Lexaria Bioscience Corp. - Quarter Report: 2010 April (Form 10-Q)

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)

PART 1 – FINANCIAL INFORMATION

Item 1. Financial Statements.

Our unaudited interim financial statements for the six month period ended April 30, 2010 form part of this quarterly report.  They are stated in United States Dollars (US$) and are prepared in accordance with United States generally accepted accounting principles.

F-3

F-4

LEXARIA CORP.
NOTES TO THE FINANCIAL STATEMENTS
April 30, 2010
(Expressed in U.S. Dollars)

1.

Basis of Presentation

The unaudited interim consolidated financial statements for the quarter ended April 30, 2010 included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with United States generally accepted accounting principles have been condensed or omitted pursuant to such rules and regulations. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included. These unaudited interim financial statements should be read in conjunction with the October 31, 2009 audited annual financial statements and notes thereto.  

On March 17, 2010, the Company increased its authorized share capital to 200,000,000 common shares.

2.

Organization and Business

The Company was formed on December 9, 2004 under the laws of the State of Nevada and commenced operations on December 9, 2004.  The Company is an independent natural gas and oil company engaged in the exploration, development and acquisition of oil and gas properties in the United States and Canada.  The Company’s entry into the oil and gas business began on February 3, 2005.  The Company has offices in Vancouver and Kelowna, BC, Canada.

These financial statements have been prepared in accordance with generally accepted accounting principles applicable to a going concern, which contemplates the realization of assets and the satisfaction of liabilities and commitments in the normal course of business.  The Company has incurred an operating loss and required additional funds to maintain its operations.  Management’s plans in this regard are to raise equity and/or debt financing as required.

These conditions raise substantial doubt about the Company’s ability to continue as a going concern.  These financial statements do not include any adjustment that might result from this uncertainty.

3.

Business Risk and Liquidity

The Company is subject to several categories of risk associated with its operating activities.  Natural gas and oil exploration and production is a speculative business and involves a high degree of risk.  Among the factors that have a direct bearing on the Company’s prospects are uncertainties inherent in estimating natural gas and oil reserves, future hydrocarbon production and cash flows, particularly with respect to wells that have not been fully tested and with wells having limited production histories; access and cost of services and equipment; and the presence of competitors with greater financial resources and capacity.

4.

Significant Accounting Policies

a)

Principles of Accounting

These financial statements are stated in U.S. dollars and have been prepared in accordance with U.S. generally accepted accounting principles.

b)   New Accounting Pronouncements

In June 2009, the FASB amended ASC 860, (formerly SFAS No. 166, Accounting for Transfers of Financial Assets, an amendment to SFAS No. 140). ASC 860 eliminates the concept of a ―qualifying special-purpose entity, changes the requirements for derecognizing financial assets, and requires additional disclosures in order to enhance information reported to users of financial statements by providing greater transparency about transfers of financial assets, including securitization transactions, and an entity’s continuing involvement in and exposure to the risks related to transferred financial assets. ASC 860 is effective for fiscal years beginning after November 15, 2009. The adoption of ASC 860 is not expected to have a material impact on our financial statements.

In June 2009, the FASB amended ASC 810 (formerly SFAS No.167, Amendments to FASB Interpretation No. 46). The amendments include: (1) the elimination of the exemption for qualifying special purpose entities, (2) a new approach for determining who should consolidate a variable-interest entity, and (3) changes to when it is necessary to reassess who should consolidate a variable-interest entity. ASC 810 is effective for the first annual reporting period beginning after November 15, 2009 and for interim periods within that first annual reporting period. The adoption of ASC 810 is not expected to have a material impact on our financial statements.  

In October 2009, the FASB issued guidance on revenue arrangements with multiple deliverables stating that when vendor specific objective evidence or third party evidence for deliverables in an arrangement cannot be determined, a best estimate of the selling price is required to separate deliverables and allocate arrangement consideration using the relative selling price method. The new guidance includes new disclosure requirements on how the application of the relative selling price method affects the timing and amount of revenue recognition. This guidance was effective for us January 1, 2011. We do not expect the application of this guidance will have a material impact on our financial position, cash flows or operating results.

