithful representation under
IAS 8, the carrying value of the Matthew’s lease by Dyami Energy was considered to be the value for Zavala Inc. as this
arrangement is simply a reorganization in substance.



On December 3, 2013, (amended January
21, 2014) the Company entered into a Joint Development Agreement with Stratex Oil and Gas Holdings, Inc. (“Stratex”)
(the “Stratex JDA”) to further develop the Matthews Lease. Under the terms of the Stratex JDA, Stratex will act as
operator and upon Stratex delivering i) US$150,000 to the lessors of the Matthews Lease on behalf of Zavala Inc., ii) delivering
US $150,000 to the Company; and iii) commencing a hydraulic fracture of the Matthews #1H not later than March 31, 2014. Stratex
earned a 66.67% working interest before payout (50% working interest after payout) in the Matthews #1H well and a 50% working
interest in the 2,629 acre Matthews Lease (see Note 17).



Through Zavala Inc., the Company holds
a 50% working interest in the 2,629 acre Matthews Lease (33.33% working interest before payout and 50% working interest after
payout in the Matthews #1H well). The Matthews Lease had a primary term extended to March 31, 2014 (the “Primary Term”)
while each lease year ends August 31. Prior to the expiration of the Primary Term, a hydraulic fracturing of the Matthews #1H
well was completed and thereafter the lease is maintained through a guaranteed minimum royalty payment of $323.30 per acre and
beginning in the second lease year and continuing thereafter for each succeeding lease year drill at least 2 wells per lease year.
The royalties payable under the Matthews Lease are 25%.



On April 11, 2014, the Company entered
into a further Joint Development Agreement (“JDA2”) with Stratex and Quadrant Resources LLC, (“Quadrant”)
for the development of the San Miguel formation on the Matthews Lease.  Pursuant to the terms of the JDA2, upon satisfaction
of certain conditions including the Phase 1 Work Program and the cash consideration described below, Quadrant can earn an undivided
66.67% before payout and a 50% working interest after payout to the base of the San Miguel formation of the Matthews Lease by
i) drilling 3 new wells and reworking 5 wells at its sole cost and expense by June 30, 2015 (the “Phase I Work Program”);
ii) deliver US$100,000 to the Company upon execution of the JDA2 (paid); and iii) deliver US$65,000 to the Company on each of
July 8, 2014 (paid); October 6, 2014, January 5, 2015 and April 6, 2015. At August 31, 2014 the Company recorded the payments
received from Quadrant of US$165,000 (CDN $177,804) as deferred revenue on the Consolidated Statement of Financial Position until
the conveyance of the earned interest at which time this amount will be reclassified and offset against exploration and evaluation
assets.



Murphy Lease, Zavala County, Texas

Subsequent to September 1, 2013 and the
continuing development of the Matthews lease, Dyami Energy continued its development efforts with the Murphy lease. A tentative
joint venture agreement with Stratex was reached but did not materialize and efforts to develop the Murphy lease were not successful.
The Company had solicited lenders and investors in an attempt to obtain debt/equity financings as a means to improve Dyami Energy’s
financial situation. Despite the Company’s attempts, these efforts were unsuccessful and management determined that it could
no longer fund the Murphy operations, hence the lease was considered impaired and an impairment loss was recorded by Dyami Energy
during the third quarter (see Note 16 to the consolidated financial statements).



15







On March 6, 2014, the Company filed a
Certificate of Termination of a Domestic Entity with the Secretary of State, Texas for our wholly-owned subsidiary Dyami Energy
and effective April 3, 2014, Dyami Energy was dissolved. All prior obligations with respect to the Matthew’s and Murhpy’s
lease on the books of Dyami Energy prior to its dissolution were recorded by the Company.



We filed Articles of Amendment effective
August 25, 2014 consolidating the common shares of Eagleford Energy Inc., on the basis of one (1) common share for every ten (10)
common shares and changed its name to Eagleford Energy Corp.



During the year ended August 30, 2014,
we converted shareholders’ loans and interest due in the aggregate amount of $1,180,570 through the issuance of a total
of 14,757,120 units in the capital of our Company at a price of $0.08 per unit. Each unit is comprised of one (1) common share
and one half of one (1/2) common share purchase warrant. Each full warrant entitles the holder to purchase one (1) common share
at an exercise price of CDN$0.10 until August 30, 2017.



For the twelve months ended August 31,
2014, the Company recorded net additions of $113,578 in exploration and evaluation assets and a net impairment loss of $1,315,276
related to the Murphy Lease.



We intend to apply additional capital
to further enhance our property interests. As part of our oil and gas development program, management of the Company anticipates
further expenditures to expand its existing portfolio of proved reserves. Amounts expended on future exploration and development
is dependent on the nature of future opportunities evaluated by us. These expenditures could be funded through cash held by the
Company or through cash flow from operations. Any expenditure which exceeds available cash will be required to be funded by additional
share capital or debt issued by us, or by other means. Our long-term profitability will depend upon our ability to successfully
implement our business plan.



Our past primary source of liquidity and
capital resources has been proceeds from the issuance of share capital, loans and advances and cash flow from our oil and gas
operations.



Our registered office and principal place
of business in Ontario is located at 1 King Street West, Suite 1505, Toronto, Ontario M5H 1A1.  Our telephone number
at that address is (416) 364-4039.



B.           BUSINESS
OVERVIEW



Directly and through our wholly owned
subsidiaries 1354166 Alberta and Zavala Inc. we are primarily engaged in the development, acquisition and production of oil and
gas interests located in Alberta, Canada and Texas, USA.



We have a 0.5% Non-Convertible Overriding
Royalty (“NCOR”) in a natural gas well located in Haynes, Alberta, Canada a 5.1975% working interest in a natural
gas unit located in Alberta, Canada both of which are carried on our consolidated statement of financial position at Nil.



Through Eagleford Energy, Zavala Inc.,
we hold a 50% working interest in the 2,629 acre Matthews Lease located in Zavala County, Texas and a 33.33% working interest
before payout and 50% working interest after payout in the Matthews #1H well. (See Item 4.B: “Information on the Company
– History and Development of the Company”).



We have a 0.3% Net Smelter Return Royalty
on 8 patented mining claims located in Red Lake, Ontario, Canada carried on our consolidated statement of financial position at
Nil.



For the three fiscal years ending August
31, 2014, 2013 and 2012 the total revenue, net of royalties derived from the sale of our natural gas interests in Canada was as
follows:



|Year            |  | Total Net Revenue |       
|--------------- |  | ----------------- | ------
|August 31, 2014 |  | $                 | 65,024
|August 31, 2013 |  | $                 | 30,062
|August 31, 2012 |  | $                 | 39,218



16







We sell our natural gas production to
integrated oil and gas companies and marketing agencies. Sales prices are generally set at market prices available in Canada or
the United States.



The level of activity in the oil and gas
industry in North America is influenced by seasonal weather patterns.  Wet weather and spring thaw make the ground unstable.
Government, municipalities and provincial transportation departments enforce road bans that may restrict the level of activity.  Seasonal
factors and unexpected weather patterns may lead to declines in production activity and increased consumer demand or changes in
supply during certain months of the year may influence the commodity prices.



There is an existing and available market
for the oil and gas produced from the properties. However, the prices obtained for production are subject to market fluctuations,
which are affected by many factors, including supply and demand. Numerous factors beyond our control, which could affect pricing
include:



| | • | the level of consumer product demand;
| | - | -------------------------------------

| | • | weather conditions;
| | - | -------------------

| | • | the foreign supply of oil and gas;
| | - | ----------------------------------

| | • | the price of foreign imports;
| | - | -----------------------------

| | • | volatility in market prices for oil and natural gas;
| | - | ----------------------------------------------------

| | • | ability to raise financing;
| | - | ---------------------------

| | • | reliance on third party operators;
| | - | ----------------------------------

| | • | ability to find or produce commercial quantities of oil
                                         and natural gas;
| | - | -----------------------------------------------------------------------------------------------------------------

| | • | liabilities inherent in oil and natural gas operations;
| | - | -------------------------------------------------------

| | • | dilution of interests in oil and natural gas properties;
| | - | --------------------------------------------------------

| | • | general business and economic conditions;
| | - | -----------------------------------------

| | • | the ability to attract and retain skilled staff;
| | - | ------------------------------------------------

| | • | reliance on joint interest parties;
| | - | -----------------------------------

| | • | uncertainties associated with estimating oil and natural
                                         gas reserves;
| | - | ---------------------------------------------------------------------------------------------------------------

| | • | competition for, among other things, financings, acquisitions
                                         of reserves, undeveloped lands and skilled personnel; and
| | - | ----------------------------------------------------------------------------------------------------------------------------------------------------------------

| | • | governmental regulation and environmental legislation
                                         (See, Item 3.D Key Information - Risk Factors).
| | - | ----------------------------------------------------------------------------------------------------------------------------------------------



We caution that the foregoing list of
important factors is not exhaustive. Investors and others who base themselves on our forward-looking statements should carefully
consider the above factors as well as the uncertainties they represent and the risk they entail. We also caution readers not to
place undue reliance on these forward-looking statements. Moreover, the forward-looking statements may not be suitable for establishing
strategic priorities and objectives, future strategies or actions, financial objectives and projections other than those mentioned
above.



We do not have a reliance on raw materials,
as we operate in an extractive industry.



We do not have a reliance on any significant
patents.



The oil and gas business is highly competitive
in every phase.  Many of our competitors have greater financial and technical resources, and have established multi-national
operations, secured land rights and licenses, which we may not have.  As a result, we may be prevented from participating
in drilling and acquisition programs (See, Item 3.D Key Information - Risk Factors).



Governmental Regulation/Environmental
Issues

Our oil and gas operations are subject
to various United States and Canadian governmental regulations including those imposed by the Texas Railroad Commission and Alberta
Energy Resources Conversation Board and Alberta Utilities Commission. Matters subject to regulation include discharge permits
for drilling operations, drilling and abandonment bonds, reports concerning operations, the spacing of wells, and pooling of properties
and taxation. From time to time, regulatory agencies have imposed price controls and limitations on production by restricting
the rate of flow of oil and gas wells below actual production capacity in order to conserve supplies of oil and gas. The production,
handling, storage, transportation and disposal of oil and gas, by-products thereof, and other substances and materials produced
or used in connection with oil and gas operations are also subject to regulation under federal, state, provincial and local laws
and regulations relating primarily to the protection of human health and the environment. To date, expenditures related to complying
with these laws, and for remediation of existing environmental contamination, have not been significant in relation to the results
of operations of our company. The requirements imposed by such laws and regulations are frequently changed and subject to interpretation,
and we are unable to predict the ultimate cost of compliance with these requirements or their effect on our operations. These
regulations may adversely affect our operations and cost of doing business. It is likely that these laws and regulations will
become more stringent in the future (See, Item 3.D Key Information - Risk Factors).



17







C.           ORGANIZATIONAL
STRUCTURE



We have two wholly owned subsidiaries.
1354166 Alberta Ltd. is a company incorporated under the Business Corporations Act (Alberta) and Eagleford Energy, Zavala
Inc. a Nevada company.



D.           PROPERTY,
PLANTS AND EQUIPMENT



Our executive offices consist of approximately
850 square feet of office space and are rented at $1,500 per month on a month to month basis.  The address of our executive
offices is 1 King Street West, Suite 1505, Toronto, Ontario Canada.



Canada

We hold directly a 0.5% NCOR in a natural
gas well located in Haynes, Alberta, Canada.



We hold through our wholly owned subsidiary
1354166 Alberta a 5.1975% working interest in a natural gas unit located in Botha, Alberta, Canada.



We have a 0.3% Net Smelter Return Royalty
on eight patented mining claims located in Red Lake, Ontario, Canada.



United States

Through Eagleford Energy, Zavala Inc.,
we hold a 50% working interest in the 2,629 acre Matthews Lease located in Zavala County, Texas and a 33.33% working interest
before payout and 50% working interest after payout in the Matthews #1H well. (See Item 4.B: “Information on the Company
– History and Development of the Company”).



Our interest in the Matthews Lease is
situated in Zavala County, Texas and is part of the Maverick Basin of Southwest Texas and downdip from the United States Geological
Studies north boundary of the Smackover-Austin-Eagle Ford total petroleum system.



The table below is a glossary of terms
and abbreviations that may be used in this Item.



GLOSSARY OF TERMS



|Natural Gas                 |  | Mcf   |  | 1,000 cubic feet                 
|--------------------------- |  | ----- |  | ---------------------------------
|                            |  | MMcf  |  | 1,000,000 cubic feet             
|                            |  | Mcf/d |  | 1,000 cubic feet per day         
|                            |  |       |  |                                  
|Oil and Natural Gas Liquids |  | Bbl   |  | Barrel                           
|                            |  | Mbbls |  | 1,000 barrels                    
|                            |  | Blpd  |  | Barrels of liquid per day        
|                            |  | Boe   |  | Barrel of oil equivalent (1)     
|                            |  | Bpd   |  | Barrels per day                  
|                            |  | Boepd |  | Barrels of oil equivalent per day
|                            |  | Bopd  |  | Barrels of oil per day           
|                            |  | NGLs  |  | Natural gas liquids              



(1) Disclosure provided herein in respect
of BOEs may be misleading, particularly if used in isolation.  A BOE conversion ratio of 6 Mcf: 1 Bbl is based on an
energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the
wellhead.



The following table sets forth certain
standard conversions between Standard Imperial Units and the International System of Units (or metric units).



18







|To Convert From    |  | To           |  | Multiply By |       
|------------------ |  | ------------ |  | ----------- | ------
|                   |  |              |  |             |       
|Mcf                |  | Cubic metres |  |             | 28.174
|Cubic metres       |  | Cubic feet   |  |             | 35.494
|Bbls               |  | Cubic metres |  |             | 0.159 
|Cubic metres       |  | Bbls         |  |             | 6.289 
|Feet               |  | Metres       |  |             | 0.305 
|Metres             |  | Feet         |  |             | 3.281 
|Miles              |  | Kilometers   |  |             | 1.609 
|Kilometers         |  | Miles        |  |             | 0.621 
|Acres (Alberta)    |  | Hectares     |  |             | 0.405 
|Hectares (Alberta) |  | Acres        |  |             | 2.471 



Reserve Information: The process
of evaluating reserves is inherently complex.  It requires significant judgments and decisions based on available geological,
geophysical, engineering and economics data.  These estimates may change substantially as additional data from ongoing
development activities and production performance becomes available and as economic conditions impacting oil and gas prices and
costs changes.  The reserve estimates contained herein are based on current production forecasts, prices and economic
conditions.  These factors and assumptions include among others (i) historical production in the area compared with
production rates from analogous producing areas; (ii) initial production rates, (iii) production decline rates, (iv) ultimate
recovery of reserves; (v) success of future development activities; (vi) marketability of production, (vii) effects of government
regulation; and (viii) other government levies imposed over the life of the reserves.



As circumstances change and additional
data becomes available, reserves estimates also change.  Estimates are reviewed and revised, either upward or downward,
as warranted by the new information.  Revisions are often required for changes in well performance, prices, economic
conditions and governmental restrictions.  Revisions to reserve estimates can arise from changes in year–end prices,
reservoir performance and geological conditions or production.  These revisions can be either positive or negative ("
3.D: “Key Information – Risk Factors”).



Proved reserves are those reserves that
can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered
will exceed the estimated proved reserves.



Probable reserves are those additional
reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities
recovered will be greater or less than the sum of the estimated proved plus probable reserves.



The qualitative certainty levels contained
in the definitions in proved, probable and possible reserves are applicable to individual reserves entities, which refers to the
lowest level at which reserves estimates are made, and to reported reserves, which refers to the highest level sum of individual
entity estimates for which reserve estimates are made.



Reported total reserves estimated by deterministic
or probabilistic methods, whether comprised of a single reserves entity or an aggregate estimate for multiple entities, should
target the following levels of certainty under a specific set of economic conditions:



a. There is a 90% probability that at
least the estimated proved reserves will be recovered.

b. There is a 50% probability that at
least the sum of the estimated proved reserves plus probable reserves will be recovered.

c. There is a 10% probability that at
least the sum of the estimated proved reserves plus probable reserves plus possible reserves will be recovered.



A quantitative measure of the probability
associated with a reserves estimate is generated only when a probabilistic estimate is conducted. The majority of reserves estimates
will be performed using deterministic methods that do not provide a quantitative measure of probability. In principle, there should
be no difference between estimates prepared using probabilistic or deterministic methods.



Additional clarification of certainty
levels associated with reserves estimates and the effect of aggregation is provided in Section 5.5.3 of the COGE Handbook. Whether
deterministic or probabilistic methods are used, evaluators are expressing their professional judgement as to what are reasonable
estimates.



The crude oil and natural gas industry
commonly applies a conversion factor to production and estimated proved reserve volumes of natural gas in order to determine an
“all commodity equivalency” referred to as barrels of oil equivalent (“boe”). The conversion factor we
have applied in this Report is the current convention used by many oil and gas companies, where six thousand cubic feet (“mcf”)
is equal to one barrel (“bbl”). A boe is based on an energy equivalency conversion method primarily applicable at
the burner tip. It may not represent equivalency at the wellhead and may be misleading if used in isolation.



19







Internal Controls for Reserves Reporting:
For the year ended August 31, 2014 and 2013 we had no recordable reserves or discernable future net revenue. For the year ended
August 31, 2012 a significant component of our internal controls in our reserve estimation effort is our practice of using an
independent third-party reserve engineering firm to prepare 100% of our year-end proved and probable reserves. The qualifications
of this firm are discussed below under “Independence and Qualifications of Reserve Preparer.” The Board of Directors
of the Company has reviewed the reserves estimates and procedures prior to acceptance of the reports.   The Board of
Directors has sufficient technical training and experience to review and approve the reports.



Our director Mr. McNeil, chair of our
petroleum and natural gas committee maintains oversight and compliance responsibility for the internal reserve estimate process
and provides appropriate data to our independent third party reserve engineers to estimate our year-end reserves. Mr. McNeil is
a self-employed oil and gas consultant and has been a geophysicist since 1972. Mr. McNeil is a member of the Association of Professional,
Engineers, Geologists and Geophysicists of Alberta, Society of Exploration Geophysicists, Canadian Society of Exploration Geophysicists,
American Association of Petroleum Geologists and the Canadian Society of Petroleum Geologists.



Independence and Qualifications of
Reserve Preparer: For the year ended August 31, 2013 the Company recorded an impairment loss of its full carrying costs of
$168,954 on its Botha, Alberta property as a result of no recordable reserves and no discernable future net revenue being assigned.
During the year ended August 31, 2013, the producing wells in the Botha property were shut in and the operator did not intend
on reactivating or remediating the wells. At August 31, 2013, our developed properties include a 5.1975% working interest in a
natural gas unit located in the Botha area Northwest, Alberta near the town of Manning, Canada held through our wholly owned subsidiary
1354166 Alberta which is carried on the consolidated statement of financial position at nil. As we had no recordable reserves
or discernable future net revenue at August 31, 2014 and 2013, we did not retain an independent reserves evaluator.



We engaged Sproule Associates Limited
(“Sproule”), third-party reserve engineers, to prepare our reserve estimates as of the effective date August 31, 2012
completed on October 11, 2012, in accordance with reserves definitions, standards and procedures contained in the Canadian Oil
and Gas Evaluation Handbook (COGE), the Canadian Securities Administrators National Instrument 51-101 (NI 51-101) using Forecast
Pricing Assumptions and, for the Securities and Exchange Commission, using Constant Pricing Assumptions. The technical person
responsible for our reserve estimates at Sproule meets the requirements regarding qualifications, independence, objectivity and
confidentiality set forth by The Association of Professional Engineers, Geologists and Geophysicists of Alberta (APEGGA). Sproule
is an independent firm of petroleum engineers, geologists, geophysicists and petrophysicists; they do not own any interest in
our properties and are not employed on a contingent fee basis.



Year-end reserves quantities for the years ended August 31,
2012 shown in the following Constant Prices and Cost tables were calculated using the unweighted arithmetic average of the first-day-of-the-month
price for each month within the 12 month period prior to the end of the reporting period.



Appropriate adjustments have been made
to account for quality and transportation, to the constant natural gas prices, and to the constant natural gas by-products prices
to reflect historical prices received for each area.  It should not be assumed that the discounted net present value
estimated by Sproule represents the fair market value of the reserves. Where the present value is based on constant price and
cost assumptions, there is no assurance that such price and cost assumptions will be attained and variances could be material.



The table below sets out in CDN dollars
the constant prices and the exchange rate used at August 31, 2014, 2013 and 2012. As of August 31, 2012 all of our reserves were
located in Alberta, Canada.



|August 31, 2014 |  | Natural Gas Alberta AECO-C
        Exchange Rate: |  | N/A
        N/A
|--------------- |  | ------------------------------------------------- |  | ---------------



|August 31, 2013 |  | Natural Gas Alberta AECO-C
        Exchange Rate: |  | N/A
        N/A                   
|--------------- |  | ------------------------------------------------- |  | ----------------------------------
|                |  |                                                   |  |                                   
|August 31, 2012 |  | Natural Gas Alberta AECO-C
        Exchange Rate: |  | $2.57/MMbtu
        0.99 $US/$ CDN



20







Proved and Probable Reserve Quantity
Estimates:   The following table reflects estimates of our proved and probable developed reserves as at August 31,
2014, 2013 and 2012 stated in CDN dollars.   All of our gas reserves were located in Canada. The following table
represents our gross and net interest in reserves (after crown royalties, freehold royalties and overriding royalties and interests
owned by others). Numbers may not add due to rounding.



|Summary of Oil and Gas Reserves Constant Prices and Costs
|---------------------------------------------------------
|Remaining Reserves                                       
|                                                         
|Reserves Category                                        
|August 31, 2014                                          
|Proved Developed Producing                               
|Probable Developed Producing                             
|Total Proved Plus Probable                               
|August 31, 2013                                          
|Proved Developed Producing                               
|Probable Developed Producing                             
|Total Proved Plus Probable                               
|August 31, 2012                                          
|Proved Developed Producing                               
|Probable Developed Producing                             
|Total Proved Plus Probable                               



The following table represents the summary
of our Net Revenue based on Constant Prices and costs before income taxes. Numbers may not add due to rounding.



|Summary of Net Revenue Constant Prices and Costs (Undiscounted)
|---------------------------------------------------------------
|Reserves Category                                              
|August 31, 2014                                                
|Proved Developed Producing                                     
|Probable Developed Producing                                   
|Total Proved Plus Probable                                     
|August 31, 2013                                                
|Proved Developed Producing                                     
|Probable Developed Producing                                   
|Total Proved Plus Probable                                     
|August 31, 2012                                                
|Proved Developed Producing                                     
|Probable Developed Producing                                   
|Total Proved Plus Probable                                     



The following table represents the summary
of our net present value of Future Net Revenue based on Constant Prices and costs before income taxes and discounted as follows.
Numbers may not add due to rounding.



21







|Summary of Net Present Values of Future Net Revenue Constant Prices and Costs
|-----------------------------------------------------------------------------
|                                                                             
|                                                                             
|Reserves Category                                                            
|August 31, 2014                                                              
|Proved Developed Producing                                                   
|Probable Developed Producing                                                 
|Total Proved Plus Probable                                                   
|August 31, 2013                                                              
|Proved Developed Producing                                                   
|Probable Developed Producing                                                 
|Total Proved Plus Probable                                                   
|August 31, 2012                                                              
|Proved Developed Producing                                                   
|Probable Developed Producing                                                 
|Total Proved Plus Probable                                                   



Production Volume:   The
following table sets forth the net quantities of natural gas produced during the fiscal years ended August 31, 2014, 2013 and
2012.



|August 31,         |  | 2014 |        |  | 2013 |  |        | 2012 | 
|------------------ |  | ---- | ------ |  | ---- |  | ------ | ---- | 
|                   |  |      |        |  |      |  |        |      | 
|Natural Gas  (Mcf) |  |      | 19,244 |  |      |  | 13,431 |      | 



Historical Production:   The
following table sets out our net share of production, average sales prices, average royalties, production costs and average net
back per unit of production for the fiscal years ended August 31, 2014, 2013 and 2012.



|                          |  | For the Years Ended |     
|------------------------- |  | ------------------- | ----
|Historical Production     |  | August 31, 2014     |     
|Natural Gas – Mcf/d       |  |                     | 53  
|Natural Gas Prices- $/Mcf |  | $                   | 4.34
|Royalty Costs - $/Mcf     |  |                     | 0.96
|Production Costs - $/Mcf  |  |                     | 0.89
|Net Back - $/Mcf          |  | $                   | 2.49



Producing and Non-Producing Wells:  The following table sets out the number of gross and net producing oil and natural gas wells and the number of
gross and net non-producing oil and natural gas wells that we have an interest in by location at August 31, 2014, 2013 and 201.
A gross well is a well in which we own an interest.  A net well represents the fractional interest we own in gross wells.



|August 31                       |  | 2014  |     |  | 2013 |  |        | 2012  | 
|------------------------------- |  | ----- | --- |  | ---- |  | ------ | ----- | 
|Alberta, Canada                 |  | Gross |     |  | Net  |  |        | Gross | 
|Natural Gas Wells-Producing     |  |       | 3.0 |  |      |  | .05175 |       | 
|Natural Gas Wells-Non Producing |  |       | 9.0 |  |      |  | .05175 |       | 
|Texas, USA                      |  |       |     |  |      |  |        |       | 
|Oil Wells – Non Producing       |  |       | 3.0 |  |      |  | .4444  |       | 



The following table sets forth the developed
and undeveloped acreage of the projects in which the Company holds an interest, on a gross and a net basis as of August 31, 2014,
2013 and 2012. The developed acreage is stated on the basis of spacing units designated by provincial authorities and typically
on the basis of 160 acre spacing unit for oil production and 640 acre spacing unit for gas production in Alberta and on the basis
of stated lease terms in conjunction with the Texas Rail Road Commission.  Our developed acreage is located in Alberta,
Canada. Our undeveloped acreage is located in Zavala County, Texas.



|August 31,                |  | 2014  |       |  | 2013 |  |         | 2012  | 
|------------------------- |  | ----- | ----- |  | ---- |  | ------- | ----- | 
|                          |  | Gross |       |  | Net  |  |         | Gross | 
|Developed Acreage, Canada |  |       | 8,320 |  |      |  | 432     |       | 
|Undeveloped Acreage, USA  |  |       | 2,629 |  |      |  | 1,314.5 |       | 



22







Additional Information Concerning Abandonment
and Reclamation Costs:   We base our estimates for costs of abandonment and reclamation of surface leases and wells
on previous experience with similar well site locations and terrain, estimates obtained from area operators and various regulatory
abandonment guidelines and requirements.



We believe that our range of estimates
for abandonment and reclamation costs are reasonable and applicable to our wells.   Ultimately all wells in which the
Company has an interest will require abandonment and reclamation.



The Company’s abandonment and reclamation
obligations result from its ownership interests in petroleum and natural gas assets including well sites, gathering systems and
processing facilities. The Company has estimated the net present value of these obligations to be $47,543 at August 31, 2014 based
on an undiscounted total future liability of $60,629. These payments are expected to be incurred between fiscal 2016 and 2031.



Capitalized Costs related to oil and
gas activities:The following table summarizes the costs incurred in our oil and gas interests for acquisition, exploration,
and development activities for the three years ended August 31, 2014, 2013 and 2012.



|Property, Plant and Equipment                  |  | 2014 |            |   | 2013 |   |            | 2012 | 
|---------------------------------------------- |  | ---- | ---------- | - | ---- | - | ---------- | ---- | 
|Net book value at September 1                  |  | $    | -          |   |      | $ | 175,000    |      | 
|Depletion                                      |  |      | -          |   |      |   | (10,212    | )    | 
|Change in decommissioning obligation estimates |  |      | -          |   |      |   | (4,166     | )    | 
|Impairment                                     |  |      | -          |   |      |   | (168,954   | )    | 
|Total Property, Plant and Equipment            |  |      | -          |   |      |   | -          |      | 
|Exploration and Evaluation Assets              |  |      |            |   |      |   |            |      | 
|Net book value at September 1                  |  | $    | 6,535,278  |   |      |   | 8,475,487  |      | 
|Additions, net                                 |  |      | 113,578    |   |      |   | 404,818    |      | 
|Change in decommissioning obligation estimates |  |      | 7,225      |   |      |   | (9,268     | )    | 
|Impairment of Murphy Lease                     |  |      | (1,675,749 | ) |      |   | (2,690,568 | )    | 
|Foreign Exchange                               |  |      | 82,686     |   |      |   | 354,809    |      | 
|Decommissioning obligations (disposal)         |  |      | (26,426    | ) |      |   | -          |      | 
|Units cancelled                                |  |      | -          |   |      |   | -          |      | 
|Total Exploration and Evaluation Assets        |  |      | 5,036,592  |   |      |   | 6,535,278  |      | 
|Total Capitalized                              |  | $    | 5,036,592  |   |      | $ | 6,535,278  |      | 



The Company’s exploration and evaluation
assets are located in Texas, USA. As at August 31, 2014 an impairment of $1,675,749 was recorded on the Murphy Lease ($1,315,276
net of foreign currency translation gain of $301,884 and write off of decommissioning obligations of $58,589) (August 31, 2013:
$2,690,568). Included in the above additions for the year ended August 31, 2014, the Company capitalized borrowing costs interest
of $Nil to exploration and evaluation assets (August 31, 2013: $240,092).



Matthews Lease, Zavala County, Texas

During the year ended August 31, 2013,
the Company, Dyami Energy and OGR Energy Corporation, the Lessees, were litigating a dispute with the Lessors of the Matthew’s
property. During the last quarter of fiscal year August 2013, the Company and the Lessors agreed to resolve the litigation and
continue with the development of the Matthew’s property. In order to comply with certain State legal requirements, it was
deemed necessary by the Lessors counsel to continue with the development through a newly executed lease document and the Company
formed, Eagleford Zavala a new wholly owned subsidiary to execute the new lease. The new lease was signed effective September
1, 2013 and the first of two payments of US$150,000 were paid to the Lessors upon signing the new lease as required initial pre-payment
of anticipated production royalties along with a continuing development obligation under the lease to complete the previously
drilled Matthews #1-H horizontal well or drill a new well on the Matthews property no later than March 30, 2014. On September
1, 2013, the Matthews lease was renewed by the Company through Eagleford Zavala and based on the concept of faithful representation
under IAS 8, the carrying value of the Matthew’s lease by Dyami Energy was considered to be the value for Eagleford Zavala
as this arrangement is simply a reorganization in substance.



On December 3, 2013, (amended January
21, 2014) the Company entered into a Joint Development Agreement with Stratex Oil and Gas Holdings, Inc. (“Stratex”)
(the “Stratex JDA”) to further develop the Matthews Lease. Under the terms of the Stratex JDA, Stratex will act as
operator and upon Stratex delivering i) US$150,000 to the lessors of the Matthews Lease on behalf of Zavala Inc., ii) delivering
US $150,000 to the Company; and iii) commencing a hydraulic fracture of the Matthews #1H not later than March 31, 2014. Stratex
earned a 66.67% working interest before payout (50% working interest after payout) in the Matthews #1H well and a 50% working
interest in the 2,629 acre Matthews Lease (see Note 17 to the Consolidated Financial Statements ).



23







Through Zavala Inc., the Company holds
a 50% working interest in the 2,629 acre Matthews Lease (33.33% working interest before payout and 50% working interest after
payout in the Matthews #1H well). The Matthews Lease had a primary term extended to March 31, 2014 (the “Primary Term”)
while each lease year ends August 31. Prior to the expiration of the Primary Term, a hydraulic fracturing of the Matthews #1H
well was completed and thereafter the lease is maintained through a guaranteed minimum royalty payment of $323.30 per acre and
beginning in the second lease year and continuing thereafter for each succeeding lease year drill at least 2 wells per lease year.
The royalties payable under the Matthews Lease are 25%.



On April 11, 2014, the Company entered
into a further Joint Development Agreement (“JDA2”) with Stratex and Quadrant Resources LLC, (“Quadrant”)
for the development of the San Miguel formation on the Matthews Lease.  Pursuant to the terms of the JDA2, upon satisfaction
of certain conditions including the Phase 1 Work Program and the cash consideration described below, Quadrant can earn an undivided
66.67% before payout and a 50% working interest after payout to the base of the San Miguel formation of the Matthews Lease by
i) drilling 3 new wells and reworking 5 wells at its sole cost and expense by June 30, 2015 (the “Phase I Work Program”);
ii) deliver US$100,000 to the Company upon execution of the JDA2 (paid); and iii) deliver US$65,000 to the Company on each of
July 8, 2014 (paid); October 6, 2014, January 5, 2015 and April 6, 2015. At August 31, 2014 the Company recorded the payments
received from Quadrant of US$165,000 (CDN $177,804) as deferred revenue on the Consolidated Statement of Financial Position until
the conveyance of the earned interest at which time this amount will be reclassified and offset against exploration and evaluation
assets.



Murphy Lease, Zavala County, Texas

Subsequent to September 1, 2013 and the
continuing development of the Matthews lease, Dyami Energy continued its development efforts with the Murphy lease. A tentative
joint venture agreement with Stratex was reached but did not materialize and efforts to develop the Murphy lease were not successful.
The Company had solicited lenders and investors in an attempt to obtain debt/equity financings as a means to improve Dyami Energy’s
financial situation. Despite the Company’s attempts, these efforts were unsuccessful and management determined that it could
no longer fund the Murphy operations, hence the lease was considered impaired and an impairment loss was recorded by Dyami Energy
during the third quarter (see Note 16 to the Consolidated Financial Statements).



On March 6, 2014, the Company filed a
Certificate of Termination of a Domestic Entity with the Secretary of State, Texas for its wholly-owned subsidiary Dyami Energy
and effective April 3, 2014, Dyami Energy was dissolved. All prior obligations with respect to the Matthew’s and Murhpy’s
lease on the books of Dyami Energy prior to its dissolution were recorded by the Company.



Present Activities, Results of Exploration
and Drilling:    During the fiscal year ended August 31, 2014, we drilled no exploratory wells on our lease located
in Zavala County, Texas USA. The Company, through Stratex completed the Matthews #1H well and placed the well on production testing.
Through Zavala Inc. we hold a 33.33% working interest before payout and 50% working interest after payout in the Matthews #1H
well.



The following table sets forth the number
of Eagleford’s gross and net exploratory wells drilled in Texas, USA during the years ended August 31, 2014, 2013 and 2012.  A
gross well is a well in which the Company owns an interest.  A net well represents the fractional interest the Company
owns in gross wells



|August 31,                |  | 2014  |   |  | 2013 |  |   | 2012  | 
|------------------------- |  | ----- | - |  | ---- |  | - | ----- | 
|Texas, USA                |  | Gross |   |  | Net  |  |   | Gross | 
|Oil Wells – Non Producing |  |       | - |  |      |  | - |       | 



Governmental Regulation/Environmental
Issues:   Our oil and gas operations are subject to various Canadian and US governmental regulations. Matters subject
to regulation include discharge permits for drilling operations, drilling and abandonment bonds, reports concerning operations,
the spacing of wells, and pooling of properties and taxation. From time to time, regulatory agencies have imposed price controls
and limitations on production by restricting the rate of flow of oil and gas wells below actual production capacity in order to
conserve supplies of oil and gas. The production, handling, storage, transportation and disposal of oil and gas, by-products thereof,
and other substances and materials produced or used in connection with oil and gas operations are also subject to regulation under
federal, state, provincial and local laws and regulations relating primarily to the protection of human health and the environment.
To date, expenditures related to complying with these laws, and for remediation of existing environmental contamination, have
not been significant in relation to the results of operations of our company. The requirements imposed by such laws and regulations
are frequently changed and subject to interpretation, and we are unable to predict the ultimate cost of compliance with these
requirements or their effect on our operations  (See, Item 3.D Key Information - Risk Factors).



24







|ITEM 4A | UNRESOLVED STAFF COMMENTS
|------- | -------------------------



Not Applicable



|ITEM 5 | OPERATING AND FINANCIAL REVIEW AND PROSPECTS
|------ | --------------------------------------------



The following discussion should be
read in conjunction with our “Selected Financial Data” under Item 3 above, our Audited Consolidated Financial Statements
for the fiscal years ended August 31, 2014 and 2013 and notes thereto included under Item 18. We adopted IFRS in accordance with
IFRS 1 First-time Adoption of International Financial Reporting Standards (“IFRS 1”) with a transition date of September
1, 2010.



Non-IFRS Measurements –Certain
measures in this Discussion and Analysis do not have any standardized meaning as prescribed by IFRS including "Operating
net back" are considered Non-IFRS measures. Therefore, these measures may not be comparable to similar measures presented
by other issuers. These measures are common with the oil and gas industry and have been described and presented in this Management’s
Discussion and Analysis in order to provide shareholders and potential investors with additional information regarding the company's
liquidity and its ability to generate funds to finance its operations. These terms are commonly used in the oil and gas industry
and are therefore presented here to provide balances comparable to other oil and gas production companies.



Certain statements made in this Item
are forward-looking statements under the Reform Act.  Forward- looking statements are based on current expectations
that involve a numbers of risks and uncertainties, which could cause actual events or results to differ materially from those
reflected herein. See, Item 3.D Key Information - Risk Factors for discussion of important factors, which could cause results
to differ materially from the forward-looking statements below.



Overview

Eagleford Energy Corp. (“Eagleford”
or the “Company”) is amalgamated under the laws of the Province of Ontario. The Company's business focus consists
of acquiring, exploring and developing oil and gas interests. The recoverability of the amount shown for these properties is dependent
upon the existence of economically recoverable reserves, the ability of the Company to obtain the necessary financing to complete
exploration and development, and future profitable production or proceeds from disposition of such property.The Company’s
oil and gas interests are locatedin Alberta, Canada and Zavala County, Texas. In addition the Company holds a 0.3% net
smelter return royalty on 8 mining claim blocks located in Red Lake, Ontario which is carried on the consolidated balance sheets
at $Nil. The Company filed Articles of Amendment effective August 25, 2014 consolidating its common shares on the basis of one
(1) common share for every ten (10) common shares and changed its name to Eagleford Energy Corp. The address of the registered
office is 1 King Street West, Suite 1505, Toronto, Ontario, M5H 1A1. Eagleford’s common shares trade on the Over-the-Counter
Bulletin Board (OTCQB) under the symbol EGFDF.



The Company’s Consolidated Financial
Statements for the year ended August 31, 2014 and 2013 include the accounts of Eagleford, the legal parent, together with its
wholly-owned subsidiaries, 1354166 Alberta Ltd. an Alberta operating company (“1354166 Alberta”) and Eagleford Energy,
Zavala Inc. a Nevada company (“Zavala Inc.”) effective August 29, 2013. All Intercompany balances and transactions
have been eliminated on consolidation. On March 6, 2014, the Company filed a Certificate of Termination of a Domestic Entity with
the Secretary of State, Texas for its wholly-owned subsidiary Dyami Energy and Dyami Energy was dissolved effective April 3, 2014.
The Company’s investment in Dyami Energy has been deconsolidated from the Company’s Consolidated Financial Statements
as at the effective date, and presented on the Consolidated Statements of Operations and Comprehensive Loss and the Consolidated
Statements of Cash Flows as an impairment of the net assets and liabilities on dissolution of subsidiary (see Note 16 to the Consolidated
Financial Statements).



25







Capital Management



The Company’s objectives when managing
capital are to ensure the Company will have sufficient financial capacity, liquidity and flexibility to funds its operations,
growth and ongoing exploration and development commitments on its oil and gas interests. The Company is dependent on funding these
activities through debt and equity financings and joint venture arrangements. Due to long lead cycles of the Company’s exploration
and development activities, the Company’s capital requirements currently exceed its operational cash flow generated. As
such the Company is dependent upon future financings in order to maintain its flexibility and liquidity and may from time to time
be required to issue equity, issue debt, adjust capital spending or obtain additional farm-in arrangements.



The Company manages the capital structure
and makes adjustments to it in light of changes in economic conditions, availability of capital and the risk characteristics of
any underlying assets in order to meet current and upcoming obligations. Current plans for the development commitments of the
Company’s Texas lease include seeking debt or equity financing or seeking additional farm-in arrangements.



The board of directors does not establish
quantitative return on capital criteria for management, but rather relies on the expertise of the Company's management and favorable
market conditions to sustain future development of the business. As at August 31, 2014 and August 31, 2013 and the Company considered
its capital structure to comprise of shareholders equity and long-term debt.



Management reviews its capital management
approach on an ongoing basis and believes that this approach, given the relative size of the Company, is reasonable. There were
no changes in the Company’s capital management plan during the period ended August 31, 2014. The Company is not subject
to any externally imposed restrictions on its capital requirements.



The board of directors does not establish
quantitative return on capital criteria for management, but rather relies on the expertise of the Company's management and favorable
market conditions and opportunities to sustain future development of the business.



Management reviews its capital management
approach on an ongoing basis and believes that this approach, given the relative size of the Company, is reasonable.



SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
AND FUTURE ACCOUNTING PRONOUNCEMENTS



Our consolidated financial statements
for the years ended August 31, 2014 and 2013 have been prepared in accordance with International Financial Reporting Standards
(“IFRS”), as issued by the International Accounting Standards Board (“IASB”) (See Item 18– Financial
Statements). We adopted IFRS in accordance with IFRS 1 First-time Adoption of International Financial Reporting Standards
(“IFRS 1”) with a transition date of September 1, 2010.



Going Concern

The consolidated financial statements
(the “Financial Statements”) have been prepared in accordance with International Financial Reporting Standards (“IFRS”)
applicable to a going concern, which contemplates the realization of assets and settlement of liabilities in the normal course
of business, as they come due for the foreseeable future. The Company is in the process of exploring and developing its oil and
gas properties and has not yet realized profitable operations. The Company requires additional financing for its working capital
and for the costs of exploration and development of its oil and gas properties.



Due to continuing operating losses, the
Company's continuance as a going concern is dependent upon its ability to obtain adequate financing and to reach profitable levels
of operation. The Company will continue to seek additional forms of debt or equity financing, or other means of funding its operations,
however, there is no assurance that it will be successful in doing so or that funds will be available on terms acceptable to the
Company or at all. The ability of the Company to arrange such financing in the future will depend in part upon the prevailing
capital market conditions as well as the business performance of the Company.



26







The Company has accumulated significant
losses and negative cash flows from operations in recent years which raise doubt as to the validity of the going concern assumption.
The Company has a working capital deficiency of $3,489,237 (2013: $4,985,312) and an accumulated deficit of $15,328,146 (2013:
$9,212,561). These material uncertainties may cast significant doubt upon the entity’s ability to continue as a going concern.
Accordingly, the consolidated financial statements do not give effect to adjustments, if any that would be necessary should the
Company be unable to continue as a going concern and, therefore, be required to realize its assets and liquidate its liabilities
in other than the normal course of business and at amounts that may differ from those shown in the accompanying consolidated financial
statements.



During the year, the Company entered into
two separate Joint Development Agreements on the Matthews Lease and received cash of $340,811 and the payment of certain obligations
under the Matthews Lease. The Company extinguished debt of $1,408,737 (2013: $544,239) through the issuance of share capital.



BASIS OF PREPARATION



Statement of Compliance

These consolidated financial statements
have been prepared in accordance with International Financial Reporting Standards (“IFRS”) as issued by the International
Accounting Standards Board (“IASB”).



These consolidated financial statements
of the Company were approved by the Board of Directors on December 26, 2014.



Basis of Preparation

These consolidated financial statements
have been prepared in accordance with IFRS as issued by the International Accounting Standards Board (the “IASB”)
which is incorporated in the Chartered Professional Accountants of Canada (“CPA Canada”) Handbook-Accounting.



The accounting policies applied in these
consolidated financial statements are based on IFRS effective for the period ended August 31, 2014, as issued and outstanding
as of the date the Board of Directors approved the consolidated financial statements.



Principles of Consolidation

Subsidiaries are all entities controlled
by the Company. Control exists when the Company is exposed to, or has rights to variable returns from its involvement with the
entity and has the ability to affect these returns through its power over the entity. The financial statements of the subsidiaries
are included in the consolidated financial statements from the date that control commences until the date that control ceases.
Intercompany balances and transactions, and any unrealized income and expenses arising from intercompany transactions, are eliminated
in preparing the consolidated financial statements.



The consolidated financial statements
include the accounts of Eagleford, the legal parent, together with its wholly-owned subsidiaries, 1354166 Alberta Ltd. a company
operating in the province of Alberta, Canada (“1354166 Alberta”), Eagleford Energy, Zavala Inc. a Nevada company (“Zavala
Inc.”) effective August 29, 2013 and Dyami Energy Inc. (“Dyami”) which was dissolved effective April 3, 2014
by filing a Certificate of Termination of a Domestic Entity with the Secretary of State, Texas (see Note 16 to the consolidated
financial statements).



SUMMARY
OF SIGNIFICANT ACCOUNTING POLICIES



The accounting policies set out below
have been applied consistently to all years presented in these consolidated financial statements and have been applied consistently
by the Company and its subsidiaries.



Revenue Recognition

Revenues from the production of oil and
gas properties from 1354166 Alberta are recognized, on the basis of the Company’s working interest in those properties,
when the significant risks and rewards of ownership of the product is transferred to the buyer, which is usually when legal title
passes to an external party. During the fiscal year ended August 31, 2012, the wells were shut in and the asset was considered
impaired and the property was written off but the Company is still receiving its share of gas revenue from the operator. Revenue
is measured net of royalties and other duties.



27







Foreign Currencies

The functional and presentation currency
of the Company is the Canadian dollar. The functional currency of the Company’s wholly-owned Alberta subsidiary, 1354166
Alberta is Canadian dollars and the functional currency of the Company’s wholly-owned Nevada subsidiary, Zavala Inc. is
United States dollars and the Company’s former wholly-owned Texas subsidiary, Dyami Energy was United States dollars.



Items included in the consolidated financial
statements of each entity are measured using the currency of the primary economic environment in which the entity operates (the
"functional currency"). Foreign currency transactions are translated into the functional currency using the exchange
rates prevailing at the dates of the transaction. Foreign exchange gains and losses resulting from the settlement of such transactions
and from the translation of monetary assets and liabilities not denominated in the functional currency of an entity are recognized
in the consolidated statements of operations.



Assets and liabilities of entities with
functional currencies other than Canadian dollars are translated at the year- end rates of exchange, and the results of their
operations are translated at average rates of exchange for the period. The resulting translation adjustments are included in the
foreign currency translation reserve under the equity section of the consolidated statement of financial position.



Loss per Share

The basic loss per share is calculated
by dividing net loss by the weighted average number of common shares outstanding during the period. The diluted loss per share
reflects the dilution that would occur if outstanding stock options and share purchase warrants were exercised or converted into
common shares using the treasury stock method and are calculated by dividing net loss applicable to common shares by the sum of
the weighted average number of common shares outstanding and all additional common shares that would have been outstanding if
potentially dilutive common shares had been issued.



The inclusion of the Company’s stock
options and share purchase warrants in the computation of diluted loss per share would have an anti-dilutive effect on loss per
share and are therefore excluded from the computation.



Financial Instruments

Classification and Measurement

Financial instruments are measured at
fair value on initial recognition of the instrument. Measurement in subsequent periods depends on whether the financial instrument
has been classified as “fair value through profit and loss”, “loans and receivables”, “available-for-sale”,
“held-to-maturity”, or “other financial liability” as defined by IAS 39, “Financial Instruments:
Recognition and Measurement”.



Financial assets and financial liabilities
at “fair value through profit or loss” are either classified as “held for trading” or “designated
at fair value through profit or loss” and are measured at fair value with changes in fair value recognized in the statement
of comprehensive income. Transaction costs are expensed when incurred. The Company has classified cash, marketable securities
and derivative liabilities as “fair value through profit and loss”.



Financial instruments classified as “loans
and receivables”, “held-to-maturity”, or “financial liabilities” are measured at amortized cost
using the effective interest method of amortization. “Loans and receivables” are non-derivative financial assets with
fixed or determinable payments that are not quoted in an active market. “Held-to-maturity” financial assets are non-derivative
investments that an entity has the positive intention and ability to hold to maturity.



“Other financial liabilities measured
at amortized cost” are those financial liabilities that are not designated as “fair value through profit or loss”
and that are not derivatives. The Company has classified trade and other receivables as “loans and receivables” and
trade and other payables, secured note payable, provisions and shareholders’ loans as “other financial liabilities”.