In January 2010, the FASB issued Accounting Standards Update 2010-02, Consolidation (Topic 810): Accounting and Reporting for Decreases in Ownership of a Subsidiary. This amendment to Topic 810 clarifies, but does not change, the scope of current US GAAP. It clarifies the decrease in ownership provisions of Subtopic 810-10 and removes the potential conflict between guidance in that Subtopic and asset derecognition and gain or loss recognition guidance that may exist in other US GAAP. An entity will be required to follow the amended guidance beginning in the period that it first adopts FAS 160 (now included in Subtopic 810-10). For those entities that have already adopted FAS 160, the amendments are effective at the beginning of the first interim or annual reporting period ending on or after December 15, 2009. The amendments should be applied retrospectively to the first period that an entity adopted FAS 160. The Company does not expect the provisions of ASU 2010-02 to have a material effect on the financial position, results of operations or cash flows of the Company.

In January 2010, the FASB issued new standards in the ASC 820, Fair Value Measurements and Disclosures, which requires reporting entities to make new disclosures about recurring or nonrecurring fair-value measurements including significant transfers into and out of Level 1 and Level 2 fair-value measurements and information on purchases, sales, issuances, and settlements on a gross basis in the reconciliation of Level 3 fair- value measurements. ASU 2010-6 is effective for annual reporting periods beginning after December 15, 2009, except for Level 3 reconciliation disclosures which are effective for annual periods beginning after December 15, 2010. We do not anticipate that this update will have a material impact on our consolidated financial statements.

5.

Capital Stock

Share Issuances

On June 23, 2009, the Company amended its Articles of Incorporation to undertake a one (1) for four (4) share consolidation of its authorized and issued and outstanding common stock.  As a result, the Company’s authorized capital decreased from 75,000,000 shares of common stock with a par value of $0.001 to 18,750,000 shares of common stock with a par value of $0.001 and its issued and outstanding shares decreased from 24,369,500 shares of common stock to 6,092,370 shares of common stock.

On July 22, 2009, the Company completed an equity financing and issued 4,545,000 unit at the price of $0.05 per unit of common stock, so that effective July 22, 2009, the Company has 10,637,370 shares of common stock issued and outstanding.  All shares and warrants issued were restricted under applicable securities rules.

On October 21, 2009 191,000 warrants were exercised for 95,500 common shares for a total proceed of $4,775.

On December 24, 2009, the Company completed an equity financing and issued 1,617,752 units at the price of CAD$0.12 per unit of common stock, so that effective December 24, 2009, the Company has 12,350,622 shares of common stock issued and outstanding.  All shares and warrants issued were restricted under applicable securities rules.

On March 17, 2010, the Company had increased its authorized share capital from 18,750,000 common shares to 200,000,000 common shares.

As at April 30, 2010, Lexaria Corp. has 12,350,622 shares issued and outstanding and 6,510,877 warrants issued and outstanding.

A summary of warrants as at April 30, 2010 is as follows:

1.  Each warrant entitles a holder to purchase one common share.

2.  Two warrants entitle a holder to purchase one common share.

6.

Oil and Gas Properties

(a) Proved properties

(1) Palmetto Point Project

On December 21, 2005, the Company agreed to purchase a 20% working and revenue interest in a 10 well drilling program in Mississippi owned by Griffin & Griffin Exploration for $700,000.  Concurrent with signing the Company paid $220,000 and January 17, 2006 the Company paid the remaining $480,000.  The Company applied the full cost method to account for its oil and gas properties, seven wells were found to be proved wells, and three wells were found impaired.  One of the wells was impaired due to uneconomic life, and the other two wells were abandoned due to no apparent gas or oil shows present.  The costs of impaired properties were added to the capitalized cost in determination of the depletion expense.

On September 22, 2006, the Company elected to participate in an additional two-well program in Mississippi owned by Griffin & Griffin Exploration and paid $140,000.  The two wells were found to be proved wells.

On June 23, 2007, the Company acquired an assignment of 10% gross working interest from a third party for $520,000 secured loan payable.  The Company recognized $501,922 in the oil and gas property.

On October 4, 2007, the Company elected to participate in the drilling of PP F-12-3 in Mississippi by Griffin & Griffin Exploration.  The Company had 30% gross working interest and paid $266,348.  On July 31, 2008, the Company accrued and paid an additional cost of $127,707 for the workovers of wells PP F-12 and PP F-12-3.  PP F-12 has started limited production from October 2007, and PP F-12-3 has started limited production from November 2007.  

On April 3, 2009, the Company entered into an Asset Purchase Agreement to acquire additional interests in its existing core producing Mississippi oil and gas properties.  The Company paid $40,073.39 to acquire additional 2% working interest in the proven Belmont Lake oil and gas and an additional 10% working interest in potential nearby exploration wells.  Total working interest for Belmont Lake is 32%; and total  working interest in the exploration wells on approximately 140,000 acres surrounding Belmont Lake in all directions is 60%.

The Company had a short-lived opportunity to acquire additional fractional interests in the upcoming Belmont Lake 12-4 well which is expected to be a horizontal well. An unrelated third party did not participate in its right to participate in the 12-4 well, and therefore a share of its interest (a “non consent” interest) was made available to the other participating parties including Lexaria. On August 28, 2009 and effective on September 1, 2009, to take best advantage of this opportunity, the Company entered into four separate assignment agreements, three of which were with people or companies with related management. The Company received from these four parties proceeds of $371,608.57 to fund additional interests in this well. As a result, the Company has a 25.84% perpetual gross interest in the well (18.0% net revenue interest); as well as a 5.2% net revenue interest in the non-consent interest. The non-consent interest remains valid until such time as the well produces 500% of all costs and expenses back to the participants in the form of revenue, at which time the non-consent interest ends. Golden Aria Corp, a company with related management, has acquired from Lexaria a 6.16% perpetual gross interest in the 12-4 well; David DeMartini, a director of Lexaria, has acquired from Lexaria a 5% gross interest in the non-consent interest in the 12-4 well; and 0743868 BC Ltd. a company owned by the President of the Company, has acquired from Lexaria a 11.60% gross interest in the non-consent interest in the 12-4 well.

As of April 30, 2010, there were no additional interest or workovers of wells PP F-12 and PP F12-3.

(2) Mississippi and Louisiana, Frio-Wilcox Project

In December 2006, the first well CMR-US 39-14 was found to have sufficient hydrocarbons to become economic.  USA 1-37 and BR F-33 had started intermittent production from November 2007.  The Company applied the full cost method to account for its oil and gas properties.

As at January 31, 2007, the Company abandoned Dixon #1 due to no economic hydrocarbons being present and $162,420 of drilling costs was added to the capitalized costs.  The Dixon #1 was the only Wilcox well the Company has drilled to date.  Every other well it has participated in located in Mississippi and Louisiana is a Frio well.

On June 2, 2007, the Company abandoned Randall #1 and $107,672 drilling costs was added to the capitalized costs in determination of depletion expense.

During August to October 2007, three additional wells, PP F-90, PP F-100, and PP F-111 were drilled in the area.  These Frio wells were abandoned due to modest gas shows and a total of $306,562 drilling costs was added to the capitalized costs in determination of depletion expense.

During December 2007, two additional wells, PP F-6A and PP F-83, were drilled and were plugged and abandoned due to non-economic gas shows.  A total of $247,086 drilling costs was added to the capitalized costs in determination of depletion expense.  

A summary of proved property is as follows:

(b) Unproved Properties

         (1)         Strachan Leduc Reef, Alberta, Canada

On September 23, 2005, the Company entered into an agreement to participate in the Strachan Leduc Reef Farm-In in Alberta, Canada.  The Company made a payment of $218,739. (CDN $253,977) for a 4% participation in the costs of Strachan Leduc Reef Farm-In.  In addition, the Company incurred $186,668 for required supplemental funds due to well hole problems.  The Company will earn on completion, capped or abandoned with respect to the well to be drilled at 14 of 9-38-9-W5M the following:

(i)

In the Spacing Unit for the Earning Well:

a.

A 2.000% interest in the petroleum and natural gas below the base of the Mannville excluding natural gas in the formation; and

b.

A 4.000% interest in the natural gas in the Leduc formation before payout subject to payment of the Overriding Royalty which is convertible upon payout at royalty owners option to 50% of the Farmee’s Interest;

(ii)

A 1.600% interest in the rights below the base of the Shunda formation in Section 10, Township 38, Range 9W5M; and

(iii)

A 1.289% interest in the rights below the base of the Shunda formation in Sections 15 and 16, Township 38, Range 9W5M down to the base as shown in the schedule attached to the agreement dated September 23, 2005.

The Company wrote down the cost of the property to a nominal value of $1 as the future realization of the property is uncertain in the fiscal year 2008.

As at April 30, 2010, the Company’s working interest in Strachan Leduc Reef property has expired and the nominal value was expensed.

(2)      Mississippi and Louisiana, USA

The Company entered into an Agreement to acquire a working interest in multiple zones of potential oil and gas production in Mississippi and Louisiana.  This Agreement contemplates up to a 50 well drill program for Wilcox and Frio wells, at the Company’s option, within the defined area of mutual interest (AMI).  The AMI includes over 200,000 gross acres located non-contiguously between Southwest Mississippi and North East Louisiana.