Financial assets classified as “available-for-sale”
are measured at fair value, with changes in fair value recognized in other comprehensive income. Available-for-sale financial
assets are non-derivatives that are either designated in this category or not classified in any of the other categories. The Company
currently has no assets classified as “available for sale”.



Derivative Financial Instruments

The Company’s derivative instruments
consist of derivative liabilities in relation to its i) share purchase warrants; and ii) its secured convertible note payable.



28







In prior years the Company had issued
share purchase warrants in conjunction with offerings for the purchase of common shares of the Company. These share purchase warrants
were issued with an exercise price in US dollars, rather than Canadian dollars (the presentation and functional currency of the
Company). Such share purchase warrants are considered to be derivative instruments and the Company is required to re-measure the
fair value of these at each reporting date. The fair value of these share purchase warrants are re-measured at each statement
of financial position date using the Black-Scholes option pricing model. Adjustments to the fair value of the share purchase warrants
at the financial position date are recorded to the statement of operations.



The Company’s secured convertible
note payable has a conversion feature which may convert any unpaid principal and accrued interest into conversion units. A conversion
unit is comprised of one (1) common share and one (1) common share purchase warrant entitling the holder to acquire a common share
of the Company at a price equal to a 15% premium to the price of the common share acquired under the conversion unit. The price
of the conversion unit is the lessor of a price equal to the 30-day rolling weighted average price of the Company as of the date
of conversion, less 20% (as adjusted for any stock splits, combinations or similar events) or eight United States Cents (US$0.08)
per share the “Conversion Unit”). The terms and features of the conversion meets the definition of an embedded derivative.
Since both components of the Conversion Unit (the common share component and warrant component) contain a variable exercise/conversion
price, the Conversion Unit meets the definition of a financial liability under IAS 32“Financial Instruments: Presentation”.
As a result, the Conversion Unit is a derivative liability that requires fair value measurement each period. The Company has selected
the Binomial Lattice model to fair value the warrant component of the conversion unit and the Monte Carlo Simulations process
for the common share component of the conversion unit (see Note 11).



Property and Equipment and Exploration
and Evaluation Assets



Exploration and Evaluation Assets (“E&E”)

Pre-acquisition expenditures on oil and
gas assets are recognized as an expense in the consolidated statements of operations when incurred. In accordance with IFRS 6,
exploration and evaluation costs are capitalized within intangible assets until the success or otherwise of the well or project
has been established and subject to an impairment review. The costs of unsuccessful wells in an area are written off to the statement
of operations.



Exploration and evaluation costs, including
the costs of acquiring licenses and directly attributable general and administrative costs, initially are capitalized either as
tangible or intangible E&E assets according to the nature of the assets acquired. The costs are accumulated in cost centers
by well, field or exploration area pending determination of technical feasibility and commercial viability.



When E&E assets are determined to
be technically feasible and commercially viable, the accumulated costs are transferred to property and equipment. When E&E
assets are determined not to be technically feasible and commercially viable or the Company decides not to continue with its activity,
the unrecoverable costs are charged to the statement of operations as exploration and evaluation expense.



E&E assets are assessed for impairment
in any circumstances where sufficient data exists to determine technical feasibility and commercial viability, and facts and circumstances
suggest that the carrying amount exceeds the recoverable amount. For purposes of impairment testing, E&E assets are allocated
to cash-generating units (“CGUs”).



Development and Production Costs

Items of property and equipment, which
include petroleum and natural gas development and production assets, are measured at cost less accumulated depletion and depreciation
and accumulated impairment losses. Development and production assets are grouped into CGUs for impairment testing.



When significant parts of an item of property
and equipment, including petroleum and natural gas interests, have different useful lives, they are accounted for as separate
items (major components).



Gains and losses on disposal of an item
of property and equipment, including petroleum and natural gas interests, are determined by comparing the proceeds from disposal
with the carrying amount of property and equipment and are recognized in profit or loss.



29







Subsequent Costs



Costs incurred subsequent to the determination
of technical feasibility and commercial viability and the costs of replacing parts of property and equipment are recognized as
exploration and evaluation assets only when they increase the future economic benefits embodied in the specific asset to which
they relate. All other expenditures are recognized in profit or loss as incurred. Such capitalized exploration and evaluation
assets generally represent costs incurred in developing proved and/or probable reserves and bringing in or enhancing production
from such reserves, and are accumulated on a field or geotechnical area basis. The carrying amount of any replaced or sold component
is derecognized. The costs of the day-to-day servicing of property and equipment are recognized in profit or loss as incurred.



Joint Oil and Gas Activities

All of the Company's oil and gas activities
are conducted jointly with others. The Company's accounts reflect only the Company's share of assets, liabilities, revenue and
expenses in the joint operations. For interests in joint operations, the Company’s share of the jointly controlled assets
are classified according to the nature of the assets, the Company’s share of any liabilities incurred jointly with the other
parties, and the Company’s share of any income and expenses incurred jointly with the partners are recognized in the consolidated
financial statements. The adoption of IFRS 11 did not change the definition of a joint arrangement/joint control and proportionate
share method previously adopted by the company.



Depletion and Depreciation

The net carrying value of development
or production assets is depleted using the units-of-production method by reference to the ratio of production in the period to
the related proved plus probable reserves, taking into account estimated future development costs necessary to bring those reserves
into production. Future development costs are estimated taking into account the level of development required to produce the reserves.
These estimates are reviewed by independent reserve engineers at least annually for developed properties.



Proved and probable reserves are estimated
using independent reserve engineer reports for developed properties only and represent the estimated quantities of crude oil,
natural gas and natural gas liquids which geological, geophysical and engineering data demonstrate with a specified degree of
certainty to be recoverable in future years from known reservoirs and which are considered commercially producible.



Reserves may be considered commercially
producible if management has the intention of developing and producing them and such intention is based upon:



| | • | a reasonable assessment of the
                                         future economic benefit of such production;
| | - | -------------------------------------------------------------------------------------------------------------------

| | • | a reasonable expectation that there
                                         is a market for all or substantially all the expected oil and natural gas production;
                                         and
| | - | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------

| | • | evidence that the necessary production,
                                         transmission and transportation facilities are available or can be made available.
| | - | -------------------------------------------------------------------------------------------------------------------------------------------------------------------



Reserves may only be considered proved
and probable if they are supported by either actual production or conclusive formation tests. The area of reservoir considered
proved includes: (a) that portion delineated by drilling and defined by gas-oil and/or oil-water contacts, if any, or both; and
(b) the immediately adjoining portions not yet drilled, but which can be reasonably judged as economically productive on the basis
of available geophysical, geological and engineering data. In the absence of information on fluid contacts, the lowest known structural
occurrence of oil and natural gas controls the lower proved limit of the reservoir.



Depreciation methods, useful lives and
residual values are reviewed at each reporting date.



Impairment

Financial Assets

A financial asset is assessed at each
reporting date to determine whether there is any objective evidence that it is impaired. A financial asset is considered to be
impaired if objective evidence indicates that one or more events have had a negative effect on the estimated future cash flows
of that asset.



An impairment loss in respect of a financial
asset measured at amortized cost is calculated as the difference between its carrying amount and the present value of the estimated
future cash flows discounted at the original effective interest rate.



30







Individually significant financial assets
are tested for impairment on an individual basis. Remaining financial assets are assessed collectively in groups that share similar
credit risk characteristics.



All impairment losses are recognized in
the profit or loss.



An impairment loss is reversed if the
reversal can be related objectively to an event occurring after the impairment loss was recognized. For financial assets measured
at amortized cost the reversal is recognized in profit or loss.



Non-financial Assets

The carrying amounts of the Company’s
non-financial assets, other than E&E assets are reviewed at each reporting date to determine whether there is any indication
of impairment. If any such indication exists, the asset’s recoverable amount is estimated. E&E assets are assessed for
impairment when they are reclassified to property and equipment as petroleum and natural gas interests, and also if facts and
circumstances suggest that their carrying amount exceeds the recoverable amount.



For the purpose of impairment testing,
assets are grouped together into the smallest group of assets that generate cash inflows from continuing use that are largely
independent of the cash inflows of other assets or groups of assets (the “cash-generating unit” or “CGU”).
The recoverable amount of an asset or a CGU is the greater of its value in use and its fair value less costs to sell.



In assessing value in use, the estimated
future cash flows are discounted to their present value using a pre-tax discount rate that reflects current market assessments
of the time value of money and the risks specific to the asset. Value in use is generally computed by reference to the present
value of the future cash flows expected to be derived from production of proved and probable reserves.



E&E assets are allocated to related
CGUs when they are assessed for impairment, both at the time of any triggering facts and circumstances as well as upon their eventual
reclassification to producing assets (petroleum and natural gas interests in property and equipment).



An impairment loss is recognized if the
carrying amount of an asset or its CGU exceeds its estimated recoverable amount. Impairment losses are recognized in profit or
loss. Impairment losses recognized in respect of CGUs are allocated first to reduce the carrying amount of any goodwill allocated
to the units and then to reduce the carrying amounts of the other assets in the unit (group of units) on a pro rata basis.



In respect of assets other than goodwill,
impairment losses recognized in prior years are assessed at each reporting date for any indications that the loss has decreased
or no longer exists. An impairment loss is reversed if there has been a change in the estimates used to determine the recoverable
amount. An impairment loss is reversed only to the extent that the asset’s carrying amount does not exceed the carrying
amount that would have been determined, net of depletion and depreciation or amortization, if no impairment loss had been recognized.



Provisions

A provision is recognized if, as a result
of a past event, the Company has a present legal or constructive obligation that can be estimated reliably, and it is probable
that an outflow of economic benefits will be required to settle the obligation.



Provisions are determined by discounting
the expected future cash flows at a pre-tax rate that reflects current market assessments of the time value of money and the risks
specific to the liability. Provisions are not recognized for future operating losses.



Decommissioning Obligations

The Company’s activities give rise
to dismantling, decommissioning and site disturbance remediation activities. Provision is made for the estimated cost of site
restoration and capitalized in the relevant asset category.



Decommissioning obligations are measured
at the present value of management’s best estimate of the expenditure required to settle the present obligation at the period-end
date. Subsequent to initial measurement, the obligation is adjusted at the end of each period to reflect the passage of time and
changes in the estimated future cash flows underlying the obligation. The increase in the provision due to the passage of time
is recognized as finance costs whereas increases/decreases due to changes in the estimated future cash flows and changes to discount
rate are capitalized. Actual costs incurred upon settlement of the decommissioning obligations are charged against the provision
to the extent the provision was established.



31







Borrowing Costs

Borrowing costs incurred for the construction
of qualifying assets are capitalized during the period of time that is required to complete and prepare the assets for their intended
use or sale. All other borrowing costs are recognized in profit or loss using the effective interest method. Interest income is
recognized as it accrues in profit or loss, using the effective interest method.



Taxes

Tax expense comprises current and deferred
tax. Tax is recognized in the consolidated statements of operations except to the extent it relates to items recognized in other
comprehensive income or directly in equity.



Current Income Tax

Current tax expense is based on the results
for the year as adjusted for items that are not taxable or not deductible. Current tax is calculated using tax rates and laws
that were enacted or substantively enacted at the end of the reporting period. Management periodically evaluates positions taken
in tax returns with respect to situations in which applicable tax regulation is subject to interpretation. Provisions are established
where appropriate on the basis of amounts expected to be paid to the tax authorities.



Deferred Tax

Deferred tax assets and liabilities are
recognized for the future income tax consequences attributable to differences between the financial statement carrying amounts
of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted
or substantively enacted tax rates expected to apply to taxable income in the years in which these temporary differences are expected
to be recovered or settled. Deferred tax assets and liabilities are offset if there is a legally enforceable right to offset current
tax liabilities and asset and they relate to the income taxes levied by the same authority on the same taxable entity, or on different
tax entities where these entities intend to settle current tax liabilities and asset on a net basis or their tax assets and liabilities
will be realized simultaneously.



Deferred tax assets and liabilities are
not recognized in respect of temporary differences that arise on initial recognition of assets and liabilities acquired other
than in a business combination.



Share-Based Compensation

The Company has a share-based compensation
plan that grants stock options to employees and non-employees. This plan is an equity settled plan. The Company uses the fair
value method for accounting for share-based awards to employees and non-employees.



The fair value determined at the grant
date of the equity-settled share-based payments is expensed on a straight-line basis over the vesting period, based on the Company’s
estimate of equity instruments that will eventually vest. At the end of each reporting period, the Company revises its estimate
of the number of equity instruments expected to vest. The impact of the revision of the original estimates, if any, is recognized
in profit or loss such that the cumulative expense reflects the revised estimate, with a corresponding adjustment to contributed
surplus.



Equity-settled share-based payment transactions
with parties other than employees are measured at the fair value of the goods or services received, except where that fair value
cannot be estimated reliably, in which case they are measured at the fair value of the equity instruments granted, measured at
the date the Company obtains the goods or the counterparty renders the service.



Warrants

When the Company issues units comprising
common shares and warrants, the Company follows the relative fair value method of accounting for warrants attached to and issued
with common shares of the Company. Under this method, the fair value of warrants issued is estimated using the Black-Scholes option
price model. The fair value is then related to the total of the net proceeds received on issuance of the common shares and the
fair value of the warrants issued therewith. The resultant relative fair value is allocated to warrants from the net proceeds
and the balance of the net proceeds is allocated to the common shares issued.



32







Critical Accounting Estimates and Judgments

The timely preparation of the consolidated
financial statements in accordance with IFRS requires that management make estimates and assumptions and use judgment regarding
the measured amounts of assets, liabilities and contingent liabilities at the date of the consolidated financial statements and
reported amounts of revenue and expenses during the reporting period. Such estimates and judgments are continuously evaluated
and are based on management’s experience and other factors, including expectations of future events that are believed to
be reasonable under the circumstances. Actual outcomes may differ from these estimates.



The key sources of estimation uncertainty
that have a significant risk of causing material adjustment to the amounts recognized in the consolidated financial statements
are:



Valuation and Classification of Exploration
and Evaluation Assets

The value of exploration and evaluation
assets are dependent upon the discovery of economically recoverable reserves which in turn is dependent on future oil and natural
gas prices, future capital expenditures and environmental and regulatory restrictions. The decision to transfer exploration and
evaluation assets to property and equipment is based upon management’s determination of an area’s technical feasibility
and commercial viability based on proved and/or probable reserve estimates.



Title to Oil and Gas Property Interests

Although the Company has taken steps to
verify title to oil and gas properties in which it has an interest, these procedures do not guarantee the Company’s title.
Such properties may be subject to prior agreements or transfers and title may be affected by undetected defects.



Stock Based Compensation

The Company measures the cost of equity-settled
transactions to the relative fair value of the equity instruments at the date at which they are issued. Estimating relative fair
value for share-based payment transactions requires determining the most appropriate valuation model, which is dependent on the
terms and conditions of the instrument. This estimate also requires determining and making assumptions about the most appropriate
inputs to the valuation model including the expected life, volatility, discount rates and dividend yield.



Decommissioning Liabilities

Decommissioning liabilities consist of
asset retirement obligations that are based, in part, on estimates of future costs to settle the obligation, in addition to estimates
of the useful life of the underlying assets, the rate of inflation and the risk-free discount rate.



Fair Value of Financial Instruments

The estimated fair value of financial
assets and liabilities, by their very nature, are subject to measurement uncertainty.



Assessment of Commercial Reserves

Management is required to assess the level
of the Company’s commercial reserves together with the future expenditures to access those reserves, which are utilized
in determining the depletion charge for the period, assessing whether any impairment charge is required against developed or undeveloped
properties, and the determination of the deferred tax liability. By their nature, these estimates of discovered proved and probable
crude oil and natural gas reserves, including the estimates of future prices, costs, related future cash flows and the selection
of a pre-tax risked discount rate relevant to the asset in question are subject to measurement uncertainty.



The Company employs an independent reserves
evaluator who periodically assesses the Company’s level of commercial reserves by reference to data sets including geological,
geophysical and engineering data together with reports, presentation and financial information pertaining to the contractual and
fiscal terms applicable to the Company’s assets. Significant judgment is involved when determining whether there have been
any significant changes in the Company’s reserves.



Income taxes

Income taxes liability is estimated for
the Company, including an assessment of temporary differences. Any temporary differences will generally result in the recognition
of deferred tax assets and liabilities in the financial statements. Management’s judgment is required in the calculation
of current and deferred taxes, as well as the likelihood of realization.



33







Provisions

Considerable judgment is used in measuring
and recognizing provisions and the exposure to contingent liabilities. Judgment is necessary to determine the likelihood that
a pending litigation or other claim will succeed, or a liability will arise and to quantify the possible range of the final settlement.



Significant changes in the assumptions,
including those with respect to future business plan and cash flows, could materially change the recorded carrying amounts.



RECENT ACCOUNTING PRONOUNCEMENTS AND
RECENT ADOPTED ACCOUNTING STANDARDS



Recent
Issued Accounting Pronouncements

The following standards, amendments and
interpretations, which may be relevant to the Company have been introduced or revised by the IASB:



(i) IFRIC 21 Levies. The Company intends
to adopt IFRIC 21 in its consolidated financial statements for the annual period beginning September 1, 2014. The Company does
not expect the amendments to have a material impact on the consolidated financial statements.



(ii) On July 24, 2014, the IASB issued
the complete IFRS 9 (IFRS 9 (2014). In November 2009, the IASB issued the first version of IFRS 9, Financial Instruments (IFRS
9 (2009) and subsequently issued various amendments in October 2010, (IFRS 9 Financial Instruments (2010) and November 2013 (IFRS
9 Financial Instruments (2013). The mandatory effective date of IFRS 9 is for annual periods beginning on or after January 1,
2018 and must be applied retrospectively with some exemptions. Early adoption is permitted. The restatement of prior periods is
not required and is only permitted if information is available without the use of hindsight. The Company does not intend to adopt
the new standard prior to its effective date and has not yet determined the impact of this new standard on the consolidated financial
statements.



Recent
Adopted Accounting Standards

The following standards, amendments and
interpretations have been adopted by the Company as of September 1, 2013. There were no material impacts on the consolidated financial
statements as a result of the adoption of these standards, amendments and interpretations: (i) IFRS 10 Consolidated Financial
Statements; (ii) IFRS 11 Joint Arrangements; (iii) IFRS 12 Disclosures of Interests in Other Entities; (iv) IFRS 13 Fair Value
Measurement; and (v) Amendments to IFRS 7 Financial Instrument Disclosures.



Segmented Information

The Company’s reportable and geographical
segments are Canada and the United States. The accounting policies used for the reportable segments are the same as the Company’s
accounting policies. For the purposes of monitoring segment performance and allocating resources between segments, the Company’s
executive officer monitors the tangible, intangible and financial assets attributable to each segment. All assets are allocated
to reportable segments. The following tables show information regarding the Company’s reportable segments.



|For the year ended August 31, 2014 |  | Canada |            |   | United States |   |            | Total | 
|---------------------------------- |  | ------ | ---------- | - | ------------- | - | ---------- | ----- | 
|Net revenue                        |  | $      | 65,024     |   |               |   | -          |       | 
|Net loss                           |  | $      | (4,683,624 | ) |               | $ | (1,431,961 | )     | 



|For the year ended August 31, 2013 |  | Canada |            |   | United States |   |            | Total | 
|---------------------------------- |  | ------ | ---------- | - | ------------- | - | ---------- | ----- | 
|Net revenue                        |  | $      | 30,062     |   |               |   | -          |       | 
|Net loss                           |  | $      | (1,431,363 | ) |               | $ | (2,834,683 | )     | 



|For the year ended August 31, 2012 |  | Canada |            |   | United States |   |          | Total | 
|---------------------------------- |  | ------ | ---------- | - | ------------- | - | -------- | ----- | 
|Net revenue                        |  | $      | 39,218     |   |               |   | -        |       | 
|Net loss                           |  | $      | (2,585,129 | ) |               | $ | (224,059 | )     | 



34







|As at August 31, 2014 |  | Canada |           |  | United States |   |           | Total | 
|--------------------- |  | ------ | --------- |  | ------------- | - | --------- | ----- | 
|Total Assets          |  | $      | 179,888   |  |               | $ | 5,117,040 |       | 
|Total Liabilities     |  | $      | 6,991,287 |  |               | $ | 1,025,076 |       | 



|As at August 31, 2013 |  | Canada |           |  | United States |   |           | Total | 
|--------------------- |  | ------ | --------- |  | ------------- | - | --------- | ----- | 
|Total Assets          |  | $      | 3,914,928 |  |               | $ | 3,003,268 |       | 
|Total Liabilities     |  | $      | 6,029,577 |  |               | $ | 746,475   |       | 



Other Information

Additional information relating to us
may be obtained or viewed from the System for Electronic Data Analysis and Retrieval at www.sedar.com and our future United States
Securities and Exchange Commission filings can be viewed through the Electronic Data Gathering Analysis and Retrieval System (EDGAR)
at www.sec.gov.



SHARE CAPITAL AND RESERVES



The Company filed Articles of Amendment
effective August 25, 2014 consolidating the common shares of Eagleford Energy Inc., on the basis of one (1) common share for every
ten (10) common shares and changing its name to Eagleford Energy Corp. The stock consolidation has been applied retrospectively
for all periods presented.



On March 16, 2012, the Company completed
a two (2) for one (1) stock split, pursuant to which one (1) newly-issued share of the Company’s common stock was issued
to each holder of a share of common stock as of the close of business. The forward stock split has been applied retrospectively
for all periods presented.



Share Capital



Authorized:

Unlimited number of common shares at no
par value

Unlimited non-participating, non-dividend
paying, voting redeemable preference shares



Issued:

The following table sets out the changes
in common shares during the respective periods:



|Common Shares                               |  | Number* |            |  | Amount |  
|------------------------------------------- |  | ------- | ---------- |  | ------ | -
|Balance August 31, 2012                     |  |         | 9,671,281  |  |        | $
|Private Placement of units (Note 8 (b) (a)) |  |         | 224,979    |  |        |  
|Debt settlement (Note 8 (b) (b))            |  |         | 2,366,257  |  |        |  
|Balance August 31, 2013                     |  |         | 12,262,517 |  |        |  
|Warrants exercised (Note 8 (b) (c))         |  |         | 651,904    |  |        |  
|Debt settlement (Note 8 (b) (e))            |  |         | 14,757,120 |  |        |  
|Balance August 31, 2014                     |  |         | 27,671,541 |  |        | $

* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



Share Purchase Warrants



The following table sets out the changes
in warrants during the respective periods:



|                                 |  | August 31, 2014     |            |   | August 31, 2013         |  
|-------------------------------- |  | ------------------- | ---------- | - | ----------------------- | -
|Warrants                         |  | Number of Warrants* |            |   | Weighted Average Price* |  
|Outstanding, beginning of period |  |                     | 4,020,095  |   |                         | $
|Warrants exercised (Note 8 (c))  |  |                     | (651,904   | ) |                         | $
|Warrants expired (Note 8 (d))    |  |                     | (1,453,191 | ) |                         | $
|Warrants issued (Note 8 (e))     |  |                     | 7,378,560  |   |                         | $
|Balance, end of period           |  |                     | 9,293,560  |   |                         | $

* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



35







(a)         On
September 25, 2012, the Company completed private placements for gross proceeds of $441,004 of equity capital from arm’s
length private placement funding through the issuance of 224,979 units at a price of US$2.00 per unit. Each unit was comprised
of one common share and one-half a common share purchase warrant, with each whole warrant entitling the holder to acquire one
common share of the Company at US$5.00 for a period of three years from the date of issuance. The amount allocated to derivative
warrant liabilities based on fair value using the Black-Scholes option pricing model was $163,541 (retranslated as $176,087 at
August 31, 2013). In connection with the private placement, the Company paid cash commissions and other expenses of $35,354 and
issued an aggregate of 17,998 broker warrants.  Each broker warrant entitles the holder to acquire one common share of the
Company at an exercise price of US$2.50 for a period of three years from the date of issuance. The amount allocated to derivative
liabilities based on fair value using the Black-Scholes option pricing model was $44,895 (retranslated as $48,340 at August 31,
2013) with a corresponding decrease in common shares (see Note 11).



(b)         On
June 1, 2013, the Company issued 2,366,257 common shares as full settlement of shareholders’ loans in the amount of $198,333
and interest due on shareholders’ loans in the amount of $345,906. The amount allocated to common shares based on fair value
was $946,503 and $402,264 was recorded as a loss on settlement of debt in the consolidated statement of operations and comprehensive
loss.



(c)         Effective
February 27, 2014, 651,904 common share purchase warrants were exercised at $0.35 expiring February 27, 2014 for settlement of
cash advances of $228,167. The amount allocated to warrants based on relative fair value using the Black-Scholes option pricing
model was $78,238 (see Note 9).



(d)         On
February 5, 2014, 200,000 common share purchase warrants exercisable at $0.35 expired. The amount allocated to warrants based
on relative fair value using the Black-Scholes option pricing model was $24,000 with a corresponding increase to contributed surplus.
On February 25, 2014, 80,052 common share purchase warrants exercisable at $0.35 expired. The amount allocated to warrants based
on relative fair value using the Black-Scholes option pricing model was $9,606 with a corresponding increase to contributed surplus.
On February 27, 2014, 1,173,139 common share purchase warrants exercisable at $0.35 expired. The amount allocated to warrants
based on relative fair value using the Black-Scholes option pricing model was $140,793 with a corresponding increase to contributed
surplus.



(e)         Effective
August 30, 2014, the Company converted shareholders’ loans and interest due in the aggregate amount of $1,180,570 through
the issuance of a total of 14,757,120 units in the capital of the Company at a price of $0.08 per unit. Each unit is comprised
of one (1) common share and one half of one (1/2) common share purchase warrant. Each full warrant entitles the holder to purchase
one (1) common share at an exercise price of CDN$0.10 until August 30, 2017.The fair value of the units ($2,516,505) was allocated
to common shares $1,715,426 and warrants $801,079 based on their relative fair values and $1,335,935 was recorded as a loss on
settlement of debt in the consolidated statement of operations and comprehensive loss. The warrant component was valued using
a Binomial Lattice model whereas the fair value of the common share component was based on the current market value of the company’s
stock (see Note 10 and 11).



The following table summarizes the outstanding
warrants as at August 31, 2014 and 2013 respectively:



|Number of Warrants* |           |  | Exercise Price* |   |      | Expiry Date |  | Weighted Average Remaining Life (Years) |  |  | Warrant Value ($) | 
|------------------- | --------- |  | --------------- | - | ---- | ----------- |  | --------------------------------------- |  |  | ----------------- | 
|                    | 600,000   |  |                 | $ | 0.50 |             |  | January 24, 2015                        |  |  | 0.40              | 
|                    | 1,315,000 |  |                 | $ | 0.50 |             |  | February 17, 2015                       |  |  | 0.47              | 
|                    | 7,378,560 |  |                 | $ | 0.10 |             |  | August 30, 2017                         |  |  | 3.00              | 
|                    | 9,293,560 |  |                 | $ | 0.50 |             |  |                                         |  |  | 2.47              | 

* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



|Number of Warrants* |           |  | Exercise Price* |   |      | Expiry Date |  | Weighted Average Remaining Life (Years) |  |  | Warrant Value ($) | 
|------------------- | --------- |  | --------------- | - | ---- | ----------- |  | --------------------------------------- |  |  | ----------------- | 
|                    | 200,000   |  |                 | $ | 0.40 |             |  | February 5, 2014                        |  |  | 0.43              | 
|                    | 80,052    |  |                 | $ | 0.40 |             |  | February 25, 2014                       |  |  | 0.49              | 
|                    | 1,825,043 |  |                 | $ | 0.40 |             |  | February 27, 2014                       |  |  | 0.49              | 
|                    | 600,000   |  |                 | $ | 0.50 |             |  | January 24, 2015                        |  |  | 1.40              | 
|                    | 1,115,000 |  |                 | $ | 0.50 |             |  | February 17, 2015                       |  |  | 1.47              | 
|                    | 200,000   |  |                 | $ | 0.50 |             |  | February 17, 2015                       |  |  | 1.47              | 
|                    | 4,020,095 |  |                 | $ | 0.40 |             |  |                                         |  |  | 0.94              | 



* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



36







Weighted Average Shares Outstanding



The following table summarizes the weighted
average shares outstanding:



|Weighted Average Shares Outstanding*                  |  | August 31, 2014 |            |  | August 31, 2013 | 
|----------------------------------------------------- |  | --------------- | ---------- |  | --------------- | 
|Weighted Average Shares Outstanding Basic and diluted |  |                 | 12,675,329 |  |                 | 



* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



The effects of any potential dilutive
instruments on loss per share are anti-dilutive and therefore have been excluded from the calculation of diluted loss per share.



Share Purchase Options



The Company has a stock option plan to
provide incentives for directors, officers, employees and consultants of the Company. The maximum number of shares, which may
be set aside for issuance under the stock option plan, is 20% of the issued and outstanding common shares of the Company on a
rolling basis.



The following table is a summary of the
status of the Company’s stock options and changes during the period:



|                                  |  | Number      |         |  | Weighted Average |  
|--------------------------------- |  | ----------- | ------- |  | ---------------- | -
|                                  |  | of Options* |         |  | Exercise Price   |  
|Balance, August 31, 2012 and 2013 |  |             | 105,000 |  |                  | $
|Granted                           |  |             | -       |  |                  |  
|Balance, August 31, 2014          |  |             | 105,000 |  |                  | $

* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



The following table is a summary of the
Company's stock options outstanding and exercisable at August 31, 2014 and 2013 respectively:



|Options Outstanding |      |  | Options Exercisable | 
|------------------- | ---- |  | ------------------- | 
|Exercise Price      |      |  | Number of Options*  | 
|$                   | 1.60 |  |                     | 
|$                   | 2.50 |  |                     | 
|                    |      |  |                     | 

* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation

(1) In October 2012, the Optionee passed
away and pursuant to the terms of the option agreement had a period of twelve (12) months
after the date of such death before the expiry of the option (see Note 17).





|Options Outstanding |      |  | Options Exercisable | 
|------------------- | ---- |  | ------------------- | 
|Exercise Price      |      |  | Number of Options*  | 
|$                   | 1.60 |  |                     | 
|$                   | 2.50 |  |                     | 
|                    |      |  |                     | 



* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



37







Contributed Surplus



Contributed surplus transactions for the
respective periods are as follows:

|                                  |  | Amount |          
|--------------------------------- |  | ------ | ---------
|Balance, August 31, 2012 and 2013 |  | $      | 506,200  
|Warrants expired                  |  |        | 174,399  
|Derivative warrants expired       |  |        | 709,299  
|Balance, August 31, 2014          |  | $      | 1,389,898



OVERALL PERFORMANCE

Revenue, net of royalties for the year
ended August 31, 2014 was up $34,962 to $65,024 compared to $30,062 for the year ended August 31, 2013. The increase in net revenue
during 2014 was primarily attributed to increases in natural gas production volume and prices received from the Company’s
Botha, Alberta property. Net loss for the year ended August 31, 2014, was $6,115,585 compared to a net loss of $4,266,046 for
the year ended August 31, 2013. The increase in net loss during 2014 was primarily related to a loss on derivative liabilities
of $2,735,476 compared to a loss of $128,041 during fiscal 2013. The increase in 2014, was attributed to the exchange of a secured
note for a secured convertible note during fiscal 2014, which terms and features of the conversion meet the definition of an embedded
derivative liability that requires fair value measurement at each reporting period. During the year ended August 31, 2014, the
Company recorded an increase in loss on settlement of debt in the amount of $933,671 to $1,335,935 compared to a loss on settlement
of debt in the amount of $$402,264 during fiscal 2013. During fiscal 2014, the Company converted shareholders’ loans and
interest due, in the aggregate amount of $1,180,570 through the issuance of a total of 14,757,120 units in the capital of the
Company at a price of $0.08 per unit. The increases during fiscal 2014, were partially offset by a reduction in the impairment
of exploration and evaluation assets in the amount of $1,375,292 to $1,315,276 compared to $2,690,568 in fiscal 2013.



During the year ended August 31, 2014,
the Company issued 14,757,120 units in the capital of the Company as full settlement of related shareholder loans and interest
due in the aggregate amount of $1,180,570.



For the twelve months ended August 31,
2014, the Company recorded net additions of $113,578 in exploration and evaluation assets.



On December 3, 2013, (amended January 21, 2014) the Company
entered into a Joint Development Agreement with Stratex Oil and Gas Holdings, Inc. (“Stratex”) ( the “JDA”)
to develop the Matthews Lease. Under the terms of the Joint Development Agreement (“JDA”), Stratex will act as operator
and upon Stratex delivering i) US$150,000 to the lessors of the Matthews Lease on behalf of Zavala Inc., ii) delivering US $150,000
to the Company; and iii) commencing a hydraulic fracture of the Matthews #1H not later than March 31, 2014. Stratex earned a 66.67%
working interest before payout (50% working interest after payout) in the Matthews #1H well and a 50% working interest in the
2,629 acre Matthews Lease.



On April 11, 2014 the Company entered
into a further Joint Development Agreement (“JDA2”) with Stratex and Quadrant Resources LLC, (“Quadrant”)
for the development of the San Miguel formation on the Matthews Lease.  Pursuant to the terms of the JDA2, upon satisfaction
of certain conditions including the Phase 1 Work Program and the cash consideration described below, Quadrant can earn an undivided
66.667% before payout and a 50% working interest after payout to the base of the San Miguel formation of the Matthews Lease by
i) drilling 3 new wells and reworking 5 existing wells at its sole cost and expense by June 30, 2015 (the “Phase I Work
Program”); ii) paying US$100,000 to the Company upon execution of the JDA2 (paid); and iii) paying US$65,000 to the Company
on each of July 8, 2014 (paid); October 6, 2014, January 5, 2015 and April 6, 2015. At August 31, 2014, the Company recorded the
payments received from Quadrant of US$165,000 (CDN $177,804) as deferred revenue on the Consolidated Statement of Financial Position
until the conveyance of the earned interest at which time such payments will be reclassified and offset against exploration and
evaluation assets.



As part of the Company’s oil and
gas development program, management of the Company anticipates further development expenditures to define reserves and extract
hydrocarbons. Amounts expended on future exploration and development is dependent on the nature of future opportunities evaluated
by the Company and cash calls from joint venture participants. Any expenditure which exceeds available cash will be required to
be funded by additional share capital or debt issued by the Company, or by other means. The Company’s long-term profitability
will depend upon its ability to successfully implement its business plan.



38







The Company’s past primary source
of liquidity and capital resources has been proceeds from the issuance of share capital, shareholders’ loans and cash flow
from oil and gas operations.



SELECTED ANNUAL FINANCIAL INFORMATION



The following table reflects the summary
of results for the years set out.



|                                  |  | For the Years Ended |           
|--------------------------------- |  | ------------------- | ----------
|                                  |  | August 31           |           
|                                  |  | 2014                |           
|Revenue, net of royalties         |  | $                   | 65,024    
|Net loss                          |  |                     | (6,115,585
|Loss per share, basic and diluted |  | $                   | (0.482    
|Assets                            |  | $                   | 5,296,928 
|Long term liabilities             |  | $                   | 4,266,790 



August 31, 2014 - 2013



For the year ended August 31, 2014, revenue,
net of royalties was up $34,962 to $65,024 compared to $30,062 for the year ended August 31, 2013. The increase in net revenue
during 2014, was primarily attributed to increases in natural gas production volume and prices received from the Company’s
Botha, Alberta property. Net loss for the year ended August 31, 2014 was $6,115,585 compared to a net loss of $4,266,046 for the
year ended August 31, 2013. The increase in net loss during 2014, was primarily related to a loss on derivative liabilities of
$2,735,476 compared to a loss of $128,041 during fiscal 2013. This increase in 2014 was attributed to the exchange of a secured
note for a secured convertible note during fiscal 2014 which terms and features of the conversion meet the definition of an embedded
derivative liability that requires fair value measurement at each reporting period. During the year ended August 31, 2014, the
Company recorded an increase in loss on settlement of debt in the amount of $933,671 to $1,335,935 compared to a loss on settlement
of debt in the amount of $$402,264 during fiscal 2013. During fiscal 2014, the Company converted shareholders’ loans and
interest due, in the aggregate amount of $1,180,570 through the issuance of a total of 14,757,120 units in the capital of the
Company at a price of $0.08 per unit. The increases during fiscal 2014, were partially offset by a reduction in the impairment
of exploration and evaluation assets in the amount of $1,375,292 to $1,315,276 compared to $2,690,568 in fiscal 2013.



August 31, 2013 – 2012



For the year ended August 31, 2013, revenue,
net of royalties was $30,062 compared to $39,218 for the same period in 2012. The decrease in net revenue was primarily attributed
to declines in natural gas production volume and prices received from the Company’s Botha, Alberta property. Net loss for
the year ended August 31, 2013, was $4,266,046 compared to a net loss of $2,809,188 for the year ended August 31, 2012. The increase
in net loss during 2013, was primarily related to an impairment of exploration and evaluation assets in the amount of $2,690,568
partially offset by a reduction in loss on settlement of debt in the amount of $1,063,201 to $402,264 compared to a loss on settlement
of debt in the amount of $1,465,465 in 2012, a reduction in general and administrative costs of $122,014 to $583,577 compared
to general and administrative costs of $705,591 during 2012, stock based compensation expense of $Nil compared to $170,972 in
2012. For the year ended August 31, 2013, assets decreased by $2,079,820 compared to assets of $8,998,016 for the year ended August
31, 2012. The decrease in assets for the year ended August 31, 2013, was primarily as result of an impairment in exploration and
evaluation assets of $2,690,568 to $6,535,278 compared to $8,475,487 for the same period in 2012, an impairment of property and
equipment of $168,954 in 2013 compared to $50,774 in 2012 and a decrease in cash during 2013 of $133,166 to $196,837 compared
to cash of $330,003 in 2012. These decreases were offset by an increase in prepaid expenses and deposits of $158,295 compared
to $Nil in 2012 and an increase of $10,261 in accounts receivable to $27,786 compared to $17,525 in 2012. Long term liabilities
decreased in fiscal 2013 by $473,256 to $1,407,822 compared to $1,881,078 in 2012. These decreases are primarily a result of a
reallocation of derivative warrant liabilities in the amount of $688,803 to current liabilities and a reallocation $178,553 of
long term provisions to current liabilities.



39







RESULTS OF OPERATIONS



|Historical                        |  | For the Years Ended |           
|--------------------------------- |  | ------------------- | ----------
|Production                        |  | August 31           |           
|                                  |  | 2014                |           
|Natural gas – mcf/d               |  |                     | 53        
|Historical Prices                 |  |                     |           
|Natural Gas - $/mcf               |  | $                   | 4.34      
|Royalties costs - $/mcf           |  | $                   | 0.96      
|Production costs - $/mcf          |  | $                   | 0.89      
|Net back - $/mcf                  |  | $                   | 2.49      
|Operations                        |  |                     |           
|Revenue, net of royalties         |  | $                   | 65,024    
|Net loss                          |  | $                   | (6,115,585
|Loss per share, basic and diluted |  | $                   | (0.482    



Production Volume

For the year ended August 31, 2014, average
natural gas sales volumes increased by 16 mcf/d to 53 mcf/d compared to 37 mcf/d for the same period in 2013. Total production
volume for the year ended August 31, 2014, was 19,244 mcf compared to 13,431 mcf for the twelve month period ended August 31,
2013.



For the year ended August 31, 2013, average
natural gas sales volumes decreased by 17 mcf/d to 37 mcf/d compared to 54 mcf/d for the same period in 2012. Total production
volume for the year ended August 31, 2013, was 13,431 mcf compared to 19,593 mcf for the twelve month period ended August 31,
2012.



Commodity Prices

For the year ended August 31, 2014, average
natural gas prices received per mcf increased to $4.34 compared to $2.15 for the year ended August 31, 2013. The increase in average
natural gas prices received was attributed to higher commodity prices received for natural gas.



For the year ended August 31, 2013, average
natural gas prices received per mcf decreased by 4% to $2.15 compared to $2.24 for the year ended August 31, 2012. The decrease
in average natural gas prices received was attributed to lower commodity prices for received natural gas.



|Revenue, Net of Royalties |  | For the Years Ended |        
|------------------------- |  | ------------------- | -------
|                          |  | August 31,          |        
|                          |  | 2014                |        
|Natural gas sales         |  | $                   | 83,471 
|Royalties                 |  |                     | (18,447
|Revenue, net of royalties |  | $                   | 65,024 



Natural gas sales for the year ended August
31, 2014, was up $44,851 to $83,471 compared to $38,620 for the year ended August 31, 2013.The increase in sales for fiscal 2014
was attributed to higher production volume and increased commodity prices received for natural gas.



Natural gas sales for the year ended August
31, 2013, was down $5,788 to $38,620 compared to $44,408 for the year ended August 31, 2012. The decrease in sales for the twelve
month period ended August 31, 2013, was attributed to lower commodity prices received for natural gas and lower production volume.



Royalties for the year ended August 31,
2014, were up $9,889 to $18,447 versus $8,558 for the same twelve month period in 2013 resulting from higher production volume
in fiscal 2014.



Royalties for the year ended August 31,
2013, were up $3,368 to $8,558 versus $5,190 for the same twelve month period in 2012. The increase during fiscal 2013 was attributed
to receipt of royalty credits in recorded in fiscal 2012.



Revenue, net of royalties for the year
ended August 31, 2014, increased by $34,962 to $65,024 compared to $30,062 for the same twelve month period ended August 31, 2013.



40







Revenue, net of royalties for the year
ended August 31, 2013, decreased by 23% to $30,062 compared to $39,218 for the same twelve month period in 2012.



Operating Costs

For year ended August 31, 2014, operating
costs were $17,138 compared to operating costs of $9,234 for the year ended August 31, 2013. The increase in operating costs for
the year ended August 31, 2014, was primarily a result of higher production volume and activity on the Company’s Botha,
Alberta wells.



For year ended August 31, 2013, operating
costs were $9,234 down $19,237 compared to operating costs of $28,471 for the year ended August 31, 2012. The decrease in operating
costs for the year ended August 31, 2013 was primarily a result of lower production volume and the shut in of the Company’s
Botha, Alberta wells in the 4th quarter.



Depletion and Accretion

Depletion and accretion for the year ended
August 31, 2014, decreased by $10,834 to $2449 compared to $13,283 for the year ended August 31, 2013. The decrease in depletion
and accretion for the year ended August 31, 2014, was primarily attributed to the previous fiscal year end impairment of the carrying
costs of the Company’s Botha, Alberta property.



Depletion and accretion for the year ended
August 31, 2013, decreased by $7,226 to $13,283 compared to $20,509 for the year ended August 31, 2012. The decrease in depletion
and accretion for the twelve months ended August 31, 2013, was primarily attributed to lower production volume and the shut in
of the Company’s Botha, Alberta wells in the 4th quarter.



|General and Administrative Expenses |  | For the Years Ended |        
|----------------------------------- |  | ------------------- | -------
|                                    |  | August 31,          |        
|                                    |  | 2014                |        
|Professional fees                   |  | $                   | 157,106
|Head office costs                   |  |                     | 44,925 
|Management fees                     |  |                     | 75,000 
|Transfer and registrar costs        |  |                     | 18,218 
|Shareholders information            |  |                     | 35,689 
|Office and general costs            |  |                     | 3,338  
|Advisory fees                       |  |                     | —      
|Directors fees                      |  |                     | 3,100  
|Salaries and wages                  |  |                     | -      
|Reserve report fees                 |  |                     | -      
|Consulting fees and expenses        |  |                     | 65,744 
|Total                               |  | $                   | 403,120



General and administrative expenses for
the year ended August 31, 2014, were $180,457 lower to $403,120 compared to $583,577 for the year ended August 31, 2013. The decrease
in expenses during fiscal 2014 was primarily attributed to a decrease in professional fees of $94,059 to $157,106 compared to
251,165 for the year ended August 31, 2013. The professional fee decreases were primarily related to a reduction in litigation
costs related to the Matthews Lease, Texas as a result of the settlement of claims in 2013. During the year ended August 31, 2014,
advisory fees decreased by $65,724 to $Nil compared to $65,724 for the same twelve month period in 2013 as a result of the expiry
of an investment banking agreement. For the year ended August 31, 2014, consulting fees were reduced by $18,048 to $65,744 compared
to $83,792 during fiscal 2013. In addition, during fiscal 2014 the Company recorded an increase in transfer and registrar costs
of $10,627 to $18,218 compared to $7,591for the year ended August 31, 2013. During fiscal 2014, the Company completed
a 1-for-10 stock consolidation which resulted in higher transfer and registrar costs. During fiscal 2014, the Company recorded
a decrease in reserve report fees of $10,059 to $Nil compared to $10,059 in fiscal 2013 as a result of no recordable reserves
and no discernable future net revenue being assigned to the Company’s Botha Alberta Property by an independent reserves
evaluator.



41







General and administrative expenses for
the year ended August 31, 2013 were $122,014 lower to $583,577 compared to $705,591 for the year ended August 31, 2012. The decrease
in expenses during fiscal 2013 was primarily attributed to a decrease in professional fees of $101,150 to $251,165 compared to
$352,315 in 2012. In addition, during fiscal 2013 the Company recorded a decrease in transfer and registrar costs of $21,581 to
$7,591 compared to $29,172 for the year ended August 31, 2012. During fiscal 2012 the Company completed a forward stock split
which resulted in higher costs incurred during the year ended August 31, 2012. During the year ended August 31, 2013 advisory
fees increased by $19,532 to $65,724 compared to $46,192 for the same twelve month period in 2012.



Interest Expense

For the year ended August 31, 2014, the
Company recorded interest costs of $284,038 versus interest costs of $76,783 for the year ended August 31, 2013. The increase
in interest costs during the year ended August 31, 2014 was primarily attributed to decreases in borrowing costs capitalized as
a result of the impairment loss recorded on exploration and evaluation assets.



For the year ended August 31, 2013, the
Company recorded interest costs of $76,783 versus interest costs of $88,789 for the year ended August 31, 2011. The decrease in
interest costs during the year ended August 31, 2013 was attributed to decreases in shareholders’ loans.



Loss on Derivative Liabilities

Derivative Warrant Liabilities

For the year ended August 31, 2014, the
Company recorded an unrealized loss on derivative warrant liabilities of $57,725 compared to an unrealized loss of $128,041 for
the year ended August 31, 2013.



For the year ended August 31, 2013, the
Company recorded an unrealized loss on derivative warrant liabilities of $128,041 compared to an unrealized loss of $46,655 for
the year ended August 31, 2012.



The Company has warrants issued with an
exercise price in US dollars which is different to the functional currency of the Company (Canadian Dollars) and accordingly the
warrants are treated as a derivative financial liability and the fair value movement during the period is recognized in the statement
of operations.



Derivative Unit Liabilities

During the year ended August 31, 2014,
the Company recorded a loss on derivative unit liabilities of $2,677,751 compared to $Nil for the year ended August 31, 2013.



At August 31, 2014, the Company exchanged
a secured note payable with a carrying value of $1,322,347 (US$1,216,175) for a secured convertible promissory note payable with
a face value of $1,322,347 (US$1,216,175) (the “Note”).The Note has a conversion option at any time to convert
any unpaid principal and accrued interest into conversion units. A conversion unit is comprised of one (1) common share and one
(1) common share purchase warrant entitling the holder to acquire a common share of the Company at a price equal to a 15% premium
to the price of the common share acquired under the conversion unit (the “Conversion Unit”). Since both components
of the Conversion Unit (the common share component and warrant component) contain a variable exercise/conversion price, the Conversion
Unit meets the definition of a financial liability under IAS 32“Financial Instruments: Presentation”. As a result,
the Conversion Unit is a derivative liability that requires fair value measurement each period.



Loss on Foreign Exchange

For the year ended August 31, 2014, the
Company recorded a loss on foreign exchange of $101,427 versus a loss on foreign exchange of $197,640 for year ended August 31,
2013.



For the year ended August 31, 2013, the
Company recorded a loss on foreign exchange of $197,640 versus a loss on foreign exchange of $36,283 for year ended August 31,
2012.



These foreign exchange gains and losses
are attributed to the translation of monetary assets and liabilities not denominated in the functional currency of the Company.



Marketing and Public Relations

For the year ended August 31, 2014, the
Company recorded a recovery of marketing and public relations expense of $14,250 compared to marketing and public relations costs
of $25,763 for the year ended August 31, 2013.