The Company originally agreed to pay 40% of all prospect fees, mineral leases, surface leases, and drilling and completion costs to earn a net 32% of all production from all producible zones to the base of the Frio formation (Frio Targets); and, 30% of all production to the base of the Wilcox formation (Wilcox Targets).  All working interests are to be registered in the name of Lexaria Corp.

The Joint Participation Agreement and Joint Lands Agreements are between Lexaria Corp. and Griffin & Griffin Exploration LLC (G&G) of Jackson, Mississippi.

On June 21, 2007, the Company acquired an additional 10% from a third party for all rights, title and benefits excluding the seven wells drilled under the AMI Agreement between August 3, 2006 and June 19, 2007, specifically wells CMR-USA-39-14, Dixon #1, Faust #1 TEC F-1, CMR/BR F-14, RB F-1 Red Bug #2, BR F-33, and Randall #1 F-4, and any offset wells that could be drilled to any of these specified wells.

On July 26, 2007, the Company acquired 5% from a third party for all rights, title and benefits in the seven wells drilled under the AMI Agreement between August 3, 2006 and June 19, 2007, specifically wells CMR-USA-39-14, Dixon #1, Faust #1 TEC F-1, CMR/BR F-14, RB F-1 Red Bug #2, BR F-33, and Randall #1 F-4, and any offset wells that could be drilled to any of these specified wells.

On April 3, 2009, the Company entered into an Asset Purchase Agreement to acquire additional interests in its existing core producing Mississippi oil and gas properties.  The Company paid $40,073.39 to acquire an additional 2% working interest in the proven Belmont Lake oil and gas field, and an additional 10% working interest in potential nearby exploration wells.  Further, the Company is required to pay $100 per month for a period of 4 years from the closing.  Total working interest for Belmont Lake as of April 30, 2010 is 32%; and total  working interest in the exploration wells on approximately 140,000 acres surrounding Belmont Lake in all directions as of April 30, 2010, is 60%.

7.

Long-term debt

On April 1, 2010, we entered into a purchase agreement with CAB Financial Services Ltd., a company controlled by Chris Bunka, our President, Chief Executive Officer and Director, (“Purchaser”) for a non-secured promissory note in the amount of US$75,000 (the “Promissory Note”).  The Purchaser agreed to purchase a non-secured 18% interest bearing Promissory Note of our company subject to and upon the terms and conditions of the Purchase Agreement.  The Promissory Note is unsecured, due and payable on April 1, 2012 or, if mutually agreed to by all parties then April 1, 2011.  The Promissory Note may be prepaid in whole or in part at any time prior to April 1, 2012 by payment of 108% of the outstanding principal amount including accrued and unpaid interest.

As long as the Promissory Note is outstanding, the Purchaser may voluntarily convert the Promissory Note including accrued and unpaid interest to common shares of our company at the conversion price of $0.30 per common share.

The Company did not incur beneficiary conversion charges as the conversion price is greater than the fair value of the Company’s equity.

8.

Loan payable

On October 27, 2008 the Company entered into a Purchase Agreement in the amount of CAD$900,000 of Notes being purchased by the President (CAD$400,000), the President’s wholly-owned company (CAD$300,000) and a shareholder (CAD$200,000) of the Company (“Purchasers”).  The Purchasers agreed to purchase an 18% interest bearing Promissory Note of the Company subject to and upon the terms and conditions of the Purchase Agreement.  The Company’s obligations to repay the Promissory Note will be secured by certain specified assets of the Company pursuant to a Security Agreement.  As long as the Promissory Note is outstanding, the Purchasers may voluntarily convert the Promissory Note to Common Shares at the conversion price of $0.45 per share of Common Stock.  The Promissory Note matures on October 27, 2010.

In connection with the Purchase Agreement, the Company issued a total of 390,000 (1,560,000 pre-consolidation) warrants which two warrants entitle a holder to purchase a common share of the Company of which 195,000 (780,000 pre-consolidation) warrants are eligible at $0.05 (adjusted price) and 195,000 (780,000 pre-consolidation) warrants are eligible at $0.05 (adjusted price) per share and expire October 27, 2009 and October 27, 2010, respectively.

The Company did not incur beneficiary conversion charges as the conversion price is greater than the fair value of the Company’s equity.

As at the date of the issuance of the above noted Promissory Note, the Company allocated CAD$21,321 and CAD$683,559 to warrants (additional paid-in capital) and Promissory Note based on their relative fair value.  

On July 10, 2009 the Purchasers converted $45,000 of the Promissory Note into equity at $0.05.  

On October 27, 2009, 191,000 warrants were exercised for 95,500 common shares.  As at April 30, 2010, the Promissory Note is valued at $846,524 based on the effective interest rate of 18% per annum and related foreign exchange rate (October 31, 2009 - $788,795).

9.

Related Party Transactions

(a)    During the quarter ended April 30, 2010, the Company paid / accrued $50,400 to CAB Financial Services (“CAB”) (2009: $65,131), RMA Resource Management Associates (“RMA”) $Nil (2009: $15,000), and BKB Management Ltd. (“BKB”) $27,036 (2009: nil) for management, accounting, and consulting services.  CAB is owned by the president of the Company and RMA is owned by a former vice president of the Company, BKB is owned by the CFO of the Company.

The related party transactions are recorded at the exchange amount established and agreed to between the related parties.

(b)   On October 27, 2008 the Company made a secured loan agreement in the amount of CAD$300,000 with CAB Financial Services Ltd. (See Note 8).  On July 10, 2009 $40,000 of the debt was converted to equity.  For the quarter ended, April 30, 2010, the Company accrued and paid interest expenses of CAD$25,366.

(c)   On October 27, 2008 the Company made a secured loan agreement in the amount of CAD$400,000 with Christopher Bunka. (See Note 8).  For the quarter ended, April 30, 2010, the Company accrued and paid interest expenses of CAD$40,024.

(d)   The Company had a short-lived opportunity to acquire additional fractional interests in the upcoming Belmont Lake 12-4 well which is expected to be a horizontal well. An unrelated third party did not participate in its right to participate in the 12-4 well, and therefore a share of its interest (a “non consent” interest) was made available to the other participating parties including Lexaria. On August 28, 2009 and effective on September 1, 2009, to take best advantage of this opportunity, the Company entered into four separate assignment agreements, three of which were with people or companies with related management. The Company received from these four parties proceeds of $371,608.57 to fund additional interests in this well. As a result, the Company has a 25.84% perpetual gross interest in the well (18.0% net revenue interest); as well as a 5.2% net revenue interest in the non-consent interest. The non-consent interest remains valid until such time as the well produces 500% of all costs and expenses back to the participants in the form of revenue, at which time the non-consent interest ends. Golden Aria Corp, a company with related management, has acquired from Lexaria a 6.16% perpetual gross interest in the 12-4 well; David DeMartini, a director of Lexaria, has acquired from Lexaria a 5% gross interest in the non-consent interest in the 12-4 well; and 0743868 BC Ltd. a company owned by the President of the Company, has acquired from Lexaria a 11.6% gross interest in the non-consent interest in the 12-4 well.

(e)   On April 1, 2010 the Company made a non-secured loan agreement in the amount of US$75,000 with CAB Financial Services Ltd. (See Note 7).  For the quarter ended, April 30, 2010, the Company accrued and paid interest expenses of US$1,125.

10.

Stock Options

On July 23, 2009, the Company had a 1 for 4 share consolidation.  The 2,000,000 maximum granting of stock options has now been reduced to 500,000 stock options.

On July 8, 2009, the Company granted 75,000 stock options to directors and consultants of the Company with exercise prices of $0.20, vested immediately, and re-priced 325,000 of the previously issued stock options to $0.20 that expire over 1.47 years.   

On January 20, 2010, the Company approved a new 2010 Equity Compensation plan and granted 975,000 stock options to directors and consultants of the Company with exercise prices of $0.20, vested immediately and expiring on January 20, 2015.  

For the quarter ended April 30, 2010, the Company recorded a total of $139,050 for stock based compensation expenses.

A summary of the stock options for the quarter ended April 30, 2010 is presented below:

*The exercise price is post re-priced.

The fair value of each option granted has been estimated as of the date of the grant using the Black-Scholes option pricing model with the following assumptions:

A summary of weighted average fair value of stock options granted during the quarter ended April 30, 2010 is as follows:

The Company has the following options outstanding and exercisable.  

11.     Commitments and Significant Contracts

On November 27, 2008, the Company entered into a Consulting Agreement with CAB Financial Services Ltd. for consulting services of CAB on a continuing basis for a consideration of US$8,000 per month plus GST.

The Company entered into a consulting agreement with BKB Management Ltd. to act as the Chief Financial Officer and a Director for a consideration of CAD $4,500 per month plus GST.  