42







For the year ended August 31, 2013, the
Company incurred marketing and public relations costs of $25,763 versus $46,272 for the year ended August 31, 2012.



Loss on Settlement of Debt

For the year endedAugust 31, 2014,
the Company recorded a loss on settlement of debt in the amount of $1,335,935 compared to $402,264 for the same twelve month period
in 2013. During fiscal 2014, the Company issued 14,757,120 units as full settlement of shareholders’ loans and interest
in the aggregate amount of $1,180,570. The fair value of the units ($2,516,505) was allocated to common shares $1,715,426 and
warrants $801,079 based on their relative fair values and $1,335,935 was recorded as loss on settlement of debt.



For the year endedAugust 31, 2013,
the Company recorded a loss on settlement of debt in the amount of $402,264 compared to $1,465,465 for the same twelve month period
in 2012. During fiscal 2013, the Company issued 2,366,257 units as full settlement of shareholders’ loans in the amount
of $198,333 and interest due on shareholders’ loans in the amount of $345,906. The amount allocated to common shares based
on fair value was $946,503 and $402,264 was recorded as a loss on settlement of debt.



Impairment Loss on Exploration and
Evaluation Assets

As at and for the year ended August 31,
2014, the Company recorded a net impairment loss of $1,315,276 compared to an impairment loss of $2,690,568 on its Murphy Lease,
Zavala County, Texas. In fiscal 2014 the impairment was recognized upon the dissolution of Dyami Energy.



As at and for the year ended August 31,
2013, the Company recorded an impairment of $2,690,568 on its Murphy Lease, Zavala County, Texas based on the amount for which
management believes the assets could be sold or farmed out in an arms’ length transaction, less estimated costs to sell
compared to $Nil in the prior period in 2012.



During the year ended August 31, 2013,
the Company, Dyami Energy and OGR Energy Corporation, the Lessees, were litigating a dispute with the Lessors of the Matthew’s
property. During the last quarter of fiscal year August 2013, the Company and the Lessors agreed to resolve the litigation and
continue with the development of the Matthew’s property. In order to comply with certain State legal requirements, it was
deemed necessary by the Lessors counsel to continue with the development through a newly executed lease document and the Company
formed, Zavala Inc. a new wholly owned subsidiary to execute the new lease. The new lease was signed effective September 1, 2013
and the first of two payments of US$150,000 were paid to the Lessors upon signing the new lease as required initial pre-payment
of anticipated production royalties along with a continuing development obligation under the lease to complete the previously
drilled Matthews #1H horizontal well or drill a new well on the Matthews property no later than March 30, 2014. On September 1,
2013, the Matthews lease was renewed by the Company through Zavala Inc. and based on the concept of faithful representation under
IAS 8, the carrying value of the Matthew’s lease by Dyami Energy was considered to be the value for Zavala Inc. as this
arrangement is simply a reorganization in substance.



Subsequent to September 1, 2013 and the
continuing development of the Matthews lease, Dyami Energy continued its development efforts with the Murphy lease. A tentative
joint venture agreement with Stratex was reached but did not materialize and efforts to develop the Murphy lease were not successful.
The Company had solicited lenders and investors in an attempt to obtain debt/equity financings as a means to improve Dyami Energy’s
financial situation. Despite the Company’s attempts, these efforts were unsuccessful and management determined that it could
no longer fund the Murphy operations, hence the lease was considered impaired and an impairment loss was recorded by Dyami Energy
during the third quarter. On March 6, 2014, the Company filed a Certificate of Termination of a Domestic Entity with the Secretary
of State, Texas for its wholly-owned subsidiary Dyami Energy and effective April 3, 2014, Dyami Energy was dissolved. All prior
obligations with respect to the Matthew’s and Murhpy’s lease on the books of Dyami Energy prior to its dissolution
were recorded by the Company.



The Company’s investment in Dyami
Energy has been deconsolidated from the Company’s Consolidated Financial Statements as at the effective date, and presented
on the Consolidated Statements of Operations and Comprehensive Loss and the Consolidated Statements of Cash Flow as an impairment
of the net assets and liabilities on dissolution of subsidiary.



43







The following table presents the effect
of the dissolution of Dyami Energy on the consolidated financial statements of the Company at April 3, 2014:



|                                                 |  | April 3, 2014 |           
|------------------------------------------------ |  | ------------- | ----------
|Exploration and evaluation assets – Murphy Lease |  | $             | (1,675,749
|Provisions                                       |  |               | 58,589    
|Foreign currency translation reserve             |  |               | 301,884   
|Net assets and liabilities                       |  | $             | (1,315,276



Impairment Loss on Property and Equipment

For the year ended August 31, 2014 the
Company recorded an impairment loss of $Nil compared to an impairment loss of $168,954 during fiscal 2013. The impairment recorded
in 2013 was a result of no recordable reserves and no discernable future net revenue being assigned to the Company’s Botha
Alberta Property by an independent reserves evaluator



Impairment Loss on Marketable Securities

For the year endedAugust 31, 2013,
the fair value of the securities was written down to $Nil (August 31, 2012 fair value - $1).



Net Loss

Net loss for the year ended August 31,
2014, was $6,115,585 compared to a net loss of $4,266,046 for the year ended August 31, 2013. The increase in net loss during
2014 was primarily related to a loss on derivative liabilities of $2,735,476 compared to a loss of $128,041 during fiscal 2013.
This increase in 2014 was attributed to the exchange of a secured note for a secured convertible note during fiscal 2014 which
terms and features of the conversion meet the definition of an embedded derivative liability that requires fair value measurement
at each reporting period. During the year ended August 31, 2014, the Company recorded an increase in loss on settlement of debt
in the amount of $933,671 to $1,335,935 compared to a loss on settlement of debt in the amount of $402,264 during fiscal 2013.
During fiscal 2014 the Company converted shareholders’ loans and interest due, in the aggregate amount of $1,180,570 through
the issuance of a total of 14,757,120 units in the capital of the Company at a price of $0.08 per unit. The increases during fiscal
2014, were partially offset by a reduction in the impairment of exploration and evaluation assets in the amount of $1,375,292
to $1,315,276 compared to $2,690,568 in fiscal 2013.



Net loss for the year ended August 31,
2013, was $4,266,046 compared to a net loss of $2,809,188 for the year ended August 31, 2012. The increase in net loss was primarily
related to an impairment of exploration and evaluation assets in the amount of $2,690,568 compared to $Nil in 2012 and an impairment
of property and equipment of $168,954 compared to $50,774 in 2012. These increases were partially offset by a reduction in loss
on settlement of debt in the amount of $1,063,201 to $402,264 compared to a loss on settlement of debt in the amount of $1,465,465
in 2012, a reduction in general and administrative costs of $122,014 to $583,577 compared to general and administrative costs
of $705,591 during 2012 and a reduction stock based compensation expense of $Nil compared to $170,972 in 2012.



Foreign Currency Translation

For the year ended August 31, 2014, the
Company recorded a loss on translation of foreign subsidiary of $199,965 versus a gain of $314,120 for the year ended August 31,
2013.



For the year ended August 31, 2013, the
Company recorded a gain on translation of foreign subsidiary of $314,120 versus a loss of $160 for the year ended August 31, 2012.



These losses are related to translation
differences between Dyami Energy’s and Zavala Inc’s US dollar functional currency converted into Canadian dollars
at the period end exchange rates, and the results operations converted at average rates of exchange for the period.



Net Loss and Comprehensive Loss

Total loss and comprehensive loss for
the year ended August 31, 2014, was $6,315,550 compared to a comprehensive loss of $3,951,926 for the year ended August 31, 2013.



Total loss and comprehensive loss for
the year ended August 31, 2013, was $3,951,926 compared to a comprehensive loss of $2,809,348 for the year ended August 31, 2012.



44







Loss per Share, Basic and Diluted

Basic and diluted net loss per share for
the year ended August 31, 2014, was $0.482 compared to a basic and diluted net loss per share of $0.407 for the same period in
2013.



Basic and diluted net loss per share for
the year ended August 31, 2013, was $0.407 compared to a basic and diluted net loss per share of $0.344 for the same period in
2012.



SUMMARY OF QUARTERLY RESULTS



The following tables reflect the summary
of quarterly results for the periods set out.



|                                  |  | 2014      |            |   | 2014   |   |            | 2014        |  |   | 2013        |  
|--------------------------------- |  | --------- | ---------- | - | ------ | - | ---------- | ----------- |  | - | ----------- | -
|For the quarter ending            |  | August 31 |            |   | May 31 |   |            | February 29 |  |   | November 30 |  
|Revenue, net of royalties         |  | $         | 19,551     |   |        | $ | 22,116     |             |  | $ | 9,754       |  
|Net income (loss) for the period  |  | $         | (4,332,092 | ) |        | $ | (1,269,732 | )           |  | $ | (401,602    | )
|Loss per share, basic and diluted |  | $         | (0.327     | ) |        | $ | (0.098     | )           |  | $ | (0.030      | )



Fiscal 2014

Revenue, net of royalties for the four
quarters fluctuated as a result of changes in production volume and commodity prices. During the quarter ended August 31, 2014,
the company recorded a loss on derivative liabilities of $2,676,655 and loss on settlement of debt in the amount of $1,335,935
upon the settlement of shareholders loans and interest due, in the aggregate amount of $1,180,570 through the issuance of a total
of 14,757,120 units in the capital of the Company at a price of $0.08 per unit. During the quarter ended May 31, 2014, the Company
recorded a net impairment loss on exploration and evaluation assets in the amount of $1,315,276. During the three months ended
February 2014, the Company recorded a loss on foreign exchange of $146,645. Other changes in net loss during the quarters were
primarily related to increases in general and administrative costs, gain or loss on foreign exchange and the fair value movement
of derivative warrant liabilities during the respective periods.



|                                  |  | 2013      |            |   | 2013   |   |          | 2013        |  |   | 2012        |  
|--------------------------------- |  | --------- | ---------- | - | ------ | - | -------- | ----------- |  | - | ----------- | -
|For the quarter ending            |  | August 31 |            |   | May 31 |   |          | February 29 |  |   | November 30 |  
|Revenue, net of royalties         |  | $         | 171        |   |        | $ | 10,206   |             |  | $ | 9,787       |  
|Net loss for the period           |  | $         | (3,557,922 | ) |        | $ | (116,520 | )           |  | $ | (374,673    | )
|Loss per share, basic and diluted |  | $         | (0.340     | ) |        | $ | (0.010   | )           |  | $ | (0.04       | )



Fiscal 2013

Revenue, net of royalties for the four
quarters fluctuated as a result of changes in production volume and commodity prices. In addition during fiscal 2013 the remaining
wells in the Company’s Botha, Alberta property were shut in. During the quarter ended August 31, 2013, the Company recorded
an impairment of exploration and evaluation assets in the amount of $2,690,568, an impairment of property and equipment of $168,954
and a loss on settlement of debt in the amount of $402,264. During the three months ended February 2013 the Company recorded a
loss on foreign exchange of $111,369. Other changes in net loss during the quarters were primarily related to increases in general
and administrative costs, gain or loss on foreign exchange and the fair value movement of derivative warrant liabilities during
the respective periods.



FOURTH QUARTER RESULTS



|Historical                        |  | For the Three Months Ended |           
|--------------------------------- |  | -------------------------- | ----------
|Production                        |  | August 31                  |           
|                                  |  | 2013                       |           
|Natural gas – mcf/d               |  |                            | 62        
|Historical Prices                 |  |                            |           
|Natural Gas - $/mcf               |  | $                          | 4.30      
|Royalties costs - $/mcf           |  | $                          | 0.82      
|Production costs - $/mcf          |  | $                          | 1.22      
|Net back - $/mcf                  |  | $                          | 2.26      
|Operations                        |  |                            |           
|Revenue, net of royalties         |  | $                          | 19,551    
|Net loss                          |  | $                          | (4,332,092
|Loss per share, basic and diluted |  | $                          | (0.327    



45







Production Volume

For the three months ended August 31,
2014 average natural gas sales volumes was 62 mcf/d compared to Nil mcf/d for the same period in 2013. Total production volume
for the three months ended August 31, 2014 was 5,622 mcf compared to Nil mcf for the same twelve month period in 2013. During
the three months ended August 31, 2013, the Company’s wells in the Botha Property, Alberta were shut in.



Commodity Prices

For the three months ended August 31,
2014 average natural gas prices received per mcf was $4.30 compared to $Nil for the three months ended August 31, 2013. During
the three months ended August 31, 2013, the Company’s wells in the Botha Property, Alberta were shut in.



|Revenue, Net of Royalties |  | For the Three Months Ended |       
|------------------------- |  | -------------------------- | ------
|                          |  | August 31,                 |       
|                          |  | 2014                       |       
|Natural gas sales         |  | $                          | 24,174
|Royalties                 |  |                            | (4,623
|Revenue, net of royalties |  | $                          | 19,551



Natural gas sales for the three months
ended August 31, 2014, was up $18,156 to $19,551 compared to $1,395 for the three months ended August 31, 2013. The increase in
sales for the three month period ended August 31, 2014 was attributed to the Company’s Botha, Alberta wells producing versus
being shut in for the same three month period in 2013.



Royalties for the three months ended August
31, 2014, were $4,623 versus $1,224 for the comparable three month period in 2013. The increase in royalties for the three months
ended August 31, 2014 was primarily attributed to higher production volume.



As a result of the above, revenue, net
of royalties for the three months ended August 31, 2014, increased to $19,551 compared to $171 for the same three month period
in 2013.



Operating Costs

For three months ended August 31, 2014,
the Company incurred operating costs of $6,843 versus operating costs of in the amount of $1,473 for the same three month period
ended August 31, 2013. Increased operating costs for the three months ended August 31, 2014 was primarily a result of higher production
volume from the Company’s Botha, Alberta wells.



Depletion and Accretion

Depletion and accretion for the three
months ended August 31, 2014, decreased by $657 to $333 compared to $990 for the three months ended August 31, 2014. The decrease
in depletion and accretion for the three months ended August 31, 2014 was primarily attributed to a reduction in the carrying
value of the Company’s Botha, Alberta property to $Nil.



|General and Administrative Expenses |  | For the Three Months Ended |        
|----------------------------------- |  | -------------------------- | -------
|                                    |  | August 31                  |        
|                                    |  | 2014                       |        
|Professional fees                   |  | $                          | 94,588 
|Head office costs                   |  |                            | 11,250 
|Management fees                     |  |                            | 18,750 
|Transfer and registrar costs        |  |                            | 12,402 
|Shareholders information            |  |                            | 2,857  
|Office and general costs            |  |                            | 2,147  
|Directors fees                      |  |                            | 600    
|Consulting fees and expenses        |  |                            | 16,146 
|Reserve report fees                 |  |                            | -      
|Total                               |  | $                          | 158,740



46







General and administrative expenses for
the three months ended August 31, 2014, were down by $4,964 to $158,740 compared to $163,704 for the year ended August 31, 2013.
The decrease in general and administrative expenses during 2014 was primarily attributed to a decrease in consulting fees and
expenses of $27,065 to $16,146 compared to $43,211 and a decrease of $5,500 in reserve report fees to $Nil compared to $5,500
during 2013. The decreases during the 2014 quarter were partially offset by higher professional fees in of $14,380 to $94,588
compared to $80,208 and higher transfer agent fees of $9,773 to $12,402 compared to $2,629 for the same three month period in
2013.



Interest Expense

For the three months ended August 31,
2014 the Company incurred interest of $171,323 versus interest costs of $15,412 for the three months ended August 31, 2013. The
increase in interest for the quarter in 2014 was attributed a decrease in borrowing costs capitalized as a result of the dissolution
of Dyami Energy.



Loss on Derivative Liabilities

Derivative Warrant Liabilities

For the three months ended August 31,
2014, the Company recorded an unrealized gain on derivative warrant liabilities of $1,098 compared to an unrealized loss of $38,375
for the three months ended August 31, 2013.



The Company has warrants issued with an
exercise price in US dollars which is different to the functional currency of the Company (Canadian Dollars) and accordingly the
warrants are treated as a derivative financial liability and the fair value movement during the period is recognized in the statement
of operations.



Derivative Unit Liabilities

During the three months ended August 31,
2014 the Company recorded a loss on derivative unit liabilities of $2,677,753 compared to $Nil for the three months ended August
31, 2013.



At August 31, 2014, the Company exchanged
a secured note payable with a carrying value of $1,322,347 (US$1,216,175) for a secured convertible promissory note payable with
a face value of $1,322,347 (US$1,216,175) (the “Note”).The Note has a conversion option at any time to convert
any unpaid principal and accrued interest into conversion units. A conversion unit is comprised of one (1) common share and one
(1) common share purchase warrant entitling the holder to acquire a common share of the Company at a price equal to a 15% premium
to the price of the common share acquired under the conversion unit (the “Conversion Unit”)..Since both components
of the Conversion Unit (the common share component and warrant component) contain a variable exercise/conversion price, the Conversion
Unit meets the definition of a financial liability under IAS 32“Financial Instruments: Presentation”. As a result,
the Conversion Unit is a derivative liability that requires fair value measurement each period.



Loss on Foreign Exchange

For the three months ended August 31,
2014, the Company recorded a loss on foreign exchange of $1,813 versus a loss on foreign exchange of $197,643 for the same three
month period in 2013.



These foreign exchange gains and losses
are attributed to the translation of monetary assets and liabilities not denominated in the functional currency of the Company.



Marketing and Public Relations

For the three months ended August 31,
2014, the Company incurred marketing and public relations costs of $Nil compared to $13,085 in the comparable three month period
in 2013.



Loss on Settlement of Debt

For the three months ended August 31,
2014, the Company recorded a loss on settlement of debt in the amount of $1,335,935 compared to $402,264 for the same three month
period in 2013.



During the quarter in fiscal 2014, the
Company issued 14,757,120 units as full settlement of shareholders’ loans and interest in the aggregate amount of $1,180,570.
The fair value of the units ($2,516,505) was allocated to common shares $1,715,426 and warrants $801,079 based on their relative
fair values and $1,335,935 was recorded as loss on settlement of debt.



47







During the quarter in fiscal 2013, the
Company issued 2,366,257 common shares as full settlement of shareholders’ loans in the amount of $198,333 and interest
due on shareholders’ loans in the amount of $345,906. The amount allocated to common shares based on fair value was $946,503
and $402,264 was recorded as a loss on settlement of debt.



Impairment Loss on Exploration and
Evaluation Assets

For the three month ended August 31, 2014,
the Company record an impairment of $Nil on its exploration and evaluation assets compared to $2,690,568 during the three month
period ended August 31, 2013.



During the three month period ended August
31, 2013 the Company record an impairment of $2,690,568 on its Murphy Lease, Zavala County, Texas based on the amount for which
management believes the assets could be sold or farmed out in an arms’ length transaction, less estimated costs to sell
compared to $Nil in the prior period in 2012.



Impairment Loss on Property and Equipment

For the three months ended August 31,
2014, the Company recorded an impairment loss on property and equipment of $Nil compared to $168,954 for the three months ended
August 31, 2013 as result of no recordable reserves and no discernable future net revenue being assigned to the Company’s
Botha Alberta Property by an independent reserves evaluator.



Write down of Marketable Securities

At August 31, 2014, the Company had no
marketable securities. For the three months endedAugust 31, 2013, the fair value of the securities were written down to
$Nil.



Impairment loss on dissolution of subsidiary

For the three months ended August 31,
2014, the Company recorded an impairment gain on dissolution of subsidiary in the amount of $8,892.



Net Loss

Net loss for the three months ended August
31, 2014, increased by $774,170 to $4,332,092 compared to a net loss of $3,557,922 for the three ended August 31, 2013. The increase
in net loss during 2014, was primarily related to a loss on derivative liabilities of $2,676,665 compared to a loss of $38,375
for the three months ended August 31, 2013, a loss on settlement of debt of $1,335,935 compared to a loss on settlement of debt
of $402,264 during the three months ended August 31, 2013. The increases in loss during 2014, were partially offset by a decrease
in the impairment of exploration and evaluation assets in the amount of $2,690,568 to $Nil versus $2,690,568 in the 2013 three
month period, and a decrease in impairment of property and equipment of $168,954 to $Nil compared to $168,954 for the three month
period ended August 31, 2013. In addition, during the three month ended August 31, 2014, the Company recorded a decrease in foreign
exchange of $61,449 to $1,813 compared to $63,262 for the comparable three month period in 2013.



Foreign Currency Translation

For the three months ended August 31,
2014, the Company recorded a loss on translation of foreign subsidiaries of $96,275 versus a gain of $98,027 for the same period
in 2013.



These losses are related to translation
differences between Dyami Energy’s and Eagleford Zavala’s US dollar functional currency converted into Canadian dollars
at the period end exchange rates, and the results operations converted at average rates of exchange for the period.



Loss and Comprehensive Loss

Comprehensive loss for the three months
ended August 31, 2014 was $4,428,367 compared to a comprehensive loss of $3,459,895 for the three months August 31, 2013.



Loss per Share, Basic and Diluted

Basic and diluted net loss per share for
the three months ended August 31, 2014 was $0.327 compared to basic and diluted net loss per share of $$0.340 for the same period
in 2013.



48







CAPITAL EXPENDITURES



For the year ended August 31, 2014, the
Company recorded net additions to exploration and evaluation assets of $113,578 on its Leases located in Zavala County, Texas
(August 31, 2013: $404,818).



The Company expects that its capital expenditures
will increase in future reporting periods as the Company incurs costs to explore and develop its oil and gas properties.



FINANCING ACTIVITIES



During the year ended August 31, 2014,
the Company issued 14,757,120 common shares as full settlement of shareholders’ loans and interest in the aggregate amount
of $1,180,570.



| | B. | LIQUIDITY AND CAPITAL RESOURCES
| | -- | -------------------------------



Cash as of August 31, 2014 was $103,215
compared to cash of $196,837 at August 31, 2013. During the year ended August 31, 2014, the Company entered into Joint Development
Agreements on the Matthews Lease and received cash of $340,811 and the payment of certain obligations under the Matthews Lease.



For the year ended August 31, 2014, the
primary use of funds was related to exploration and evaluation asset expenditures incurred on the Company’s Matthews lease
located in Zavala County, Texas and administrative expenses. The Company’s working capital deficiency at August 31, 2014
was $3,489,237 compared to a working capital deficiency of $4,985,312 at August 31, 2013.



Our current assets of $260,336 as at August
31, 2014, ($382,918 as of August 31, 2013) include the following items: cash $103,215 ($196,837 as of August 31, 2013); trade
and other receivables $112,285 ($27,786 as of August 31, 2013); and prepaid expenses and deposits of $44,836 ($158,295 as of August
31, 2013).



Our current liabilities of $3,749,573
as of August 31, 2013 ($5,368,230 as of August 31, 2013) include the following items: trade and other payables $1,483,775 ($1,379,581
as of August 31, 2013); shareholders’ loans $981,834 ($2,108,205 as of August 31, 2013); secured note payable of $Nil ($1,013,088
as of August 31, 2013); derivative liabilities of $1,094,392 ($688,803 as of August 31, 2013); deferred revenue of $177,804 ($Nil
as of August 31, 2013); and provisions of $11,768 ($178,553 as of August 31, 2013).



At August 31, 2014, the Company had outstanding
the following common share purchase warrants: 7,378,560 warrants exercisable at $0.10 per share; 1,915,000 warrants exercisable
at $0.50 per share; 641,240 warrants exercisable at US$5.00 per share; and 102,598 warrants exercisable at US$2.50. If any of
these common share purchase warrants are exercised it would generate additional capital for us.



Management of the Company recognizes that
cash flow from operations is not sufficient to develop its oil and gas operations or meet its working capital requirements. The
Company has liquidity risk which necessitates the Company to obtain debt financing, enter into joint venture arrangements, or
raise equity. There is no assurance the Company will be able to obtain the necessary financing in a timely manner.



The Company’s past primary source
of liquidity and capital resources has been proceeds from the issuance of share capital, shareholders’ loans and cash flow
from oil and gas operations.



If the Company issued additional common
shares from treasury it would cause the current shareholders of the Company dilution.



Outlook and Capital Requirements

A part of our oil and gas development
program, we anticipate further expenditures may be required to define reserves and extract hydrocarbons. Amounts expended on future
exploration and development is dependent on the nature of future opportunities evaluated by us and cash calls from joint venture
participants. Any expenditure which exceeds available cash will be required to be funded by additional share capital or debt issued
by us, or by other means. Our long-term profitability will depend upon our ability to successfully implement our business plan.



| | C. | RESEARCH AND DEVELOPMENT, PATENTS AND LICENSES
| | -- | ----------------------------------------------



We do not engage in research and development activities.



49







| | D. | TREND INFORMATION
| | -- | -----------------



Seasonality

Our oil and gas operations is not a seasonal
business, but increased consumer demand or changes in supply in certain months of the year can influence the price of produced
hydrocarbons, depending on the circumstances. Production from our oil and gas properties is the primary determinant for the volume
of sales during the year.



There are a number of trends that have
been developing in the oil and gas industry during the past several years that appear to be shaping the near future of the business.



The first trend is the volatility of commodity
prices. Natural gas is a commodity influenced by factors within North America. A tight supply demand balance for natural gas causes
significant elasticity in pricing, whereas higher than average storage levels tend to depress natural gas pricing. Drilling activity,
weather, fuel switching and demand for electrical generation are all factors that affect the supply-demand balance. Recently,
liquefied natural gas shipments to North America have also resulted in natural gas supply and natural gas pricing being based
more on factors other than supply and demand in North America. Changes to any of these or other factors create price volatility.



Crude oil is influenced by the world economy,
Organization of the Petroleum Exporting Countries' ("OPEC") ability to adjust supply to world demand and weather. Political
events also trigger large fluctuations in price levels. The current global financial crisis has reduced liquidity in financial
markets thereby restricting access to financing and has caused significant volatility to commodity prices. Petroleum prices are
expected to remain volatile for at least the near term as a result of market uncertainties over the supply and demand of these
commodities due to the current state of the world economies, OPEC actions and the ongoing global credit and liquidity concerns.



The impact on the oil and gas industry
from commodity price volatility is significant. During periods of high prices, producers generate sufficient cash flows to conduct
active exploration programs without external capital. Increased commodity prices frequently translate into very busy periods for
service suppliers triggering premium costs for their services. Purchasing land and properties similarly increase in price during
these periods. During low commodity price periods, acquisition costs drop, as do internally generated funds to spend on exploration
and development activities. With decreased demand, the prices charged by the various service suppliers also decline.



World oil and gas prices are quoted in
United States dollars and the price received by Canadian producers is therefore effected by the Canadian/U.S. dollar exchange
rate, which will fluctuate over time. Material increases in the value of the Canadian dollar may negatively impact production
revenues from Canadian producers. Such increases may also negatively impact the future value of such entities' reserves as determined
by independent evaluators. In recent years, the Canadian dollar has increased materially in value against the United States dollar
although the Canadian dollar has recently decreased from such levels.



A second trend within the Canadian oil
and gas industry is the "renewal" of private and small junior oil and gas companies starting up business. These companies
often have experienced management teams from previous industry organizations that have disappeared as a part of the ongoing industry
consolidation. Many are able to raise capital and recruit well qualified personnel. To the extent that this trend continues, we
will have to compete with these companies and others to attract qualified personnel.



A third trend currently affecting the
oil and gas industry is the impact on capital markets caused by investor uncertainty in the global economy. Market events and
conditions in recent years including disruptions in the international credit markets and other financial systems and the deterioration
of global economic conditions have caused significant volatility to commodity prices. These conditions caused a loss of confidence
in the global credit and financial markets. Notwithstanding various actions by governments, concerns about the general condition
of the capital markets, financial instruments, banks, investment banks, insurers and other financial institutions caused the broader
credit markets to further deteriorate and stock markets to decline substantially. These factors have negatively impacted company
valuations and may impact the performance of the global economy going forward. The recovery from the recession has been slow in
various jurisdictions including in Europe and the United States and has been impacted by various ongoing factors including sovereign
debt levels and high levels of unemployment which continue to impact commodity prices and result in high volatility in the stock
market.



50







| | E. | OFF-BALANCE SHEET ARRANGEMENTS
| | -- | ------------------------------



There are no off-balance sheet arrangements
that have or are reasonably likely to have a current or future effect on our financial condition, changes of financial condition,
revenues, or expenses, results of operations, liquidity, capital expenditures or capital resources, which individually or in the
aggregate are material to our investors.



| | F. | TABULAR DISCLOSURE OF CONTRACTUAL OBLIGATIONS
| | -- | ---------------------------------------------



The following table illustrates the contractual
maturities of financial liabilities:



|                          |  | Payments Due by Period |          
|------------------------- |  | ---------------------- | ---------
|August 31, 2014           |  | Total                  |          
|Trade and others payables |  | $                      | 1,483,775
|Shareholders’ loans (1)   |  |                        | 981,834  
|Total                     |  | $                      | 2,465,609



SECURED NOTE PAYABLE AND SHAREHOLDERS’ LOANS



Secured Note Payable



At August 31, 2014, the Company exchanged
a secured note payable to Benchmark with a carrying value of $1,322,347 (US$1,216,175) for a secured convertible promissory note
payable to Benchmark with a face value of $1,322,347 (US$1,216,175) (the “Note”). The Note has an interest rate of
10%. The Note is due on the earliest to occur of: (a) August 31, 2015; (b) the closing of any subsequent financing or series of
financings by the Company that results in gross proceeds of an aggregate amount equal to or greater than US$4,400,000, excluding
conversion of any existing debt into equity; (c) the date of a sale by the Company of all of the shares in the capital stock of
Zavala Inc. held by the Company from time to time; (d) the closing of a merger, reorganization, take-over or other business combination
which results in a change of control of the Company or Zavala Inc.; or (e) an event of default.



In the event that the Company closes any
subsequent financing or series of financings that results in gross proceeds to the Company of an aggregate amount equal to or
greater than US$2,000,000, excluding conversion of any existing debt into equity of the Company, the Company shall allocate US$0.50
of every US$1.00 exceeding the US$2,000,000 raised from such financing to repay the Note. The Note is secured by all of the assets
of the Company and Zavala Inc. The Company may, in its sole discretion, prepay any portion of the principal amount upon seven
days’ notice. Benchmark has the option at any time while the Note is outstanding to convert any unpaid principal and accrued
interest into conversion units. A conversion unit is comprised of one (1) common share and one (1) common share purchase warrant
entitling the holder to acquire a common share of the Company at a price equal to a 15% premium to the price of the common share
acquired under the conversion unit. The price of the conversion unit is the lessor of a price equal to the 30-day VWAP of the
Company as of the date of conversion, less 20% (as adjusted for any stock splits, combinations or similar events) or eight United
States Cents (US$0.08) per share the “Conversion Unit”).



Accounting Considerations



The Company has accounted for this transaction
as an exchange of debt instruments. Under IAS 39 “Financial Instruments: Recognition and Measurement”., an exchange
between an existing borrower and lender of debt instruments with substantially different terms or substantial modification of
the terms of an existing financial liability of part thereof is accounted for as an extinguishment. Since the new debt instrument
has a conversion option, the terms are considered substantially different and therefore gives rise to extinguishment accounting.
Further, the Company analyzed the conversion unit under IAS 39 and determined that it meets the definition of an embedded derivative.
Since both components of the Conversion Unit (the common share component and warrant component) contain a variable exercise/conversion
price, the Conversion Unit meets the definition of a financial liability under IAS 32 “Financial Instruments: Presentation”.
As a result, the Conversion Unit is a derivative liability that requires fair value measurement each period.



51







Based on the previous conclusions, the
Company allocated the old note first to the derivative component at its fair value with the residual allocated to the host debt
contract, as follows:



|                                              |  | Allocation CDN$ |           
|--------------------------------------------- |  | --------------- | ----------
|Secured promissory note (old debt instrument) |  | $               | 1,322,347 
|Derivative liability (Conversion Unit)        |  |                 | (4,000,100
|Loss on exchange of debt instruments          |  |                 | 2,677,753 
|                                              |  | $               | -         



The Note will be accreted up to its face
value of $1,322,347 (US$1,216,175) over the life of Note based on an effective interest rate (see Note 11).



Shareholder Loans

Effective August 30, 2014, the Company
converted shareholders’ loans and interest due in the aggregate amount of $1,180,570 through the issuance of a total of
14,757,120 units in the capital of the Company at a price of $0.08 per unit. Each unit is comprised of one (1) common share and
one half of one (1/2) common share purchase warrant. Each full warrant entitles the holder to purchase one (1) common share at
an exercise price of CDN$0.10 until August 30, 2017. The fair value of the units ($2,516,505) was allocated to common shares $1,715,426
and warrants $801,079 based on their relative fair values and $1,335,935 was recorded as loss on settlement of debt. The original
terms of the debt did not include settlement by the issuance of equity instruments.



Accounting Considerations



The Company has accounted for this transaction
as an extinguishment of debt instruments for equity instruments under the guidance of IFRIC Interpretation 19 “Extinguishing
Financial Liabilities with Equity Instruments”. IFRIC 19 addresses the accounting of when the terms of a financial liability
are renegotiated and result in the entity issuing equity instruments to a creditor of the entity to extinguish all or part of
the financial liability. It states that if a debtor issues equity instruments to a creditor to extinguish all or part of a financial
liability, those equity instruments are 'consideration paid' in accordance with IAS 39.41. Accordingly, the debtor should derecognise
the financial liability fully or partly. IFRIC 19 further states that the debtor recognises in profit or loss the difference between
the carrying amount of the financial liability (or part) extinguished and the fair value of the equity instruments issued. As
result, the Company recorded a loss on extinguishment in the amount of $1,335,935 in profit and loss which is the difference of
the fair value of the equity instruments ($2,516,505) and the carrying value of the debt instruments ($1,180,570).



The warrant component was valued using
a Binomial Lattice model whereas the fair value of the common share component was based on the current market value of the company’s
stock. The fair value of the conversion unit ($2,516,505) was allocated to the common stock component ($1,715,426) and warrant
component ($801,079) based on their relative fair values. Significant assumptions utilized in the Binomial Lattice process are
as follows for the warrant component of the conversion unit as of August 30, 2014:



|                                                           |  | August 30, 2014 |           
|---------------------------------------------------------- |  | --------------- | ----------
|Market value on valuation date                             |  | $               | 0.16      
|Contractual exercise rate                                  |  | $               | 0.092     
|Term (years)                                               |  |                 | 5.00 Years
|Expected market volatility                                 |  |                 | 196.97    
|Risk free rate using zero coupon US Treasury Security rate |  |                 | 0.94      



PROVISIONS

|                                 |  | Decommissioning Provisions (Note a) |         |   | Other Provisions (Note b) |   |          | Total  Provisions | 
|-------------------------------- |  | ----------------------------------- | ------- | - | ------------------------- | - | -------- | ----------------- | 
|Balance, August 31, 2012         |  | $                                   | 114,755 |   |                           | $ | 125,917  |                   | 
|Accretion expense                |  |                                     | 3,071   |   |                           |   | -        |                   | 
|Change in estimate               |  |                                     | (5,104  | ) |                           |   | -        |                   | 
|Additions                        |  |                                     | -       |   |                           |   | 169,196  |                   | 
|Reductions                       |  |                                     | -       |   |                           |   | (125,917 | )                 | 
|Foreign exchange                 |  |                                     | 7,020   |   |                           |   | 9,357    |                   | 
|Balance, August 31, 2013         |  |                                     | 119,742 |   |                           |   | 178,553  |                   | 
|Accretion expense                |  |                                     | 961     |   |                           |   | -        |                   | 
|Change in estimate               |  |                                     | 7,225   |   |                           |   | -        |                   | 
|Disposals                        |  |                                     | (26,426 | ) |                           |   | -        |                   | 
|Reductions                       |  |                                     | -       |   |                           |   | (169,196 | )                 | 
|De-consolidation of Dyami Energy |  |                                     | (58,589 | ) |                           |   |          |                   | 
|Foreign exchange                 |  |                                     | 4,630   |   |                           |   | (9,357   | )                 | 
|Balance, August 31, 2014         |  | $                                   | 47,543  |   |                           | $ | -        |                   | 



52







a)	          Decommissioning Obligations

The Company’s decommissioning obligations
result from its ownership interests in petroleum and natural gas assets including well sites, gathering systems and processing
facilities. The total decommissioning obligation is estimated based on the Company’s net ownership interest in all wells
and facilities, estimated costs to reclaim and abandon these wells and facilities, and the estimated timing of the costs to be
incurred in future years. The Company has estimated the net present value of decommissioning obligations to be $47,543 ($11,768
current and $35,775 long term) at August 31, 2014 (August 31, 2013: $119,742) based on an undiscounted total future liability
of $60,629 (August 31, 2013: $166,578). These payments are expected to be incurred between 2016 and 2031. The discount factor,
being the risk free rate related to the liability is 2.57% (August 31, 2013: 3.09%). The above amount has been classified as long
term.



b)	          Other Provisions

In February 2013, a vendor of Dyami Energy
applied a lien on the Murphy #4 well and filed a claim in the District Court of Zavala County, Texas (Case No. 13-02-12941-ZCV)
seeking payment of US$169,196 for services. Dyami Energy was disputing the amount on the basis of negligence by the vendor. On
January 28, 2014 the vendor received a summary judgment against Dyami Energy in the amount of $169,196 plus interest at a rate
of 18% per annum from September 17, 2012 until paid and legal fees of $21,178 plus interest at a rate of 5% per annum from the
date of judgment until paid. The full amount of the provision had been recorded together with legal fees and interest. The provision,
legal fees and interest were transferred to trade and other payables (see Note 16 to the Consolidated Financial Statements).



In May
2012 a vendor of Dyami Energy filed a claim in the District Court of Harris County, Texas seeking payment of US$64,866. Dyami
Energy was disputing the amount charged due to faulty equipment. The full amount of the provision which was accrued in the prior
year 2012 was reversed in 2013 as the vendor is no longer in good standing as a Texas corporation and the vendor’s attorney
filed in the District Court of Harris County, Texas a motion to withdraw as counsel (see Note 16 to the Consolidated Financial
Statements).



In December 2011, a vendor of Dyami Energy
filed a claim in the District Court of Harris County, Texas (Case No. 2011-74035/Court: 113) seeking payment of US$62,800. Dyami
Energy disputed the claim on the basis of excessive charges. In December 2013 an agreed final judgment in favour of the vendor
was entered into court in the amount of $42,803 and post judgment interest at 5% per annum until paid in full. The provision was
transferred to trade and other payables (see Note 16 to the Consolidated Financial Statements).



DERIVATIVE LIABILITIES



Derivative Warrant Liabilities

The Company has warrants issued with an
exercise price in US dollars which are different from the functional currency of the Company (Canadian Dollars) and accordingly
the warrants are treated as a financial liability and the fair value movement during the period is recognized in the profit or
loss.



The following table set out the changes
in derivative warrant liabilities during the respective periods.



|                               |  | Number of Warrants* |          |   | Fair Value Assigned $ |  |           | Average Exercise Price US $ | 
|------------------------------ |  | ------------------- | -------- | - | --------------------- |  | --------- | --------------------------- | 
|As at August 31, 2012          |  |                     | 784,273  |   |                       |  | 1,640,406 |                             | 
|Warrants issued                |  |                     | 112,490  |   |                       |  | 163,541   |                             | 
|Broker warrants issued         |  |                     | 17,998   |   |                       |  | 44,895    |                             | 
|Change in fair value estimates |  |                     | -        |   |                       |  | 128,041   |                             | 
|As at August 31, 2013          |  |                     | 914,761  |   |                       |  | 1,976,883 |                             | 
|Warrants expired               |  |                     | (170,923 | ) |                       |  | (709,299  | )                           | 
|Change in fair value estimates |  |                     | -        |   |                       |  | 57,723    |                             | 
|As at August 31, 2014          |  |                     | 743,838  |   |                       |  | 1,325,307 |                             | 



* Reflects the March 16, 2012 two-for-one stock split and the
August 25, 2014 one-for-ten consolidation



53







On September 25, 2012 the Company issued
112,490 common share purchase warrants exercisable at US$5.00 and 17,998 common share purchase broker warrants exercisable at
US$2.50 expiring September 25, 2015. The fair value measured using the Black-Scholes option pricing model was $163,541 and $45,895,
respectively.



On August 31, 2014 170,923 warrants exercisable
at US$5.00 expired and the fair value measured using the Black-Scholes option pricing model of $709,299 was recorded as an increase
to contributed surplus.



The following tables set out the number
of derivative warrant liabilities outstanding at August 31, 2014 and 2013 respectively:



|Number of Warrants* |         |  | Exercise Price  US ($)* |  |      | Expiry  Date |  | Weighted Average Remaining  Life (Years) |  |  | Fair Value   CDN ($) | 
|------------------- | ------- |  | ----------------------- |  | ---- | ------------ |  | ---------------------------------------- |  |  | -------------------- | 
|                    | 187,500 |  |                         |  | 5.00 |              |  | April 13, 2015 (1)                       |  |  | 0.62                 | 
|                    | 30,000  |  |                         |  | 2.50 |              |  | April 13, 2015(1)                        |  |  | 0.62                 | 
|                    | 91,250  |  |                         |  | 5.00 |              |  | July 20, 2015(1)                         |  |  | 0.88                 | 
|                    | 14,600  |  |                         |  | 2.50 |              |  | July 20, 2015(1)                         |  |  | 0.88                 | 
|                    | 250,000 |  |                         |  | 5.00 |              |  | August 7, 2015(1)                        |  |  | 0.93                 | 
|                    | 40,000  |  |                         |  | 2.50 |              |  | August 7, 2015(1)                        |  |  | 0.93                 | 
|                    | 112,490 |  |                         |  | 5.00 |              |  | September 25, 2015                       |  |  | 1.07                 | 
|                    | 17,998  |  |                         |  | 2.50 |              |  | September 25, 2015                       |  |  | 1.07                 | 
|                    | 743,838 |  |                         |  |      |              |  |                                          |  |  | 0.70                 | 

| | (1) | Current
| | --- | -------

* Reflects the March 16, 2012 two-for-one stock split and the
August 25, 2014 one-for-ten consolidation



|Number of Warrants* |         |  | Exercise Price  US ($)* |  |      | Expiry  Date |  | Weighted Average Remaining  Life (Years) |  |  | Fair Value   CDN ($) | 
|------------------- | ------- |  | ----------------------- |  | ---- | ------------ |  | ---------------------------------------- |  |  | -------------------- | 
|                    | 170,923 |  |                         |  | 5.00 |              |  | August 31, 2014(1)                       |  |  | 1.00                 | 
|                    | 187,500 |  |                         |  | 5.00 |              |  | April 13, 2015                           |  |  | 1.62                 | 
|                    | 30,000  |  |                         |  | 2.50 |              |  | April 13, 2015                           |  |  | 1.62                 | 
|                    | 91,250  |  |                         |  | 5.00 |              |  | July 20, 2015                            |  |  | 1.88                 | 
|                    | 14,600  |  |                         |  | 2.50 |              |  | July 20, 2015                            |  |  | 1.88                 | 
|                    | 250,000 |  |                         |  | 5.00 |              |  | August 7, 2015                           |  |  | 1.93                 | 
|                    | 40,000  |  |                         |  | 2.50 |              |  | August 7, 2015                           |  |  | 1.93                 | 
|                    | 112,490 |  |                         |  | 5.00 |              |  | September 25, 2015                       |  |  | 2.07                 | 
|                    | 17,998  |  |                         |  | 2.50 |              |  | September 25, 2015                       |  |  | 2.07                 | 
|                    | 914,761 |  |                         |  |      |              |  |                                          |  |  | 1.70                 | 

(1) Current

* Reflects the March 16, 2012 two-for-one stock split and the
August 25, 2014 one-for-ten consolidation



The fair value of the warrants issued
during the year ended August 31, 2013, were estimated using the Black-Scholes option pricing model with the following assumptions:



|Black-Scholes Assumptions used |  | 2013 |           
|------------------------------ |  | ---- | ----------
|Risk-free interest rate        |  |      | 1.5       
|Expected volatility            |  |      | 217       
|Expected life (years)          |  |      | 3.00 Years
|Dividend yield                 |  |      | -         



Derivative Unit Liabilities

The following tables summarize the components
of the Company’s derivative liabilities reflected in US Dollars and linked common shares as at August 31, 2014:



54







|                                                                     |  | August 31, 2014 |           
|-------------------------------------------------------------------- |  | --------------- | ----------
|The financings giving rise to derivative financial instruments       |  | Indexed Shares  |           
|Conversion unit (1 common share and 1 common share purchase warrant) |  |                 | 15,202,188



The Company’s face value $1,322,347
(US$1,216,175) Secured Convertible Promissory Note issued on August 31, 2014 gave rise to a derivative financial instrument. As
more fully discussed in Note 10 the Company issued a face value $1,322,347 (US$1,216,175) Secured Convertible Promissory Note
on August 31, 2014 (the “Note”). The Note embodied certain terms and conditions that were not clearly and closely
related to the host debt agreement in terms of economic risks and characteristics. Additionally these features met the definition
of a financial liability under IAS 32 “Financial Instruments: Presentation”. These terms and features consist of the
conversion unit which is comprised of one (1) common share and one (1) common share purchase warrant entitling the holder to acquire
a common share of the Company at a price equal to a 15% premium to the price of the common share acquired under the conversion
unit.



Current accounting principles that are
provided in IAS 32 and IAS 39 require derivative financial instruments to be classified in liabilities and carried at fair value
with changes recorded in profit and loss. The Company has selected the Monte Carlo Simulations valuation technique to fair value
the common share component of the conversion unit because it believes that this technique is reflective of all significant assumption
types, and ranges of assumption inputs, that market participants would likely consider in transactions involving common share
components. Such assumptions include, among other inputs, interest risk assumptions, credit risk assumptions and redemption behaviors
in addition to traditional inputs for option models such as market trading volatility and risk free rates.



The Company has selected the Binomial
Lattice model to fair value the warrant component of the conversion unit because it believes this technique is reflective of all
significant assumption types market participants would likely consider in transactions involving warrants.



Significant inputs and results arising
from the Monte Carlo Simulations process are as follows for the common share component contained in the conversion unit:



|                                              |  | August 31, 2014 |                
|--------------------------------------------- |  | --------------- | ---------------
|Underlying price on valuation date*           |  | $               | 0.3090         
|Contractual conversion rate                   |  | $               | 0.08           
|Contractual term to maturity                  |  |                 | 1.00 Years     
|Implied expected term to maturity             |  |                 | 0.613 Years    
|Market volatility:                            |  |                 |                
|Range of volatilities                         |  |                 | 78.41% - 269.09
|Equivalent volatility                         |  |                 | 181.25         
|Contractual interest rate                     |  |                 | 10.0           
|Equivalent market risk adjusted interest rate |  |                 | 10.00          
|Equivalent credit risk adjusted yield         |  |                 | 3.45           



*The underlying price of the common share component of the
conversion unit is the sum of the market price on the valuation date and the fair value of the warrant component derived from
the binomial lattice model.



Significant assumptions utilized in the Binomial Lattice process
are as follows for the warrant component of the conversion unit as of August 31, 2014:



|                                                           |  | August 31, 2014 |           
|---------------------------------------------------------- |  | --------------- | ----------
|Market value on valuation date                             |  | $               | 0.16      
|Contractual exercise rate                                  |  | $               | 0.092     
|Term (years)                                               |  |                 | 5.00 Years
|Expected market volatility                                 |  |                 | 179.21    
|Risk free rate using zero coupon US Treasury Security rate |  |                 | 1.63      



55







| | G. | SAFE HARBOR
| | -- | -----------



Certain statements in Sections 5.E and
5.F of this Annual Report may constitute "forward looking statements" within the meaning of the United States Private
Securities Litigation Reform Act of 1995, Section 21E of the United States Securities Exchange Act of 1934, as amended, and Section
27A of the United States Securities Act of 1933, as amended. Such statements are generally identifiable by the terminology used
such as "plans", "expects", "estimates", "budgets", "intends", "anticipates",
"believes", "projects", "indicates", "targets", "objective", "could",
"may", or other similar words. The forward-looking statements are subject to known and unknown risks and uncertainties
and other factors that may cause actual results, levels of activity and achievements to differ materially from those expressed
or implied by such statements. Readers should not place undue reliance on any forward-looking statement and should recognize that
the statements are predictions of future results, which may not occur as anticipated.



| | ITEM 6. | DIRECTORS, SENIOR MANAGEMENT AND EMPLOYEES
| | ------- | ------------------------------------------



| | A. | DIRECTORS AND SENIOR MANAGEMENT
| | -- | -------------------------------



The following table sets forth the names
of all of our directors and executive officers as of the date of the filing of this Annual Report, with each position and office
held by them in our Company, and the period of their service as a director or as an officer.



|Name          |  | Age |    | Position with the Company |                                                                          | Date First Elected as Director
|------------- |  | --- | -- | ------------------------- | ------------------------------------------------------------------------ | ------------------------------
|James Cassina |  |     | 58 |                           | President, Chief Executive Officer, Chief Financial Officer and Director |                               
|Milton Klyman |  |     | 89 |                           | Director                                                                 |                               
|Colin McNeil  |  |     | 68 |                           | Director                                                                 |                               
|              |  |     |    |                           |                                                                          |                               

All of our directors’ serve until
our next Annual General Meeting or until a successor is duly elected, unless the office is vacated in accordance with our Articles
or Bylaws.  Subject to the terms of their employment agreements, if any, executive officers are appointed by the Board
of Directors to serve until the earlier of their resignation or removal, with or without cause by the directors.  James
Cassina, our sole executive officer, devotes approximately 85% of his work time to his duties as an officer and director.



There are no family relationships between
any of our directors or executive officers.  There are no arrangements or understandings between any two or more directors
or executive officers.



Mr. Cassina has been an officer since
June 18, 2010 a director of ours since February 9, 2010. Mr. Cassina is the President of Eagleford Energy, Zavala Inc. our Nevada
subsidiary. As Chairman of Assure Energy, Inc. (“Assure”) (OTCBB: ASUR), an oil and gas exploration and production
company, Mr. Cassina led Assure’s merger in September 2005 with Geocan Energy Inc. (TSX: GCA) (“Geocan”), an
oil and gas company which then grew to daily production of over 3,700 barrels of oil or gas equivalents. Mr. Cassina thereafter
served as a Director of Geocan and later Chairperson of its Board appointed Special Advisory Committee formed to seek strategic
alternatives to enhance shareholder value. Subsequently Geocan merged with Arsenal Energy Inc. in October 2008. .



Mr. Milton Klyman has been a director
of ours since November 15, 1996.  Mr. Klyman was also our Treasurer from December 31, 2003 to December 28, 2007. From
February 27, 2009 to present, Mr. Klyman has been a director of 1354166 Alberta Ltd., our Alberta subsidiary. Mr. Klyman is a
self-employed financial consultant and has been a Chartered Accountant since 1952. Mr. Klyman is a Life Member of the Canadian
Institute of Chartered Accountants.  Mr. Klyman serves as a director on the board of Western Troy Capital Resources
Inc.



Mr. Colin McNeil has been a director of
ours since June 18, 2010. Mr. McNeil is a self-employed oil and gas consultant and has been a geophysicist since 1972. Mr. McNeil
has managed exploration programs and structured technical assessments for companies in the Middle East, Africa, Asia, Central
and South America, the Arctic, and Canada. Mr. McNeil is a member of the Association of Professional, Engineers, Geologists and
Geophysicists of Alberta, Society of Exploration Geophysicists, Canadian Society of Exploration Geophysicists, American Association
of Petroleum Geologists and the Canadian Society of Petroleum Geologists.



56







| | B. | COMPENSATION
| | -- | ------------



Executive Compensation



The following table presents a summary
of all annual and long-term compensation paid or accrued by us including our subsidiaries, for services rendered to us by our
executive officers and directors in any capacity for the year ended August 31, 2014.



|Summary Compensation Table (CDN$)                                 
|------------------------------------------------------------------
|Name and Principal Position                                       
|                                                                  
|James
Cassina, Chief Executive Officer, President and Director (4)
|Milton Klyman, Director                                           
|Colin McNeil, Director                                            



| | (1) | Management fees.
| | --- | ----------------

| | (2) | These amounts represent the value
                                         of stock options granted. The fair value of the option grated is estimated on the date
                                         of grant using the Black Scholes option pricing model taking into account the following
                                         assumptions: (i) risk free interest rate (%); (ii) expected life (years); (iii) expected
                                         volatility (%). This is consistent with the accounting values used in the Company’s
                                         consolidated financial statements. The dollar amount in the column represents the total
                                         value ascribed to the stock options.
| | --- | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------

| | (3) | Accrued on account of directors fees at a rate of $100 per meeting.
| | --- | -------------------------------------------------------------------



Outstanding Option-Based Awards

The following table sets forth the outstanding option-based
awards for the Company held by executive officers and directors at August 31, 2014.



|                                                               |  | Option-based Awards (CDN$)                                  |       
|-------------------------------------------------------------- |  | ----------------------------------------------------------- | ------
|Name                                                           |  | Number of Securities underlying unexercised options (#) (1) |       
|James Cassina, Chief Executive Officer, President and Director |  |                                                             | 20,000
|Milton Klyman, Director                                        |  |                                                             | 20,000
|Colin McNeil, Director                                         |  |                                                             | 20,000



| | (1) | On March 1, 2012, the Company granted
                                         options to purchase 60,000 common shares to directors. These options are exercisable
                                         at $1.60per share, vest immediately and expire on February 28, 2017.
| | --- | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------

| | (2) | Calculated using the closing price
                                         of the Company’s common shares of the OTCQB on August 29, 2014 of US$0.21 and subtracting
                                         the exercise price of in-the-money stock options.
| | --- | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------

| | (3) | Converted to Canadian dollars using
                                         the Bank of Canada noon exchange rate on August 29, 2014.
| | --- | --------------------------------------------------------------------------------------------------------------------------------------



Compensation Discussion and Analysis



Objective of the Compensation Program



The objectives of the Company's compensation
program are to attract, hold and inspire performance of its named executive officers (“NEOs”) of a quality and nature
that will enhance the sustainable profitability and growth of the Company. The Company views it as an important objective of the
Company's compensation program to ensure staff retention.



57







The Compensation Review Process



To determine compensation payable, the
compensation committee of the Company (the "Compensation Committee") determines an appropriate compensation reflecting
the need to provide incentive and compensation for the time and effort expended by the NEOs of the Company while taking into account
the financial and other resources of the Company.



The Company’s Compensation Committee
is comprised of Milton Klyman (Chair) and Colin McNeil. The Compensation Committee is comprised entirely of independent directors.
Compensation is determined in the context of our strategic plan, our growth, shareholder returns and other achievements and considered
in the context of position descriptions, goals and the performance of each NEO. With respect to directors’ compensation,
the Compensation Committee reviews the level and form of compensation received by the directors, members of each committee, the
board chair and the chair of each board committee, considering the duties and responsibilities of each director, his or her past
service and continuing duties in service to us. The compensation of directors, the CEO and executive officers of competitors are
considered, to the extent publicly available, in determining compensation and the Compensation Committee has the power to engage
a compensation consultant or advisor to assist in determining appropriate compensation.



Elements of Executive Compensation



The Company's NEO compensation program
is based on the objectives of: (a) recruiting and retaining the executives critical to the success of the Company; (b) providing
fair and competitive compensation; (c) balancing the interests of management and shareholders of the Company; and (d) rewarding
performance, on the basis of both individual and corporate performance.



For the financial year ended August 31,
2014, the Company's NEO compensation program consisted of the following elements:



| | (a) | a management fee (the "Short-Term
                                         Incentive").
| | --- | ---------------------------------------------------------------------------------------



| | (b) | a long-term equity compensation
                                         consisting of stock options granted under the Company's stock incentive plan ("Long-Term
                                         Incentive").
| | --- | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



The specific rationale and design of each
of these elements are outlined in detail below.



Short-Term Incentive

Salaries form an essential element of
the Company's compensation mix as they are the first base measure to compare and remain competitive relative to peer groups. Base
salaries are fixed and therefore not subject to uncertainty and are used as the base to determine other elements of compensation
and benefits. The base salary provides an immediate cash incentive for the Named Executive Officers. The Compensation Committee
and the Board review salaries at least annually.



Base salary/management fees of the Named
Executive Officers is set by the Compensation Committee on the basis of the applicable officer’s responsibilities, experience
and past performance. In determining the base salary to be paid to a particular Named Executive Officer, the Compensation Committee
considers the particular responsibilities related to the position, the experience level of the officer, and his or her past performance
at the Company and the current financial position of the Company.



Long-Term Incentive

The granting of stock options is a variable
component of compensation intended to reward the Company's Named Executive Officers for their success in achieving sustained,
long-term profitability and increases in stock value. Stock options ensure that the Named Executive Officers are motivated to
achieve long-term growth of the Company and continuing increases in shareholder value. In terms of relative emphasis, the Company
places more importance on stock options.



58







The Company provides long-term incentive
compensation through its stock option plan. The Compensation Committee recommends the granting of stock options from time to time
based on its assessment of the appropriateness of doing so in light of the long-term strategic objectives of the Company, its
current stage of development, the need to retain or attract particular key personnel, the number of stock options already outstanding
and overall market conditions. The Compensation Committee views the granting of stock options as a means of promoting the success
of the Company and higher returns to its shareholders. The Board grants stock options after reviewing recommendations made by
the Compensation Committee.



Stock Option Plan

The Company’s Amended Stock Option
Plan (the "Plan") was adopted by the board of directors on January 20, 2012 and approved by a majority of our shareholders
voting at the Annual and Special Meeting held on February 24, 2012.  The Plan was adopted in order that we may be able
to provide incentives for directors, officers, employees, consultants and other persons (an "Eligible Individual") to
participate in our growth and development by providing us with the opportunity through share options to acquire an ownership interest
in us.  Directors and officers currently are not remunerated for their services except as stated in "Executive
Compensation" above.



The maximum number of common shares which
may be set aside for issue under the Plan is an amount not to exceed 20% of the total shares issued and outstanding of the Company
as of the date of each Option grant provided that the board has the right, from time to time, to increase such number subject
to the approval of our shareholders and any relevant stock exchange or other regulatory authority.   Any common
shares subject to an option, which are not exercised, will be available for subsequent grant under the Plan.  The option
price of any common shares is to be determined by the Board in its sole discretion.



Options granted under the Plan may be
exercised during a period no exceeding five years, subject to earlier termination upon the optionee ceasing to be an Eligible
Individual, or, in accordance with the terms of the grant of the option.  The options are non-transferable and non-assignable
except between an Eligible Individual and a related corporation controlled by such Eligible Individual upon the consent of the
board of directors.  The Plan contains provisions for adjustment in the number of shares issuable there under in the
event of subdivision, consolidation, reclassification, reorganization or change in the number of common shares, a merger or other
relevant change in the Company’s capitalization.  The board of directors may from time to time amend or revise
the terms of the Plan or may terminate the Plan at any time. The Company does not have any other long-term incentive plans, including
any supplemental executive retirement plans.



Overview of How the Compensation
Program Fits with Compensation Goals



The compensation package is designed to
meet the goal of attracting, holding and motivating key talent in a highly competitive oil and gas exploration environment through
salary and providing an opportunity to participate in the Company’s growth through stock options. Through the grant of stock
options, if the price of the Company shares increases over time, both the Named Executive Officer and shareholders will benefit.



Incentive Plan Awards

At August 31, 2014 the Company has outstanding
60,000 stock options exercisable at $$1.60until February 28, 2017 to Named Executive Officers and directors.



Pension Plan Benefits

The Company does not currently provide
pension plan benefits to its Named Executive Officers.



Termination and Change of Control Benefits

The Company does not currently have executive
employment agreements in place with any of its Named Executive Officers.



The Company has no compensatory plan,
contract or arrangement where a named executive officer or director is entitled to receive compensation in the event of resignation,
retirement, termination, change of control or a change in responsibilities following a change in control.



Director Compensation

Each director of the Company is entitled
to receive the sum of $100 for each meeting of the directors, meeting of a committee of the directors or meeting of the shareholders
attended. During the fiscal year ended August 31, 2014 no amount was paid by the Company with respect to such fees.



59







Retirement Policy for Directors

The Company does not have a retirement
policy for its directors.



Directors’ and Officers’ Liability Insurance

The Company does not maintain directors’
and officers’ liability insurance.



| | C. | BOARD PRACTICES
| | -- | ---------------



Board of Directors

The mandate of our board of directors,
prescribed by the Business Corporations Act (Ontario), is to manage or supervise the management of our business and affairs and
to act with a view to our best interests. In doing so, the board oversees the management of our affairs directly and through its
committees.



The term of Mr. Klyman as a director began
on August 10, 2000. Mr. Cassina was appointed as a director on February 9, 2010, and Mr. McNeil who was appointed on June 18,
2010. Our directors’ serve until our next Annual General Meeting or until a successor is duly elected, unless the office
is vacated in accordance with our Articles or Bylaws.  Our sole executive officer was appointed by our Board of Directors
to serve until the earlier of his resignation or removal, with or without cause by the directors. There was no compensation paid
by us to our directors during the fiscal year ended August 31, 2014 for their services in their capacity as directors or any compensation
paid to committee members.



As of the date of this Annual Report our
board of directors consists of three directors, two of which are "independent directors" in that they are "independent
from management and free from any interest and any business or other relationship which could, or could reasonably be perceived
to, materially interfere with the directors ability to act with a view to our best interests, other than interests and relationships
arising from shareholding".  The independent directors are Milton Klyman and Colin McNeil.  It is our
practice to attempt to maintain a diversity of professional and personal experience among our directors.



The independent directors of the Company
do not hold regularly scheduled meetings at which non-independent directors and members of management are not in attendance. The
Company holds meetings as required, at which the opinions of the independent directors are sought and duly acted upon for all
material matters relating to the Company.



Directorships

The following directors of ours are directors
of other Canadian or United States reporting issuers as follows:



|Milton Klyman | Western Troy Capital Resources Inc.
|------------- | -----------------------------------



Board and Committee Meetings

The board of directors has met at least once annually or otherwise
as circumstances warrant to review our business operations, corporate governance and financial results.  The table below
reflects the attendance of each director of ours at each Board and committee meeting of the Board during the fiscal year ended
August 31, 2014.



|Name              |  | Board of
        Directors
        Meetings |  |  | Audit
        Committee
        Meetings |  | Compensation
        Committee
        Meetings |  | Petroleum and
        Natural Gas
        Committee
        Meetings |  | Disclosure
        Committee
        Meetings
|----------------- |  | ------------------------------------------- |  |  | ---------------------------------------- |  | ----------------------------------------------- |  | -------------------------------------------------------------------- |  | ---------------------------------------------
|Milton Klyman     |  | 4                                           |  |  | 4                                        |  | 1                                               |  | 1                                                                    |  | Nil                                          
|James Cassina     |  | 4                                           |  |  | 4                                        |  | 1                                               |  | 1                                                                    |  | Nil                                          
|Colin McNeil      |  | 4                                           |  |  | 4                                        |  | 1                                               |  | 1                                                                    |  | Nil                                          
|Alan D. Gaines(1) |  | 1                                           |  |  | Nil                                      |  | Nil                                             |  | Nil                                                                  |  | Nil                                          



| | (1) | Alan Gaines resigned as a director
                                         of the Company on February 26, 2014.
| | --- | ----------------------------------------------------------------------------------------------------------------



60







Board Mandate

The Board assumes responsibility for stewardship
of the Company, including overseeing all of the operation of the business, supervising management and setting milestones for the
Company. The Board reviews the statements of responsibilities for the Company including, but not limited to, the code of ethics
and expectations for business conduct.



The Board approves all significant decisions
that affect the Company and its subsidiaries and sets specific milestones towards which management directs their efforts.



The Board ensures, at least annually,
that there are long-term goals and a strategic planning process in place for the Company and participates with management directly
or through its committees in developing and approving the mission of the business of the Company and the strategic plan by which
it proposes to achieve its goals, which strategic plan takes into account, among other things, the opportunities and risks of
the Company's business. The strategic planning process is carried out at each Board meeting where there are regularly reviewed
specific milestones for the Company.



The strategic planning process incorporates
identifying the main risks to the Company's objectives and ensuring that mitigation plans are in place to manage and minimize
these risks. The Board also takes responsibility for identifying the principal risks of the Company's business and for ensuring
these risks are effectively monitored and mitigated to the extent practicable. The Board appoints senior management.



The Company adheres to regulatory requirements
with respect to the timeliness and content of its disclosure. The Board approves all of the Company's major communications, including
annual and quarterly reports and press releases. The Chief Executive Officer authorizes the issuance of news releases. The Chief
Executive Officer is generally the only individual authorized to communicate with analysts, the news media and investors about
information concerning the Company.



The Board and the audit committee of the
Company (the "Audit Committee") examines the effectiveness of the Company's internal control processes and information
systems.



The Board as a whole, given its small
size, is involved in developing the Company's approach to corporate governance. The number of scheduled board meetings varies
with circumstances. In addition, special meetings are called as necessary. The Chief Executive Officer establishes the agenda
at each Board meeting and submits a draft to each director for their review and recommendation for items for inclusion on the
agenda. Each director has the ability to raise subjects that are not on the agenda at any board meeting. Meeting agendas and other
materials to be reviewed and/or discussed for action by the Board are distributed to directors in time for review prior to each
meeting. Board members have full and free access to senior management and employees of the Company.



Position Descriptions

The Board has not developed written position
descriptions for the Chairman of the Board or the Chief Executive Officer. The Board is currently of the view that the respective
corporate governance roles of the Board and management, as represented by the Chief Executive Officer, are clear and that the
limits to management's responsibility and authority are well-defined.



Each of the Audit Committee, Compensation
Committee, Disclosure Committee and a Petroleum and Natural Gas Committee has a chair and a mandate.



Orientation and Continuing Education

We have developed an orientation program
for new directors including a director’s manual ("Director’s Manual") which contains information regarding
the roles and responsibilities of the board, each board committee, the board chair, the chair of each board committee and our
president. The Director’s Manual contains information regarding its organizational structure, governance policies including
the Board Mandate and each Board committee charter, and our code of business conduct and ethics. The Director’s Manual is
updated as our business, governance documents and policies change. We update and inform the board regarding corporate developments
and changes in legal, regulatory and industry requirements affecting us.



61







Ethical Business Conduct

We have adopted a written code of business
conduct and ethics (the "Code") for our directors, officers and employees. The board encourages following the
Code by making it widely available. It is distributed to directors in the Director’s Manual and to officers, employees and
consultants at the commencement of their employment or consultancy.  The Code reminds those engaged in service to us
that they are required to report perceived or actual violations of the law, violations of our policies, dangers to health, safety
and the environment, risks to our property, and accounting or auditing irregularities to the chair of the Audit Committee who
is an independent director of ours. In addition, to requiring directors, officers and employees to abide by the Code, we encourage
consultants, service providers and all parties who engage in business with us to contact the chair of the Audit Committee regarding
any perceived and all actual breaches by our directors, officers and employees of the Code. The chair of our Audit Committee is
responsible for investigating complaints, presenting complaints to the applicable board committee or the board as a whole, and
developing a plan for promptly and fairly resolving complaints. Upon conclusion of the investigation and resolution of a complaint,
the chair of our Audit Committee will advise the complainant of the corrective action measures that have been taken or advise
the complainant that the complaint has not been substantiated. The Code prohibits retaliation by us, our directors and management,
against complainants who raise concerns in good faith and requires us to maintain the confidentiality of complainants to the greatest
extent practical. Complainants may also submit their concerns anonymously in writing. In addition to the Code, we have an Audit
Committee Charter and a Policy of Procedures for Disclosure Concerning Financial/Accounting Irregularities.



Since the beginning of our most recently
completed financial year, no material change reports have been filed that pertain to any conduct of a director or executive officer
that constitutes a departure from the Code. The board encourages and promotes a culture of ethical business conduct by appointing
directors who demonstrate integrity and high ethical standards in their business dealings and personal affairs. Directors are
required to abide by the Code and expected to make responsible and ethical decisions in discharging their duties, thereby setting
an example of the standard to which management and employees should adhere. The board is required by the Board Mandate to satisfy
our CEO and other executive officers are acting with integrity and fostering a culture of integrity throughout the Company. The
board is responsible for reviewing departures from the Code, reviewing and either providing or denying waivers from the Code,
and disclosing any waivers that are granted in accordance with applicable law. In addition, the board is responsible for responding
to potential conflict of interest situations, particularly with respect to considering existing or proposed transactions and agreements
in respect of which directors or executive officers advise they have a material interest. The Board Mandate requires that directors
and executive officers disclose any interest and the extent, no matter how small, of their interest in any transaction or agreement
with us, and that directors excuse themselves from both board deliberations and voting in respect of transactions in which they
have an interest. By taking these steps the board strives to ensure that directors exercise independent judgment, unclouded by
the relationships of the directors and executive officers to each other and us, in considering transactions and agreements in
respect of which directors and executive officers have an interest.



Nomination of Directors

The Board has not appointed a nominating
committee and does not believe that such a committee is warranted at the present time. The entire Board determines new nominees
to the Board, although a formal process has not been adopted. The nominees are generally the result of recruitment efforts by
the Board members, including both formal and informal discussions among Board members and officers. The Board generally looks
for the nominee to have direct experience in the oil and gas business and significant public company experience. The nominee must
not have a significant conflicting public company association.



Compensation

The Board determines director and executive
officer compensation by recommendation of the Compensation Committee. The Company's Compensation Committee reviews the amounts
and effectiveness of compensation. Each of the members of the Compensation Committee are independent. The Board reviews the adequacy
and form of compensation and compares it to other companies of similar size and stage of development. There is no minimum share
ownership requirement of directors.



The Compensation Committee generally convenes
at least once annually to review director and officer compensation and status of stock options. The Compensation Committee also
responds to requests from management and the Board to review recommendations of management for new senior employees and their
compensation. The Compensation Committee has the power to approve and/or amend these recommendations.



The Company has felt no need to retain
any compensation consultants or advisors at any time since the beginning of the Company's most recently completed financial year.



Committees of the Board

Our board of directors discharges its
responsibilities directly and through committees of the board of directors, currently consisting of the Audit Committee, a compensation
committee (the "Compensation Committee"), a disclosure committee (the "Disclosure Committee")
and a petroleum and natural gas committee (the "Petroleum and Natural Gas Committee").



62







Each of the Audit Committee, Disclosure
Committee and the Petroleum and Natural Gas Committee consists of a majority of independent directors, while the Compensation
Committee consists of independent directors.  Each Committee has a specific mandate and responsibilities, as reflected
in the charters for each committee.



Audit Committee

The mandate of the Audit Committee is
formalized in a written charter.  The members of the Audit Committee are James Cassina, Milton Klyman (Chair) and Colin
McNeil. Based on his professional certification and experience, the board has determined that Milton Klyman is an Audit Committee
Financial Expert and that James Cassina and Colin McNeil are financially literate. The Audit Committee's primary duties and responsibilities
are to serve as an independent and objective party to monitor our financial reporting process and control systems, review and
appraise the audit activities of our independent auditors, financial and senior management, and the lines of communication among
the independent auditors, financial and senior management, and the board of directors for financial reporting and control matters
including investigating fraud, illegal acts or conflicts of interest.



Compensation Committee

The mandate of the Compensation Committee
is formalized in a written charter. The members of the Compensation Committee are Colin McNeil and Milton Klyman (Chair).  The
Compensation Committee is comprised entirely of independent directors. Compensation is determined in the context of our strategic
plan, our growth, shareholder returns and other achievements and considered in the context of position descriptions, goals and
the performance of each individual director and officer. With respect to directors’ compensation, the Compensation Committee
reviews the level and form of compensation received by the directors, members of each committee, the board chair and the chair
of each board committee, considering the duties and responsibilities of each director, his or her past service and continuing
duties in service to us. The compensation of directors, the CEO, CFO and executive officers of competitors are considered, to
the extent publicly available, in determining compensation and the Compensation Committee has the power to engage a compensation
consultant or advisor to assist in determining appropriate compensation.



Disclosure Committee

The mandate of the Disclosure Committee
is formalized in a written charter. The members of the Disclosure Committee are Milton Klyman, Colin McNeil and James Cassina
(Chair).  The Committee's duties and responsibilities include, but are not limited to, review and revise our controls
and other procedures ("Disclosure and Controls Procedures") to ensure that (i) information required by us to be disclosed
to the applicable regulatory authorities and other written information that we will disclose to the public is reported accurately
and on a timely basis, and (ii) such information is accumulated and communicated to management, as appropriate to allow timely
decisions regarding required disclosure; assist in documenting and monitoring the integrity and evaluating the effectiveness of
the Disclosure and Control Procedures; the identification and disclosure of material information about us, the accuracy completeness
and timeliness of our financial reports and all communications with the investing public are timely, factual and accurate and
are conducted in accordance with applicable legal and regulatory requirements.



Petroleum and Natural Gas Committee

The members of the Petroleum and Natural
Gas Committee are Milton Klyman, James Cassina and Colin McNeil (Chair).  The Petroleum and Natural Gas Committee has
the responsibility of meeting with the independent engineering firms commissioned to conduct the reserves evaluation on our oil
and natural gas assets and to discuss the results of such evaluation with each of the independent engineers and management.  Specifically,
the Petroleum and Natural Gas Committee’s responsibilities include, but are not limited to, a review of management’s
recommendations for the appointment of independent engineers, review of the independent engineering reports and considering the
principal assumptions upon which such reports are based, appraisal of the expertise of the independent engineering firms retained
to evaluate our reserves, review of the scope and methodology of the independent engineers’ evaluations, reviewing any problems
experienced by the independent engineers in preparing the reserve evaluation, including any restrictions imposed by management
or significant issues on which there was a disagreement with management and a review of reserve additions and revisions which
occur from one report to the next.



63







Assessments

The board assesses, on an annual basis,
the contributions of the board as a whole, the Audit Committee and each of the individual directors, in order to determine whether
each is functioning effectively. The board monitors the adequacy of information given to directors, communication between the
board and management and the strategic direction and processes of the board and committees.  The Audit Committee will
annually review the Audit Committee Charter and recommend, if any, revisions to the board as necessary.



Relevant Education and Experience of Audit Committee Members

Milton Klyman is the Chairman of the Audit
Committee.  He is a self-employed financial consultant and has been a Chartered Accountant since 1952.  Milton
Klyman is a Life Member of the Institute of Chartered Accountants of Ontario, a Life member of the Canadian Institute of Mining
Metallurgy and Petroleum and a Fellow of the Institute of Chartered Secretaries and Administrators.



James Cassina is a consultant in business
development, mergers and acquisitions and corporate finance. James Cassina has served as a director and held various executive
positions with public companies.



Colin McNeil is an independent consulting
geophysicist and has managed exploration programs and structured technical assessments for companies in the Middle East, Africa,
Asia, Central and South America, the Arctic, and Canada Colin McNeil has served as a director and held various positions with
public and private companies.



Audit Committee Charter

| | • | Our Audit Committee Charter
                                         (the “Charter”) has been adopted by our board of directors.  The
                                         Audit Committee of the board (the “Committee”) will review and reassess this
                                         charter annually and recommend any proposed changes to the board for approval.  The
                                         Audit Committee’s primary duties and responsibilities are to:
| | - | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | • | Oversee (i) the integrity
                                         of our financial statements; (ii) our compliance with legal and regulatory requirements;
                                         and (iii) the independent auditors’ qualifications and independence.
| | - | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | • | Serve as an independent and
                                         objective party to monitor our financial reporting processes and internal control systems.
| | - | ---------------------------------------------------------------------------------------------------------------------------------------------------------------



| | • | Review and appraise the audit
                                         activities of our independent auditors and the internal auditing functions.
| | - | --------------------------------------------------------------------------------------------------------------------------------------------------



| | • | Provide open lines of communication
                                         among the independent auditors, financial and senior management, and the board for financial
                                         reporting and control matters.
| | - | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



Role and Independence: Organization

The Committee assists the board on fulfilling
its responsibility for oversight of the quality and integrity of our accounting, auditing, internal control and financial reporting
practices.  It may also have such other duties as may from time to time be assigned to it by the board.



The Audit Committee is to be comprised
of at least three directors.  The majority of the Committee members must be independent from management and free from
any relationship that, in the opinion of the Board, would interfere with the exercise of his or her independent judgment as a
member of the Committee.



All members shall, to the satisfaction
of the board, be financially literate (i.e. will have the ability to read and understand a balance sheet, an income statement,
a cash flow statement and the notes attached thereto), and at least one member shall have accounting or related financial management
expertise to qualify as “financially sophisticated”.  A person will qualify as “financially sophisticated”
if an individual who possesses the following attributes:



| | • | an understanding of financial
                                         statements and generally accepted accounting principles;
| | - | -------------------------------------------------------------------------------------------------------------------------------



| | • | an ability to assess the general
                                         application of such principles in connection with the accounting for estimates, accruals
                                         and reserves;
| | - | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



64







| | • | experience preparing, auditing,
                                         analyzing or evaluating financial statements that present a breadth and level of complexity
                                         of accounting issues that are generally comparable to the breadth and complexity of issues
                                         that can reasonably be expected to be raised by our financial statements, or experience
                                         actively supervising one or more persons engaged in such activities;
| | - | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | • | an understanding of internal
                                         controls and procedures for financial reporting; and
| | - | --------------------------------------------------------------------------------------------------------------------------



| | • | an understanding of audit
                                         committee functions.
| | - | ---------------------------------------------------------------------------------------



Colin McNeil and Milton Klyman are “independent”
as defined by the Securities and Exchange Commission, and the Board has determined that Milton Klyman is an “audit committee
financial expert” as defined in Item 401(h) of Regulation S-K promulgated by the Securities and Exchange Commission.



The Committee members will be elected
annually at the first meeting of the Board following the annual meeting of shareholders.  Each member of the Committee
serves during the pleasure of the Board and, in any event, only so long as he or she is a director.



One member of the Committee shall be appointed
as chair.  The chair shall be responsible for leadership of the Committee, including scheduling and presiding over meetings
and making regular reports to the Board.  The chair will also maintain regular liaison with the CEO, CFO, and the lead
independent audit partner.



Responsibilities and Powers

Although the Committee may wish to consider
other duties from time to time, the general recurring activities of the Committee in carrying out its oversight role are described
below.



| | · | Annual
                                         review and revision of the Charter as necessary with the approval of the board.
| | - | -------------------------------------------------------------------------------------------------------------------------------



| | · | Review
                                         and obtain from the independent auditors a formal written statement delineating all relationships
                                         between the auditor and us, consistent with Independence Standards Board Standard 1.
| | - | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | · | Recommending
                                         to the board the independent auditors to be retained (or nominated for shareholder approval)
                                         to audit our financial statements.  Such auditors are ultimately accountable
                                         to the board and the Committee, as representatives of the shareholders.
| | - | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | · | Evaluating,
                                         together with the board and management, the performance of the independent auditors and,
                                         where appropriate, replacing such auditors.
| | - | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | · | Obtaining
                                         annually from the independent auditors a formal written statement describing all relationships
                                         between the auditors and us. The Committee shall actively engage in a dialogue with the
                                         independent auditors with respect to any relationship that may impact the objectivity
                                         and the independence of the auditors and shall take, or recommend that the board take,
                                         appropriate actions to oversee and satisfy itself as to the auditors’ independence.
| | - | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | · | Ensuring
                                         that the independent auditors are prohibited from providing the following non-audit services
                                         and determining which other non-audit services the independent auditors are prohibited
                                         from providing:
| | - | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | o | Bookkeeping
                                         or other services related to our accounting records or consolidated financial statements;
| | - | ----------------------------------------------------------------------------------------------------------------------------------------------

| | o | Financial
                                         information systems design and implementation;
| | - | -------------------------------------------------------------------------------------------------

| | o | Appraisal
                                         or valuation services, fairness opinions, or contribution-in-kind reports;
| | - | -----------------------------------------------------------------------------------------------------------------------------

| | o | Actuarial
                                         services;
| | - | ------------------------------------------------------------

| | o | Internal
                                         audit outsourcing services;
| | - | -----------------------------------------------------------------------------

| | o | Management
                                         functions or human resources;
| | - | ---------------------------------------------------------------------------------

| | o | Broker
                                         or dealer, investment advisor or investment banking services;
| | - | -------------------------------------------------------------------------------------------------------------

| | o | Legal
                                         services and expert services unrelated to the audit; and
| | - | -------------------------------------------------------------------------------------------------------

| | o | Any
                                         other services which the Public Company Accounting Oversight Board determines to be impermissible.
| | - | -----------------------------------------------------------------------------------------------------------------------------------------------



| | · | Approving
                                         any permissible non-audit engagements of the independent auditors.
| | - | ---------------------------------------------------------------------------------------------------------------------

| | · | Meeting
                                         with our auditors and management to review the scope of the proposed audit for the current
                                         year, and the audit procedures to be used, and to approve audit fees.
| | - | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



65







| | · | Reviewing
                                         the audited consolidated financial statements and discussing them with management and
                                         the independent auditors.  Consideration of the quality our accounting principles
                                         as applied in its financial reporting.  Based on such review, the Committee
                                         shall make its recommendation to the Board as to the inclusion of our audited consolidated
                                         financial statement in our Annual Report to Shareholders.
| | - | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | · | Discussing
                                         with management and the independent auditors the quality and adequacy of and compliance
                                         with our internal controls.
| | - | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | · | Establishing
                                         procedures: (i) for receiving, handling and retaining of complaints received by us regarding
                                         accounting, internal controls, or auditing matters, and (ii) for employees to submit
                                         confidential anonymous concerns regarding questionable accounting or auditing matters.
| | - | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | · | Review
                                         and discuss all related party transactions involving us.
| | - | --------------------------------------------------------------------------------------------------------



| | · | Engaging
                                         independent counsel and other advisors if the Committee determines that such advisors
                                         are necessary to assist the Committee in carrying out its duties.
| | - | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | · | Publicly
                                         disclose the receipt of warning about any violations of corporate governance rules.
| | - | -------------------------------------------------------------------------------------------------------------------------------------



Authority

The Committee will have the authority
to retain special legal, accounting or other experts for advice, consultation or special investigation.  The Committee
may request any officer or employee of ours, our outside legal counsel, or the independent auditor to attend a meeting of the
Committee, or to meet with any member of, or consultants to, the Committee.  The Committee will have full access to
our books, records and facilities.



Meetings

The Committee shall meet at least yearly,
or more frequently as the Committee considers necessary.  Opportunities should be afforded periodically to the external
auditor and to senior management to meet separately with the independent members of the Committee. Meetings may be with representatives
of the independent auditors, and appropriate members of management, all either individually or collectively as may be required
by the Chairman of the Committee.



The independent auditors will have direct
access to the Committee at their own initiative.



The Chairman of the Committee will report
periodically the Committee’s findings and recommendations to the board of directors.



| | D. | EMPLOYEES
| | -- | ---------



As of August 31, 2014 and the date of
the filing of this Annual Report we did not have any employees other than our sole executive officer.



| | E. | SHARE OWNERSHIP
| | -- | ---------------



Our common shares are owned by Canadian
residents, United States residents and residents of other countries.  The only class of our securities, which is outstanding
as of the date of the filing of this Annual Report, is common stock.  All holders of our common stock have the same
voting rights with respect to their ownership of our common stock.



The following table sets forth as of November
28, 2014, certain information with respect to the amount and nature of beneficial ownership of the common stock held by (i) each
person known to our management to be the beneficial owner of more than 5% of our outstanding shares of common stock; (ii) each
person who is a director or an executive officer of ours; and (iii) all directors and executive officers of ours, as a group.  Shares
of our common stock subject to options, warrants, or convertible securities currently exercisable or convertible or exercisable
or convertible within 60 days of the date of filing of this Annual Report are deemed outstanding for computing the share ownership
and percentage of the person holding such options, warrants, or convertible securities but are not deemed outstanding for computing
the percentage of any other person.



66







|Name and Owner                                    |  | Identity                                   |  | Amount and Nature of Beneficial Ownership of Common Stock  (1) |           |  | Note |                    | Percentage | 
|------------------------------------------------- |  | ------------------------------------------ |  | -------------------------------------------------------------- | --------- |  | ---- | ------------------ | ---------- | 
|Milton Klyman                                     |  | Director                                   |  |                                                                | 280,000   |  |      | (2)                |            | 
|Colin McNeil                                      |  | Director                                   |  |                                                                | 270,000   |  |      | (3)                |            | 
|James Cassina                                     |  | Officer/Director and Principal Shareholder |  |                                                                | 4,592,220 |  |      | (4)                |            | 
|Core Energy Enterprise Inc. (5)                   |  | Principal Shareholder                      |  |                                                                | 407,321   |  |      | (6)                |            | 
|All officers and directors as a group (4 persons) |  |                                            |  |                                                                | 5,142,220 |  |      | (2) (3) (4) (5)(6) |            | 



| | (1) | Unless
                                         otherwise indicated, the persons named have sole ownership, voting and investment power
                                         with respect to their stock, subject to applicable laws relative to rights of spouses.  Percentage
                                         ownership is based on 27,671,541 shares of common stock outstanding as of the date of
                                         filing of this Annual Report.
| | --- | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (2) | Includes 10,000 outstanding shares and
                                         270,000 shares underlying 270,000 presently exercisable stock options.
| | --- | ------------------------------------------------------------------------------------------------------------------------------------------------------



| | (3) | Includes 270,000 shares underlying 270,000
                                         presently exercisable stock options.
| | --- | ------------------------------------------------------------------------------------------------------------------------



| | (4) | Includes 407,321 outstanding shares
                                         owned by Core Energy Enterprises Inc.  Also includes 3,100,549 outstanding
                                         shares and 814,350 shares underlying 814,350 presently exercisable warrants and 270,000
                                         shares underlying 270,000 presently exercisable stock options owned directly by James
                                         Cassina.
| | --- | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (5) | James
                                         Cassina has voting and investment power with respect to the shares owned by Core Energy
                                         Enterprises Inc.
| | --- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (6) | Includes
                                         407,321 outstanding shares.
| | --- | -----------------------------------------------------------------------------



As of the date of the filing of this Annual
Report, to the knowledge of our management, there are no arrangements which, could at a subsequent date result in a change in
control of us.  As of such date, and except as disclosed herein, our management has no knowledge that we are owned or
controlled directly or indirectly by another company or any foreign government.



| | ITEM 7 | MAJOR SHAREHOLDERS AND RELATED PARTY TRANSACTIONS
| | ------ | -------------------------------------------------



| | A. | MAJOR SHAREHOLDERS
| | -- | ------------------



There are 27,671,541 issued and outstanding
shares of our common stock as of November 28, 2014.  As of November 28, 2014, to the best of our knowledge, no persons
hold directly or indirectly or exercise control or direction over, shares of our common stock carrying 5% or more of the voting
rights attached to all issued and outstanding shares of the common stock except as stated under Item 6.E above or set out in the
table below.  The shares of our common stock, owned by our major shareholders have identical voting rights as those
owned by our other shareholders.



|Name                            |  | Amount and Nature  of Beneficial Ownership of Common Stock |           |  | Note |      | Percentage | 
|------------------------------- |  | ---------------------------------------------------------- | --------- |  | ---- | ---- | ---------- | 
|James Cassina                   |  |                                                            | 4,592,220 |  |      | (1)  |            | 
|Core Energy Enterprise Inc. (2) |  |                                                            | 407,321   |  |      | (3)  |            | 
|CDS & Co                        |  |                                                            | 1,810,538 |  |      |      |            | 
|CEDE & Co                       |  |                                                            | 2,150,110 |  |      |      |            | 
|Eternal Viceroy Limited         |  |                                                            | 2,544,844 |  |      | (4)  |            | 
|Fieldston Traders Limited       |  |                                                            | 2,731,096 |  |      | (5)  |            | 
|Galaxy Dragon Limited           |  |                                                            | 2,295,926 |  |      | (6)  |            | 
|Lion City Capital Inc.          |  |                                                            | 2,742,021 |  |      | (7)  |            | 
|Madera Inc.                     |  |                                                            | 2,730,187 |  |      | (8)  |            | 
|Terama Company Limited          |  |                                                            | 2,215,087 |  |      | (9)  |            | 
|Tonbridge Financial Corp.       |  |                                                            | 2,677,331 |  |      | (10) |            | 



67







| | (1) | Includes 407,321 outstanding shares
                                         owned by Core Energy Enterprises Inc.  Also includes 3,100,549 outstanding
                                         shares and 814,350 shares underlying 814,350 presently exercisable warrants and 270,000
                                         shares underlying 270,000 presently exercisable stock options owned directly by James
                                         Cassina.
| | --- | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (2) | James
                                         Cassina has voting and investment power with respect to the shares owned by Core Energy
                                         Enterprises Inc.
| | --- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (3) | Includes
                                         407,321 outstanding shares.
| | --- | -----------------------------------------------------------------------------



| | (4) | Includes 1,696,563 outstanding shares
                                         and 848,281 shares underlying 848,281 presently exercisable warrants.
| | --- | ----------------------------------------------------------------------------------------------------------------------------------------------------



| | (5) | Includes 1,687,397 outstanding shares
                                         and 1,043,699 shares underlying 1,043,699 presently exercisable warrants.
| | --- | --------------------------------------------------------------------------------------------------------------------------------------------------------



| | (6) | Includes 1,532,519 outstanding shares
                                         and 763,407 shares underlying 763,407 presently exercisable warrants.
| | --- | ----------------------------------------------------------------------------------------------------------------------------------------------------



| | (7) | Includes 1,828,014 outstanding shares
                                         and 914,007 shares underlying 914,007 presently exercisable warrants.
| | --- | ----------------------------------------------------------------------------------------------------------------------------------------------------



| | (8) | Includes 1,860,803 outstanding shares
                                         and 869,384 shares underlying 869,384 presently exercisable warrants.
| | --- | ----------------------------------------------------------------------------------------------------------------------------------------------------



| | (9) | Includes 1,490,018 outstanding shares
                                         and 725,069 shares underlying 725,069 presently exercisable warrants.
| | --- | ----------------------------------------------------------------------------------------------------------------------------------------------------



| | (10) | Includes 1,843,309 outstanding shares
                                         and 834,022 shares underlying 834,022 presently exercisable warrants.
| | ---- | ----------------------------------------------------------------------------------------------------------------------------------------------------



The following table discloses the geographic
distribution of the majority of the holders of record of our common stock as of date of November 28, 2014.



|Country   |  | Number
        of
        Shareholders |       |  | Number
        of
        Shares |  |            | Percentage
        of
        Shareholders |  | Percentage
        of
        Shares
|--------- |  | -------------------------------------- | ----- |  | -------------------------------- |  | ---------- | ------------------------------------------ |  | ------------------------------------
|Canada    |  |                                        | 1079  |  |                                  |  | 8,537,441  |                                            |  |                                     
|USA       |  |                                        | 44    |  |                                  |  | 3,783,016  |                                            |  |                                     
|All Other |  |                                        | 29    |  |                                  |  | 15,351,084 |                                            |  |                                     
|Total     |  |                                        | 1,152 |  |                                  |  | 27,671,541 |                                            |  |                                     



We are not directly or indirectly owned
or controlled by another corporation, by any foreign government or by any other natural or legal person. There are no arrangements
known to us, the operation of which may at a subsequent date result in a change in the control of us.



B.           RELATED
PARTY TRANSACTIONS



The following transactions with individuals
related to the Company arose in the normal course of business have been accounted for at the exchange amount being the amount
agreed to by the related parties, which approximates the arm’s length equivalent value.



Compensation of Key Management Personnel

The remuneration of directors and other members of key management
personnel during the years ended were as follows:



|                                       |  | August 31, 2014 |        |  | August 31, 2013 |   |        | August 31, 2012 | 
|-------------------------------------- |  | --------------- | ------ |  | --------------- | - | ------ | --------------- | 
|Short term employee benefits (1)       |  | $               | 75,000 |  |                 | $ | 75,000 |                 | 
|Directors stock based compensation (2) |  |                 | -      |  |                 |   | -      |                 | 
|                                       |  | $               | 75,000 |  |                 | $ | 75,000 |                 | 



68







The following balances owing to the President of the Company
are included in trade and other payables and are unsecured, non-interest bearing and due on demand:



|                                       |  | August 31, 2014 |         |  | August 31, 2013 |  
|-------------------------------------- |  | --------------- | ------- |  | --------------- | -
|Short term employee benefits (1)       |  | $               | 281,250 |  |                 | $
|Expenses paid on behalf of the Company |  |                 | -       |  |                 |  
|                                       |  | $               | 281,250 |  |                 | $



| | (1) | The Company accrues management fees
                                         for the President of the Company at a rate of $6,250 per month.
| | --- | --------------------------------------------------------------------------------------------------------------------------------------------

| | (2) | On March 1, 2012, the Company granted
                                         60,000 share purchase options to directors with an exercise price of $1.60 per share
                                         expiring on February 28, 2017.
| | --- | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



At August 31, 2014, the amount of directors’
fees included in trade and other payables was $19,200 (August 31, 2013: $16,100).



At August 31, 2014, the Company had a
promissory note payable to the President of $Nil (August 31, 2013: $28,845 and US$300,000). For the year ended August 31, 2014,
the Company recorded interest of $24,162 (August 31, 2013: $35,324). At August 31, 2014, included in trade and other payables
is interest of $91,727 (August 31, 2013: $65,826). The notes were due on demand and bear interest at 10% per annum. Interest was
payable annually on the anniversary date of the notes. Effective February 27, 2014, 651,904 common share purchase warrants were
exercised by the President at $0.35 expiring February 27, 2014 for settlement of cash advances of $228,167 (see Note 8 (b) (c)).
On August 30, 2014, the Company issued 1,628,700 units at $0.08 per unit as full settlement of a promissory note payable of US$120,000
(see Note 8 (b) (e) and Note 10 to the Consolidated Financial Statements). At August 31, 2014, the Company had a note payable
to Core Energy Enterprises Inc. (“Core”) of US$249,250. The President is a major shareholder, officer and a director
of Core.



At August 31, 2014, the Company had a
secured convertible promissory note of $1,322,347 (US$1,216,175), 10% per annum secured promissory note payable to Benchmark Enterprises
LLC (“Benchmark”) (2013: US$960,000). Benchmark is a shareholder of the Company. For the year ended August 31, 2014,
the Company recorded interest of $104,237 (August 31, 2013: $101,309). At August 31, 2014 included in trade and other payables
is interest of $Nil (August 31, 2013: $169,033) (see Note 10 and Note 11 to the Consolidated Financial Statements).



At August 31, 2014, the Company had shareholders’
loans payable of US$655,000. (August 31, 2013: US$1,433,500 and $250,000). For the year ended August 31, 2014, the Company recorded
interest of $180,349 (August 31, 2013: $183,490). At August 31, 2014, included in trade and other payables, is interest of $269
August 31, 2013: $47,037). The notes are payable on demand and bear interest at 10% per annum. Interest is payable annually on
the anniversary date of the notes. On August 30, 2014, the Company issued 13,128,420 units at $0.08 per unit as full settlement
of promissory notes payable of US$529,250, $250,000 and interest payable of $225,614 (see Note 8 (b) (e)). During the year ended
August 31, 2013, the Company issued 2,366,257 common shares as full settlement of shareholders’ loans in the amount of $198,333
and interest due on shareholders’ loans in the amount of $345,906 (see Note 8 (b) (b) and Note 10 to the Consolidated Financial
Statements).



Inter-Company Balances

As at August 31, 2014, the
inter-company balance due from our wholly owned subsidiary 1354166 Alberta was $39,000. As at August 31, 2014, the
inter-company balance due from  our wholly owned subsidiary Zavala Inc. was $4,774,597. As of November 28, 2014, the
inter-company balance due from 1354166 Alberta was $14,000 and the inter-company balance due from Zavala Inc. was
$4,784,939.



| | C. | INTERESTS OF EXPERTS AND COUNSEL
| | -- | --------------------------------



Not Applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



| | ITEM 8 | FINANCIAL INFORMATION
| | ------ | ---------------------



| | A. | CONSOLIDATED STATEMENTS AND OTHER FINANCIAL INFORMATION
| | -- | -------------------------------------------------------



The Company's Audited Consolidated Financial
Statements for the fiscal years ended August 31, 2014 and 2013 and the notes thereto required as part of this Annual Report are
filed under Item 18 of this Annual Report.