Item 2.  Management’s Discussion and Analysis of Financial Condition and Results of Operations

Forward-Looking Statements

This quarterly report contains forward-looking statements as that term is defined in the Private Securities Litigation Reform Act of 1995. 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 these terms or other comparable terminology. These statements are only predictions and involve known and unknown risks, uncertainties and other factors, including the risks in the section entitled "Risk Factors", that may cause our or our industry's actual results, levels of activity, performance or achievements to be materially different from any future results, levels of activity, performance or achievements expressed or implied by these 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 these statements to actual results.

Our unaudited interim financial statements are stated in United States Dollars (US$) and are prepared in accordance with United States Generally Accepted Accounting Principles. The following discussion should be read in conjunction with our financial statements and the related notes that appear elsewhere in this quarterly report. The following discussion contains forward-looking statements that reflect our plans, estimates and beliefs. Our actual results could differ materially from those discussed in the forward looking statements. Factors that could cause or contribute to such differences include, but are not limited to, those discussed below and elsewhere in this quarterly report, particularly in the section entitled "Risk Factors" of this quarterly report.

In this quarterly report, unless otherwise specified, all dollar amounts are expressed in United States dollars. All references to "CDN$" refer to Canadian dollars and all references to "common shares" refer to the common shares in our capital stock.

As used in this quarterly report, the terms "we", "us", "our" and "Company" mean Company and/or our subsidiaries, unless otherwise indicated.

Overview

We were incorporated in the State of Nevada on December 9, 2004. We are an exploration and development oil and gas company currently engaged in the exploration for and development of petroleum and natural gas in North America. We maintain our registered agent's office and our U.S business office at Nevada Agency and Transfer Company, 50 West Liberty, Suite 880, Reno, Nevada 89501.  Our telephone number is (755) 322-0626.

The address of our principal executive office is Suite 950, 1130 West Pender Street, Vancouver, British Columbia V6E 4A4. Our telephone number is (604) 602-1675.  We have another office located in Kelowna. Our current locations provide adequate office space for our purposes at this stage of our development.

Our common stock is quoted on the OTC Bulletin Board under the symbol "LXRP" and on the Canadian National Stock Exchange under the symbol “LXX”

Lexaria is an oil and gas company  engaged in the exploration for oil and natural gas in Canada and the United States. The Company is currently generating revenues from its business operations in Mississippi.  The Company’s business plan is to focus on development of the Belmont Lake oil field, in which it has working interests, in order to maximize cash flow and use excess cash flow to pay debt and conduct additional development well drilling. Eventually, if cash flows are strong enough, the Company will once again be able to explore for additional oil and gas by way of its existing 60% interest option to drill 38 exploratory wells (see “Oil & Gas Properties - Mississippi and Louisiana: Frio-Wilcox Project”). To accomplish this, the Company intends to focus on development drilling first. Eventually the Company will seek a balance between exploration, development and exploitation drilling.  To achieve sustainable and profitable growth, the Company intends to control the timing and costs of its projects wherever possible.  The Company is not currently the operator of any of its properties and will consider becoming the operator only when its financial conditions have improved sufficiently.

Due to the implementation of British Columbia Instrument 51-509 on September 30, 2008 by the British Columbia Securities Commission, we have been deemed to be a British Columbia based reporting issuer.  As such, we are required to file certain information and documents at www.sedar.com.

On February 26 2010, Lexaria Corp. (“Lexaria” or the “Company”) held its Annual and Special Meeting of Shareholders for the following purposes:  

1.

To approve an increase in the Company’s authorized capital from 18,750,000 to 200,000,000.

2.

To approve the Company’s proposed 2010 Equity Compensation Plan.

3.

To elect Chris Bunka, Bal Bhullar, and David DeMartini as directors of the Company for the ensuing year.

4.

To appoint Chang Lee LLP, Chartered Accountants, as the auditors of the Company for the ensuing year, at a remuneration to be fixed by the directors.

All proposals were approved by the shareholders. The proposals are described in detail in the Company’s definitive proxy statement filed with the Securities and Exchange Commission on February 2, 2010.

On March 17, 2010, the Company had increased its authorized share capital from 18,750,000 common shares to 200,000,000 common shares.

Our Current Business

The Company is an oil and gas company engaged in the exploration for oil and natural gas in Canada and the United States. The Company is currently generating revenues from its business operations in Mississippi.  

We have acquired working interests in various oil and gas properties in Mississippi USA. All of our current oil and gas assets are located in Wilkinson and Amite counties, Mississippi, where we have between 32% gross working interest and 60% gross working interests in producing oil and/or gas wells and in exploration wells yet to be drilled. Our Belmont Lake oil field discovered in December 2006 is located within the Palmetto Point area of Wilkinson county, Mississippi. We previously had an interest in oil and gas wells located in Oklahoma but those assets were sold in August 2008. We had a nominal interest in a non-commercial well located in Strachan Alberta, but during this quarter, that lease expired and has now been written down.