69







Litigation

Except as discussed below there are no
pending legal proceedings to which we or our subsidiaries are a party or of which any of our property is the subject. There are
no legal proceedings to which any of the directors, officers or affiliates or any associate of any such directors, officers or
affiliates of either our company or our subsidiary is a party or has a material interest adverse to us except for the following:



On or about September 30, 2014, Stratex
filed a petition against Zavala Inc. in the District Court of Zavala County, Texas seeking breach of contract and actual damages
of US$152,293 (the “Purported Debt”) for Zavala Inc’s alleged non-payment of its proportionate share of minimum
royalties due under the Matthews Lease. Zavala Inc. disputes the claim citing $300,000 paid by the Company to be credited against
the minimum royalties which Stratex has failed to do. Zavala Inc. paid the $152,293 under protest and filed a Response and Cross
Notice of Default against Stratex (Cause No. 14-09-13290-ZCV)



On or about October 27, 2014, the Company
filed a statement of claim in the Ontario Superior Court of Justice against Alan Gaines, a former director of the Company for
breach of fiduciary duty to the Company relating to Gaines role in the Company contracting with Stratex (Court File No.: 65-14-514935).
The Company is seeking a declaration that Gaines breached his duty to the Company, an accounting and disgorgement of profits made
by Gaines in breach of his duties or in the alternative, damages and/or restitution for breach of fiduciary duty, deceit, and
unjust enrichment in an amount to be determined before trial and $1.0 million in punitive damages.



Other Litigation

In February 2013, a vendor of Dyami Energy
applied a lien on the Murphy #4 well and filed a claim in the District Court of Zavala County, Texas (Case No. 13-02-12941-ZCV)
seeking payment of US$169,196 for services. Dyami Energy was disputing the amount on the basis of negligence by the vendor. On
January 28, 2014 the vendor received a summary judgment against Dyami Energy in the amount of $169,196 plus interest at a rate
of 18% per annum from September 17, 2012 until paid and legal fees of $21,178 plus interest at a rate of 5% per annum from the
date of judgment until paid. The full amount of the provision had been recorded together with legal fees and interest. The provision,
legal fees and interest were transferred to trade and other payables (see Note 16 to the Consolidated Financial Statements).



In May
2012 a vendor of Dyami Energy filed a claim in the District Court of Harris County, Texas seeking payment of US$64,866. Dyami
Energy was disputing the amount charged due to faulty equipment. The full amount of the provision which was accrued in the prior
year 2012 was reversed in 2013 as the vendor is no longer in good standing as a Texas corporation and the vendor’s attorney
filed in the District Court of Harris County, Texas a motion to withdraw as counsel (see Note 16 to the Consolidated Financial
Statements).



In December 2011, a vendor of Dyami Energy
filed a claim in the District Court of Harris County, (Case No. 2011-74035/Court: 113) seeking payment of US$62,800. Dyami Energy
disputed the claim on the basis of excessive charges. In December 2013 an agreed final judgment in favor of the vendor was entered
into court in the amount of $42,803 and post judgment interest at 5% per annum until paid in full.



Dividends

We have not paid any dividends on our
common stock during the past five years. We do not intend to pay dividends on shares of common stock in the foreseeable future
as we anticipate that our cash resources will be used to finance growth.



| | B. | SIGNIFICANT CHANGES
| | -- | -------------------



There have been no significant changes
that have occurred since the date of our annual financial statements included with this Annual Report except as disclosed in the
Annual Report.



| | ITEM 9 | THE OFFER AND LISTING
| | ------ | ---------------------



Common Shares

Our authorized capital consists of an
unlimited number of common shares without par value, of which 27,671,541 were issued and outstanding as of November 28, 2014.
All shares are initially issued in registered form. There are no restrictions on the transferability of our common shares imposed
by our constating documents.  Holders of our common shares are entitled to one vote for each common share held of record
on all matters to be acted upon by our shareholders. Holders of common shares are entitled to receive such dividends as may be
declared from time to time by our board of directors, in their discretion. In addition we are authorized to issue an unlimited
number of preferred shares, with such rights, preferences and privileges as may be determined from time to time by our board of
directors.  There were no preferred shares outstanding at November 28, 2014.



70







Our common shares entitle their holders
to: (i) vote at all meetings of our shareholders except meetings at which only holders of specified classes of shares are entitled
to vote, having one vote per common share, (ii) receive dividends at the discretion of our board of directors; and (iii) receive
our remaining property on liquidation, dissolution or winding up.



| | A. | OFFER AND LISTING DETAILS
| | -- | -------------------------



Our common
stock became eligible for trading on October 22, 2009 on the Over the Counter Bulletin Board ("OTCBB") under the symbol
(“EGNKF”). Following the amalgamation on November 30, 2009 with our wholly owned subsidiary 1406768 Ontario, we changed
our name to Eagleford Energy Inc. and commenced trading under the symbol (“EFRDF”). Prior to our common stock being
listed on the OTCBB, our common stock had not publicly traded since 1990. We completed a
2-for-1 forward stock split, pursuant to which one (1) newly-issued share of the Company’s common stock was issued to each
holder of a share of common stock as of the close of business on March 16, 2012 and on August 31, 2014 we completed a 1-for-10
stock consolidation and following commenced trading under the symbol (“EGFDF”).



The following table set forth the reported
high and low bid prices for shares of our common stock on the OTCQB in US dollars for the periods indicated.



|                            |  | Period (1)                      |  | High (3) |       |  | Low(3) |  
|--------------------------- |  | ------------------------------- |  | -------- | ----- |  | ------ | -
|                            |  |                                 |  |          |       |  |        |  
|Fiscal Year August 31, 2014 |  | Year Ended August 31, 2014      |  | $        | 1.00  |  |        | $
|Fiscal Year August 31, 2013 |  | Year Ended August 31, 2013      |  | $        | 4.00  |  |        | $
|Fiscal Year August 31, 2012 |  | Year Ended August 31, 2012      |  | $        | 5.10  |  |        | $
|Fiscal Year August 31, 2011 |  | Year Ended August 31, 2011      |  | $        | 10.20 |  |        | $
|Fiscal Year August 31, 2010 |  | Year Ended August 31, 2010      |  | $        | 6.50  |  |        | $
|                            |  |                                 |  |          |       |  |        |  
|Fiscal Year 2015 by Quarter |  | First Quarter ended 11/30/2014  |  | $        | 0.15  |  |        | $
|                            |  |                                 |  |          |       |  |        |  
|Fiscal Year 2014 by Quarter |  | First Quarter ended 11/30/2013  |  | $        | 0.70  |  |        | $
|                            |  | Second Quarter Ended 02/29/2014 |  | $        | 0.90  |  |        | $
|                            |  | Third Quarter Ended 05/31/2014  |  | $        | 0.80  |  |        | $
|                            |  | Fourth Quarter Ended 08/31/2014 |  | $        | 4.50  |  |        | $
|                            |  |                                 |  |          |       |  |        |  
|Fiscal Year 2013 by Quarter |  | First Quarter ended 11/30/2012  |  | $        | 4.00  |  |        | $
|                            |  | Second Quarter Ended 02/29/2013 |  | $        | 2.00  |  |        | $
|                            |  | Third Quarter Ended 05/31/2013  |  | $        | 1.50  |  |        | $
|                            |  | Fourth Quarter Ended 08/31/2013 |  | $        | 0.60  |  |        | $
|                            |  |                                 |  |          |       |  |        |  
|Calendar Year 2014 by Month |  | June                            |  | $        | 0.60  |  |        | $
|                            |  | July                            |  | $        | 0.50  |  |        | $
|                            |  | August                          |  | $        | 0.50  |  |        | $
|                            |  | September                       |  | $        | 1.20  |  |        | $
|                            |  | October                         |  | $        | 0.70  |  |        | $
|                            |  | November                        |  | $        | 0.40  |  |        | $



Notes



| | (1) | Our stock commenced trading on the
                                         OTCBB on October 22, 2009.
| | --- | ------------------------------------------------------------------------------------------------------



| | (2) | The closing price on the OTCQB
                                         for our common stock on November 28, 2014 was $0.11.
| | --- | ----------------------------------------------------------------------------------------------------------------------------



71







| | (3) | Adjusted for the 2-for-1 forward
                                         stock split on March 16, 2012 and the 1-for-10 stock consolidation on August 25, 2014.
| | --- | ----------------------------------------------------------------------------------------------------------------------------------------------------------------



There is currently only a limited public
market for the common stock in the United States. There can be no assurance that a more activemarket will develop in the future.



| | B. | PLAN OF DISTRIBUTION
| | -- | --------------------



Not Applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



| | C. | MARKETS
| | -- | -------



See Item 9.A.



| | D. | SELLING SHAREHOLDERS
| | -- | --------------------



Not Applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



| | E. | DILUTION
| | -- | --------



Not Applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



| | F. | EXPENSES OF THE ISSUE
| | -- | ---------------------



Not Applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



| | ITEM 10 | ADDITIONAL INFORMATION
| | ------- | ----------------------



| | A. | SHARE CAPITAL
| | -- | -------------



Not Applicable.  This Form 20-F is being filed as
an Annual Report under the Exchange Act.



| | B. | MEMORANDUM AND ARTICLES OF ASSOCIATION
| | -- | --------------------------------------



Certificate of Incorporation

We were incorporated under the Business
Corporations Act (Ontario) on September 22, 1978 under the name Bonanza Red Lake Explorations Inc.  The corporation
number as assigned by Ontario is 396323.



Articles of Amendment dated January
14, 1985

By Articles of Amendment dated January
14, 1985, our Articles were amended as follows:



1.	The
minimum number of directors of the Company shall be 3 and the maximum number of directors of the Company shall be 10.



2.	     (a)	Delete
the existing objects clauses and provide that there are no restrictions on the business we may carry on or on the powers that
we may exercise;



(b)	Delete
the term "head office" where it appears in the articles and substitute therefor the term "registered office";



(c)	Delete
the existing special provisions contained in the articles and substitute therefor the following:



The following special provisions shall
be applicable to the Company:



Subject to the provisions of the Business
Corporations Act, as amended or re-enacted from time to time, the directors may, without authorization of the shareholders:



| | (i) | borrow money on the credit
of the Company;
| | --- | ------------------------------------------



| | (ii) | issue, re-issue, sell or
pledge debt obligations of the Company;
| | ---- | ----------------------------------------------------------------



72







| | (iii) | give a guarantee on behalf
of the Company to secure performance of an obligation of any person;
| | ----- | -----------------------------------------------------------------------------------------------



| | (iv) | mortgage, hypothecate,
pledge or otherwise create a security interest in all or any property of the  Company owned or subsequently acquired,
to secure any obligation of the Company; and
| | ---- | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (v) | by resolution, delegate
any or all such powers to a director, a committee of directors or an officer of the Company.
| | --- | --------------------------------------------------------------------------------------------------------------------



| | 3. | (a)	   Provide that the
Company is authorized to issue an unlimited number of shares;
| | -- | -------------------------------------------------------------------------------------



| | (b) | Provide that the Company is authorized to issue an unlimited
number of preference shares.
| | --- | -----------------------------------------------------------------------------------------



Articles of Amendment dated August
16, 2000

By Articles of Amendment dated August
16, 2000 our articles were amended to consolidate our issued and outstanding common shares on the basis on one common share for
every three issued and outstanding common shares in our capital, and change our name from Bonanza Red Lake Explorations Inc. to
Eugenic Corp.



Our Articles of Amendment state that there
are no restrictions on the business that may carry on, but do not contain a stated purpose or objective.



Articles of Amalgamation dated November
30, 2009

By Articles of Amalgamation dated November
30, 2009 we amalgamated with our wholly owned subsidiary Eagleford Energy Inc., (formerly: 1406768 Ontario Inc.) and changed the
entity’s name to Eagleford Energy Inc.



Our Articles of Amalgamation state that
there are no restrictions on the business that may carry on or on the powers the Company may exercise.



We are authorized to issue an unlimited
number of common shares and an unlimited number of preference shares of which Nil were outstanding as of the date of this Annual
Report (the “Preference Shares”).



A description of the rights,
preferences and privileges relating to the Company's Preference Shares is as follows:



(a)	          Our Preference Shares have a par
value of one-tenth of one cent (1/10) and are redeemable, voting, non-participating shares.



(b)	          No dividends at any time shall
be declared, set aside or paid on our Preference Shares.



(c)	          In the event of a liquidation,
dissolution or winding of the Company or other distribution of assets or property of the Company among shareholders for the purpose
of winding up its affairs, the holders of the Preference Shares shall be entitled to received from the assets and property of
the Company a sum equivalent to the aggregate par value of the Preference Shares held by them respectively before any amount shall
be paid or any property or assets of the Company distributed to holders of any common shares or shares of any other class ranking
junior to the Preference Shares. After payment to the holders of the Preference Shares of the amount so payable to them as above
provided, they shall not be entitled to share in any further distribution of the assets or property of the Company.



(d)	          The Company may not redeem the
Preference Shares prior to the expiration of five years from the respective dates of issuance thereof, without the prior consent
of the holders of the Preference Shares to be redeemed. The Company shall redeem all of the then outstanding Preference Shares
five years from the respective dates of issue



(e)	          The Company may at any time or
times purchase for cancellation all or any part of the Preference Shares outstanding from time to time from the holders thereof,
at a price not exceeding the par value thereof, with the consent of the holders thereof.



(f)	          The holders of the Preference Shares
shall be entitled to receive notice of and attend all meetings of shareholders of the Company and shall have one (1) vote for
each Preference Share held at all meetings of the shareholders of the Company.



73







Other Provisions

The following special provisions shall
be applicable to the Company:



Subject to the provisions of the Business
Corporations Act, as amended or re-enacted from time to time, the directors may, without authorization of the shareholders:



(i)	borrow
money on the credit of the Company;



(ii)	issue,
re-issue, sell or pledge debt obligations of the Company;



(iii)	give
a guarantee on behalf of the Company to secure performance of an obligation of any person;



(iv)	mortgage,
hypothecate, pledge or otherwise create a security interest in all or any property of the  Company owned or subsequently
acquired, to secure any obligation of the Company; and



(v)	by
resolution, delegate any or all such powers to a director, a committee of directors or an officer of the Company.



Articles of Amendment dated effective
March 16, 2012

By
Articles of Amendment dated effective March 16, 2012 our articles were amended to



a)	           To change each issued and outstanding
common share in the capital of the Corporation into two (2) common share of the Corporation (the "Stock Split") effective
as of the close of business on March 16, 2012; and



b)	           To provide that no fractional shares
shall be issued as a result of the Stock Split, and if any fractional share would otherwise result from the Stock Split, such
fractional share shall be rounded up to the nearest whole share and distributed to the holder of the fractional interest as his
or her interest appears



Bylaws

At the Annual and Special Meeting of Shareholders
held on February 24, 2012, shareholders approved a resolution to repeal and replace the Company's By-Law No. 1 and Special By-Law
No. 1 (the "Old By-Laws") with a new By-Law No. 1 (the "New By-Laws") in order to reflect the
current circumstances and practices of the Company and certain amendments to the Business Corporations Act(Ontario) (the
"OBCA"), which came into force on August 1, 2007.



No director of ours is permitted to vote
on any resolution to approve a material contract or transaction in which such director has a material interest (Bylaws, Article
3.17).



Neither our Articles nor our Bylaws limit
the directors’ power, in the absence of an independent quorum, to vote compensation to themselves or any members of their
body.  The Bylaws provide that directors shall receive remuneration as the board of directors shall determine from time
to time (Bylaws, Article 3.19).



Under our Articles and Bylaws, our board
of directors may, without the authorization of our shareholders, (i) borrow money upon our credit; (ii) issue, reissue, sell or
pledge debt obligations of ours; whether secured or unsecured (iii) give a guarantee on behalf of us to secure performance of
obligations; and (iv) charge, mortgage, hypothecate, pledge or otherwise create a security interest in all currently owned or
subsequently acquired real or personal, movable or immovable, tangible or intangible, property of ours to secure obligations(Bylaws,
Article 13.1).



The annual meeting of
shareholders shall be held at such time in each year as the board, the Chairman of the Board (if any), The Chief Executive Officer,
or the President may from time to time determine, for the purpose of considering the financial statements and reports required
by the Act to be placed before the annual meeting, electing directors, appointing an auditor and for the transaction of such other
business as may properly be brought before the meeting (Bylaws, Article 9.1).



The board, the Chairman
of the Board (if any) or the President shall have power to call a special meeting of shareholders at any time (Bylaws, Article
9.2).



Shareholders of record must be given notice
of any meeting not less than 21 days or more than 50 days before the date of the meeting or as otherwise prescribed by applicable
laws.  Notice of a meeting of shareholders called for any purpose other than consideration of the financial statements
and auditors’ report, election of directors and reappointment of the incumbent auditor shall state or be accompanied by
a statement of the nature of such business in sufficient detail to permit the shareholder to form a reasoned judgment thereon
and the text of any special resolution or by-law to be submitted to the meeting (Bylaws, Article 9.4). Our board of directors
is permitted to fix a record date for any meeting of the shareholders that is between 30 and 60 days prior to such meeting or
as otherwise prescribed by applicable laws. (Bylaws, Article 9.6).  The only persons entitled to be present at a meeting
of shareholders shall be those entitled to vote thereat, the directors and the auditor of the Company and others who, although
not entitled to vote are entitled or required under any provision of the Act or the articles or the by-laws to be present at the
meeting. Any other person may be admitted only on the invitation of the chairman of the meeting or with the consent of the meeting
(Bylaws, Article 9.9).



74







Neither our Articles nor our Bylaws discuss
limitations on the rights to own securities or exercise voting rights thereon, and there is no provision of our Articles or Bylaws
that would delay, defer or prevent a change in control of us, or that would operate only with respect to a merger, acquisition,
or corporate restructuring involving us or any of its subsidiaries.  Our Bylaws do not contain a provision indicating
an ownership threshold above which shareholder ownership must be disclosed.



Articles of Amendment dated effective
August 25, 2014

By
Articles of Amendment dated effective August 25, 2014 our articles were amended to



| | a) | To change every ten (10) issued and
                                         outstanding common share in the capital of the Corporation into one (1) common share
                                         of the Corporation (the "Stock Consolidation") effective as of the close of
                                         business on August 25, 2014; and
| | -- | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | b) | To provide that no fractional shares
                                         shall be issued as a result of the Stock Consolidation and if any fractional share would
                                         otherwise result from the Stock Split, such fractional share shall be rounded up to the
                                         nearest whole share and distributed to the holder of the fractional interest as his or
                                         her interest appears.
| | -- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



Other Provisions

Neither our Articles nor our Bylaws discuss
the retirement or non-retirement of directors under an age limit requirement or the number of shares required for director qualification.



Neither our Articles nor our Bylaws require
that a director hold a share in the capital of the Company as qualification for his/her office.



Neither our Articles nor our Bylaws contain
sinking fund provisions, provisions allowing us to make further capital calls with respect to any shareholder of ours, or provisions
which discriminate against any holders of securities as a result of such shareholder owning a substantial number of shares.



| | C. | MATERIAL CONTRACTS
| | -- | ------------------



During the two year period preceding the
filing date of this Annual Report, we entered into no material contracts other than contracts entered into in the ordinary course
except for the following:



During the year ended August 31, 2013,
we entered into an agreement with the lessors of the Matthews Property, OGR Energy Corporation (“OGR Energy”) and
Texas Onshore Energy, Inc. (“Texas Onshore”) together holding a 15% working interest in the Matthews Property with
back in rights to earn an additional 15% working interest after production achieved $15.0 million of revenue. A new lease was
signed with the Company’s subsidiary, Zavala Inc. (the “Lessee”) effective September 1, 2013 (the “New
Matthews Lease”). Upon the Company satisfying certain pre-royalty payments to the Lessors and fracturing of the Matthews
1-H well, OGR Corporation and Texas Offshore assigned their working interests to Zavala Inc.



The New Matthews Lease had a primary term
extendable to March 31, 2014 (the “Primary Term”) while each lease year ends August 31. Prior to the expiration of
the Primary Term, a hydraulic fracturing of the Matthews #1H well was completed and thereafter the lease is maintained through
a guaranteed minimum royalty payment of $323.30 per acre held for the first 5 lease years and beginning in the second lease year
and continuing thereafter for each succeeding lease year drill or have drilled at least 2 wells per lease year. The royalties
payable under the Matthews Lease are 25%.



On September 10, 2013 we terminated the
agreements with PrinceRidge. As of the date of filing this report the Company has not paid any success fees to PrinceRidge.



75







On December 3, 2013, (amended January
21, 2014) the Company entered into a Joint Development Agreement with Stratex Oil and Gas Holdings, Inc. (“Stratex”)
(the “Stratex JDA”) to further develop the Matthews Lease. Under the terms of the Stratex JDA, Stratex will act as
operator and upon Stratex delivering i) US$150,000 to the lessors of the Matthews Lease on behalf of Zavala Inc., ii) delivering
US $150,000 to the Company; and iii) commencing a hydraulic fracture of the Matthews #1H not later than March 31, 2014. Stratex
earned a 66.67% working interest before payout (50% working interest after payout) in the Matthews #1H well and a 50% working
interest in the 2,629 acre Matthews Lease.



On April 11, 2014, the Company entered
into a further Joint Development Agreement (“JDA2”) with Stratex and Quadrant Resources LLC, (“Quadrant”)
for the development of the San Miguel formation on the Matthews Lease.  Pursuant to the terms of the JDA2, upon satisfaction
of certain conditions including the Phase 1 Work Program and the cash consideration described below, Quadrant can earn an undivided
66.67% before payout and a 50% working interest after payout to the base of the San Miguel formation of the Matthews Lease by
i) drilling 3 new wells and reworking 5 wells at its sole cost and expense by June 30, 2015 (the “Phase I Work Program”);
ii) deliver US$100,000 to the Company upon execution of the JDA2 (paid); and iii) deliver US$65,000 to the Company on each of
July 8, 2014 (paid); October 6, 2014, January 5, 2015 and April 6, 2015. At August 31, 2014 the Company recorded the payments
received from Quadrant of US$165,000 (CDN $177,804) as deferred revenue on the Consolidated Statement of Financial Position until
the conveyance of the earned interest at which time this amount will be reclassified and offset against exploration and evaluation
assets.



On August 31, 2014we entered
into a had a 10% per annum secured convertible promissory note payable in the amount of US$1,216,175, a General Security Agreement
and Release. The secured convertible promissory note is due on the earliest to occur of: (a) August 31, 2015; (b) the closing
of any subsequent financing or series of financings by the Company that results in gross proceeds of an aggregate amount equal
to or greater than US$4,400,000, excluding conversion of any existing debt into equity; (c) the date of a sale by the Company
of all of the shares in the capital stock of Zavala Inc. held by the Company from time to time; (d) the closing of a merger, reorganization,
take-over or other business combination which results in a change of control of the Company or Zavala Inc.; or (e) an event of
default (the “Note”). In the event that the Company closes any subsequent financing or series of financings that results
in gross proceeds to the Company of an aggregate amount equal to or greater than US$2,000,000, excluding conversion of any existing
debt into equity of the Company, the Company shall allocate US$0.50 of every US$1.00 exceeding the US$2,000,000 raised from such
financing to repay the Note. The Note is secured by all of the assets of the Company and Zavala Inc. The Lender has the right
but not the obligation, at any time to convert all or any portion of the unpaid principal and interest into Units of the Company.
Each Unit is comprised of one (1) common share and one (1) common share purchase warrant entitling the holder to acquire a common
share of the Company at a price equal to a 15% premium to the price of the common share acquired under the Unit. The price of
the Units be the lessor of a price equal to the 30-day volume weighted average price of the Company as of the date of conversion,
less 20% (as adjusted for any stock splits, combinations or similar events) or eight US$0.08 per share.



| | D. | EXCHANGE CONTROLS
| | -- | -----------------



There are no governmental laws, decrees
or regulations in Canada that restrict the export or import of capital, or affect the remittance of dividends, interest or other
payments to a non-resident holder of our common stock, other than withholding tax requirements (See "Taxation" below).



Except as provided in the Investment Canada
Act, there are no limitations imposed under the laws of Canada, the Province of Ontario, or by our constituent documents on the
right of a non-resident to hold or vote our common stock.



The Investment Canada Act (the "ICA"),
which became effective on June 30, 1985, regulates the acquisition by non-Canadians of control of a Canadian business enterprise.  In
effect, the ICA requires review by Investment Canada, the agency which administers the ICA, and approval by the Canadian government,
in the case of an acquisition of control of a Canadian business by a non-Canadian where: (i) in the case of a direct acquisition
(for example, through a share purchase or asset purchase), the assets of the business are CDN $5 million or more in value; or
(ii) in the case of an indirect acquisition (for example, the acquisition of the foreign parent of the Canadian business) where
the Canadian business has assets of CDN $5 million or more in value or if the Canadian business represents more than 50% of the
assets of the original group and the Canadian business has assets of CDN $5 million or more in value.  Review and approval
are also required for the acquisition or establishment of a new business in areas concerning "Canada's cultural heritage
or national identity" such as book publishing, film production and distribution, television and radio production and distribution
of music, and the oil and natural gas industry, regardless of the size of the investment.



76







As applied to an investment in us, three
methods of acquiring control of a Canadian business would be regulated by the ICA: (i) the acquisition of all or substantially
all of the assets used in carrying on the Canadian business; (ii) the acquisition, directly or indirectly, of voting shares of
a Canadian corporation carrying on the Canadian business; or (iii) the acquisition of voting shares of an entity which controls,
directly or indirectly, another entity carrying on a Canadian business.  An acquisition of a majority of the voting
interests of an entity, including a corporation, is deemed to be an acquisition of control under the ICA.  An acquisition
of less than one-third of the voting shares of a corporation is deemed not to be an acquisition of control.  An acquisition
of less than a majority, but one-third or more, of the voting shares of a corporation is presumed to be an acquisition of control
unless it can be established that on the acquisition the corporation is not, in fact, controlled by the acquirer through the ownership
of voting shares.  For partnerships, trusts, joint ventures or other unincorporated entities, an acquisition of less
than a majority of the voting interests is deemed not to be an acquisition of control.



In 1988, the ICA was amended, pursuant
to the Free Trade Agreement dated January 2, 1988 between Canada and the United States, to relax the restrictions of the ICA.  As
a result of these amendments, except where the Canadian business is in the cultural, oil and gas, uranium, financial services
or transportation sectors, the threshold for direct acquisition of control by US investors and other foreign investors acquiring
control of a Canadian business from US investors has been raised from CDN $5 million to CDN $150 million of gross assets, and
indirect acquisitions are not reviewable.



In addition to the foregoing, the ICA
requires that all other acquisitions of control of Canadian businesses by non-Canadians are subject to formal notification to
the Canadian government.  These provisions require a foreign investor to give notice in the required form, which notices
are for information, as opposed to review, purposes.



| | E. | TAXATION
| | -- | --------



Certain Canadian Federal Income Tax Consequences

The following discussion describes the
principal Canadian federal income tax consequences applicable to a holder of our common shares which are traded on the OTCQB,
who, at all material times, is a resident of the United States for purposes of the Canada-United States Income Tax Convention
(the "Treaty") entitled to the full benefit of the Treaty and is not a resident, or deemed to be a resident, of Canada,
deals at arm's length and is not affiliated with the Company, did not acquire our common shares by virtue of employment, is not
a financial institution, specified financial institution, registered non-resident insurer, authorized foreign bank, partnership
or a trust as defined in the Income Tax Act (Canada) (the "ITA"), holds our common shares as capital property and as
beneficial owner, and does not use or hold, is not deemed to use or hold, his or her common shares in connection with carrying
on a business in Canada and, did not, does not and will not have a fixed base or permanent establishment in Canada within the
meaning of the Treaty (a "non-resident holder").



This description is based upon the current
provisions of the ITA, the regulations thereunder (the "Regulations"), management's understanding of the current publicly
announced administration and assessing policies of Canada Revenue Agency, and all specific proposals (the "Tax Proposals")
to amend the ITA and Regulations announced by the Minister of Finance (Canada) prior to the date hereof.  This description
is not exhaustive of all possible Canadian federal income tax consequences and, except for the Tax Proposals, does not take into
account or anticipate any changes in law, whether by legislative, governmental or judicial action, nor does it take into account
any income tax laws or considerations of any province or territory of Canada or foreign tax considerations which may differ significantly
from those discussed below.



The following discussion is for general
information only and is not intended to be, nor should it be construed to be, legal or tax advice to any holder of common shares
of the Company, and no opinion or representation with respect to the Canadian Federal Income Tax consequences to any such holder
or prospective holder is made.  Accordingly, holders and prospective holders of common shares are urged to consult with
their own tax advisors about the federal, provincial and foreign tax consequences of purchasing, owning and disposing of common
shares.



Dividends

Dividends paid on our common shares to
a non-resident holder will be subject to a 25% withholding tax pursuant to the provision of the ITA.  The Treaty provides
that the normal 25% withholding tax rate is generally reduced to 15% on dividends paid on shares of a corporation resident in
Canada (such as the Company) to beneficial owners who are residents of the United States.  However, if the beneficial
owner is a resident of the United States and is a corporation which owns at least 10% of the voting stock of the Company,
the withholding tax rate on dividends is reduced to 5%.



77









Capital Gains

A non-resident of Canada is subject to
tax under the ITA in respect of a capital gain realized upon the disposition of a share of a corporation if the shares are considered
to be "taxable Canadian property" of the holder within the meaning of the ITA and no relief is afforded under an applicable
tax treaty.  For purposes of the ITA, a common share of the Company will be taxable Canadian property to a non-resident
holder if more than 50% of the fair market value of the common share during the 60 month period immediately preceding the disposition
of the common share, was derived directly or indirectly from real or immovable property situated in Canada, Canadian resource properties
or any options or interests in such properties.



In the case of a non-resident holder to
whom shares of our common stock represent taxable Canadian property and who is a resident in the United States and not a former
resident of Canada, no Canadian taxes will be payable on a capital gain realized on such shares by reason of the Treaty unless
the value of such shares is derived principally from real property situated in Canada within the meaning of the Treaty at the time
of the disposition.



Certain United States Federal Income
Tax Consequences

The following is a general discussion of
certain possible United States Federal income tax consequences, under current law, generally applicable to a US Holder (as defined
below) of our common shares.  This discussion does not address all potentially relevant Federal income tax matters and
does not address consequences peculiar to persons subject to special provisions of Federal income tax law, such as those described
below as excluded from the definition of a US Holder.  In addition, this discussion does not cover any state, local or
foreign tax consequences (See “Certain Canadian Federal Income Tax Consequences” above).



The following discussion is based upon
the sections of the Internal Revenue Code of 1986, as amended (the “Code”), Treasury Regulations, published Internal
Revenue Service (“IRS”) rulings, published administrative positions of the IRS and court decisions that are currently
applicable, any or all of which could be materially and adversely changed, possibly on a retroactive basis, at any time.  In
addition, this discussion does not consider the potential effects, both adverse and beneficial, of recently proposed legislation
which, if enacted, could be applied, possibly on a retroactive basis, at any time.  The following discussion is for general
information only and it is not intended to be, nor should it be construed to be, legal or tax advice to any holder or prospective
holder of common shares, and no opinion or representation with respect to the United States Federal income tax consequences to
any such holder or prospective holder is made.  Accordingly, holders and prospective holders of common shares are urged
to consult their own tax advisors about the Federal, state, local, and foreign tax consequences of purchasing, owning and disposing
of common shares.



U.S. Holders

As used herein, a “U.S. Holder”
means a holder of common shares who is a citizen or individual resident (as defined under United States tax laws) of the United
States; a corporation created or organized in or under the laws of the United States or of any political subdivision thereof; an
estate the income of which is taxable in the United States irrespective of source; or a trust if (a) a court within the United
States is able to exercise primary supervision over the trust’s administration and one or more United States persons have
the authority to control all of its substantial decisions or (b) the trust was in existence on August 20, 1996 and has properly
elected to continue to be treated as a United States person.  This summary does not address the United States tax consequences
to, and U.S. Holder does not include, persons subject to specific provisions of federal income tax law, including but not limited
to tax-exempt organizations, qualified retirement plans, individual retirement accounts and other tax-deferred accounts, financial
institutions, insurance companies, real estate investment trusts, regulated investment companies, broker-dealers, non-resident
alien individuals, persons or entities that have a “functional currency” other than the U.S. dollar, persons who hold
common shares as part of a straddle, hedging or a conversion transaction, and persons who acquire their common shares as compensation
for services.  This discussion is limited to U.S. Holders who own common shares as capital assets and who hold the common
shares directly (e.g., not through an intermediary entity such as a corporation, partnership, limited liability company, or trust).  This
discussion does not address the consequences to a person or entity of the ownership, exercise or disposition of any options, warrants
or other rights to acquire common shares.



78







Distributions on Our Common Shares

Subject to the discussion below regarding
passive foreign investment companies (“PFICs”), the gross amount of any distribution (including non-cash property)
by us (including any Canadian taxes withheld therefrom) with respect to common shares generally should be included in the gross
income of a U.S. Holder as foreign source dividend income to the extent such distribution is paid out of current or accumulated
earnings and profits of ours, as determined under United States Federal income tax principles.  Distributions received
by non-corporate U.S. Holders may be subject to United States Federal income tax at lower rates than other types of ordinary income
(generally 15%) in taxable years beginning on or before December 31, 2010 if certain conditions are met.  These conditions
include the Company not being classified as a PFIC, it being a “qualified foreign corporation,” the U.S. Holder’s
satisfaction of a holding period requirement, and the U.S. Holder not treating the distribution as “investment income”
for purposes of the investment interest deduction rules.  To the extent that the amount of any distribution exceeds our
current and accumulated earnings and profits for a taxable year, the distribution first will be treated as a tax-free return of
capital to the extent of the U.S. Holder’s adjusted tax basis in our common shares and to the extent that such distribution
exceeds the Holder’s adjusted tax basis in our common shares, will be taxed as capital gain.  In the case of U.S.
Holders that are corporations, such dividends generally will not be eligible for the dividends received deduction.



If a U.S. Holder receives a dividend in
Canadian dollars, the amount of the dividend for United States federal income tax purposes will be the U.S. dollar value of the
dividend (determined at the spot rate on the date of such payment) regardless of whether the payment is later converted into U.S.
dollars.  In such case, the U.S. Holder may recognize additional ordinary income or loss as a result of currency fluctuations
between the date on which the dividend is paid and the date the dividend amount is converted into U.S. dollars.



Disposition of Common Shares

Subject to the discussion below
regarding PFIC’s, gain or loss, if any, realized by a U.S. Holder on the sale or other disposition of our common shares
(including, without limitation, a complete redemption of our common shares) generally will be subject to United States Federal
income taxation as capital gain or loss in an amount equal to the difference between the U.S. Holder’s adjusted tax basis
in our common shares and the amount realized on the disposition. Net capital gain (i.e., capital gain in excess of capital loss)
recognized by a non-corporate U.S. Holder (including an individual) upon a sale or other disposition of our common shares that
have been held for more than one year will generally be subject to a maximum United States federal income tax rate of 15% subject
to the PFIC rules below.  Deductions for capital losses are subject to certain limitations.  If the U.S. Holder
receives Canadian dollars on the sale or disposition, it will have a tax basis in such dollars equal to the U.S. dollar value.  Generally,
any gain or loss realized on a subsequent disposition of the Canadian dollars will be U.S. source ordinary income or loss.



U.S. “Anti-Deferral” Rules



Passive Foreign Investment Company (“PFIC”)
Regime.  If we, or a non-U.S. entity directly or indirectly owned by us (“Related Entity”), has 75% or
more of its gross income as “passive” income, or if the average value during a taxable year of ours or the Related
Entity’s “passive assets” (generally, assets that generate passive income) is 50% or more of the average value
of all assets held by us or the Related Entity, then the United States PFIC rules may apply to U.S. Holders.  If we or
a Related Entity is classified as a PFIC, a U.S. Holder will be subject to increased tax liability in respect of gain recognized
on the sale of his, her or its common shares or upon the receipt of certain distributions, unless such person makes a “qualified
electing fund” election to be taxed currently on its pro rata portion of our income and gain, whether or not such
income or gain is distributed in the form of dividends or otherwise, and we provide certain annual statements which include the
information necessary to determine inclusions and assure compliance with the PFIC rules.  As another alternative to the
foregoing rules, a U.S. Holder may make a mark-to-market election to include in income each year as ordinary income an amount equal
to the increase in value of its common shares for that year or to claim a deduction for any decrease in value (but only to the
extent of previous mark-to-market gains).  We or a related entity can give no assurance as to its status as a PFIC for
the current or any future year.  U.S. Holders should consult their own tax advisors with respect to the PFIC issue and
its applicability to their particular tax situation.



Controlled Foreign Corporation Regime
(“CFC”).  If a U.S. Holder (or person defined as a U.S. persons under Section 7701(aX301 of the Code)
owns 10% or more of the total combined voting power of all classes of our stock (, a “U. S. Shareholder”) and U.S.
Shareholders own more than 50% of the vote or value of our Company, we would be a “controlled foreign corporation”.  This
classification would result in many complex consequences, including the required inclusion into income by such U. S. Shareholders
of their pro rata shares of “Subpart F income” of our Company (as defined by the Code) and our earnings invested in
“US property” (as defined by the Code).  In addition, under Section 1248 of the Code, gain from the sale
or exchange of our common shares by a US person who is or was a U. S. Shareholder at any time during the five year period before
the sale or exchange may be treated as ordinary income to the extent of earnings and profits of ours attributable to the stock
sold or exchanged.  It is not clear the CFC regime would apply to the U.S. Holders of our common shares, and is outside
the scope of this discussion.



79







Foreign Tax Credit

A U.S. Holder who pays (or has withheld
from distributions) Canadian income tax with respect to us may be entitled to either a deduction or a tax credit for such foreign
tax paid or withheld, at the option of the U.S. Holder.  Generally, it will be more advantageous to claim a credit because
a credit reduces United States federal income tax on a dollar-for-dollar basis, while a deduction merely reduces the taxpayer’s
income subject to tax.  This election is made on a year-by-year basis and generally applies to all foreign taxes paid
by (or withheld from) the U.S. Holder during that year.



There are significant and complex limitations
which apply to the credit, among which is the general limitation that the credit cannot exceed the proportionate share of the U.S.
Holder’s United States income tax liability that the U.S. Holder’s foreign source income bears to its worldwide taxable
income.  This limitation is designed to prevent foreign tax credits from offsetting United States source income.  In
determining this limitation, the various items of income and deduction must be classified into foreign and domestic sources.  Complex
rules govern this classification process.



In addition, this limitation is calculated
separately with respect to specific “baskets” of income such as passive income, high withholding tax interest, financial
services income, shipping income, and certain other classifications of income.  Foreign taxes assigned to a particular
class of income generally cannot offset United States tax on income assigned to another class.  Under the American Jobs
Creation Act of 2004 (the “Act”), this basket limitation will be modified significantly after 2006.



Unused foreign tax credits can generally
be carried back one year and carried forward ten years.  U.S. Holders should consult their own tax advisors concerning
the ability to utilize foreign tax credits, especially in light of the changes made by the Act.



Backup Withholding



Payment of dividends and sales proceeds
that are made within the United States or through certain U.S.-related financial intermediaries generally are subject to information
reporting requirement and to backup withholding unless the US Holder (i) is a corporation or other exempt recipient or (ii) in
the case of backup withholding, provides a correct taxpayer identification number and certifies that no loss of exemption from
backup withholding has occurred



The amount of any backup withholding from
a payment to a US Holder will be allowed as a credit against the US Federal income tax liability of the US Holder and may entitle
the US Holder to a refund, provided that the required information is furnished to the IRS.



F.           DIVIDENDS
AND PAYING AGENTS



Not Applicable.  This Form 20-F is being filed as
an Annual Report filed under the Exchange Act.



G.           STATEMENT
BY EXPERTS



Not Applicable.  This Form 20-F is being filed as
an Annual Report filed under the Exchange Act.



H.           DOCUMENTS
ON DISPLAY



The documents and exhibits referred to
in this Annual Report are available for inspection at the registered and management office at 1 King Street West, Suite 1505, Toronto,
Ontario M5H 1A1 during normal business hours.



I.           SUBSIDIARY
INFORMATION



Not Applicable.  This Form 20-F is being filed as
an Annual Report filed under the Exchange Act.



80







ITEM 11       QUANTITATIVE
AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK



The Company is exposed in varying degrees
of risks arising from its financial instruments. The Company has entered
into certain financial derivative contracts. These instruments are not used for trading or speculative purposes. The Company has
not designated its financial derivative contracts as effective accounting hedges, and thus has not applied hedge accounting. As
a result, all financial derivative contracts are classified as fair value through “fair value through profit or loss”
and are recorded on the statement of financial position at fair value.



The Board approves
and monitors the risk management processes. The Board’s main objectives for managing risks are to ensure liquidity, the fulfillment
of obligations and limited exposure to credit and market risks while ensuring greater returns on any surplus funds.



The Company has classified its financial
instruments as follows:





|Financial Instrument                         |  | Category                          |  | Measurement method
|-------------------------------------------- |  | --------------------------------- |  | ------------------
|Cash                                         |  | Fair value through profit or loss |  | Fair value        
|Marketable securities                        |  | Fair value through profit or loss |  | Fair value        
|Derivative liabilities                       |  | Fair value through profit or loss |  | Fair value        
|Trade and other receivables                  |  | Loans and receivables             |  | Amortized cost    
|Trade and other payables                     |  | Other financial liabilities       |  | Amortized cost    
|Provisions                                   |  | Other financial liabilities       |  | Amortized cost    
|Secured note payable and shareholders’ loans |  | Other financial liabilities       |  | Amortized cost    







The types of risk exposure and the ways
in which such exposures are managed are as follows:



Credit Risk

Credit risk is primarily related to the
Company’s receivables from joint venture partners and the risk of financial loss if a partner or counterparty to a financial
instrument fails to meet its contractual obligations. Receivables from joint venture partners are normally collected within one
to three months of the joint venture bill being issued to the partner. The Company historically has not experienced any collection
issues with its joint venture partners to date. The Company attempts to mitigate the risk from joint venture receivables by obtaining
partner approval of significant capital expenditures prior to expenditure. The Company establishes an allowance for doubtful accounts
as determined by management based on their assessed collectability; therefore, the carrying amount of trade and other receivables
generally represents the maximum credit exposure. The Company believes that its counterparties currently have the financial capacity
to settle outstanding obligations in the normal course of business.



Concentration risks exist in cash because
significant balances are maintained with one financial institution. The risk is mitigated because the financial institution is
an international bank.



The Company’s maximum exposure to
credit risk is as follows:



|                              |  | August 31, 2014 |         |  | August 31, 2013 |  
|----------------------------- |  | --------------- | ------- |  | --------------- | -
|Cash                          |  | $               | 103,215 |  |                 | $
|Trade and other receivables   |  |                 | 157,121 |  |                 |  
|Prepaid expenses and deposits |  |                 |         |  |                 |  
|Balance                       |  | $               | 260,336 |  |                 | $



Liquidity Risk

The Company monitors its liquidity position
regularly to assess whether it has the funds necessary to fulfill planned exploration commitments on its oil and gas properties
or that viable options are available to fund such commitments from new equity issuances or alternative sources such as farm-out
agreements. However, as an exploration company at an early stage of development and without significant internally generated cash
flow, there are inherent liquidity risks, including the possibility that additional financing may not be available to the Company,
or that actual exploration expenditures may exceed those planned. The current uncertainty in global markets could have an impact
on the Company’s future ability to access capital on terms that are acceptable to the Company. The Company has so far been
able to raise the required financing to meet its obligations however, there can be no assurance that it will continue to do so
in the future. The following table illustrates the contractual maturities of financial liabilities:



81







|                          |  | Payments Due by Period |          
|------------------------- |  | ---------------------- | ---------
|August 31, 2014           |  | Total                  |          
|Trade and others payables |  | $                      | 1,483,775
|Shareholders’ loans (1)   |  |                        | 981,834  
|Total                     |  | $                      | 2,465,609



|                          |  | Payments Due by Period |          
|------------------------- |  | ---------------------- | ---------
|August 31, 2013           |  | Total                  |          
|Trade and others payables |  | $                      | 1,379,581
|Secured note payable (1)  |  |                        | 1,013,088
|Shareholders’ loans (1)   |  |                        | 2,108,205
|Total                     |  | $                      | 4,500,874



| | (1) | Translated at current exchange rate.
| | --- | ------------------------------------



Market Risk

Market risk represents the risk of loss
that may impact the Company’s financial position, results of operations, or cash flows due to adverse changes in financial
market prices, including interest rate risk, foreign currency exchange rate risk, commodity price risk, and other relevant market
or price risks. The Company does not use derivative financial instruments or derivative commodity instruments to mitigate this
risk.



The oil and gas industry is exposed to
a variety of risks including the uncertainty of finding and recovering economic reserves, the performance of hydrocarbon reservoirs,
securing markets for production, commodity prices, interest rate fluctuations, potential damage to or malfunction of equipment
and changes to income tax, royalty, environmental or other such factors.



Market events and conditions in recent
years including oil and gas supply and demand, disruptions in the international credit markets and other financial systems and
the deterioration of global economic conditions have caused significant volatility to commodity prices. These conditions contributed
to a loss of confidence in the broader U.S. and global credit and financial markets. Notwithstanding various actions by governments,
concerns about the general condition of the capital markets, financial instruments, banks, investment banks, insurers and other
financial institutions contributed to the broader credit markets to further deteriorate and stock markets to decline. These factors
have negatively impacted company valuations and may impact the performance of the global economy going forward. Although economic
conditions improved, the recovery has been slow in various sectors including in Europe and the United States and has been impacted
by various ongoing factors including sovereign debt levels and high levels of unemployment which continue to impact commodity prices
and to result in volatility in the stock market.



The Company mitigates these risks by:



| | • | utilizing competent, professional consultants as support
to management,
| | - | -----------------------------------------------------------------------

| | • | reviewing available petrophyisical analysis of prospects,
| | - | ---------------------------------------------------------

| | • | focusing on a limited number of core properties.
| | - | ------------------------------------------------



| | (i) | Commodity Price Risk
| | --- | --------------------



Commodity price risk is the risk that the
fair value or future cash flows will fluctuate as a result of changes in commodity prices. Commodity prices for petroleum and natural
gas are impacted by world economic events that affect the levels of supply and demand.



The Company believes that movement in commodity
prices that are reasonably possible over the next twelve month period may have a significant impact on the Company as all its oil
properties are still in a development stage.



Commodity Price Sensitivity



The following table summarizes the sensitivity
of the fair value of the Company’s risk management position for the year ended August 31, 2014 and 2013 to fluctuations in
natural gas prices, with all other variables held constant. When assessing the potential impact of these price changes, the Company
utilized a 10 percent volatility as a reasonable measure of illustration. Fluctuations in natural gas prices potentially could
have resulted in unrealized gains (losses) impacting net income as follows:



82







|            |  | 2014         |            |   | 2013         |  
|----------- |  | ------------ | ---------- | - | ------------ | -
|            |  | Increase 10% |            |   | Decrease 10% |  
|Net revenue |  | $            | 72,451     |   |              | $
|Net loss    |  | $            | (6,108,158 | ) |              | $



| | (ii) | Currency Risk
| | ---- | -------------



The Company is exposed to the fluctuations
in foreign exchange rates. The prices received by the Company for the production of natural gas and natural gas liquids are primarily
determined in reference to United States dollars but are settled with the Company in Canadian dollars. The Company’s cash
flow for commodity sales will therefore be impacted by fluctuations in foreign exchange rates.



The Company operates in Canada and a portion
of its expenses are incurred in U.S. dollars. A significant change in the currency exchange rates between the Canadian dollar relative
to US dollar could have an effect on the Company’s financial instruments. The Company does not hedge its foreign currency
exposure.



The following assets and liabilities are
denominated in US dollars at August 31, 2014 and 2013:



|                                                  |  | August 31, 2014 |            |   | August 31, 2013 |  
|------------------------------------------------- |  | --------------- | ---------- | - | --------------- | -
|Cash                                              |  | $               | 73,099     |   |                 | $
|Trade and other receivables                       |  |                 | 74,091     |   |                 |  
|Exploration and evaluation assets                 |  |                 | 4,638,600  |   |                 |  
|Prepaid expenses and deposits                     |  |                 | 27,478     |   |                 |  
|Trade and other  payables                         |  |                 | (882,877   | ) |                 |  
|Provisions                                        |  |                 | (32,948    | ) |                 |  
|Derivative liabilities                            |  |                 | (4,899,511 | ) |                 |  
|Shareholders’ loans                               |  |                 | (904,250   | ) |                 |  
|Secured note payable                              |  |                 | -          |   |                 |  
|Deferred revenue                                  |  |                 | (165,000   | ) |                 |  
|Net assets denominated in US$                     |  | $               | (2,071,318 | ) |                 | $
|Net asset CDN dollar equivalent at period end (1) |  | $               | (2,249,038 | ) |                 | $



|(1)	Translated at the exchange rate in effect at August 31, 2014 $1.0858 (August 31, 2013 $1.0553)
|--------------------------------------------------------------------------------------------------



The following table shows the estimated
sensitivity of the Company’s total comprehensive loss for the periods set out from a change in the U.S dollar exchange rate
in which the Company has exposure with all other variables held constant.



|                                |    |   | August 31, 2014                                                                |  |          | August 31, 2013                                                                | 
|------------------------------- | -- | - | ------------------------------------------------------------------------------ |  | -------- | ------------------------------------------------------------------------------ | 
|                                |    |   | Increase                                                                       |  |          | Decrease                                                                       | 
|Percentage change 
in US Dollar |    |   | In total comprehensive loss
    from a change in % in the US Exchange Rate ($) |  |          | In total comprehensive loss
    from a change in % in the US Exchange Rate ($) | 
|                                | 2  | % |                                                                                |  | (48,840  | )                                                                              | 
|                                | 4  | % |                                                                                |  | (97,680  | )                                                                              | 
|                                | 6  | % |                                                                                |  | (146,250 | )                                                                              | 
|                                | 8  | % |                                                                                |  | (195,360 | )                                                                              | 
|                                | 10 | % |                                                                                |  | (244,201 | )                                                                              | 



| | (iii) | Interest Rate Risk
| | ----- | ------------------



Interest rate risk refers to the risk that
the value of a financial instrument or cash flows associated with the instrument will fluctuate due to changes in market interest
rates. The majority of the Company’s debt is short-term in nature with fixed rates. Based on management's knowledge and experience
of the financial markets, the Company believes that the movements in interest rates that are reasonably possible over the next
twelve month period will not have a significant impact on the Company.



83







| | (iv) | Fair Value of Financial Instruments
| | ---- | -----------------------------------



The Company’s financial instruments
included on the consolidated statement of financial position as at August 31, 2014 and 2013 are comprised of cash, derivative liabilities,
trade and other receivables, trade and other payables, secured note payable, shareholders’ loans and provisions.



The Company classifies the fair value of
financial instruments measured at fair value according to the following hierarchy based on the amount of observable inputs used
to value the instrument.



• 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
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. Prices in Level 2 are either directly or indirectly observable
as of the reporting date. Level 2 valuations are based on inputs, including quoted forward prices for commodities, time value and
volatility factors, which can be substantially observed or corroborated in the marketplace.



• Level 3 – Valuations in this
level are those with inputs for the asset or liability that are not based on observable market data.



|                                    |  | August 31, 2014   |           |  | August 31, 2013 | 
|----------------------------------- |  | ----------------- | --------- |  | --------------- | 
|Financial Instrument Classification |  | Carrying Value
 $ |           |  | Fair Value $    | 
|Fair value through profit or loss:  |  |                   |           |  |                 | 
|Cash                                |  |                   | 103,215   |  |                 | 
|Derivative liabilities              |  |                   | 5,325,407 |  |                 | 
|Loans and receivables:              |  |                   |           |  |                 | 
|Trade and other receivables         |  |                   | 157,121   |  |                 | 
|Other financial liabilities:        |  |                   |           |  |                 | 
|Trade and other  payables           |  |                   | 1,483,775 |  |                 | 
|Secured note payable                |  |                   | -         |  |                 | 
|Shareholders’ loans                 |  |                   | 981,834   |  |                 | 
|Provisions                          |  |                   | 47,543    |  |                 | 



Cash and derivative liabilities are stated
at fair value (Level 1 measurement). The carrying value of trade and other receivables, trade and other payables, secured note
payable, shareholders’ loans and provisions approximate their fair value due to the short-term maturity of these financial
instruments (Level 3 measurement).



ITEM 12       DESCRIPTION
OF SECURITIES OTHER THAN EQUITY SECURITIES



A.           DEBT
SECURITIES



Not applicable.



B.           WARRANTS
AND RIGHTS



Not applicable.



C.           OTHER
SECURITIES



Not Applicable.



D.           AMERICAN
DEPOSITORY SHARES



Not Applicable.



84







PART II



| | ITEM | 13       DEFAULTS, DIVIDENDS ARREARAGES AND
                                                                                      DELINQUENCIES
| | ---- | -----------------------------------------------------------------------------------------------------------------------------------------------



Not Applicable.





| | ITEM 14 | MATERIAL
MODIFICATIONS TO THE RIGHTS OF SECURITY HOLDERS AND USE OF PROCEEDS
| | ------- | ----------------------------------------------------------------------------





Not applicable.



| | ITEM | 15      CONTROLS AND PROCEDURES
| | ---- | -------------------------------





Disclosure Controls and Procedures

Under the supervision and with the
participation of our senior management, including our chief executive officer and chief financial officer, James Cassina, we conducted
an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures, as defined in Rules
13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), as of the end
of the period covered by this annual report (the “Evaluation Date”). Based on this evaluation, our chief executive
officer and chief financial officer concluded as of the Evaluation Date that our disclosure controls and procedures were effective
such that the information relating to us, required to be disclosed in our Securities and Exchange Commission (“SEC”)
reports (i) is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms, and (ii)
is accumulated and communicated to our management, including our chief executive officer and chief financial officer, as appropriate
to allow timely decisions regarding required disclosure.



Management’s Annual Report on
Internal Control over Financial Reporting



Our management is responsible for establishing
and maintaining adequate internal control over financial reporting. Our internal control over financial reporting is a process
designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements
for external reporting purposes in accordance with generally accepted accounting principles.



Our internal control over financial reporting
includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and
fairly reflect transactions and dispositions of assets; (ii) provide reasonable assurances that transactions are recorded as necessary
to permit preparation of financial statements in accordance with generally accepted accounting principles and that receipts and
expenditures are being made only in accordance with authorizations of management and the directors of the Company; and (iii) provide
reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Company's
assets that could have a material effect on our financial statements. Because of its inherent limitations, internal control over
financial reporting may not prevent or detect misstatements.



Management assessed the effectiveness of
our internal control over financial reporting as of August 31, 2014 based on the framework established in Internal Control—Integrated
Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on that assessment, management
concluded that, as of August 31, 2014, our internal control over financial reporting was effective based on the criteria established
in Internal Control—Integrated Framework.



Limitations on Effectiveness of Controls
and Procedures

Our management, including our Chief Executive
Officer (Principal Executive Officer) and Chief Financial Officer (Principal Financial Officer), does not expect that our disclosure
controls and procedures or our internal controls will prevent all errors 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. Our control
systems are designed to provide such reasonable assurance of achieving their objectives. 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 its stated goals under all potential future
conditions. Over time, controls may become inadequate because of changes in conditions, or the degree of compliance with the policies
or procedures may deteriorate. Because of the inherent limitations in a cost-effective control system, misstatements due to error
or fraud may occur and not be detected.



85







Changes in Internal Control over Financial
Reporting

There have been no changes in our internal
control over financial reporting that occurred during the quarter ended August 31, 2014 that have materially affected or are reasonably
likely to materially affect our internal control over financial reporting.



| | ITEM | 16       [RESERVED]
| | ---- | -------------------



A.           AUDIT
COMMITTEE FINANCIAL EXPERT



Our Board of Directors has determined
that Mr. Milton Klyman is an "audit committee financial expert", as defined in Item 16A of Form 20-F and is
independent. Milton Klyman is the Chairman of the Audit Committee.  He is a self-employed financial consultant and has
been a Chartered Professional Accountant since 1952.  Milton Klyman is a Life Member of the Institute of Chartered Professional
Accountants of Ontario, a Life member of the Canadian Institute of Mining Metallurgy and Petroleum and a Fellow of the Institute
of Chartered Secretaries and Administrators.



B.           CODE
OF ETHICS



We have adopted a written code of business
conduct and ethics (the "Code") for our directors, officers and employees. The board encourages following the Code by
making it widely available. It is distributed to directors in the Director’s Manual and to officers, employees and consultants
at the commencement of their employment or consultancy.  The Code reminds those engaged in service to us that they are
required to report perceived or actual violations of the law, violations of our policies, dangers to health, safety and the environment,
risks to our property, and accounting or auditing irregularities to the chair of the Audit Committee who is an independent director
of ours. In addition, to requiring directors, officers and employees to abide by the Code, we encourage consultants, service providers
and all parties who engage in business with us to contact the chair of the Audit Committee regarding any perceived and all actual
breaches by our directors, officers and employees of the Code. The chair of our Audit Committee is responsible for investigating
complaints, presenting complaints to the applicable board committee or the board as a whole, and developing a plan for promptly
and fairly resolving complaints. Upon conclusion of the investigation and resolution of a complaint, the chair of our Audit Committee
will advise the complainant of the corrective action measures that have been taken or advise the complainant that the complaint
has not been substantiated. The Code prohibits retaliation by us, our directors and management, against complainants who raise
concerns in good faith and requires us to maintain the confidentiality of complainants to the greatest extent practical. Complainants
may also submit their concerns anonymously in writing. In addition to the Code, we have an Audit Committee Charter and a Policy
of Procedures for Disclosure Concerning Financial/Accounting Irregularities.



Since the beginning of our most recently
completed financial year, no material change reports have been filed that pertain to any conduct of a director or executive officer
that constitutes a departure from the Code. The board encourages and promotes a culture of ethical business conduct by appointing
directors who demonstrate integrity and high ethical standards in their business dealings and personal affairs. Directors are required
to abide by the Code and expected to make responsible and ethical decisions in discharging their duties, thereby setting an example
of the standard to which management and employees should adhere. The board is required by the Board Mandate to satisfy our CEO
and other executive officers are acting with integrity and fostering a culture of integrity throughout the Company. The board is
responsible for reviewing departures from the Code, reviewing and either providing or denying waivers from the Code, and disclosing
any waivers that are granted in accordance with applicable law. In addition, the board is responsible for responding to potential
conflict of interest situations, particularly with respect to considering existing or proposed transactions and agreements in respect
of which directors or executive officers advise they have a material interest. The Board Mandate requires that directors and executive
officers disclose any interest and the extent, no matter how small, of their interest in any transaction or agreement with us,
and that directors excuse themselves from both board deliberations and voting in respect of transactions in which they have an
interest. By taking these steps the board strives to ensure that directors exercise independent judgment, unclouded by the relationships
of the directors and executive officers to each other and us, in considering transactions and agreements in respect of which directors
and executive officers have an interest. Our Code applies to our directors, officers and employees, including our principal executive
officer, principal financial officer, principal accounting officer or persons performing similar functions of the Company. There
have been no waivers of our Code granted to our principal executive officer, principal financial officer, principal accounting
officer or controller, or similar persons during the period covered by this Annual Report.



86







Upon written request to us at our registered
and management office, attention: the President, we will provide by mail, to any person without charge a copy of our Code of Ethics.



C.           PRINCIPAL
ACCOUNTANT FEES AND SERVICES



It is the policy of the Audit Committee
that all audit and non-audit services are pre-approved prior to engagement. Before the initiation of each audit, the principal
accountant submits a budget of the expected range of expenditures to complete their audit engagement (including Audit Fees, Audit-Related
Fees and Tax Fees) to the Audit Committee for approval. In the event that the principal accountant exceeds these parameters, the
individual auditor is expected to communicate to management the reasons for the variances, so that such variances can be ratified
by the Audit Committee. As a result, 100% of expenditures within the scope of the noted budget are approved by the Audit Committee.



During fiscal 2014 and 2013 there were
no hours performed by any person other than the primary accountant’s fulltime permanent employees.



Since the commencement of the Company's
most recently completed financial year, no recommendations were made by the Audit Committee to nominate or compensate an external
auditor.



External Auditor Service Fees (By Category)



The aggregate fees billed or accrued for
professional fees rendered by Schwartz Levitsky Feldman llp, Chartered Accountants for the years ended August 31, 2014 and August
31, 2013 are as follows:



|Nature of Services    |  | Fees Paid to Auditor for Year- ended  August 31, 2014 |        |  | Fees Paid to Auditor for Year- ended  August 31, 2013 |  
|--------------------- |  | ----------------------------------------------------- | ------ |  | ----------------------------------------------------- | -
|Audit Fees(1)         |  | $                                                     | 55,000 |  |                                                       | $
|Audit-Related Fees(2) |  |                                                       | Nil    |  |                                                       |  
|Tax Fees(3)           |  |                                                       | 5,000  |  |                                                       |  
|All Other Fees(4)     |  |                                                       | Nil    |  |                                                       |  
|TOTALS                |  | $                                                     | 60,000 |  |                                                       | $



Notes:



| | 1. | "Audit Fees" include fees necessary to perform the annual audit and any quarterly
reviews of the Company's financial statements management discussion and analysis. This includes fees for the review of tax provisions
and for accounting consultations on matters reflected in the financial statements. This also includes audit or other attest services
required by legislation or regulation, such as comfort letters, consents, reviews of securities filings and statutory audits.
| | -- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | 2. | "Audit-Related Fees" include fees for assurance and related services that are
reasonably related to the performance of the audit or review of the Company's financial statements and that are not included in
"Audit Fees".
| | -- | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | 3. | "Tax Fees" include fees for all professional services rendered by the Company's
auditors for tax compliance, tax advice and tax planning.
| | -- | -----------------------------------------------------------------------------------------------------------------------------------------



| | 4. | "All Other Fees" include all fees for products and services provided by the Company's
auditors not included in "Audit Fees", "Audit-Related Fees" and "Tax Fees".
| | -- | -----------------------------------------------------------------------------------------------------------------------------------------------------------------



D.           EXEMPTIONS
FROM THE LISTING STANDARDS FOR AUDIT COMMITTEES



Not Applicable.



E.           PURCHASES
OF EQUITY SECURITIES BY THE ISSUER AND AFFILIATED PURCHASERS



Not applicable.



87









F.           CHANGE
IN REGISTRANT’S CERTIFYING ACCOUNTANT



Not Applicable.



G.           CORPORATE
GOVERNANCE



Not Applicable.



H.	 MINE SAFETY DISCLOSURE



Not applicable.



PART III



ITEM 17       FINANCIAL
STATEMENTS



Not applicable.



ITEM 18     FINANCIAL STATEMENTS



The following attached Consolidated Financial
Statements are included in this Annual Report on Form 20-F beginning with page F-1:



| | 1. | Audited Consolidated Financial Statements of Eagleford Energy Corp.
for the years ended August 31, 2014 and 2013, comprised of the following:
| | -- | ---------------------------------------------------------------------------------------------------------------------------------------------



| | (a) | Independent Auditor’s Report of Registered Public Accounting Firm, Schwartz Levitsky Feldman
LLP, Chartered Accountants for the years ended August 31, 2014 and 2013;
| | --- | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (b) | Consolidated Statements
of Financial Position as at August 31, 2014 and 2013;
| | --- | -----------------------------------------------------------------------------



| | (c) | Consolidated Statements of Operations and Comprehensive Loss for the years ended August 31, 2014,
2013 and 2012;
| | --- | ----------------------------------------------------------------------------------------------------------------



| | (d) | Consolidated Statements
of Shareholders’ Equity (Deficiency) for the years ended August 31, 2014, 2013 and 2012;
| | --- | ----------------------------------------------------------------------------------------------------------------



| | (e) | Consolidated Statements
of Cash Flows for the years ended August 31, 2014, 2013 and 2012;
| | --- | -----------------------------------------------------------------------------------------



| | (f) | Notes to the Consolidated
Financial Statements.
| | --- | -----------------------------------------------



ITEM 19     EXHIBITS



The following exhibits are included in the Annual Report on
Form 20-F:



|Exhibit # |  | Description                                                                                                                                                             
|--------- |  | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|1.1       |  | Certificate of Incorporation of Bonanza Red Lake Explorations Inc. (presently known as Eagleford Energy Inc.) dated September 22, 1978 (1)                              
|1.2       |  | Articles of Amendment dated January 14, 1985 (1)                                                                                                                        
|1.3       |  | Articles of Amendment dated August 16, 2000 (1)                                                                                                                         
|1.4       |  | Bylaw No 1 of Bonanza Red Lake Explorations Inc. (presently known as Eagleford Energy Inc.) (1)                                                                         
|1.5       |  | Special By-Law No 1 – Respecting the borrowing of money and the issue of securities of Bonanza Red Lake Explorations Inc. (presently known as Eagleford Energy Inc.) (1)
|1.6       |  | Articles of Amalgamation dated November 30, 2009 (3)                                                                                                                    
|4.1       |  | 2000 Stock Option Plan (1)                                                                                                                                              
|4.2       |  | Code of Business Conduct and Ethics (1)                                                                                                                                 
|4.3       |  | Audit Committee Charter (1)                                                                                                                                             



88







|4.4  |  | Petroleum
    and Natural Gas Committee Charter (1)                                                                                                                                                                     
|---- |  | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|4.5  |  | Compensation Committee
    Charter (1)                                                                                                                                                                                  
|4.6  |  | Purchase and Sale
    Agreement dated February 5, 2008 among Eugenic Corp., 1354166 Alberta Ltd., and the Vendors of 1354166 Alberta Ltd. (1)                                                                           
|4.7  |  | Amended Audit
    Committee Charter (3)                                                                                                                                                                                 
|4.8  |  | Amended Stock
    Option Plan (4)                                                                                                                                                                                       
|4.9  |  | Asset Purchase
    Agreement between Eagleford Energy Inc., and Source Re-Work Program Inc., dated May 12, 2010 (6)                                                                                                     
|4.10 |  | Addendum dated
    June 10, 2010 to the Asset Purchase Agreement between Eagleford Energy Inc. and Source Re-Work Program Inc., dated May 12,
    2010 (6)                                                              
|4.11 |  | Addendum 2 dated
    June 30, 2010 to the Asset Purchase Agreement between Eagleford Energy Inc. and Source Re-Work Program Inc., dated May 12,
    2010 (6)                                                            
|4.12 |  | Acquisition  Agreement
    among Eagleford Energy Inc., Dyami Energy LLC and the Members of Dyami Energy LLC dated August 10, 2010 (5)                                                                                  
|4.13 |  | Financial Advisory
    Services Agreement between Eagleford Energy Inc. and GarWood Securities, LLC dated June 10, 2010 (6)                                                                                             
|4.14 |  | Amended Stock
    Option Plan, February 24, 2011 (7)                                                                                                                                                                    
|4.15 |  | Amendment dated
    December 31, 2011 to 6% Secured Promissory Note between Eagleford Energy Inc. and Benchmark Enterprises LLC (8)                                                                                     
|4.16 |  | Consent of Sproule
    Associates Limited dated February 16, 2012 (9)                                                                                                                                                   
|4.17 |  | Evaluation of
    P&NG Reserves of Eagleford Energy Inc., at August 31, 2011 (11)                                                                                                                                       
|4.18 |  | Amended Stock
    Option Plan, February 24, 2012  (8)                                                                                                                                                                   
|4.19 |  | By-Law No. 1,
    February 24, 2012 (8)                                                                                                                                                                                 
|4.20 |  | Articles of Amendment,
    effective March 16, 2012  (10)                                                                                                                                                               
|4.21 |  | 2nd
    Amendment dated June 30, 2012 to 6% Secured Promissory Note between Eagleford Energy Inc. and Benchmark Enterprises LLC (12)                                                                                    
|4.22 |  | Evaluation of
    P&NG Reserves of Eagleford Energy Inc., at August 31, 2012 (12)                                                                                                                                       
|4.23 |  | Consent of Sproule
    Associates Limited dated (12)                                                                                                                                                                    
|4.24 |  | Placement Agency
    Agreement dated March 12, 2012 between Eagleford Energy Inc. and Gottbetter Capital Markets, LLC(12)                                                                                               
|4.25 |  | Amendment dated
    April 13, 2012 to Placement Agency Agreement dated March 12, 2012 between Eagleford Energy Inc. and Gottbetter Capital Markets,
    LLC (12)                                                        
|4.26 |  | Amendment No.
    2 dated July 17, 2012 to Placement Agency Agreement dated March 12, 2012 between Eagleford Energy Inc. and Gottbetter Capital
    Markets, LLC (12)                                                   
|4.27 |  | Amendment No.
    3 dated August 14, 2012 to Placement Agency Agreement dated March 12, 2012 between Eagleford Energy Inc. and Gottbetter Capital
    Markets, LLC (12)                                                 
|4.28 |  | Amendment No.
    4 dated August 31, 2012 to Placement Agency Agreement dated March 12, 2012 between Eagleford Energy Inc. and Gottbetter Capital
    Markets, LLC (12)                                                 
|4.29 |  | 3rd
     Amendment dated November 23, 2012 to Secured Promissory Note between Eagleford Energy Inc. and Benchmark Enterprises
    LLC (12)                                                                              
|4.30 |  | 4th
     Amendment dated March 1, 2013 to Secured Promissory Note between Eagleford Energy Inc. and Benchmark Enterprises LLC
    (13)                                                                                  
|4.31 |  | Eagleford Energy,
    Zavala Inc., Certificate of Incorporation  dated August 29, 2013 (13)                                                                                                                             
|4.32 |  | Rule 14 Agreement
    among The Matthews Family Mineral Account, LP, Delta  Star Holdings, LLC, Dyami Energy, LLC, Eagleford Energy, Inc.,OGR
    Energy Corporation, OGR 2000 Ltd., and Texas Onshore Energy, Inc. (13)
|4.33 |  | Termination of
    Financial Advisory Agreement between Eagleford Energy Inc. and The PrinceRidge Group LLC dated September 5, 2013 (13)                                                                                
|4.34 |  | Joint Development
    Agreement dated December 3, 2013 between Eagleford Energy Inc., Eagleford Energy, Zavala Inc., and Stratex Oil and Gas Holdings,
    Inc. (13)                                                    
|4.35 |  | Articles of Amendment,
    effective August 25, 2014 (14)                                                                                                                                                               
|4.36 |  | Amendment dated
    January 21, 2014 to the Joint Development Agreement between Eagleford Energy Inc., Eagleford Energy, Zavala Inc., and Stratex
    Oil and Gas Holdings, Inc. (15)                                   
|4.37 |  | Joint Development
    Agreement dated April 11, 2014 by and among Quadrant Resources LLC Eagleford Energy, Zavala Inc., and Stratex Oil and Gas
    Holdings, Inc.(15)                                                  
|4.38 |  | Secured Convertible
    Promissory Note, General Security Agreement and Release dated August31,
    2014 between Eagleford Energy Inc. and Benchmark Enterprises LLC (15)                                               



89









|8.1       |  | Subsidiaries of Eagleford Energy Inc. (15)                             
|--------- |  | -----------------------------------------------------------------------
|12.1/12.2 |  | Section 302 Certification of Chief Executive and Financial Officer (15)
|13.1/13.2 |  | Section 906 Certification of Chief Executive and Financial Officer (15)







|Reference # |  | Incorporated by Reference                                                                                             
|----------- |  | ----------------------------------------------------------------------------------------------------------------------
|(1)         |  | Previously filed on April 29, 2009 by Registrant as part of Registration Statement on Form 20-F (SEC File No. 0-53646)
|(2)         |  | Previously Filed by Registrant as part of Amendment #2 to Registration Statement on Form 20F/A on July 14, 2009       
|(3)         |  | Previously Filed by Registrant on Form 6 K on December 1, 2009                                                        
|(4)         |  | Previously filed by Registrant on Form 20F/A on March 12, 2010                                                        
|(5)         |  | Previously filed by Registrant on Form 6-K on September 16, 2010                                                      
|(6)         |  | Previously Filed by Registrant on Form 20F on February 11, 2011                                                       
|(7)         |  | Previously filed by Registrant on Form 6-K on January 27, 2011                                                        
|(8)         |  | Previously filed by Registrant on Form 6-K on February 1, 2012                                                        
|(9)         |  | Previously filed by Registrant on Form 20F on February 16, 2012                                                       
|(10)        |  | Previously filed by Registrant on Form 6-K on March 9, 2012                                                           
|(11)        |  | Previously filed by Registrant on Form 20F/A on April 26, 2012                                                        
|(12)        |  | Previously filed by Registrant on Form 20F on December 31, 2012                                                       
|(13)        |  | Previously filed by Registrant on Form 20F on December 24, 2013                                                       
|(14)        |  | Previously filed by Registrant on Form 6-K on August 20, 2014                                                         
|(15)        |  | Filed as an Exhibit hereto                                                                                            



The registrant hereby certifies that it
meets all of the requirements for filing on Form 20-F and that it has duly caused and authorized the undersigned to sign this Annual
Report on its behalf.



| | EAGLEFORD ENERGY CORP.
| | ----------------------
| |                       
| | By:                   
| |                       
| |                       



Date: December 31, 2014



90







INDEX TO FINANCIAL STATEMENTS



Audited Consolidated Financial Statements of Eagleford Energy
Corp. for the years ended August 31, 2014, and 2013 , comprised of the following:









|(a) | Independent Auditor’s Report of Registered Public Accounting Firm,  Schwartz Levitsky Feldman LLP, Chartered Accountants for the years ended August 31, 2014 and 2013; |  | F-2   
|--- | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------- |  | ------
|(b) | Consolidated Statements of Financial Position for the years ended August 31, 2014 and 2013;                                                                            |  | F-4   
|(c) | Consolidated Statements of Operations and Comprehensive Loss for the years ended August 31, 2014, 2013 and 2012;                                                       |  | F-5   
|(d) | Consolidated Statements of Shareholders’ Equity (Deficiency) for the years ended August 31, 2014, 2013 and 2012;                                                       |  | F-6   
|(e) | Consolidated Statements of Cash Flows for the years ended August 31, 2014, 2013 and 2012;                                                                              |  | F-7   
|(f) | Notes to the Consolidated Financial Statements.                                                                                                                        |  | F8-F37





F-1











Schwartz Levitsky Feldman llp

CHARTERED ACCOUNTANTS

LICENSED PUBLIC ACCOUNTANTS

TORONTO·MONTREAL



INDEPENDENT AUDITOR’S REPORT OF
REGISTERED PUBLIC ACCOUNTING FIRM



To the Shareholders of Eagleford Energy
Corp.

(Formerly Eagleford Energy Inc.)



We have audited the accompanying consolidated
financial statements of Eagleford Energy Corp. (formerly: Eagleford Energy Inc.) (the “Company”), which comprise the
consolidated statements of financial position as at August 31, 2014 and 2013, the consolidated statements of operations and comprehensive
loss, changes in shareholders’ equity (deficiency) and cash flows for the years ended August 31, 2014, 2013 and 2012, and
a summary of significant accounting policies and other explanatory information.



Management's Responsibility for the
Consolidated Financial Statements



Management is responsible for the preparation
and fair presentation of these consolidated financial statements in accordance with International Financial Reporting Standards
as issued by the International Accounting Standards Board, and for such internal control as management determines is necessary
to enable the preparation of the consolidated financial statements that are free from material misstatement, whether due to fraud
or error.



Auditor's Responsibility



Our responsibility is to express an opinion
on these consolidated financial statements based on our audits. We conducted our audits in accordance with Canadian generally accepted
auditing standards and the Standards of the Public Company Accounting Oversight Board (United States). Those standards require
that we comply with ethical requirements and plan and perform the audit to obtain reasonable assurance about whether the consolidated
financial statements are free from material misstatement. We were not engaged to perform an audit of the Company’s internal
control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for
designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness
of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.



An audit involves performing procedures
to obtain audit evidence about the amounts and disclosures in the consolidated financial statements. The procedures selected depend
on the auditor's judgment, including the assessment of the risks of material misstatement of the consolidated financial statements,
whether due to fraud or error. An audit also includes evaluating the appropriateness of accounting policies used and the reasonableness
of accounting estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements.



| | 2300 Yonge Street, Suite 1500, Box 2434
        Toronto, Ontario M4P 1E4
        Tel:  416 785 5353
        Fax:  416 785 5663
| | ------------------------------------------------------------------------------------------------------------------------------



F-2







We believe that the audit evidence we have
obtained in our audits is sufficient and appropriate to provide a basis for our audit opinion.



Opinion



In our opinion, the consolidated financial
statements present fairly, in all material respects, the financial position of Eagleford Energy Corp. (formerly: Eagleford Energy
Inc.) as at August 31, 2014 and 2013, and its financial performance and its cash flows for the years ended August 31, 2014, 2013
and 2012 in accordance with International Financial Reporting Standards as issued by the International Accounting Standards Board.



Emphasis of Matter



Without qualifying our opinion, we draw
attention to Note 1 in the consolidated financial statements which indicates that the Company incurred a net loss of $6,115,585
during the year ended August 31, 2014 and, as of that date its current liabilities exceeded its current assets by $3,489,237. These
conditions, along with other matters as set forth in Note 1, raise substantial doubt about the Company's ability to continue
as a going concern. Management’s plans in regard to these matters are also described in Note 1. The consolidated financial
statements do not include any adjustments that might result from the outcome of this uncertainty.



|                         | /s/ “Schwartz
    Levitsky Feldman, llp”
|------------------------ | ----------------------------------------
|                         |                                         
|Toronto, Ontario, Canada | Chartered Accountants                   
|December 29, 2014        | Licensed Public Accountants             



F-3









(Formerly: Eagleford Energy Inc.)



|Consolidated Statements of Financial Position

(Expressed in Canadian Dollars) |  | August 31, 2014 |             |   | August 31, 2013 |  
|------------------------------------------------------------------------------ |  | --------------- | ----------- | - | --------------- | -
|Assets                                                                         |  |                 |             |   |                 |  
|Current assets                                                                 |  |                 |             |   |                 |  
|Cash                                                                           |  | $               | 103,215     |   |                 | $
|Trade and other receivables                                                    |  |                 | 157,121     |   |                 |  
|Prepaid expenses and deposits                                                  |  |                 | -           |   |                 |  
|Total current assets                                                           |  |                 | 260,336     |   |                 |  
|Non-current assets                                                             |  |                 |             |   |                 |  
|Exploration and evaluation assets (Note 6)                                     |  |                 | 5,036,592   |   |                 |  
|Total non-current assets                                                       |  |                 | 5,036,592   |   |                 |  
|                                                                               |  |                 |             |   |                 |  
|Total Assets                                                                   |  | $               | 5,296,928   |   |                 | $
|                                                                               |  |                 |             |   |                 |  
|Liabilities and Shareholders’ Equity (Deficiency)                              |  |                 |             |   |                 |  
|Current liabilities                                                            |  |                 |             |   |                 |  
|Trade and other payables                                                       |  | $               | 1,483,775   |   |                 | $
|Secured note payable (Note 10)                                                 |  |                 | -           |   |                 |  
|Shareholders’ loans (Note 9 and 10)                                            |  |                 | 981,834     |   |                 |  
|Derivative liabilities (Note 11)                                               |  |                 | 1,094,392   |   |                 |  
|Deferred revenue (Note 6)                                                      |  |                 | 177,804     |   |                 |  
|Provisions (Note 7(a))                                                         |  |                 | 11,768      |   |                 |  
|Total current liabilities                                                      |  |                 | 3,749,573   |   |                 |  
|Non-current liabilities                                                        |  |                 |             |   |                 |  
|Derivative liabilities (Note 11)                                               |  |                 | 4,231,015   |   |                 |  
|Provisions (Note 7(a))                                                         |  |                 | 35,775      |   |                 |  
|Total non-current liabilities                                                  |  |                 | 4,266,790   |   |                 |  
|                                                                               |  |                 |             |   |                 |  
|Total Liabilities                                                              |  |                 | 8,016,363   |   |                 |  
|                                                                               |  |                 |             |   |                 |  
|Shareholders’ equity (deficiency)                                              |  |                 |             |   |                 |  
|Share capital (Note 8 (a))                                                     |  |                 | 9,072,181   |   |                 |  
|Share purchase warrants (Note 8 (b))                                           |  |                 | 1,970,968   |   |                 |  
|Share purchase options  (Note 8 (d))                                           |  |                 | 170,972     |   |                 |  
|Contributed surplus (Note 8 (e))                                               |  |                 | 1,389,898   |   |                 |  
|Foreign currency translation reserve                                           |  |                 | 4,692       |   |                 |  
|Accumulated deficit                                                            |  |                 | (15,328,146 | ) |                 |  
|Total shareholders’ equity (deficiency)                                        |  |                 | (2,719,435  | ) |                 |  
|                                                                               |  |                 |             |   |                 |  
|Total Liabilities and Shareholders’ Equity (Deficiency)                        |  | $               | 5,296,928   |   |                 | $



Going Concern (Note 1)

Related Party Transactions and Balances (Note 9)

Commitments and Contingencies (Note 15)

Dissolution of Subsidiary (Note 16)

Subsequent Events (Note 17)



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



Approved by the Board of Directors



|/s/ “James
    Cassina” |  | /s/“Milton
    Klyman” 
|----------------------- |  | -----------------------
|James Cassina, Director |  | Milton Klyman, Director



F-4









(Formerly: Eagleford Energy Inc.)



Consolidated Statements of Operations and
Comprehensive Loss

|For the years ended August 31, (Expressed in Canadian Dollars)            |  | 2014 |            |   | 2013 |   |            | 2012 | 
|------------------------------------------------------------------------- |  | ---- | ---------- | - | ---- | - | ---------- | ---- | 
|                                                                          |  |      |            |   |      |   |            |      | 
|Revenue                                                                   |  |      |            |   |      |   |            |      | 
|Natural gas sales, net of royalties                                       |  | $    | 65,024     |   |      | $ | 30,062     |      | 
|Expenses                                                                  |  |      |            |   |      |   |            |      | 
|Operating costs                                                           |  |      | 17,138     |   |      |   | 9,234      |      | 
|Depletion and accretion                                                   |  |      | 2,449      |   |      |   | 13,283     |      | 
|General and administrative                                                |  |      | 403,120    |   |      |   | 583,577    |      | 
|Interest expense                                                          |  |      | 284,038    |   |      |   | 76,783     |      | 
|Loss on derivative liabilities (Note 11)                                  |  |      | 2,735,476  |   |      |   | 128,041    |      | 
|Loss on foreign exchange                                                  |  |      | 101,427    |   |      |   | 197,640    |      | 
|Marketing and public relations                                            |  |      | (14,250    | ) |      |   | 25,763     |      | 
|Loss on settlement of debt (Note 8 (b) (e))                               |  |      | 1,335,935  |   |      |   | 402,264    |      | 
|Impairment loss on exploration and evaluation assets, net (Note 6 and 16) |  |      | 1,315,276  |   |      |   | 2,690,568  |      | 
|Impairment loss on property and equipment                                 |  |      | -          |   |      |   | 168,954    |      | 
|Impairment loss on marketable securities                                  |  |      | -          |   |      |   | 1          |      | 
|Stock based compensation - non employees                                  |  |      | -          |   |      |   | -          |      | 
|Stock based compensation                                                  |  |      | -          |   |      |   | -          |      | 
|Compensation expense on re-pricing of units                               |  |      | -          |   |      |   | -          |      | 
|                                                                          |  |      | 6,180,609  |   |      |   | 4,296,108  |      | 
|                                                                          |  |      |            |   |      |   |            |      | 
|Net loss                                                                  |  |      | (6,115,585 | ) |      |   | (4,266,046 | )    | 
|                                                                          |  |      |            |   |      |   |            |      | 
|Other comprehensive income (loss)                                         |  |      |            |   |      |   |            |      | 
|Foreign currency translation                                              |  |      | (199,965   | ) |      |   | 314,120    |      | 
|Total other comprehensive income (loss)                                   |  |      | (199,965   | ) |      |   | 314,120    |      | 
|                                                                          |  |      |            |   |      |   |            |      | 
|Net loss and comprehensive loss                                           |  | $    | (6,315,550 | ) |      | $ | (3,951,926 | )    | 
|                                                                          |  |      |            |   |      |   |            |      | 
|Loss per shares, basic and diluted                                        |  | $    | (0.482     | ) |      | $ | (0.407     | )    | 
|                                                                          |  |      |            |   |      |   |            |      | 
|Weighted average shares outstanding, basic and diluted (Note 8 (c))*      |  |      | 12,675,329 |   |      |   | 10,477,429 |      | 



* Reflects the March 16, 2012 two-for-one stock split (Note
8 (a))

* Reflects the August 25, 2014 one-for-ten stock consolidation
(Note 8 (a))



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



F-5









(Formerly: Eagleford Energy Inc.)



Consolidated Statements of Changes in Shareholders’
Equity (Deficiency)

For the years ended August 31, 2014, 2013 and 2012

(Expressed in Canadian Dollars)

---







|                                         |  | SHARE CAPITAL Number of Shares* |            |   | SHARE CAPITAL Amount $ |  |            | SHARE PURCHASE WARRANTS $ |  |  | SHARE PURCHASE OPTIONS $ |   |  | CONTRI-
BUTED SURPLUS $ |         |  | FOREIGN CURRENCY TRANS-
LATION RESERVE $ |  |           | ACCU- MULATED DEFICIT $ |  |  | TOTAL SHARE- HOLDERS’ DEFICIENCY $ |  
|---------------------------------------- |  | ------------------------------- | ---------- | - | ---------------------- |  | ---------- | ------------------------- |  |  | ------------------------ | - |  | ----------------------- | ------- |  | ---------------------------------------- |  | --------- | ----------------------- |  |  | ---------------------------------- | -
|Balance, August 31, 2011                 |  |                                 | 6,712,788  |   |                        |  | 4,635,556  |                           |  |  | 252,637                  |   |  |                         | -       |  |                                          |  | 85,737    |                         |  |  | (109,303                           | )
|Issuance of shares as debt settlement    |  |                                 | 310,701    |   |                        |  | 395,589    |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | -         |                         |  |  | -                                  |  
|Issuance of units as debt settlement     |  |                                 | 1,715,000  |   |                        |  | 1,150,367  |                           |  |  | 1,102,348                |   |  |                         | -       |  |                                          |  | -         |                         |  |  | -                                  |  
|Private placement of units               |  |                                 | 200,000    |   |                        |  | 32,459     |                           |  |  | 67,541                   |   |  |                         | -       |  |                                          |  | -         |                         |  |  | -                                  |  
|Private placement of units               |  |                                 | 300,000    |   |                        |  | 342,786    |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | -         |                         |  |  | -                                  |  
|Compensation expense on re-pricing units |  |                                 | 75,000     |   |                        |  | -          |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | 118,507   |                         |  |  | -                                  |  
|Private placement of units               |  |                                 | 682,500    |   |                        |  | 702,528    |                           |  |  |                          |   |  |                         |         |  |                                          |  |           |                         |  |  |                                    |  
|Warrants expired                         |  |                                 | -          |   |                        |  | -          |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | 318,552   |                         |  |  | -                                  |  
|Issuance of shares as debt settlement    |  |                                 | 17,139     |   |                        |  | 44,547     |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | -         |                         |  |  | -                                  |  
|Imputed interest                         |  |                                 | -          |   |                        |  | -          |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | 2,334     |                         |  |  | -                                  |  
|Stock based compensation                 |  |                                 | -          |   |                        |  | -          |                           |  |  |                          |   |  |                         | 170,972 |  |                                          |  | -         |                         |  |  | -                                  |  
|Units cancelled                          |  |                                 | (341,847   | ) |                        |  | (1,397,199 | )                         |  |  | -                        |   |  |                         | -       |  |                                          |  | (18,930   | )                       |  |  | -                                  |  
|Foreign currency translation             |  |                                 | -          |   |                        |  | -          |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | -         |                         |  |  | (160                               | )
|Net loss for the year                    |  |                                 | -          |   |                        |  | -          |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | -         |                         |  |  | -                                  |  
|Balance, August 31, 2012                 |  |                                 | 9,671,281  |   |                        |  | 5,906,633  |                           |  |  | 1,422,526                |   |  |                         | 170,972 |  |                                          |  | 506,200   |                         |  |  | (109,463                           | )
|Private placement of units               |  |                                 | 224,979    |   |                        |  | 197,214    |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | -         |                         |  |  | -                                  |  
|Issuance of shares as debt settlement    |  |                                 | 2,366,257  |   |                        |  | 946,503    |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | -         |                         |  |  | -                                  |  
|Foreign currency translation             |  |                                 | -          |   |                        |  | -          |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | -         |                         |  |  | 314,120                            |  
|Net loss for the year                    |  |                                 | -          |   |                        |  | -          |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | -         |                         |  |  | -                                  |  
|Balance, August 31, 2013                 |  |                                 | 12,262,517 |   |                        |  | 7,050,350  |                           |  |  | 1,422,526                |   |  |                         | 170,972 |  |                                          |  | 506,200   |                         |  |  | 204,657                            |  
|Warrants exercised                       |  |                                 | 651,904    |   |                        |  | 306,405    |                           |  |  | (78,238                  | ) |  |                         | -       |  |                                          |  | -         |                         |  |  | -                                  |  
|Warrants expired                         |  |                                 | -          |   |                        |  | -          |                           |  |  | (174,399                 | ) |  |                         | -       |  |                                          |  | 174,399   |                         |  |  | -                                  |  
|Derivative warrants expired              |  |                                 | -          |   |                        |  | -          |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | 709,299   |                         |  |  | -                                  |  
|Issuance of units as debt settlement     |  |                                 | 14,757,120 |   |                        |  | 1,715,426  |                           |  |  | 801,079                  |   |  |                         | -       |  |                                          |  | -         |                         |  |  | -                                  |  
|Foreign currency translation             |  |                                 | -          |   |                        |  | -          |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | -         |                         |  |  | (199,965                           | )
|Net loss for the year                    |  |                                 | -          |   |                        |  | -          |                           |  |  | -                        |   |  |                         | -       |  |                                          |  | -         |                         |  |  | -                                  |  
|Balance, August 31, 2014                 |  |                                 | 27,671,541 |   |                        |  | 9,072,181  |                           |  |  | 1,970,968                |   |  |                         | 170,972 |  |                                          |  | 1,389,898 |                         |  |  | 4,692                              |  



* Reflects the March 16, 2012 two-for-one stock split (Note
8 (a))

* Reflects the August 25, 2014 one-for-ten stock consolidation
(Note 8 (a))



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



F-6









(Formerly: Eagleford Energy Inc.)



|Consolidated Statements of Cash Flows                                     |  |      |            |   |      |   |            |      | 
|------------------------------------------------------------------------- |  | ---- | ---------- | - | ---- | - | ---------- | ---- | 
|For the years ended August 31, (Expressed in Canadian Dollars)            |  | 2014 |            |   | 2013 |   |            | 2012 | 
|                                                                          |  |      |            |   |      |   |            |      | 
|Cash provided by (used in)                                                |  |      |            |   |      |   |            |      | 
|Operating activities                                                      |  |      |            |   |      |   |            |      | 
|Net loss                                                                  |  | $    | (6,115,585 | ) |      | $ | (4,266,046 | )    | 
|Items not involving cash:                                                 |  |      |            |   |      |   |            |      | 
|Depletion and accretion                                                   |  |      | 2,449      |   |      |   | 13,283     |      | 
|Loss on derivative liabilities (Note 11)                                  |  |      | 2,735,476  |   |      |   | 128,041    |      | 
|Loss on settlement of debt (Note 8(b)(e) and Note 10)                     |  |      | 1,335,935  |   |      |   | 402,264    |      | 
|Decommissioning obligation expenditure                                    |  |      | (706       | ) |      |   | -          |      | 
|Impairment loss on exploration and evaluation assets, net (Note 6 and 16) |  |      | 1,315,276  |   |      |   | 2,690,568  |      | 
|Impairment loss on property and equipment                                 |  |      | -          |   |      |   | 168,954    |      | 
|Impairment loss on marketable securities                                  |  |      | -          |   |      |   | 1          |      | 
|Shares and warrants issue for services                                    |  |      | -          |   |      |   | -          |      | 
|Stock based compensation                                                  |  |      | -          |   |      |   | -          |      | 
|Compensation expense on re-pricing of units                               |  |      | -          |   |      |   | -          |      | 
|Imputed interest                                                          |  |      | -          |   |      |   | -          |      | 
|Net changes in non-cash working capital (Note 13)                         |  |      | 538,244    |   |      |   | 569,428    |      | 
|Net cash used in operating activities                                     |  |      | (188,911   | ) |      |   | (293,507   | )    | 
|                                                                          |  |      |            |   |      |   |            |      | 
|Investing activities                                                      |  |      |            |   |      |   |            |      | 
|Additions to exploration and evaluations assets, net                      |  |      | (113,578   | ) |      |   | (404,818   | )    | 
|Net cash used in investing activities                                     |  |      | (113,578   | ) |      |   | (404,818   | )    | 
|                                                                          |  |      |            |   |      |   |            |      | 
|Financing activities                                                      |  |      |            |   |      |   |            |      | 
|Secured note payable, net                                                 |  |      | 83,629     |   |      |   | 66,240     |      | 
|Shareholders’ loans, net                                                  |  |      | 52,378     |   |      |   | 126,763    |      | 
|Private placement of units, net of share issue costs                      |  |      | -          |   |      |   | 405,650    |      | 
|Net cash provided by financing activities                                 |  |      | 146,009    |   |      |   | 598,653    |      | 
|                                                                          |  |      |            |   |      |   |            |      | 
|Increase (decrease) in cash for the year                                  |  |      | (156,480   | ) |      |   | (99,672    | )    | 
|Effect of exchange rate changes on cash                                   |  |      | 62,858     |   |      |   | (33,494    | )    | 
|Cash, beginning of year                                                   |  |      | 196,837    |   |      |   | 330,003    |      | 
|Cash, end of year                                                         |  | $    | 103,215    |   |      | $ | 196,837    |      | 



Supplemental Cash Flow Information and Non-cash Transactions
(Note 13)



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



F-7









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012



1.           Nature
of Business and Going Concern



Eagleford Energy Corp. (“Eagleford”
or the “Company”) was amalgamated under the Business Corporations Act (Ontario) on November 30, 2009. The principal
activities of the Company consist of exploration, development and production of petroleum and natural gas properties. In addition,
the Company holds a 0.3% net smelter return royalty on 8 mining claim blocks located in Red Lake, Ontario which is carried on the
consolidated statement of financial position at nil.



The company's registered office is 1 King
Street West, Suite 1505, Toronto, Ontario, M5H 1A1.



The Company’s common shares trade
on the Over-the-Counter Bulletin Board (OTCQB) under the symbol EGFDF.



These consolidated financial statements
(the “Financial Statements”) have been prepared in accordance with International Financial Reporting Standards (“IFRS”)
applicable to a going concern, which contemplates the realization of assets and settlement of liabilities in the normal course
of business, as they come due for the foreseeable future. The Company is in the process of exploring and developing its oil and
gas properties and has not yet realized profitable operations. The Company requires additional financing for its working capital
and for the costs of exploration and development of its oil and gas properties.



Due to continuing operating losses, the
Company's continuance as a going concern is dependent upon its ability to obtain adequate financing and to reach profitable levels
of operation. The Company will continue to seek additional forms of debt or equity financing,or
other means of funding its operations,however, there is no assurance that it will be successful
in doing so or that funds will be available on terms acceptable to the Company or at all. The ability of the Company to arrange
such financing in the future will depend in part upon the prevailing capital market conditions as well as the business performance
of the Company.



The Company has accumulated significant
losses and negative cash flows from operations in recent years which raise doubt as to the validity of the going concern assumption.
The Company has a working capital deficiency of $3,489,237 (2013: $4,985,312) and an accumulated deficit of $15,328,146 (2013:
$9,212,561). These material uncertainties may cast significant doubt upon the entity’s ability to continue as a going concern.
Accordingly, the consolidated financial statements do not give effect to adjustments, if any that would be necessary should the
Company be unable to continue as a going concern and, therefore, be required to realize its assets and liquidate its liabilities
in other than the normal course of business and at amounts that may differ from those shown in the accompanying consolidated financial
statements.



During the year, the Company entered into
two separate Joint Development Agreements on the Matthews Lease and received cash of $340,811 and the payment of certain obligations
under the Matthews Lease. The Company extinguished debt of $1,408,737 (2013: $544,239) through the issuance of share capital.



2.           Basis
of Preparation



Statement of Compliance

These consolidated financial statements
have been prepared in accordance with International Financial Reporting Standards (“IFRS”) as issued by the International
Accounting Standards Board (“IASB”).



These consolidated financial statements
of the Company were approved by the Board of Directors on December 26, 2014.



Basis of Preparation

These consolidated financial statements
have been prepared in accordance with IFRS as issued by the International Accounting Standards Board (the “IASB”) which
is incorporated in the Chartered Professional Accountants of Canada (“CPA Canada”) Handbook-Accounting.