The Company’s business plan is to focus on development of the Belmont Lake oil field, in which it has working interests, in order to maximize cash flow and use excess cash flow to pay debt and conduct additional development well drilling. Eventually, if cash flows are strong enough, the Company expects to explore for additional oil and gas by way of its existing 60% interest option to drill 38 exploratory wells (see “Oil & Gas Properties - Mississippi and Louisiana: Frio-Wilcox Project”). To accomplish this, the Company intends to focus on development drilling first. Eventually the Company will seek a balance between exploration, development and exploitation drilling.  To achieve sustainable and profitable growth, the Company intends to control the timing and costs of its projects wherever possible.  The Company is not currently the operator of any of its properties and will consider becoming the operator only when its financial conditions have improved sufficiently.

In 2010, we experienced the following significant corporate developments:

1.

On November 13, 2009, the Company announced that its Operator in Mississippi, Griffin & Griffin Exploration LLC, has declared force majeure on the Belmont Lake offset wells.

2.

On December 21, 2009, our Board of Directors amended and restated our bylaws. The amendment and restatement of the bylaws was for the purpose of, among other things, removing certain outdated and redundant provisions that existed in our prior bylaws with respect to corporate governance, shareholder and director meeting procedures, and indemnification procedures. The changes to our prior bylaws include: (i) expanding certain provisions with respect to shareholders’ meetings including change of quorum requirements; (ii) amending certain provisions respecting appointment of directors, corporate governance and committees, and directors’ meetings; (iii) expanding certain provisions with respect to officers and their duties; (iv) changing certain provisions with respect to share certificates; and (vi) adding certain indemnification provisions.

3.

During the first quarter of its 2010 fiscal year the Company completed an equity financing from the sale of 1,617,752 units at a price of CAD$0.12 per unit for net proceeds of CAD$194,130.  Each unit consisted of one common share and a half warrant.  Two half warrants entitles the holder to purchase an additional common share of the Company for a period of one year from the date of closing of the financing at an exercise price of CAD$0.22.  Effective December 27, 2009 the Company has 12,350,622 shares of common stock issued and outstanding.

The Company plans to continue its current business of acquiring interests in potentially high-impact oil and gas property interests that offer a high probability of being able to drill without significant time delays. The Company also tries to choose North American properties where, if drilling is successful, the wells could be quickly connected to infrastructure and thus, with success, brought into production and able to generate cash flow as quickly as possible.

The Company’s business plan does not anticipate that it will hire a large number of employees or that it will require extensive office space. The Company has, to date, and plans to continue to acquire most of the industry and geological expertise it requires through third party contractual relationships with consulting experts and with operating companies which will act as operators of the Company’s various interests. Although this exposes the Company to certain risks on behalf of those operators, it also allows the Company to participate in the often unique experience and knowledge that local persons have related to certain properties. This strategy allows the Company to participate in a wider variety of oil and gas opportunities than if all of its geological expertise were in-house and confined to a single geographical area. From a business operations perspective, this strategy also enables the Company to minimize its ongoing fixed in-house costs for geological or geophysical analytical expenses while still allowing it to contract for that expertise when and as needed. This business strategy has been successful during a time of declining oil and gas prices, when many companies with high internal overheads and cost structures due to large numbers of highly expensive in-house professionals cannot be sustained due to declining revenues. The Company will hire third-party consulting geophysicists and geologists on an as-needed basis to evaluate oil and gas properties that may be of interest, and to reinforce and double-check the technical work and abilities of its third-party operators. This provides the Company with the required expertise it needs, when its needed, whilst avoiding high fixed long-term costs.

The Company relies on the business experience of its existing management, on the technical abilities of consulting experts, and on the technical and operational abilities of its operating partner companies to evaluate business opportunities.

Alberta

We have acquired an interest in a property located 80 miles northwest of Calgary, Alberta, Canada. On September 23, 2005, we signed an agreement to participate in a 13,330 foot drill program. As to date, our Company has paid $405,407 for a 4% gross interest to participate in any oil and gas produced (before recovery of the costs of the drill program), reducing to a 2% interest after recovery of the drilling costs. The property is reached by traveling 100 miles north from the city of Calgary on Highway #22, and is approximately a one-half hour drive past the town of Rocky Mountain House.