F-8









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)

For The Years Ended August 31, 2014 and 2013 and 2012



2.           Basis
of Preparation (cont’d)



The accounting policies applied in these
consolidated financial statements are based on IFRS effective for the period ended August 31, 2014, as issued and outstanding as
of the date the Board of Directors approved the consolidated financial statements.



Principles of Consolidation

Subsidiaries are all entities controlled
by the Company. Control exists when the Company is exposed to, or has rights to variable returns from its involvement with the
entity and has the ability to affect these returns through its power over the entity. The financial statements of the subsidiaries
are included in the consolidated financial statements from the date that control commences until the date that control ceases.
Intercompany balances and transactions, and any unrealized income and expenses arising from intercompany transactions, are eliminated
in preparing the consolidated financial statements.



The consolidated financial statements include
the accounts of Eagleford, the legal parent, together with its wholly-owned subsidiaries, 1354166 Alberta Ltd. a company operating
in the province of Alberta, Canada (“1354166 Alberta”), Eagleford Energy, Zavala Inc. a Nevada company (“Zavala
Inc.”) effective August 29, 2013 and Dyami Energy Inc. (“Dyami”) which was dissolved effective April 3, 2014
by filing a Certificate of Termination of a Domestic Entity with the Secretary of State, Texas (see Note 16).



3.           Summary
of Significant Accounting Policies



The accounting policies set out below have
been applied consistently to all years presented in these consolidated financial statements and have been applied consistently
by the Company and its subsidiaries.



Revenue Recognition

Revenues from the production of oil and
gas properties from 1354166 Alberta are recognized, on the basis of the Company’s working interest in those properties, when
the significant risks and rewards of ownership of the product is transferred to the buyer, which is usually when legal title passes
to an external party. During the fiscal year ended August 31, 2012, the wells were shut in and the asset was considered impaired
and the property was written off but the Company is still receiving its share of gas revenue from the operator. Revenue is measured
net of royalties and other duties.



Foreign Currencies

The functional and presentation currency
of the Company is the Canadian dollar. The functional currency of the Company’s wholly-owned Alberta subsidiary, 1354166
Alberta is Canadian dollars and the functional currency of the Company’s wholly-owned Nevada subsidiary, Zavala Inc. is United
States dollars and the Company’s former wholly-owned Texas subsidiary, Dyami Energy was United States dollars.



Items included in the consolidated financial
statements of each entity are measured using the currency of the primary economic environment in which the entity operates (the
"functional currency"). Foreign currency transactions are translated into the functional currency using the exchange
rates prevailing at the dates of the transaction. Foreign exchange gains and losses resulting from the settlement of such transactions
and from the translation of monetary assets and liabilities not denominated in the functional currency of an entity are recognized
in the consolidated statements of operations.



Assets and liabilities of entities with
functional currencies other than Canadian dollars are translated at the year- end rates of exchange, and the results of their operations
are translated at average rates of exchange for the period. The resulting translation adjustments are included in the foreign currency
translation reserve under the equity section of the consolidated statement of financial position.



F-9









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

3.           Summary
of Significant Accounting Policies (cont’d)



Loss per Share

The basic loss per share is calculated
by dividing net loss by the weighted average number of common shares outstanding during the period. The diluted loss per share
reflects the dilution that would occur if outstanding stock options and share purchase warrants were exercised or converted into
common shares using the treasury stock method and are calculated by dividing net loss applicable to common shares by the sum of
the weighted average number of common shares outstanding and all additional common shares that would have been outstanding if potentially
dilutive common shares had been issued.



The inclusion of the Company’s stock
options and share purchase warrants in the computation of diluted loss per share would have an anti-dilutive effect on loss per
share and are therefore excluded from the computation.



Financial Instruments

Classification and Measurement

Financial instruments are measured at fair
value on initial recognition of the instrument. Measurement in subsequent periods depends on whether the financial instrument has
been classified as “fair value through profit and loss”, “loans and receivables”, “available-for-sale”,
“held-to-maturity”, or “other financial liability” as defined by IAS 39, “Financial Instruments:
Recognition and Measurement”.



Financial assets and financial liabilities
at “fair value through profit or loss” are either classified as “held for trading” or “designated
at fair value through profit or loss” and are measured at fair value with changes in fair value recognized in the statement
of comprehensive income. Transaction costs are expensed when incurred. The Company has classified cash, marketable securities and
derivative liabilities as “fair value through profit and loss”.



Financial instruments classified as “loans
and receivables”, “held-to-maturity”, or “financial liabilities” are measured at amortized cost using
the effective interest method of amortization. “Loans and receivables” are non-derivative financial assets with fixed
or determinable payments that are not quoted in an active market. “Held-to-maturity” financial assets are non-derivative
investments that an entity has the positive intention and ability to hold to maturity.



“Other financial liabilities measured
at amortized cost” are those financial liabilities that are not designated as “fair value through profit or loss”
and that are not derivatives. The Company has classified trade and other receivables as “loans and receivables” and
trade and other payables, secured note payable, provisions and shareholders’ loans as “other financial liabilities”.



Financial assets classified as “available-for-sale”
are measured at fair value, with changes in fair value recognized in other comprehensive income. Available-for-sale financial assets
are non-derivatives that are either designated in this category or not classified in any of the other categories. The Company currently
has no assets classified as “available for sale”.



Derivative Financial Instruments

The Company’s derivative instruments
consist of derivative liabilities in relation to its i) share purchase warrants; and ii) its secured convertible note payable.



In prior years the Company had issued share
purchase warrants in conjunction with offerings for the purchase of common shares of the Company. These share purchase warrants
were issued with an exercise price in US dollars, rather than Canadian dollars (the presentation and functional currency of the
Company). Such share purchase warrants are considered to be derivative instruments and the Company is required to re-measure the
fair value of these at each reporting date. The fair value of these share purchase warrants are re-measured at each statement of
financial position date using the Black-Scholes option pricing model. Adjustments to the fair value of the share purchase warrants
at the financial position date are recorded to the statement of operations.



F-10









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

3.           Summary
of Significant Accounting Policies (cont’d)



The Company’s secured convertible
note payable has a conversion feature which may convert any unpaid principal and accrued interest into conversion units. A conversion
unit is comprised of one (1) common share and one (1) common share purchase warrant entitling the holder to acquire a common share
of the Company at a price equal to a 15% premium to the price of the common share acquired under the conversion unit. The price
of the conversion unit is the lessor of a price equal to the 30-day rolling weighted average price of the Company as of the date
of conversion, less 20% (as adjusted for any stock splits, combinations or similar events) or eight United States Cents (US$0.08)
per share the “Conversion Unit”). The terms and features of the conversion meets the definition of an embedded derivative.
Since both components of the Conversion Unit (the common share component and warrant component) contain a variable exercise/conversion
price, the Conversion Unit meets the definition of a financial liability under IAS 32“Financial Instruments: Presentation”.
As a result, the Conversion Unit is a derivative liability that requires fair value measurement each period. The Company has selected
the Binomial Lattice model to fair value the warrant component of the conversion unit and the Monte Carlo Simulations process for
the common share component of the conversion unit (see Note 11).



Property and Equipment and Exploration
and Evaluation Assets



Exploration and Evaluation Assets (“E&E”)

Pre-acquisition expenditures on oil and
gas assets are recognized as an expense in the consolidated statements of operations when incurred. In accordance with IFRS 6,
exploration and evaluation costs are capitalized within intangible assets until the success or otherwise of the well or project
has been established and subject to an impairment review. The costs of unsuccessful wells in an area are written off to the statement
of operations.



Exploration and evaluation costs, including
the costs of acquiring licenses and directly attributable general and administrative costs, initially are capitalized either as
tangible or intangible E&E assets according to the nature of the assets acquired. The costs are accumulated in cost centers
by well, field or exploration area pending determination of technical feasibility and commercial viability.



When E&E assets are determined to be
technically feasible and commercially viable, the accumulated costs are transferred to property and equipment. When E&E assets
are determined not to be technically feasible and commercially viable or the Company decides not to continue with its activity,
the unrecoverable costs are charged to the statement of operations as exploration and evaluation expense.



E&E assets are assessed for impairment
in any circumstances where sufficient data exists to determine technical feasibility and commercial viability, and facts and circumstances
suggest that the carrying amount exceeds the recoverable amount. For purposes of impairment testing, E&E assets are allocated
to cash-generating units (“CGUs”).



Development and Production Costs

Items of property and equipment, which
include petroleum and natural gas development and production assets, are measured at cost less accumulated depletion and depreciation
and accumulated impairment losses. Development and production assets are grouped into CGUs for impairment testing.



When significant parts of an item of property
and equipment, including petroleum and natural gas interests, have different useful lives, they are accounted for as separate items
(major components).



Gains and losses on disposal of an item
of property and equipment, including petroleum and natural gas interests, are determined by comparing the proceeds from disposal
with the carrying amount of property and equipment and are recognized in profit or loss.



F-11









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

3.           Summary
of Significant Accounting Policies (cont’d)



Subsequent Costs

Costs incurred subsequent to the determination
of technical feasibility and commercial viability and the costs of replacing parts of property and equipment are recognized as
exploration and evaluation assets only when they increase the future economic benefits embodied in the specific asset to which
they relate. All other expenditures are recognized in profit or loss as incurred. Such capitalized exploration and evaluation assets
generally represent costs incurred in developing proved and/or probable reserves and bringing in or enhancing production from such
reserves, and are accumulated on a field or geotechnical area basis. The carrying amount of any replaced or sold component is derecognized.
The costs of the day-to-day servicing of property and equipment are recognized in profit or loss as incurred.



Joint Oil and Gas Activities

All of the Company's oil and gas activities
are conducted jointly with others. The Company's accounts reflect only the Company's share of assets, liabilities, revenue and
expenses in the joint operations. For interests in joint operations, the Company’s share of the jointly controlled assets
are classified according to the nature of the assets, the Company’s share of any liabilities incurred jointly with the other
parties, and the Company’s share of any income and expenses incurred jointly with the partners are recognized in the consolidated
financial statements. The adoption of IFRS 11 did not change the definition of a joint arrangement/joint control and proportionate
share method previously adopted by the company.



Depletion and Depreciation

The net carrying value of development or
production assets is depleted using the units-of-production method by reference to the ratio of production in the period to the
related proved plus probable reserves, taking into account estimated future development costs necessary to bring those reserves
into production. Future development costs are estimated taking into account the level of development required to produce the reserves.
These estimates are reviewed by independent reserve engineers at least annually for developed properties.



Proved and probable reserves are estimated
using independent reserve engineer reports for developed properties only and represent the estimated quantities of crude oil, natural
gas and natural gas liquids which geological, geophysical and engineering data demonstrate with a specified degree of certainty
to be recoverable in future years from known reservoirs and which are considered commercially producible.



Reserves may be considered commercially
producible if management has the intention of developing and producing them and such intention is based upon:



| | • | a reasonable assessment of the future economic benefit of such production;
| | - | --------------------------------------------------------------------------

| | • | a reasonable expectation that there is a market for all or substantially all the expected oil and
natural gas production; and
| | - | -----------------------------------------------------------------------------------------------------------------------------

| | • | evidence that the necessary production, transmission and transportation facilities are available
or can be made available.
| | - | --------------------------------------------------------------------------------------------------------------------------



Reserves may only be considered proved
and probable if they are supported by either actual production or conclusive formation tests. The area of reservoir considered
proved includes: (a) that portion delineated by drilling and defined by gas-oil and/or oil-water contacts, if any, or both; and
(b) the immediately adjoining portions not yet drilled, but which can be reasonably judged as economically productive on the basis
of available geophysical, geological and engineering data. In the absence of information on fluid contacts, the lowest known structural
occurrence of oil and natural gas controls the lower proved limit of the reservoir.



Depreciation methods, useful lives and
residual values are reviewed at each reporting date.



F-12









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

3.           Summary
of Significant Accounting Policies (cont’d)



Impairment

Financial Assets

A financial asset is assessed at each reporting
date to determine whether there is any objective evidence that it is impaired. A financial asset is considered to be impaired if
objective evidence indicates that one or more events have had a negative effect on the estimated future cash flows of that asset.



An impairment loss in respect of a financial
asset measured at amortized cost is calculated as the difference between its carrying amount and the present value of the estimated
future cash flows discounted at the original effective interest rate.



Individually significant financial assets
are tested for impairment on an individual basis. Remaining financial assets are assessed collectively in groups that share similar
credit risk characteristics.



All impairment losses are recognized in
the profit or loss.



An impairment loss is reversed if the reversal
can be related objectively to an event occurring after the impairment loss was recognized. For financial assets measured at amortized
cost the reversal is recognized in profit or loss.



Non-financial Assets

The carrying amounts of the Company’s
non-financial assets, other than E&E assets are reviewed at each reporting date to determine whether there is any indication
of impairment. If any such indication exists, the asset’s recoverable amount is estimated. E&E assets are assessed for
impairment when they are reclassified to property and equipment as petroleum and natural gas interests, and also if facts and circumstances
suggest that their carrying amount exceeds the recoverable amount.



For the purpose of impairment testing,
assets are grouped together into the smallest group of assets that generate cash inflows from continuing use that are largely independent
of the cash inflows of other assets or groups of assets (the “cash-generating unit” or “CGU”). The recoverable
amount of an asset or a CGU is the greater of its value in use and its fair value less costs to sell.



In assessing value in use, the estimated
future cash flows are discounted to their present value using a pre-tax discount rate that reflects current market assessments
of the time value of money and the risks specific to the asset. Value in use is generally computed by reference to the present
value of the future cash flows expected to be derived from production of proved and probable reserves.



E&E assets are allocated to related
CGUs when they are assessed for impairment, both at the time of any triggering facts and circumstances as well as upon their eventual
reclassification to producing assets (petroleum and natural gas interests in property and equipment).



An impairment loss is recognized if the
carrying amount of an asset or its CGU exceeds its estimated recoverable amount. Impairment losses are recognized in profit or
loss. Impairment losses recognized in respect of CGUs are allocated first to reduce the carrying amount of any goodwill allocated
to the units and then to reduce the carrying amounts of the other assets in the unit (group of units) on a pro rata basis.



In respect of assets other than goodwill,
impairment losses recognized in prior years are assessed at each reporting date for any indications that the loss has decreased
or no longer exists. An impairment loss is reversed if there has been a change in the estimates used to determine the recoverable
amount. An impairment loss is reversed only to the extent that the asset’s carrying amount does not exceed the carrying amount
that would have been determined, net of depletion and depreciation or amortization, if no impairment loss had been recognized.



F-13









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

3.           Summary
of Significant Accounting Policies (cont’d)



Provisions

A provision is recognized if, as a result
of a past event, the Company has a present legal or constructive obligation that can be estimated reliably, and it is probable
that an outflow of economic benefits will be required to settle the obligation.



Provisions are determined by discounting
the expected future cash flows at a pre-tax rate that reflects current market assessments of the time value of money and the risks
specific to the liability. Provisions are not recognized for future operating losses.



Decommissioning Obligations

The Company’s activities give rise
to dismantling, decommissioning and site disturbance remediation activities. Provision is made for the estimated cost of site restoration
and capitalized in the relevant asset category.



Decommissioning obligations are measured
at the present value of management’s best estimate of the expenditure required to settle the present obligation at the period-end
date. Subsequent to initial measurement, the obligation is adjusted at the end of each period to reflect the passage of time and
changes in the estimated future cash flows underlying the obligation. The increase in the provision due to the passage of time
is recognized as finance costs whereas increases/decreases due to changes in the estimated future cash flows and changes to discount
rate are capitalized. Actual costs incurred upon settlement of the decommissioning obligations are charged against the provision
to the extent the provision was established.



Borrowing Costs

Borrowing costs incurred for the construction
of qualifying assets are capitalized during the period of time that is required to complete and prepare the assets for their intended
use or sale. All other borrowing costs are recognized in profit or loss using the effective interest method. Interest income is
recognized as it accrues in profit or loss, using the effective interest method.



Taxes

Tax expense comprises current and deferred
tax. Tax is recognized in the consolidated statements of operations except to the extent it relates to items recognized in other
comprehensive income or directly in equity.



Current Income Tax

Current tax expense is based on the results
for the year as adjusted for items that are not taxable or not deductible. Current tax is calculated using tax rates and laws that
were enacted or substantively enacted at the end of the reporting period. Management periodically evaluates positions taken in
tax returns with respect to situations in which applicable tax regulation is subject to interpretation. Provisions are established
where appropriate on the basis of amounts expected to be paid to the tax authorities.



Deferred Tax

Deferred tax assets and liabilities are
recognized for the future income tax consequences attributable to differences between the financial statement carrying amounts
of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted
or substantively enacted tax rates expected to apply to taxable income in the years in which these temporary differences are expected
to be recovered or settled. Deferred tax assets and liabilities are offset if there is a legally enforceable right to offset current
tax liabilities and asset and they relate to the income taxes levied by the same authority on the same taxable entity, or on different
tax entities where these entities intend to settle current tax liabilities and asset on a net basis or their tax assets and liabilities
will be realized simultaneously.



Deferred tax assets and liabilities are
not recognized in respect of temporary differences that arise on initial recognition of assets and liabilities acquired other than
in a business combination.



F-14









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

3.           Summary
of Significant Accounting Policies (cont’d)



Share-Based Compensation

The Company has a share-based compensation
plan that grants stock options to employees and non-employees. This plan is an equity settled plan. The Company uses the fair value
method for accounting for share-based awards to employees and non-employees.



The fair value determined at the grant
date of the equity-settled share-based payments is expensed on a straight-line basis over the vesting period, based on the Company’s
estimate of equity instruments that will eventually vest. At the end of each reporting period, the Company revises its estimate
of the number of equity instruments expected to vest. The impact of the revision of the original estimates, if any, is recognized
in profit or loss such that the cumulative expense reflects the revised estimate, with a corresponding adjustment to contributed
surplus.



Equity-settled share-based payment transactions
with parties other than employees are measured at the fair value of the goods or services received, except where that fair value
cannot be estimated reliably, in which case they are measured at the fair value of the equity instruments granted, measured at
the date the Company obtains the goods or the counterparty renders the service.



Warrants

When the Company issues units comprising
common shares and warrants, the Company follows the relative fair value method of accounting for warrants attached to and issued
with common shares of the Company. Under this method, the fair value of warrants issued is estimated using the Black-Scholes option
price model. The fair value is then related to the total of the net proceeds received on issuance of the common shares and the
fair value of the warrants issued therewith. The resultant relative fair value is allocated to warrants from the net proceeds and
the balance of the net proceeds is allocated to the common shares issued.



Critical Accounting Estimates and Judgments

The timely preparation of the consolidated
financial statements in accordance with IFRS requires that management make estimates and assumptions and use judgment regarding
the measured amounts of assets, liabilities and contingent liabilities at the date of the consolidated financial statements and
reported amounts of revenue and expenses during the reporting period. Such estimates and judgments are continuously evaluated and
are based on management’s experience and other factors, including expectations of future events that are believed to be reasonable
under the circumstances. Actual outcomes may differ from these estimates.



The key sources of estimation uncertainty
that have a significant risk of causing material adjustment to the amounts recognized in the consolidated financial statements
are:



Valuation and Classification of Exploration
and Evaluation Assets

The value of exploration and evaluation
assets are dependent upon the discovery of economically recoverable reserves which in turn is dependent on future oil and natural
gas prices, future capital expenditures and environmental and regulatory restrictions. The decision to transfer exploration and
evaluation assets to property and equipment is based upon management’s determination of an area’s technical feasibility
and commercial viability based on proved and/or probable reserve estimates.



Title to Oil and Gas Property Interests

Although the Company has taken steps to
verify title to oil and gas properties in which it has an interest, these procedures do not guarantee the Company’s title.
Such properties may be subject to prior agreements or transfers and title may be affected by undetected defects.



F-15









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

3.           Summary
of Significant Accounting Policies (cont’d)



Stock Based Compensation

The Company measures the cost of equity-settled
transactions to the relative fair value of the equity instruments at the date at which they are issued. Estimating relative fair
value for share-based payment transactions requires determining the most appropriate valuation model, which is dependent on the
terms and conditions of the instrument. This estimate also requires determining and making assumptions about the most appropriate
inputs to the valuation model including the expected life, volatility, discount rates and dividend yield.



Decommissioning Liabilities

Decommissioning liabilities consist of
asset retirement obligations that are based, in part, on estimates of future costs to settle the obligation, in addition to estimates
of the useful life of the underlying assets, the rate of inflation and the risk-free discount rate.



Fair Value of Financial Instruments

The estimated fair value of financial assets
and liabilities, by their very nature, are subject to measurement uncertainty.



Assessment of Commercial Reserves

Management is required to assess the level
of the Company’s commercial reserves together with the future expenditures to access those reserves, which are utilized in
determining the depletion charge for the period, assessing whether any impairment charge is required against developed or undeveloped
properties, and the determination of the deferred tax liability. By their nature, these estimates of discovered proved and probable
crude oil and natural gas reserves, including the estimates of future prices, costs, related future cash flows and the selection
of a pre-tax risked discount rate relevant to the asset in question are subject to measurement uncertainty.



The Company employs an independent reserves
evaluator who periodically assesses the Company’s level of commercial reserves by reference to data sets including geological,
geophysical and engineering data together with reports, presentation and financial information pertaining to the contractual and
fiscal terms applicable to the Company’s assets. Significant judgment is involved when determining whether there have been
any significant changes in the Company’s reserves.



Income taxes

Income taxes liability is estimated for
the Company, including an assessment of temporary differences. Any temporary differences will generally result in the recognition
of deferred tax assets and liabilities in the financial statements. Management’s judgment is required in the calculation
of current and deferred taxes, as well as the likelihood of realization.



Provisions

Considerable judgment is used in measuring
and recognizing provisions and the exposure to contingent liabilities. Judgment is necessary to determine the likelihood that a
pending litigation or other claim will succeed, or a liability will arise and to quantify the possible range of the final settlement.



Significant changes in the assumptions,
including those with respect to future business plan and cash flows, could materially change the recorded carrying amounts.



F-16









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

4.           Recent
Accounting Pronouncements andRecent Adopted Accounting Standards



Recent
Issued Accounting Pronouncements

The following standards, amendments and
interpretations, which may be relevant to the Company have been introduced or revised by the IASB:



(i) IFRIC 21 Levies. The Company intends
to adopt IFRIC 21 in its consolidated financial statements for the annual period beginning September 1, 2014. The Company does
not expect the amendments to have a material impact on the consolidated financial statements.



(ii) On July 24, 2014, the IASB issued
the complete IFRS 9 (IFRS 9 (2014). In November 2009, the IASB issued the first version of IFRS 9, Financial Instruments (IFRS
9 (2009) and subsequently issued various amendments in October 2010, (IFRS 9 Financial Instruments (2010) and November 2013 (IFRS
9 Financial Instruments (2013). The mandatory effective date of IFRS 9 is for annual periods beginning on or after January 1, 2018
and must be applied retrospectively with some exemptions. Early adoption is permitted. The restatement of prior periods is not
required and is only permitted if information is available without the use of hindsight. The Company does not intend to adopt the
new standard prior to its effective date and has not yet determined the impact of this new standard on the consolidated financial
statements.



Recent
Adopted Accounting Standards

The following standards, amendments and
interpretations have been adopted by the Company as of September 1, 2013. There were no material impacts on the consolidated financial
statements as a result of the adoption of these standards, amendments and interpretations: (i) IFRS 10 Consolidated Financial Statements;
(ii) IFRS 11 Joint Arrangements; (iii) IFRS 12 Disclosures of Interests in Other Entities; (iv) IFRS 13 Fair Value Measurement;
and (v) Amendments to IFRS 7 Financial Instrument Disclosures.



5.           Segmented
Information



The Company’s reportable and geographical
segments are Canada and the United States. The accounting policies used for the reportable segments are the same as the Company’s
accounting policies. For the purposes of monitoring segment performance and allocating resources between segments, the Company’s
executive officer monitors the tangible, intangible and financial assets attributable to each segment. All assets are allocated
to reportable segments. The following tables show information regarding the Company’s reportable segments.



|For the year ended August 31, 2014 |  | Canada |            |   | United States |   |            | Total | 
|---------------------------------- |  | ------ | ---------- | - | ------------- | - | ---------- | ----- | 
|Net revenue                        |  | $      | 65,024     |   |               |   | -          |       | 
|Net loss                           |  | $      | (4,683,624 | ) |               | $ | (1,431,961 | )     | 



|For the year ended August 31, 2013 |  | Canada |            |   | United States |   |            | Total | 
|---------------------------------- |  | ------ | ---------- | - | ------------- | - | ---------- | ----- | 
|Net revenue                        |  | $      | 30,062     |   |               |   | -          |       | 
|Net loss                           |  | $      | (1,431,363 | ) |               | $ | (2,834,683 | )     | 



|For the year ended August 31, 2012 |  | Canada |            |   | United States |   |          | Total | 
|---------------------------------- |  | ------ | ---------- | - | ------------- | - | -------- | ----- | 
|Net revenue                        |  | $      | 39,218     |   |               |   | -        |       | 
|Net loss                           |  | $      | (2,585,129 | ) |               | $ | (224,059 | )     | 



|As at August 31, 2014 |  | Canada |           |  | United States |   |           | Total | 
|--------------------- |  | ------ | --------- |  | ------------- | - | --------- | ----- | 
|Total Assets          |  | $      | 179,888   |  |               | $ | 5,117,040 |       | 
|Total Liabilities     |  | $      | 6,991,287 |  |               | $ | 1,025,076 |       | 



|As at August 31, 2013 |  | Canada |           |  | United States |   |           | Total | 
|--------------------- |  | ------ | --------- |  | ------------- | - | --------- | ----- | 
|Total Assets          |  | $      | 3,914,928 |  |               | $ | 3,003,268 |       | 
|Total Liabilities     |  | $      | 6,029,577 |  |               | $ | 746,475   |       | 



F-17









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

6.           Exploration
and Evaluation Assets



|Cost                                                        |  |   |            |  
|----------------------------------------------------------- |  | - | ---------- | -
|Balance August 31, 2012                                     |  | $ | 8,475,487  |  
|Additions                                                   |  |   | 404,818    |  
|Change in decommissioning obligation estimates              |  |   | (9,268     | )
|Impairment of Murphy Lease                                  |  |   | (2,690,568 | )
|Foreign exchange                                            |  |   | 354,809    |  
|Balance August 31, 2013                                     |  | $ | 6,535,278  |  
|Additions, net                                              |  |   | 113,578    |  
|Change in decommissioning obligation estimates              |  |   | 7,225      |  
|Disposal of decommissioning obligations, Matthews Lease JDA |  |   | (26,426    | )
|Impairment of Murphy Lease                                  |  |   | (1,675,749 | )
|Foreign exchange                                            |  |   | 82,686     |  
|Balance August 31, 2014                                     |  | $ | 5,036,592  |  



The Company’s exploration and evaluation
assets are located in Texas, USA. As at August 31, 2014 an impairment of $1,675,749 was recorded on the Murphy Lease ($1,315,276
net of foreign currency translation gain of $301,884 and write off of decommissioning obligations of $58,589) (August 31, 2013:
$2,690,568). Included in the above additions for the year ended August 31, 2014, the Company capitalized borrowing costs interest
of $Nil to exploration and evaluation assets (August 31, 2013: $240,092).



Matthews Lease, Zavala County, Texas

During the year ended August 31, 2013,
the Company, Dyami Energy and OGR Energy Corporation, the Lessees, were litigating a dispute with the Lessors of the Matthew’s
property. During the last quarter of fiscal year August 2013, the Company and the Lessors agreed to resolve the litigation and
continue with the development of the Matthew’s property. In order to comply with certain State legal requirements, it was
deemed necessary by the Lessors counsel to continue with the development through a newly executed lease document and the Company
formed, Zavala Inc. a new wholly owned subsidiary to execute the new lease. The new lease was signed effective September 1, 2013
and the first of two payments of US$150,000 were paid to the Lessors upon signing the new lease as required initial pre-payment
of anticipated production royalties along with a continuing development obligation under the lease to complete the previously drilled
Matthews #1H horizontal well or drill a new well on the Matthews property no later than March 30, 2014. On September 1, 2013, the
Matthews lease was renewed by the Company through Zavala Inc. and based on the concept of faithful representation under IAS 8,
the carrying value of the Matthew’s lease by Dyami Energy was considered to be the value for Zavala Inc. as this arrangement
is simply a reorganization in substance.



On December 3, 2013, (amended January 21,
2014) the Company entered into a Joint Development Agreement with Stratex Oil and Gas Holdings, Inc. (“Stratex”) (the
“Stratex JDA”) to further develop the Matthews Lease. Under the terms of the Stratex JDA, Stratex will act as operator
and upon Stratex delivering i) US$150,000 to the lessors of the Matthews Lease on behalf of Zavala Inc., ii) delivering US $150,000
to the Company; and iii) commencing a hydraulic fracture of the Matthews #1H not later than March 31, 2014 Stratex earned a 66.67%
working interest before payout (50% working interest after payout) in the Matthews #1H well and a 50% working interest in the 2,629
acre Matthews Lease (see Note 17).



Through Zavala Inc., the Company holds
a 50% working interest in the 2,629 acre Matthews Lease (33.33% working interest before payout and 50% working interest after payout
in the Matthews #1H well). The Matthews Lease had a primary term extended to March 31, 2014 (the “Primary Term”) while
each lease year ends August 31. Prior to the expiration of the Primary Term, a hydraulic fracturing of the Matthews #1H well was
completed and thereafter the lease is maintained through a guaranteed minimum royalty payment of $323.30 per acre and beginning
in the second lease year and continuing thereafter for each succeeding lease year drill at least 2 wells per lease year. The royalties
payable under the Matthews Lease are 25%.



F-18









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

6.           Exploration
and Evaluation Assets (cont’d)



On
April 11, 2014, the Company entered into a further Joint Development Agreement (“JDA2”) with Stratex and Quadrant Resources
LLC, (“Quadrant”) for the development of the San Miguel formation on the Matthews Lease.  Pursuant to the terms
of the JDA2, upon satisfaction of certain conditions including the Phase 1 Work Program and the cash consideration described below,
Quadrant can earn an undivided 66.67% before payout and a 50% working interest after payout to the base of the San Miguel formation
of the Matthews Lease by i) drilling 3 new wells and reworking 5 wells at its sole cost and expense by June 30, 2015 (the “Phase
I Work Program”); ii) deliver US$100,000 to the Company upon execution of the JDA2 (paid); and iii) deliver US$65,000 to
the Company on each of July 8, 2014 (paid); October 6, 2014, January 5, 2015 and April 6, 2015. At
August 31, 2014 the Company recorded the payments received from Quadrant of US$165,000 (CDN $177,804) as deferred revenue on the
Consolidated Statement of Financial Position until the conveyance of the earned interest at which time this amount will be reclassified
and offset against exploration and evaluation assets.



Murphy Lease, Zavala County, Texas

Subsequent to September 1, 2013 and the
continuing development of the Matthews lease, Dyami Energy continued its development efforts with the Murphy lease. A tentative
joint venture agreement with Stratex was reached but did not materialize and efforts to develop the Murphy lease were not successful.
The Company had solicited lenders and investors in an attempt to obtain debt/equity financings as a means to improve Dyami Energy’s
financial situation. Despite the Company’s attempts, these efforts were unsuccessful and management determined that it could
no longer fund the Murphy operations, hence the lease was considered impaired and an impairment loss was recorded by Dyami Energy
during the third quarter (see Note 16).



On March 6, 2014, the Company filed a Certificate
of Termination of a Domestic Entity with the Secretary of State, Texas for its wholly-owned subsidiary Dyami Energy and effective
April 3, 2014, Dyami Energy was dissolved. All prior obligations with respect to the Matthew’s and Murhpy’s lease on
the books of Dyami Energy prior to its dissolution were recorded by the Company.



7.            Provisions

|                                        |  | Decommissioning Obligations (Note a) |         |   | Other Provisions (Note b) |   |          | Total
 Provisions | 
|--------------------------------------- |  | ------------------------------------ | ------- | - | ------------------------- | - | -------- | ----------------- | 
|Balance, August 31, 2012                |  | $                                    | 114,755 |   |                           | $ | 125,917  |                   | 
|Accretion expense                       |  |                                      | 3,071   |   |                           |   | -        |                   | 
|Change in estimate                      |  |                                      | (5,104  | ) |                           |   | -        |                   | 
|Additions                               |  |                                      | -       |   |                           |   | 169,196  |                   | 
|Reductions                              |  |                                      | -       |   |                           |   | (125,917 | )                 | 
|Foreign exchange                        |  |                                      | 7,020   |   |                           |   | 9,357    |                   | 
|Balance, August 31, 2013                |  |                                      | 119,742 |   |                           |   | 178,553  |                   | 
|Accretion expense                       |  |                                      | 961     |   |                           |   | -        |                   | 
|Change in estimate                      |  |                                      | 7,225   |   |                           |   | -        |                   | 
|Disposals                               |  |                                      | (26,426 | ) |                           |   | -        |                   | 
|Reductions                              |  |                                      | -       |   |                           |   | (169,196 | )                 | 
|Dissolution of subsidiary (see Note 16) |  |                                      | (58,589 | ) |                           |   |          |                   | 
|Foreign exchange                        |  |                                      | 4,630   |   |                           |   | (9,357   | )                 | 
|Balance, August 31, 2014                |  | $                                    | 47,543  |   |                           | $ | -        |                   | 



F-19









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

| | 7 | Provisions (cont’d)
| | - | -------------------



| | a) | Decommissioning Obligations
| | -- | ---------------------------

The Company’s decommissioning obligations
result from its ownership interests in petroleum and natural gas assets including well sites, gathering systems and processing
facilities. The total decommissioning obligation is estimated based on the Company’s net ownership interest in all wells
and facilities, estimated costs to reclaim and abandon these wells and facilities, and the estimated timing of the costs to be
incurred in future years. The Company has estimated the net present value of decommissioning obligations to be $47,543 ($11,768
current and $35,775 long term) at August 31, 2014 (August 31, 2013: $119,742 long term) based on an undiscounted total future liability
of $60,629 (August 31, 2013: $166,578). These payments are expected to be incurred between 2015 and 2031. The discount factor,
being the risk free rate related to the liability is 2.57% (August 31, 2013: 3.09%).



| | b) | Other Provisions
| | -- | ----------------

In February 2013, a vendor of Dyami Energy
applied a lien on the Murphy #4 well and filed a claim in the District Court of Zavala County, Texas (Case No. 13-02-12941-ZCV)
seeking payment of US$169,196 for services. Dyami Energy was disputing the amount on the basis of negligence by the vendor. On
January 28, 2014 the vendor received a summary judgment against Dyami Energy in the amount of $169,196 plus interest at a rate
of 18% per annum from September 17, 2012 until paid and legal fees of $21,178 plus interest at a rate of 5% per annum from the
date of judgment until paid. During 2013 full amount of the provision had been recorded together with legal fees and interest.
The provision, legal fees and interest were transferred to trade and other payables (see Note 16).



In May 2012 a vendor of Dyami Energy filed
a claim in the District Court of Harris County, Texas seeking payment of US$64,866. Dyami Energy was disputing the amount charged
due to faulty equipment. The full amount of the provision which was accrued in the prior year 2012 was reversed in 2013 as the
vendor is no longer in good standing as a Texas corporation and the vendor’s attorney filed in the District Court of Harris
County, Texas a motion to withdraw as counsel (see Note 16).



In December 2011, a vendor of Dyami Energy
filed a claim in the District Court of Harris County, Texas (Case No. 2011-74035/Court: 113) seeking payment of US$62,800. Dyami
Energy disputed the claim on the basis of excessive charges. In December 2013 an agreed final judgment in favour of the vendor
was entered into court in the amount of $42,803 and post judgment interest at 5% per annum until paid in full. The provision was
transferred to trade and other payables (see Note 16).



8.           Share
Capital and Reserves



The Company filed Articles of Amendment
effective August 25, 2014 consolidating the common shares of Eagleford Energy Inc., on the basis of one (1) common share for every
ten (10) common shares and changing its name to Eagleford Energy Corp. The stock consolidation has been applied retrospectively
for all periods presented.



On March 16, 2012, the Company completed
a two (2) for one (1) stock split, pursuant to which one (1) newly-issued share of the Company’s common stock was issued
to each holder of a share of common stock as of the close of business. The forward stock split has been applied retrospectively
for all periods presented.



F-20









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

8 (a)       Share
Capital



Authorized:

Unlimited number of common shares at no
par value

Unlimited non-participating, non-dividend
paying, voting redeemable preference shares



Issued:

The following table sets out the changes
in common shares during the respective periods:



|Common Shares                               |  | Number* |            |  | Amount |  
|------------------------------------------- |  | ------- | ---------- |  | ------ | -
|Balance August 31, 2012                     |  |         | 9,671,281  |  |        | $
|Private Placement of units (Note 8 (b) (a)) |  |         | 224,979    |  |        |  
|Debt settlement (Note 8 (b) (b))            |  |         | 2,366,257  |  |        |  
|Balance August 31, 2013                     |  |         | 12,262,517 |  |        |  
|Warrants exercised (Note 8 (b) (c))         |  |         | 651,904    |  |        |  
|Debt settlement (Note 8 (b) (e))            |  |         | 14,757,120 |  |        |  
|Balance August 31, 2014                     |  |         | 27,671,541 |  |        | $



* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



8 (b)       Share
Purchase Warrants



The following table sets out the changes
in warrants during the respective periods:



|                                 |  | August 31, 2014     |            |   | August 31, 2013         |  
|-------------------------------- |  | ------------------- | ---------- | - | ----------------------- | -
|Warrants                         |  | Number of Warrants* |            |   | Weighted
Average Price* |  
|Outstanding, beginning of period |  |                     | 4,020,095  |   |                         | $
|Warrants exercised (Note 8  (c)) |  |                     | (651,904   | ) |                         | $
|Warrants expired (Note 8 (d))    |  |                     | (1,453,191 | ) |                         | $
|Warrants issued (Note 8  (e))    |  |                     | 7,378,560  |   |                         | $
|Balance, end of period           |  |                     | 9,293,560  |   |                         | $



* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



(a)          On
September 25, 2012, the Company completed private placements for gross proceeds of $441,004 of equity capital from arm’s
length private placement funding through the issuance of 224,979 units at a price of US$2.00 per unit. Each unit was comprised
of one common share and one-half a common share purchase warrant, with each whole warrant entitling the holder to acquire one common
share of the Company at US$5.00 for a period of three years from the date of issuance. The amount allocated to derivative warrant
liabilities based on fair value using the Black-Scholes option pricing model was $163,541 (retranslated as $176,087 at August 31,
2013). In connection with the private placement, the Company paid cash commissions and other expenses of $35,354 and issued an
aggregate of 17,998 broker warrants.  Each broker warrant entitles the holder to acquire one common share of the Company at
an exercise price of US$2.50 for a period of three years from the date of issuance. The amount allocated to derivative liabilities
based on fair value using the Black-Scholes option pricing model was $44,895 (retranslated as $48,340 at August 31, 2013) with
a corresponding decrease in common shares (see Note 11).



(b)          On
June 1, 2013, the Company issued 2,366,257 common shares as full settlement of shareholders’ loans in the amount of $198,333
and interest due on shareholders’ loans in the amount of $345,906. The amount allocated to common shares based on fair value
was $946,503 and $402,264 was recorded as a loss on settlement of debt in the consolidated statement of operations and comprehensive
loss.



(c)          Effective
February 27, 2014, 651,904 common share purchase warrants were exercised at $0.35 expiring February 27, 2014 for settlement of
cash advances of $228,167. The amount allocated to warrants based on relative fair value using the Black-Scholes option pricing
model was $78,238 (see Note 9).



F-21









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

8 (b)       Share
Purchase Warrants (cont’d)



(d)          On
February 5, 2014, 200,000 common share purchase warrants exercisable at $0.35 expired. The amount allocated to warrants based on
relative fair value using the Black-Scholes option pricing model was $24,000 with a corresponding increase to contributed surplus.
On February 25, 2014, 80,052 common share purchase warrants exercisable at $0.35 expired. The amount allocated to warrants based
on relative fair value using the Black-Scholes option pricing model was $9,606 with a corresponding increase to contributed surplus.
On February 27, 2014, 1,173,139 common share purchase warrants exercisable at $0.35 expired. The amount allocated to warrants based
on relative fair value using the Black-Scholes option pricing model was $140,793 with a corresponding increase to contributed surplus.



(e)          Effective
August 30, 2014, the Company converted shareholders’ loans and interest due in the aggregate amount of $1,180,570 through
the issuance of a total of 14,757,120 units in the capital of the Company at a price of $0.08 per unit. Each unit is comprised
of one (1) common share and one half of one (1/2) common share purchase warrant. Each full warrant entitles the holder to purchase
one (1) common share at an exercise price of CDN$0.10 until August 30, 2017.The fair value of the units ($2,516,505) was allocated
to common shares $1,715,426 and warrants $801,079 based on their relative fair values and $1,335,935 was recorded as a loss on
settlement of debt in the consolidated statement of operations and comprehensive loss. The warrant component was valued using a
Binomial Lattice model whereas the fair value of the common share component was based on the current market value of the company’s
stock (see Note 10 and 11).



The following table summarizes the outstanding
warrants as at August 31, 2014 and 2013 respectively:



|Number of Warrants* |           |  | Exercise Price* |   |      | Expiry Date |  | Weighted Average Remaining Life (Years) |  |  | Warrant Value ($) | 
|------------------- | --------- |  | --------------- | - | ---- | ----------- |  | --------------------------------------- |  |  | ----------------- | 
|                    | 600,000   |  |                 | $ | 0.50 |             |  | January 24, 2015                        |  |  | 0.40              | 
|                    | 1,315,000 |  |                 | $ | 0.50 |             |  | February 17, 2015                       |  |  | 0.47              | 
|                    | 7,378,560 |  |                 | $ | 0.10 |             |  | August 30, 2017                         |  |  | 3.00              | 
|                    | 9,293,560 |  |                 | $ | 0.50 |             |  |                                         |  |  | 2.47              | 

* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



|Number of Warrants* |           |  | Exercise Price* |   |      | Expiry Date |  | Weighted Average Remaining
    Life (Years) |  |  | Warrant Value ($) | 
|------------------- | --------- |  | --------------- | - | ---- | ----------- |  | ------------------------------------------- |  |  | ----------------- | 
|                    | 200,000   |  |                 | $ | 0.40 |             |  | February 5, 2014                            |  |  | 0.43              | 
|                    | 80,052    |  |                 | $ | 0.40 |             |  | February 25, 2014                           |  |  | 0.49              | 
|                    | 1,825,043 |  |                 | $ | 0.40 |             |  | February 27, 2014                           |  |  | 0.49              | 
|                    | 600,000   |  |                 | $ | 0.50 |             |  | January 24, 2015                            |  |  | 1.40              | 
|                    | 1,115,000 |  |                 | $ | 0.50 |             |  | February 17, 2015                           |  |  | 1.47              | 
|                    | 200,000   |  |                 | $ | 0.50 |             |  | February 17, 2015                           |  |  | 1.47              | 
|                    | 4,020,095 |  |                 | $ | 0.40 |             |  |                                             |  |  | 0.94              | 



* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



8 (c)       Weighted
Average Shares Outstanding



The following table summarizes the weighted
average shares outstanding:



|Weighted Average Shares Outstanding*                  |  | August 31, 2014 |            |  | August 31, 2013 | 
|----------------------------------------------------- |  | --------------- | ---------- |  | --------------- | 
|Weighted Average Shares Outstanding Basic and diluted |  |                 | 12,675,329 |  |                 | 



* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



The effects of any potential dilutive instruments
on loss per share are anti-dilutive and therefore have been excluded from the calculation of diluted loss per share.



F-22









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

8 (d)       Share
Purchase Options



The Company has a stock option plan to
provide incentives for directors, officers, employees and consultants of the Company. The maximum number of shares, which may be
set aside for issuance under the stock option plan, is 20% of the issued and outstanding common shares of the Company on a rolling
basis.



The following table is a summary of the
status of the Company’s stock options and changes during the period:



|                                  |  | Number      |         |  | Weighted Average |  
|--------------------------------- |  | ----------- | ------- |  | ---------------- | -
|                                  |  | of Options* |         |  | Exercise Price   |  
|Balance, August 31, 2012 and 2013 |  |             | 105,000 |  |                  | $
|Granted                           |  |             | -       |  |                  |  
|Balance, August 31, 2014          |  |             | 105,000 |  |                  | $

* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



The following table is a summary of the
Company's stock options outstanding and exercisable at August 31, 2014 and 2013 respectively:



|Options Outstanding |      |  | Options Exercisable | 
|------------------- | ---- |  | ------------------- | 
|Exercise Price      |      |  | Number of Options*  | 
|$                   | 1.60 |  |                     | 
|$                   | 2.50 |  |                     | 
|                    |      |  |                     | 

* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation

(1) In October 2012, the Optionee passed
away and pursuant to the terms of the option agreement had a period of twelve (12) months
after the date of such death before the expiry of the option (see Note 17).



|Options Outstanding |      |  | Options Exercisable | 
|------------------- | ---- |  | ------------------- | 
|Exercise Price      |      |  | Number of Options*  | 
|$                   | 1.60 |  |                     | 
|$                   | 2.50 |  |                     | 
|                    |      |  |                     | 

* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten stock consolidation



8 (e)       Contributed
Surplus



Contributed surplus transactions for the
respective periods are as follows:

|                                  |  | Amount |          
|--------------------------------- |  | ------ | ---------
|Balance, August 31, 2012 and 2013 |  | $      | 506,200  
|Warrants expired                  |  |        | 174,399  
|Derivative warrants expired       |  |        | 709,299  
|Balance, August 31, 2014          |  | $      | 1,389,898



F-23









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

9.           Related
Party Transactions and Balances



The following transactions with individuals
related to the Company arose in the normal course of business have been accounted for at the exchange amount being the amount agreed
to by the related parties, which approximates the arm’s length equivalent value.



Compensation of Key Management Personnel

The remuneration of directors and other
members of key management personnel during the years ended were as follows:



|                                       |  | August 31, 2014 |        |  | August 31, 2013 |   |        | August 31, 2012 | 
|-------------------------------------- |  | --------------- | ------ |  | --------------- | - | ------ | --------------- | 
|Short term employee benefits (1)       |  | $               | 75,000 |  |                 | $ | 75,000 |                 | 
|Directors stock based compensation (2) |  |                 | -      |  |                 |   | -      |                 | 
|                                       |  | $               | 75,000 |  |                 | $ | 75,000 |                 | 



The following balances owing to the President
of the Company are included in trade and other payables and are unsecured, non-interest bearing and due on demand:



|                                       |  | August 31, 2014 |         |  | August 31, 2013 |  
|-------------------------------------- |  | --------------- | ------- |  | --------------- | -
|Short term employee benefits (1)       |  | $               | 281,250 |  |                 | $
|Expenses paid on behalf of the Company |  |                 | -       |  |                 |  
|                                       |  | $               | 281,250 |  |                 | $



| | (1) | The Company accrues management fees for the President of the Company at a rate of $6,250 per month.
| | --- | ---------------------------------------------------------------------------------------------------

| | (2) | On March 1, 2012, the Company granted 60,000 share purchase options to directors with an exercise
price of $1.60 per share expiring on February 28, 2017.
| | --- | ---------------------------------------------------------------------------------------------------------------------------------------------------------



At August 31, 2014 the amount of directors’
fees included in trade and other payables was $19,200 (August 31, 2013: $16,100).



At August 31, 2014 the Company had a promissory
note payable to the President of the Company of $Nil (August 31, 2013: $28,845 and US$300,000). For the year ended August 31, 2014,
the Company recorded interest on the promissory note of $24,162 (August 31, 2013: $35,324). At August 31, 2014, included in trade
and other payables is interest of $91,727 (August 31, 2013: $65,826). The notes were due on demand and bear interest at 10% per
annum. Interest was payable annually on the anniversary date of the notes. Effective February 27, 2014, 651,904 common share purchase
warrants expiring February 27, 2014,were exercised by the President of the Company at $0.35, for settlement of cash advances of
$228,167 (see Note 8 (b) (c)). On August 30, 2014 the Company issued 1,628,700 units at $0.08 per unit as full settlement of a
promissory note payable to the President of US$120,000 (see Note 8 (b) (e) and Note 10). At August 31, 2014, the Company had a
note payable to Core Energy Enterprises Inc. (“Core”) of US$249,250. The President of the Company is a major shareholder,
officer and a director of Core.



At August 31, 2014 the Company had a $1,322,347
(US$1,216,175), 10% per annum secured convertible promissory note payable to Benchmark Enterprises LLC (“Benchmark”)
(2013: US$960,000). Benchmark is a shareholder of the Company. For the year ended August 31, 2014, the Company recorded interest
on the secured promissory note of $104,237 (August 31, 2013: $101,309). At August 31, 2014 included in trade and other payables
is interest of $Nil (August 31, 2013: $169,033) (see Note 10 and Note 11).



F-24









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

| | 9 | Related Party Transactions and Balances (cont’d)
| | - | ------------------------------------------------



At August 31, 2014, the Company had shareholders’
loans payable of US$655,000. (August 31, 2013: US$1,433,500 and $250,000). For the year ended August 31, 2014 the Company recorded
interest of $180,349 (August 31, 2013: $183,490) on the shareholders’ loans payable. At August 31, 2014, included in trade
and other payables, is interest of $269 August 31, 2013: $47,037). The notes are payable on demand and bear interest at 10% per
annum. Interest is payable annually on the anniversary date of the notes. On August 30, 2014, the Company issued 13,128,420 units
at $0.08 per unit as full settlement of promissory notes payable of US$529,250, $250,000 and interest payable of $225,614 (see
Note 8 (b) (e)). During the year ended August 31, 2013, the Company issued 2,366,257 common shares as full settlement of shareholders’
loans in the amount of $198,333 and interest due on shareholders’ loans in the amount of $345,906 (see Note 8 (b) (e) and
Note 10).



| | 10 | Secured Note Payable and Shareholders’ Loans
| | -- | --------------------------------------------



Secured Note Payable

At August 31, 2014, the Company exchanged
a secured note payable to Benchmark with a carrying value of $1,322,347 (US$1,216,175) for a secured convertible promissory note
payable to Benchmark with a face value of $1,322,347 (US$1,216,175) (the “Note”). The Note has an interest rate of
10%. The Note is due on the earliest to occur of: (a) August 31, 2015; (b) the closing of any subsequent financing or series of
financings by the Company that results in gross proceeds of an aggregate amount equal to or greater than US$4,400,000, excluding
conversion of any existing debt into equity; (c) the date of a sale by the Company of all of the shares in the capital stock of
Zavala Inc. held by the Company from time to time; (d) the closing of a merger, reorganization, take-over or other business combination
which results in a change of control of the Company or Zavala Inc.; or (e) an event of default.



In the event that the Company closes any
subsequent financing or series of financings that results in gross proceeds to the Company of an aggregate amount equal to or
greater than US$2,000,000, excluding conversion of any existing debt into equity of the Company, the Company shall allocate US$0.50
of every US$1.00 exceeding the US$2,000,000 raised from such financing to repay the Note. The Note is secured by all of the assets
of the Company and Zavala Inc. The Company may, in its sole discretion, prepay any portion of the principal amount upon seven
days’ notice. Benchmark has the option at any time while the Note is outstanding to convert any unpaid principal and accrued
interest into conversion units. A conversion unit is comprised of one (1) common share and one (1) common share purchase warrant
entitling the holder to acquire a common share of the Company at a price equal to a 15% premium to the price of the common share
acquired under the conversion unit. The price of the conversion unit is the lessor of a price equal to the 30-day VWAP of the
Company as of the date of conversion, less 20% (as adjusted for any stock splits, combinations or similar events) or eight United
States Cents (US$0.08) per share the “Conversion Unit”).



Accounting Considerations



The Company has accounted for this transaction
as an exchange of debt instruments. Under IAS 39 “Financial Instruments: Recognition and Measurement”., an exchange
between an existing borrower and lender of debt instruments with substantially different terms or substantial modification of
the terms of an existing financial liability of part thereof is accounted for as an extinguishment. Since the new debt instrument
has a conversion option, the terms are considered substantially different and therefore gives rise to extinguishment accounting.
Further, the Company analyzed the conversion unit under IAS 39 and determined that it meets the definition of an embedded derivative.
Since both components of the Conversion Unit (the common share component and warrant component) contain a variable exercise/conversion
price, the Conversion Unit meets the definition of a financial liability under IAS 32 “Financial Instruments: Presentation”.
As a result, the Conversion Unit is a derivative liability that requires fair value measurement each period.



F-25









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

| | 10 | Secured Note Payable and Shareholders’
                                         Loans (cont’d)
| | -- | ----------------------------------------------------------------------------------------------



Based on the previous conclusions, the
Company allocated the old note first to the derivative component at its fair value with the residual allocated to the host debt
contract, as follows:



|                                              |  | Allocation CDN$ |           
|--------------------------------------------- |  | --------------- | ----------
|Secured promissory note (old debt instrument) |  | $               | 1,322,347 
|Derivative liability (Conversion Unit)        |  |                 | (4,000,100
|Loss on exchange of debt instruments          |  |                 | 2,677,753 
|                                              |  | $               | -         



The Note will be accreted up to its face
value of $1,322,347 (US$1,216,175) over the life of Note based on an effective interest rate (see Note 11).



Shareholder Loans

Effective August 30, 2014, the Company
converted shareholders’ loans and interest due in the aggregate amount of $1,180,570 through the issuance of a total of
14,757,120 units in the capital of the Company at a price of $0.08 per unit. Each unit is comprised of one (1) common share and
one half of one (1/2) common share purchase warrant. Each full warrant entitles the holder to purchase one (1) common share at
an exercise price of CDN$0.10 until August 30, 2017. The fair value of the units ($2,516,505) was allocated to common shares $1,715,426
and warrants $801,079 based on their relative fair values and $1,335,935 was recorded as loss on settlement of debt. The original
terms of the debt did not include settlement by the issuance of equity instruments.



Accounting Considerations



The Company has accounted for this transaction
as an extinguishment of debt instruments for equity instruments under the guidance of IFRIC Interpretation 19 “Extinguishing
Financial Liabilities with Equity Instruments”. IFRIC 19 addresses the accounting of when the terms of a financial liability
are renegotiated and result in the entity issuing equity instruments to a creditor of the entity to extinguish all or part of
the financial liability. It states that if a debtor issues equity instruments to a creditor to extinguish all or part of a financial
liability, those equity instruments are 'consideration paid' in accordance with IAS 39.41. Accordingly, the debtor should derecognise
the financial liability fully or partly. IFRIC 19 further states that the debtor recognises in profit or loss the difference between
the carrying amount of the financial liability (or part) extinguished and the fair value of the equity instruments issued. As
result, the Company recorded a loss on extinguishment in the amount of $1,335,935 in profit and loss which is the difference of
the fair value of the equity instruments ($2,516,505) and the carrying value of the debt instruments ($1,180,570).



The warrant component was valued using
a Binomial Lattice model whereas the fair value of the common share component was based on the current market value of the company’s
stock. The fair value of the conversion unit ($2,516,505) was allocated to the common stock component ($1,715,426) and warrant
component ($801,079) based on their relative fair values. Significant assumptions utilized in the Binomial Lattice process are
as follows for the warrant component of the conversion unit as of August 30, 2014:



|                                                           |  | August 30, 2014 |           
|---------------------------------------------------------- |  | --------------- | ----------
|Market value on valuation date                             |  | $               | 0.16      
|Contractual exercise rate                                  |  | $               | 0.092     
|Term (years)                                               |  |                 | 5.00 Years
|Expected market volatility                                 |  |                 | 196.97    
|Risk free rate using zero coupon US Treasury Security rate |  |                 | 0.94      



F-26









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

11.         Derivative
Liabilities



Derivative Warrant Liabilities

The Company has warrants issued with an
exercise price in US dollars which are different from the functional currency of the Company (Canadian Dollars) and accordingly
the warrants are treated as a financial liability and the fair value movement during the period is recognized in the profit or
loss.



The following table set out the changes
in derivative warrant liabilities during the respective periods.



|                               |  | Number of Warrants* |          |   | Fair Value Assigned $ |  |           | Average Exercise Price US $ | 
|------------------------------ |  | ------------------- | -------- | - | --------------------- |  | --------- | --------------------------- | 
|As at August 31, 2012          |  |                     | 784,273  |   |                       |  | 1,640,406 |                             | 
|Warrants issued                |  |                     | 112,490  |   |                       |  | 163,541   |                             | 
|Broker warrants issued         |  |                     | 17,998   |   |                       |  | 44,895    |                             | 
|Change in fair value estimates |  |                     | -        |   |                       |  | 128,041   |                             | 
|As at August 31, 2013          |  |                     | 914,761  |   |                       |  | 1,976,883 |                             | 
|Warrants expired               |  |                     | (170,923 | ) |                       |  | (709,299  | )                           | 
|Change in fair value estimates |  |                     | -        |   |                       |  | 57,723    |                             | 
|As at August 31, 2014          |  |                     | 743,838  |   |                       |  | 1,325,307 |                             | 

* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten consolidation



On September 25, 2012 the Company issued
112,490 common share purchase warrants exercisable at US$5.00 and 17,998 common share purchase broker warrants exercisable at US$2.50
expiring September 25, 2015. The fair value measured using the Black-Scholes option pricing model was $163,541 and $45,895, respectively.



On August 31, 2014 170,923 warrants exercisable
at US$5.00 expired and the fair value measured using the Black-Scholes option pricing model of $709,299 was recorded as an increase
to contributed surplus.



The following tables set out the number
of derivative warrant liabilities outstanding at August 31, 2014 and 2013 respectively:



|Number of Warrants* |         |  | Exercise  Price US ($)* |  |      | Expiry Date |  | Weighted Average Remaining Life (Years) |  |  | Fair Value CDN ($) | 
|------------------- | ------- |  | ----------------------- |  | ---- | ----------- |  | --------------------------------------- |  |  | ------------------ | 
|                    | 187,500 |  |                         |  | 5.00 |             |  | April 13, 2015 (1)                      |  |  | 0.62               | 
|                    | 30,000  |  |                         |  | 2.50 |             |  | April 13, 2015(1)                       |  |  | 0.62               | 
|                    | 91,250  |  |                         |  | 5.00 |             |  | July 20, 2015(1)                        |  |  | 0.88               | 
|                    | 14,600  |  |                         |  | 2.50 |             |  | July 20, 2015(1)                        |  |  | 0.88               | 
|                    | 250,000 |  |                         |  | 5.00 |             |  | August 7, 2015(1)                       |  |  | 0.93               | 
|                    | 40,000  |  |                         |  | 2.50 |             |  | August 7, 2015(1)                       |  |  | 0.93               | 
|                    | 112,490 |  |                         |  | 5.00 |             |  | September 25, 2015                      |  |  | 1.07               | 
|                    | 17,998  |  |                         |  | 2.50 |             |  | September 25, 2015                      |  |  | 1.07               | 
|                    | 743,838 |  |                         |  |      |             |  |                                         |  |  | 0.70               | 



| | (1) | Current
| | --- | -------



* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten consolidation



F-27









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

| | 11 | Derivative Liabilities (cont’d)
| | -- | -------------------------------



|Number of Warrants* |         |  | Exercise Price US ($)* |  |      | Expiry Date |  | Weighted Average Remaining Life (Years) |  |  | Fair Value CDN ($) | 
|------------------- | ------- |  | ---------------------- |  | ---- | ----------- |  | --------------------------------------- |  |  | ------------------ | 
|                    | 170,923 |  |                        |  | 5.00 |             |  | August 31, 2014(1)                      |  |  | 1.00               | 
|                    | 187,500 |  |                        |  | 5.00 |             |  | April 13, 2015                          |  |  | 1.62               | 
|                    | 30,000  |  |                        |  | 2.50 |             |  | April 13, 2015                          |  |  | 1.62               | 
|                    | 91,250  |  |                        |  | 5.00 |             |  | July 20, 2015                           |  |  | 1.88               | 
|                    | 14,600  |  |                        |  | 2.50 |             |  | July 20, 2015                           |  |  | 1.88               | 
|                    | 250,000 |  |                        |  | 5.00 |             |  | August 7, 2015                          |  |  | 1.93               | 
|                    | 40,000  |  |                        |  | 2.50 |             |  | August 7, 2015                          |  |  | 1.93               | 
|                    | 112,490 |  |                        |  | 5.00 |             |  | September 25, 2015                      |  |  | 2.07               | 
|                    | 17,998  |  |                        |  | 2.50 |             |  | September 25, 2015                      |  |  | 2.07               | 
|                    | 914,761 |  |                        |  |      |             |  |                                         |  |  | 1.70               | 

(1) Current

* Reflects the March 16, 2012 two-for-one
stock split and the August 25, 2014 one-for-ten consolidation



The fair value of the warrants issued during
the year ended August 31, 2013, were estimated using the Black-Scholes option pricing model with the following assumptions:

|Black-Scholes Assumptions used |  | 2013 |           
|------------------------------ |  | ---- | ----------
|Risk-free interest rate        |  |      | 1.5       
|Expected volatility            |  |      | 217       
|Expected life (years)          |  |      | 3.00 Years
|Dividend yield                 |  |      | -         



Derivative Unit Liabilities

The following tables summarize the components
of the Company’s derivative liabilities reflected in US Dollars and linked common shares as at August 31, 2014:

|                                                                     |  | August 31, 2014 |           
|-------------------------------------------------------------------- |  | --------------- | ----------
|The financings giving rise to derivative financial instruments       |  | Indexed Shares  |           
|Conversion unit (1 common share and 1 common share purchase warrant) |  |                 | 15,202,188



The Company’s face value $1,322,347
(US$1,216,175) Secured Convertible Promissory Note issued on August 31, 2014 gave rise to a derivative financial instrument. As
more fully discussed in Note 10 the Company issued a face value $1,322,347 (US$1,216,175) Secured Convertible Promissory Note
on August 31, 2014 (the “Note”). The Note embodied certain terms and conditions that were not clearly and closely
related to the host debt agreement in terms of economic risks and characteristics. Additionally these features met the definition
of a financial liability under IAS 32 “Financial Instruments: Presentation”. These terms and features consist of the
conversion unit which is comprised of one (1) common share and one (1) common share purchase warrant entitling the holder to acquire
a common share of the Company at a price equal to a 15% premium to the price of the common share acquired under the conversion
unit.



Current accounting principles that are
provided in IAS 32 and IAS 39 require derivative financial instruments to be classified in liabilities and carried at fair value
with changes recorded in profit and loss. The Company has selected the Monte Carlo Simulations valuation technique to fair value
the common share component of the conversion unit because it believes that this technique is reflective of all significant assumption
types, and ranges of assumption inputs, that market participants would likely consider in transactions involving common share components.
Such assumptions include, among other inputs, interest risk assumptions, credit risk assumptions and redemption behaviors in addition
to traditional inputs for option models such as market trading volatility and risk free rates.



F-28









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

| | 11 | Derivative Liabilities (cont’d)
| | -- | -------------------------------



The Company has selected the Binomial
Lattice model to fair value the warrant component of the conversion unit because it believes this technique is reflective of all
significant assumption types market participants would likely consider in transactions involving warrants.



Significant inputs and results arising
from the Monte Carlo Simulations process are as follows for the common share component contained in the conversion unit:



|                                              |  | August 31, 2014 
|--------------------------------------------- |  | ----------------
|Underlying price on valuation date*           |  | $0.3090         
|Contractual conversion rate                   |  | $0.08           
|Contractual term to maturity                  |  | 1.00 Years      
|Implied expected term to maturity             |  | 0.613 Years     
|Market volatility:                            |  |                 
|Range of volatilities                         |  | 78.41% - 269.09%
|Equivalent volatility                         |  | 181.25%         
|Contractual interest rate                     |  | 10.0%           
|Equivalent market risk adjusted interest rate |  | 10.00%          
|Equivalent credit risk adjusted yield         |  | 3.45%           



*The underlying price of the common share
component of the conversion unit is the sum of the market price on the valuation date and the fair value of the warrant component
derived from the binomial lattice model.



Significant assumptions utilized in the
Binomial Lattice process are as follows for the warrant component of the conversion unit as of August 31, 2014:



|                                                           |  | August 31, 2014 |           
|---------------------------------------------------------- |  | --------------- | ----------
|Market value on valuation date                             |  | $               | 0.16      
|Contractual exercise rate                                  |  | $               | 0.092     
|Term (years)                                               |  |                 | 5.00 Years
|Expected market volatility                                 |  |                 | 179.21    
|Risk free rate using zero coupon US Treasury Security rate |  |                 | 1.63      



| | 12 | Financial Instruments and
                                         Concentration of Risks
| | -- | -----------------------------------------------------------------------------------------



The Company has classified its financial
instruments as follows:



|Financial Instrument                         |  | Category                          |  | Measurement method
|-------------------------------------------- |  | --------------------------------- |  | ------------------
|Cash                                         |  | Fair value through profit or loss |  | Fair value        
|Marketable securities                        |  | Fair value through profit or loss |  | Fair value        
|Derivative liabilities                       |  | Fair value through profit or loss |  | Fair value        
|Trade and other receivables                  |  | Loans and receivables             |  | Amortized cost    
|Trade and other payables                     |  | Other financial liabilities       |  | Amortized cost    
|Provisions                                   |  | Other financial liabilities       |  | Amortized cost    
|Secured note payable and shareholders’ loans |  | Other financial liabilities       |  | Amortized cost    



The types of risk exposure and the ways
in which such exposures are managed are as follows:



F-29









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

| | 12 | Financial Instruments and Concentration of Risks (cont’d)
| | -- | ---------------------------------------------------------



Credit Risk

Credit risk is primarily related to the
Company’s receivables from joint venture partners and the risk of financial loss if a partner or counterparty to a financial
instrument fails to meet its contractual obligations. Receivables from joint venture partners are normally collected within one
to three months of the joint venture bill being issued to the partner. The Company historically has not experienced any collection
issues with its joint venture partners to date. The Company attempts to mitigate the risk from joint venture receivables by obtaining
partner approval of significant capital expenditures prior to expenditure. The Company establishes an allowance for doubtful accounts
as determined by management based on their assessed collectability; therefore, the carrying amount of trade and other receivables
generally represents the maximum credit exposure. The Company believes that its counterparties currently have the financial capacity
to settle outstanding obligations in the normal course of business.



Concentration risks exist in cash because
significant balances are maintained with one financial institution. The risk is mitigated because the financial institution is
an international bank.



The Company’s maximum exposure to
credit risk is as follows:



|                              |  | August 31, 2014 |         |  | August 31, 2013 |  
|----------------------------- |  | --------------- | ------- |  | --------------- | -
|Cash                          |  | $               | 103,215 |  |                 | $
|Trade and other receivables   |  |                 | 157,121 |  |                 |  
|Prepaid expenses and deposits |  |                 | -       |  |                 |  
|Balance                       |  | $               | 260,336 |  |                 | $



Liquidity Risk

The Company monitors its liquidity position
regularly to assess whether it has the funds necessary to fulfill planned exploration commitments on its oil and gas properties
or that viable options are available to fund such commitments from new equity issuances or alternative sources such as farm-out
agreements. However, as an exploration company at an early stage of development and without significant internally generated cash
flow, there are inherent liquidity risks, including the possibility that additional financing may not be available to the Company,
or that actual exploration expenditures may exceed those planned. The current uncertainty in global markets could have an impact
on the Company’s future ability to access capital on terms that are acceptable to the Company. The Company has so far been
able to raise the required financing to meet its obligations however, there can be no assurance that it will continue to do so
in the future.



The following table illustrates the contractual
maturities of financial liabilities:



|August 31, 2014           |  | Payments Due by Period |          
|------------------------- |  | ---------------------- | ---------
|                          |  | Total                  |          
|Trade and others payables |  | $                      | 1,483,775
|Shareholders’ loans (1)   |  |                        | 981,834  
|Total                     |  | $                      | 2,465,609



|August 31, 2013           |  | Payments Due by Period |          
|------------------------- |  | ---------------------- | ---------
|                          |  | Total                  |          
|Trade and others payables |  | $                      | 1,379,581
|Secured note payable (1)  |  |                        | 1,013,088
|Shareholders’ loans (1)   |  |                        | 2,108,205
|Total                     |  | $                      | 4,500,874



(1)         Translated
at current exchange rate.



F-30









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012



| | 12 | Financial Instruments and Concentration of Risks (cont’d)
| | -- | ---------------------------------------------------------



Market Risk

Market risk represents the risk of loss
that may impact the Company’s financial position, results of operations, or cash flows due to adverse changes in financial
market prices, including interest rate risk, foreign currency exchange rate risk, commodity price risk, and other relevant market
or price risks. The Company does not use derivative financial instruments or derivative commodity instruments to mitigate this
risk.



The oil and gas industry is exposed to
a variety of risks including the uncertainty of finding and recovering economic reserves, the performance of hydrocarbon reservoirs,
securing markets for production, commodity prices, interest rate fluctuations, potential damage to or malfunction of equipment
and changes to income tax, royalty, environmental or other such factors.



Market events and conditions in recent
years including oil and gas supply and demand, disruptions in the international credit markets and other financial systems and
the deterioration of global economic conditions have caused significant volatility to commodity prices. These conditions contributed
to a loss of confidence in the broader U.S. and global credit and financial markets. Notwithstanding various actions by governments,
concerns about the general condition of the capital markets, financial instruments, banks, investment banks, insurers and other
financial institutions contributed to the broader credit markets to further deteriorate and stock markets to decline. These factors
have negatively impacted company valuations and may impact the performance of the global economy going forward. Although economic
conditions improved, the recovery has been slow in various sectors including in Europe and the United States and has been impacted
by various ongoing factors including sovereign debt levels and high levels of unemployment which continue to impact commodity prices
and to result in volatility in the stock market.



The Company mitigates these risks by:



•	     utilizing competent, professional
consultants as support to management,

•	     reviewing available petrophyisical
analysis of prospects,

•	     focusing on a limited number
of core properties.



(i)           Commodity
Price Risk



Commodity price risk is the risk that the
fair value or future cash flows will fluctuate as a result of changes in commodity prices. Commodity prices for petroleum and natural
gas are impacted by world economic events that affect the levels of supply and demand.



The Company believes that movement in commodity
prices that are reasonably possible over the next twelve month period may have a significant impact on the Company as all its oil
properties are still in a development stage.



Commodity Price Sensitivity



The following table summarizes the sensitivity
of the fair value of the Company’s risk management position for the year ended August 31, 2014 and 2013 to fluctuations in
natural gas prices, with all other variables held constant. When assessing the potential impact of these price changes, the Company
believes that 10 percent volatility is a reasonable measure. Fluctuations in natural gas prices potentially could have resulted
in unrealized gains (losses) impacting net income as follows:

|            |  | 2014         |            |   | 2013         |  
|----------- |  | ------------ | ---------- | - | ------------ | -
|            |  | Increase 10% |            |   | Decrease 10% |  
|Net revenue |  | $            | 72,451     |   |              | $
|Net loss    |  | $            | (6,108,158 | ) |              | $



F-31









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

| | 12 | Financial Instruments and Concentration of Risks (cont’d)
| | -- | ---------------------------------------------------------



(ii)         Currency
Risk

The Company is exposed to the fluctuations
in foreign exchange rates. The prices received by the Company for the production of natural gas and natural gas liquids are primarily
determined in reference to United States dollars but are settled with the Company in Canadian dollars. The Company’s cash
flow for commodity sales will therefore be impacted by fluctuations in foreign exchange rates.



The Company operates in Canada and a portion
of its expenses are incurred in U.S. dollars. A significant change in the currency exchange rates between the Canadian dollar relative
to US dollar could have an effect on the Company’s financial instruments. The Company does not hedge its foreign currency
exposure.



The following assets and liabilities are
denominated in US dollars at August 31, 2014 and 2013:



|                                                  |  | August 31, 2014 |            |   | August 31, 2013 |  
|------------------------------------------------- |  | --------------- | ---------- | - | --------------- | -
|Cash                                              |  | $               | 73,099     |   |                 | $
|Trade and other receivables                       |  |                 | 74,091     |   |                 |  
|Exploration and evaluation assets                 |  |                 | 4,638,600  |   |                 |  
|Prepaid expenses and deposits                     |  |                 | 27,478     |   |                 |  
|Trade and other  payables                         |  |                 | (882,877   | ) |                 |  
|Provisions                                        |  |                 | (32,948    | ) |                 |  
|Derivative liabilities                            |  |                 | (4,899,511 | ) |                 |  
|Shareholders’ loans                               |  |                 | (904,250   | ) |                 |  
|Secured note payable                              |  |                 | -          |   |                 |  
|Deferred revenue                                  |  |                 | (165,000   | ) |                 |  
|Net assets denominated in US$                     |  | $               | (2,071,318 | ) |                 | $
|Net asset CDN dollar equivalent at period end (1) |  | $               | (2,249,038 | ) |                 | $



| | (1) | Translated at the exchange rate in effect at August 31, 2014 $1.0858 (August 31, 2013 $1.0553)
| | --- | ----------------------------------------------------------------------------------------------



The following table shows the estimated
sensitivity of the Company’s total comprehensive loss for the periods set out from a change in the U.S dollar exchange rate
in which the Company has exposure with all other variables held constant.

|                               |    |   | August 31, 2014                                                            |  |          | August 31, 2013                                                            | 
|------------------------------ | -- | - | -------------------------------------------------------------------------- |  | -------- | -------------------------------------------------------------------------- | 
|                               |    |   | Increase                                                                   |  |          | Decrease                                                                   | 
|Percentage change in US Dollar |    |   | In total comprehensive loss from a change in % in the US Exchange Rate ($) |  |          | In total comprehensive loss from a change in % in the US Exchange Rate ($) | 
|                               | 2  | % |                                                                            |  | (48,840  | )                                                                          | 
|                               | 4  | % |                                                                            |  | (97,680  | )                                                                          | 
|                               | 6  | % |                                                                            |  | (146,520 | )                                                                          | 
|                               | 8  | % |                                                                            |  | (195,360 | )                                                                          | 
|                               | 10 | % |                                                                            |  | (244,201 | )                                                                          | 



(iii)        Interest
Rate Risk

Interest rate risk refers to the risk that
the value of a financial instrument or cash flows associated with the instrument will fluctuate due to changes in market interest
rates. The majority of the Company’s debt is short-term in nature with fixed rates. Based on management's knowledge and experience
of the financial markets, the Company believes that the movements in interest rates that are reasonably possible over the next
twelve month period will not have a significant impact on the Company.



F-32









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

| | 12 | Financial Instruments and Concentration of Risks (cont’d)
| | -- | ---------------------------------------------------------



(iv)        Fair
Value of Financial Instruments

The Company’s financial instruments
included on the consolidated statement of financial position as at August 31, 2014 and 2013 are comprised of cash, derivative liabilities,
trade and other receivables, trade and other payables, secured note payable, shareholders’ loans and provisions.



The Company classifies the fair value of
financial instruments measured at fair value according to the following hierarchy based on the amount of observable inputs used
to value the instrument.



• 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
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. Prices in Level 2 are either directly or indirectly observable
as of the reporting date. Level 2 valuations are based on inputs, including quoted forward prices for commodities, time value and
volatility factors, which can be substantially observed or corroborated in the marketplace.



• Level 3 – Valuations in this
level are those with inputs for the asset or liability that are not based on observable market data.



|                                    |  | August 31, 2014  |           |  | August 31, 2013 | 
|----------------------------------- |  | ---------------- | --------- |  | --------------- | 
|Financial Instrument Classification |  | Carrying Value $ |           |  | Fair Value $    | 
|Fair value through profit or loss:  |  |                  |           |  |                 | 
|Cash                                |  |                  | 103,215   |  |                 | 
|Derivative liabilities              |  |                  | 5,325,407 |  |                 | 
|Loans and receivables:              |  |                  |           |  |                 | 
|Trade and other receivables         |  |                  | 157,121   |  |                 | 
|Other financial liabilities:        |  |                  |           |  |                 | 
|Trade and other  payables           |  |                  | 1,483,775 |  |                 | 
|Secured note payable                |  |                  | -         |  |                 | 
|Shareholders’ loans                 |  |                  | 981,834   |  |                 | 
|Provisions (short and long term)    |  |                  | 47,543    |  |                 | 



Cash and derivative liabilities are stated
at fair value (Level 1 measurement). The carrying value of trade and other receivables, trade and other payables, secured note
payable, shareholders’ loans and provisions approximate their fair value due to the short-term maturity of these financial
instruments (Level 3 measurement).



Capital Management

The Company’s objectives when managing
capital are to ensure the Company will have sufficient financial capacity, liquidity and flexibility to funds its operations, growth
and ongoing exploration and development commitments on its oil and gas interests. The Company is dependent on funding these activities
through debt and equity financings and joint venture arrangements. Due to long lead cycles of the Company’s exploration and
development activities, the Company’s capital requirements currently exceed its operational cash flow generated. As such
the Company is dependent upon future financings in order to maintain its flexibility and liquidity and may from time to time be
required to issue equity, issue debt, adjust capital spending or obtain additional farm-in arrangements.



The Company manages the capital structure
and makes adjustments to it in light of changes in economic conditions, availability of capital and the risk characteristics of
any underlying assets in order to meet current and upcoming obligations. Current plans for the development commitments of the Company’s
Texas lease include seeking debt or equity financing or seeking additional farm-in arrangements.



F-33









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

| | 12 | Financial Instruments and Concentration of Risks (cont’d)
| | -- | ---------------------------------------------------------



The board of directors does not establish
quantitative return on capital criteria for management, but rather relies on the expertise of the Company's management and favourable
market conditions to sustain future development of the business. As at August 31, 2014 and August 31, 2013 and the Company considered
its capital structure to comprise of shareholders equity and long-term debt.



Management reviews its capital management
approach on an ongoing basis and believes that this approach, given the relative size of the Company, is reasonable. There were
no changes in the Company’s capital management plan during the period ended August 31, 2014. The Company is not subject to
any externally imposed restrictions on its capital requirements.



The board of directors does not establish
quantitative return on capital criteria for management, but rather relies on the expertise of the Company's management and favorable
market conditions and opportunities to sustain future development of the business.



Management reviews its capital management
approach on an ongoing basis and believes that this approach, given the relative size of the Company, is reasonable.



13.         Supplemental
cash flow information and Non-Cash Transactions



The following table summarizes the non-cash
transactions for the years set out:



|Non-cash transactions                                              |  | August 31, 2014 |           |   | August 31, 2013 |   |         | August 31, 2012 | 
|------------------------------------------------------------------ |  | --------------- | --------- | - | --------------- | - | ------- | --------------- | 
|Warrants expired                                                   |  |                 | (78,238   | ) |                 |   | -       |                 | 
|Derivative warrants expired                                        |  |                 | (709,299  | ) |                 |   | -       |                 | 
|Warrants exercised for settlement of cash advances                 |  |                 | 228,167   |   |                 |   | -       |                 | 
|Disposal of decommissioning obligation                             |  |                 | 26,426    |   |                 |   | -       |                 | 
|Royalties paid under Matthews JDA                                  |  |                 | (167,715  | ) |                 |   | -       |                 | 
|Units issued to settle debt                                        |  |                 | 1,180,570 |   |                 |   | -       |                 | 
|Shares issued for interest on secured note and shareholders’ loans |  |                 | -         |   |                 | $ | 601,576 |                 | 
|Broker warrants issued                                             |  |                 | -         |   |                 |   | 44,895  |                 | 
|Shares issued to settle debt                                       |  |                 | -         |   |                 |   | 344,927 |                 | 
|Warrants expired                                                   |  |                 | -         |   |                 |   | -       |                 | 
|Units cancelled                                                    |  |                 | -         |   |                 |   | -       |                 | 
|Prepaid portion of shares for services                             |  |                 | -         |   |                 |   | -       |                 | 
|Issuance of units as compensation                                  |  |                 | -         |   |                 |   | -       |                 | 
|Compensation expense on re-pricing of units                        |  |                 | -         |   |                 |   |         |                 | 



The following table summarizes the changes
in non-cash working capital for the years set out:



|Changes in non-cash working capital |  | August 31, 2014 |          |   | August 31, 2013 |   |          | August 31, 2012 | 
|----------------------------------- |  | --------------- | -------- | - | --------------- | - | -------- | --------------- | 
|Trade and other receivables         |  | $               | (129,335 | ) |                 | $ | (10,261  | )               | 
|Trade and other payables            |  |                 | 331,481  |   |                 |   | 339,622  |                 | 
|Prepaid expenses and deposits       |  |                 | 158,295  |   |                 |   | (158,295 | )               | 
|Deferred revenue                    |  |                 | 177,804  |   |                 |   | -        |                 | 
|Provisions                          |  |                 | -        |   |                 |   | 398,362  |                 | 
|Net change                          |  | $               | 538,244  |   |                 | $ | 569,428  |                 | 



F-34









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

14.         Income
Taxes



The Company has unused capital losses in
the amount of approximately $195,852 (2013: $195,852) which may be carried forward indefinitely to offset future capital gains,
and unused non capital losses in the amount of approximately $3,335,413 (2013: $3,055,152) available to reduce income in future
years expiring as follows:



|2014 |  | $ | 46,501    | 
|---- |  | - | --------- | 
|2015 |  |   | 47,434    | 
|2026 |  |   | 55,415    | 
|2027 |  |   | 42,337    | 
|2028 |  |   | 49,166    | 
|2029 |  |   | 268,782   | 
|2030 |  |   | 286,991   | 
|2031 |  |   | 648,310   | 
|2032 |  |   | 780,686   | 
|2033 |  |   | 829,530   | 
|2034 |  |   | 280,261   | 
|     |  | $ | 3,335,413 | 



A reconciliation between income taxes provided
at actual rates and at the basic rate ranging from 26.50% to 34% (2013: 26.50%% to 34%) for federal and provincial taxes is as
follows:

|                                          |  | 2014 |            |   | 2013 |  
|----------------------------------------- |  | ---- | ---------- | - | ---- | -
|Net Loss                                  |  | $    | 6,115,585  |   |      | $
|Taxes at statutory rates                  |  |      | (1,620,630 | ) |      |  
|Non-taxable items and others              |  |      | 1,412,019  |   |      |  
|Change in unrecognized deferred tax asset |  |      | 208,611    |   |      |  
|                                          |  | $    | -          |   |      | $



The significant components of the Company's
unrecognized deferred income tax asset are summarized as follows:



|                                |  | 2014 |           |  | 2013 |  
|------------------------------- |  | ---- | --------- |  | ---- | -
|Operating loss carry forwards   |  | $    | 1,019,911 |  |      | $
|Share issue costs               |  |      | 19,112    |  |      |  
|Marketable securities           |  |      | 777       |  |      |  
|Capital losses carry forwards   |  |      | 28,070    |  |      |  
|Oil and gas interests           |  |      | 76,713    |  |      |  
|Cumulative eligible capital     |  |      | 1,237     |  |      |  
|Unrecognized deferred tax asset |  | $    | 1,145,821 |  |      | $



15.         Commitments
and Contingencies



The Company has certain commitments on
its Lease located in Zavala County, Texas, USA (see Note 6).



F-35









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

16.         Dissolution
of Dyami Energy LLC



During the year ended August 31, 2013,
the Company, Dyami Energy and OGR Energy Corporation, the Lessees, were litigating a dispute with the Lessors of the Matthew’s
property. During the last quarter of fiscal year August 2013, the Company and the Lessors agreed to resolve the litigation and
continue with the development of the Matthew’s property. In order to comply with certain State legal requirements, it was
deemed necessary by the Lessors counsel to continue with the development through a newly executed lease document and the Company
formed, Zavala Inc. a new wholly owned subsidiary to execute the new lease. The new lease was signed effective September 1, 2013
and the first of two payments of US$150,000 were paid to the Lessors upon signing the new lease as required initial pre-payment
of anticipated production royalties along with a continuing development obligation under the lease to complete the previously drilled
Matthews #1H horizontal well or drill a new well on the Matthews property no later than March 30, 2014. On September 1, 2013, the
Matthews lease was renewed by the Company through Zavala Inc. and based on the concept of faithful representation under IAS 8,
the carrying value of the Matthew’s lease by Dyami Energy was considered to be the value for Zavala Inc. as this arrangement
is simply a reorganization in substance.



Subsequent to September 1, 2013 and the
continuing development of the Matthews lease, Dyami Energy continued its development efforts with the Murphy lease. A tentative
joint venture agreement with Stratex was reached but did not materialize and efforts to develop the Murphy lease were not successful.
The Company had solicited lenders and investors in an attempt to obtain debt/equity financings as a means to improve Dyami Energy’s
financial situation. Despite the Company’s attempts, these efforts were unsuccessful and management determined that it could
no longer fund the Murphy operations, hence the lease was considered impaired and an impairment loss was recorded by Dyami Energy
during the third quarter. On March 6, 2014, the Company filed a Certificate of Termination of a Domestic Entity with the Secretary
of State, Texas for its wholly-owned subsidiary Dyami Energy and effective April 3, 2014, Dyami Energy was dissolved. All prior
obligations with respect to the Matthew’s and Murhpy’s lease on the books of Dyami Energy prior to its dissolution
were recorded by the Company.



The Company’s investment in Dyami
Energy has been deconsolidated from the Company’s Consolidated Financial Statements as at the effective date, and presented
on the Consolidated Statements of Operations and Comprehensive Loss and the Consolidated Statements of Cash Flow as an impairment
of the net assets and liabilities on dissolution of subsidiary.



The following table presents the effect
of the dissolution of Dyami Energy on the consolidated financial statements of the Company at April 3, 2014:

|                                                 |  | April 3, 2014 |           
|------------------------------------------------ |  | ------------- | ----------
|Exploration and evaluation assets – Murphy Lease |  | $             | (1,675,749
|Provisions                                       |  |               | 58,589    
|Foreign currency translation reserve             |  |               | 301,884   
|Net assets and liabilities                       |  | $             | (1,315,276



| | 17 | Subsequent Events
| | -- | -----------------

On or about September 30, 2014, Stratex
filed a petition against Zavala Inc. in the District Court of Zavala County, Texas seeking breach of contract and actual damages
of US$152,293 (the “Purported Debt”) for Zavala Inc’s alleged non-payment of its proportionate share of minimum
royalties due under the Matthews Lease. Zavala Inc. disputes the claim citing $300,000 paid by the Company to be credited against
the minimum royalties which Stratex has failed to do. Zavala Inc. paid the $152,293 under protest and filed a Response and Cross
Notice of Default against Stratex (Cause No. 14-09-13290-ZCV).



On or about October 27, 2014, the Company
filed a statement of claim in the Ontario Superior Court of Justice against Alan Gaines, a former director of the Company for breach
of fiduciary duty to the Company relating to Gaines role in the Company contracting with Stratex (Court File No.: 65-14-514935).
The Company is seeking a declaration that Gaines breached his duty to the Company, an accounting and disgorgement of profits made
by Gaines in breach of his duties or in the alternative, damages and/or restitution for breach of fiduciary duty, deceit, and unjust
enrichment in an amount to be determined before trial and $1.0 million in punitive damages.



F-36









(Formerly: Eagleford Energy Inc.)



Notes to the Consolidated Financial Statements

(Expressed In Canadian
Dollars)
For The Years Ended August 31, 2014 and 2013 and 2012

| | 17 | Subsequent Events (cont’d)
| | -- | --------------------------



On October 29, 2014, 5,000 share purchase
options expired and $11,112 was recorded as a decrease in share purchase options and a corresponding increase in contributed surplus.



On October
30, 2014 the President of the Company loaned the Company $10,000. The loan ispayable on demand and bears interest at 10%
per annum.



On November
4, 2014 1288131 Alberta Ltd., loaned the Company US$121,000. Colin McNeil a director of the Company is also an officer, director
and shareholder of 1288131 Alberta Ltd. The loan ispayable on demand and bears interest at 10% per annum.



On November 12, 2014 the Company granted
immediately vesting share purchase options to acquire 1,000,000 common shares at an exercise price of $0.12 per share for a period
of 5 years to directors and a consultant and recorded stock based compensation expense and share purchase options with a fair value
of $112,693.





F-37







INDEX TO EXHIBITS

|Exhibit # |  | Description                                                                                                                                                             
|--------- |  | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|1.1       |  | Certificate of Incorporation of Bonanza Red Lake Explorations Inc. (presently known as Eagleford Energy Inc.) dated September 22, 1978 (1)                              
|1.2       |  | Articles of Amendment dated January 14, 1985 (1)                                                                                                                        
|1.3       |  | Articles of Amendment dated August 16, 2000 (1)                                                                                                                         
|1.4       |  | Bylaw No 1 of Bonanza Red Lake Explorations Inc. (presently known as Eagleford Energy Inc.) (1)                                                                         
|1.5       |  | Special By-Law No 1 – Respecting the borrowing of money and the issue of securities of Bonanza Red Lake Explorations Inc. (presently known as Eagleford Energy Inc.) (1)
|1.6       |  | Articles of Amalgamation dated November 30, 2009 (3)                                                                                                                    
|4.1       |  | 2000 Stock Option Plan (1)                                                                                                                                              
|4.2       |  | Code of Business Conduct and Ethics (1)                                                                                                                                 
|4.3       |  | Audit Committee Charter (1)                                                                                                                                             
|4.4       |  | Petroleum and Natural Gas Committee Charter (1)                                                                                                                         
|4.5       |  | Compensation Committee Charter (1)                                                                                                                                      
|4.6       |  | Purchase and Sale Agreement dated February 5, 2008 among Eugenic Corp., 1354166 Alberta Ltd., and the Vendors of 1354166 Alberta Ltd. (1)                               
|4.7       |  | Amended Audit Committee Charter (3)                                                                                                                                     
|4.8       |  | Amended Stock Option Plan (4)                                                                                                                                           
|4.9       |  | Asset Purchase Agreement between Eagleford Energy Inc., and Source Re-Work Program Inc., dated May 12, 2010 (6)                                                         
|4.10      |  | Addendum dated June 10, 2010 to the Asset Purchase Agreement between Eagleford Energy Inc. and Source Re-Work Program Inc., dated May 12, 2010 (6)                      
|4.11      |  | Addendum 2 dated June 30, 2010 to the Asset Purchase Agreement between Eagleford Energy Inc. and Source Re-Work Program Inc., dated May 12, 2010 (6)                    
|4.12      |  | Acquisition  Agreement among Eagleford Energy Inc., Dyami Energy LLC and the Members of Dyami Energy LLC dated August 10, 2010 (5)                                      
|4.13      |  | Financial Advisory Services Agreement between Eagleford Energy Inc. and GarWood Securities, LLC dated June 10, 2010 (6)                                                 
|4.14      |  | Amended Stock Option Plan, February 24, 2011 (7)                                                                                                                        
|4.15      |  | Amendment dated December 31, 2011 to Secured Promissory Note between Eagleford Energy Inc. and Benchmark Enterprises LLC (8)                                            
|4.16      |  | Consent of Sproule Associates Limited dated February 16, 2012 (9)                                                                                                       
|4.17      |  | Evaluation of P&NG Reserves of Eagleford Energy Inc., at August 31, 2011 (11)                                                                                           
|4.18      |  | Amended Stock Option Plan, February 24, 2012  (8)                                                                                                                       
|4.19      |  | By-Law No. 1, February 24, 2012 (8)                                                                                                                                     
|4.20      |  | Articles of Amendment, effective March 16, 2012  (10)                                                                                                                   
|4.21      |  | 2nd Amendment dated June 30, 2012 to Secured Promissory Note between Eagleford Energy Inc. and Benchmark Enterprises LLC (12)                                           
|4.22      |  | Evaluation of P&NG Reserves of Eagleford Energy Inc., at August 31, 2012 (12)                                                                                           
|4.23      |  | Consent of Sproule Associates Limited dated (12)                                                                                                                        
|4.24      |  | Financial Advisory Agreement between Eagleford Energy Inc. and The PrinceRidge Group LLC dated June 1, 2012 (12)                                                        
|4.25      |  | Amendment dated April 13, 2012 to Placement Agency Agreement dated March 12, 2012 between Eagleford Energy Inc. and Gottbetter Capital Markets, LLC (12)                
|4.26      |  | Amendment No. 2 dated July 17, 2012 to Placement Agency Agreement dated March 12, 2012 between Eagleford Energy Inc. and Gottbetter Capital Markets, LLC (12)           
|4.27      |  | Amendment No. 3 dated August 14, 2012 to Placement Agency Agreement dated March 12, 2012 between Eagleford Energy Inc. and Gottbetter Capital Markets, LLC (12)         
|4.28      |  | Amendment No. 4 dated August 31, 2012 to Placement Agency Agreement dated March 12, 2012 between Eagleford Energy Inc. and Gottbetter Capital Markets, LLC (12)         
|4.29      |  | 3rd  Amendment dated November 23, 2012 to Secured Promissory Note between Eagleford Energy Inc. and Benchmark Enterprises LLC (12)                                      
|4.30      |  | 4th  Amendment dated March 1, 2013 to Secured Promissory Note between Eagleford Energy Inc. and Benchmark Enterprises LLC (13)                                          











|4.31 |  | Eagleford
    Energy, Zavala Inc., Certificate of Incorporation  dated August 29, 2013 (13)                                                                                                                            
|---- |  | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|4.32 |  | Rule 14 Agreement
    among The Matthews Family Mineral Account, LP, Delta  Star Holdings, LLC, Dyami Energy, LLC, Eagleford Energy Inc.,OGR
    Energy Corporation, OGR 2000 Ltd., and Texas Onshore Energy, Inc. (13)
|4.33 |  | Termination
    of Financial Advisory Agreement between Eagleford Energy Inc. and The PrinceRidge Group LLC dated September 5, 2013 (13)                                                                               
|4.34 |  | Joint Development
    Agreement dated December 3, 2013 between Eagleford Energy Inc., Eagleford Energy, Zavala Inc., and Stratex Oil and Gas Holdings,
    Inc. (13)                                                   
|4.35 |  | Articles of Amendment,
    effective August 25, 2014 (14)                                                                                                                                                              
|4.36 |  | Amendment dated
    January 21, 2014 to the Joint Development Agreement between Eagleford Energy Inc., Eagleford Energy, Zavala Inc., and Stratex
    Oil and Gas Holdings, Inc.(15)                                   
|4.37 |  | Joint Development
    Agreement dated April 11, 2014 by and among Quadrant Resources LLC Eagleford Energy, Zavala Inc., and Stratex Oil and Gas
    Holdings, Inc.(15)                                                 
|4.38 |  | Secured Convertible
    Promissory Note, General Security Agreement and Release dated August 31, 2014 between Eagleford Energy Inc. and Benchmark
    Enterprises LLC (15)                                             



|8.1       |  | Subsidiaries of Eagleford Energy Inc. (15)                             
|--------- |  | -----------------------------------------------------------------------
|12.1/12.2 |  | Section 302 Certification of Chief Executive and Financial Officer (15)
|13.1/13.2 |  | Section 906 Certification of Chief Executive and Financial Officer (15)



|Reference # |  | Incorporated by Reference                                                                                             
|----------- |  | ----------------------------------------------------------------------------------------------------------------------
|(1)         |  | Previously filed on April 29, 2009 by Registrant as part of Registration Statement on Form 20-F (SEC File No. 0-53646)
|(2)         |  | Previously Filed by Registrant as part of Amendment #2 to Registration Statement on Form 20F/A on July 14, 2009       
|(3)         |  | Previously Filed by Registrant on Form 6 K on December 1, 2009                                                        
|(4)         |  | Previously filed by Registrant on Form 20F/A on March 12, 2010                                                        
|(5)         |  | Previously filed by Registrant on Form 6-K on September 16, 2010                                                      
|(6)         |  | Previously Filed by Registrant on Form 20F on February 11, 2011                                                       
|(7)         |  | Previously filed by Registrant on Form 6-K on January 27, 2011                                                        
|(8)         |  | Previously filed by Registrant on Form 6-K on February 1, 2012                                                        
|(9)         |  | Previously filed by Registrant on Form 20F on February 16, 2012                                                       
|(10)        |  | Previously filed by Registrant on Form 6-K on March 9, 2012                                                           
|(11)        |  | Previously filed by Registrant on Form 20F/A on April 26, 2012                                                        
|(12)        |  | Previously filed by Registrant on Form 20F on December 31, 2012                                                       
|(13)        |  | Previously filed by Registrant on Form 20F on December 24, 2013                                                       
|(14)        |  | Previously filed by Registrant on Form 6-K on August 20, 2014                                                         
|(15)        |  | Filed as an Exhibit hereto