Drilling of this well has been completed and some evaluation has been completed. The well appears to be noncommercial and it is possible that we could abandon our interest in this well. In fiscal year 2008, the Company wrote down the cost of the property to a nominal value of $1.  As of April 30, 2010, the lease has expired and the property has been written down.

Mississippi

On December 21, 2005, the Company agreed to purchase a 20% gross working and revenue interest in a 10 well drilling program in Palmetto Point, Mississippi owned by Griffin & Griffin Exploration (“Griffin”) for cash payments of $700,000, comprised of $220,000 paid upon entering the Agreement and the remaining balance of $480,000 paid on January 17, 2006.  The Company applied the full cost method to account for its oil and gas properties and as of April 30, 2010, seven wells were found to be proved wells, and three wells were found impaired.  One of the wells was impaired due to uneconomic life, and the other two wells were abandoned due to no apparent gas or oil shows present.  The costs of impaired properties were added to the capitalized cost in determination of the depletion expense.  Palmetto Point is approximately 150 miles southwest of Jackson, Mississippi and approximately 50 miles north/northwest of Baton Rouge, Louisiana.  It is 30 miles west of Woodville, Mississippi off of State Highway 33 and is entirely within Wilkinson County.

There were no further costs to the Company in earning its interest in the 10 well drilling program, including well development costs or pipeline connections. Griffin has agreed that the leases held by it covering any mineral estate underlying the applicable well site acreage shall not provide for more than twenty-five (25%) percent royalty and overriding royalty interest. The Company’s net interest in any oil and gas produced is calculated by subtracting the applicable royalties from its 20% gross interest. Consequently, its original net working interest in the drilling program was a minimum fifteen (15%) percent net working interest. Griffin conducted the Drilling Program in its capacity as Operator and receives a 15% carried interest.

One of these original 10 wells was the PP F-12-1 well, which was the discovery well of a field now known as the Belmont Lake field. All of these original 10 wells were targeting the Frio geological formation of the Cenozoic era and Oligocene series, which is characterized in this region as a generally shallow, sandstone-rich layer. In this area of Mississippi, the Frio geologic formation is generally found between 2,000 and 4,500 foot depth from surface.

On September 22, 2006, the Company elected to participate in an additional two-well program in Palmetto Point, Mississippi owned by Griffin by paying an additional $140,000 (paid).  The Company earned the same 20% gross interest in the two (2) additional wells (12 wells total and all drilled) and subsequently increased its gross interest to 32% in these 12 wells, or a net revenue interest of 20.802815%. 

On June 23, 2007, the Company acquired an assignment of a 10% gross working interest in the Palmetto Point wells described above from a third party for $520,000 which was payable by a secured loan.  The $520,000 loan was valued at a Net Present Value of $501,922, which is the capitalized amount. The Company calculated the net present value of the secured loan payable by applying 8% interest rate, which was based on a T-bill rate of 4.28% plus a risk premium.

On October 4, 2007, the Company elected to participate in the drilling of the PP F-12-3 well in Palmetto Point, Mississippi which was conducted by Griffin.  This well was the second well drilled in the Belmont Lake oil field. The Company had a 30% gross working interest and paid $266,348.  On July 31, 2008, the Company accrued and paid an additional cost of $127,707 for the workovers of wells PP F-12 and PP F-12-3.  PP F-12 has had intermittent production from October 2007, and PP F-12-3 has had intermittent production from November 2007.  

On April 3, 2009, the Company entered into an Asset Purchase Agreement with Delta Oil & Gas, Inc., and The Stallion Group to acquire additional interests in its existing core producing Mississippi oil and gas properties.  The Company paid $40,073.39 to acquire an additional two percent (2%) working interest in the proven Belmont Lake oil and gas field and an additional 10% working interest in potential nearby exploration wells.  Total working interest for Belmont Lake as of July 31, 2009 is 32%; and total working interest in the exploration wells on approximately 140,000 acres surrounding Belmont Lake in all directions as of April 30, 2010, is 60%.

As of April 30, 2010, no additional interest and workovers were made to wells PP F-12 and PP F12-3.

As of April 30, 2010, the status of the Palmetto Point, Mississippi wells is as follows:

Mississippi and Louisiana: Frio-Wilcox Project

After participating in the Palmetto Point project, the Company entered into a separate agreement that expanded both its percentage interest in future wells, and also expanded the geographical area on which those wells could be drilled.

On August 3, 2006, the Company entered into a Phase II agreement with Griffin, to acquire a working interest in multiple zones of potential oil and gas production in Mississippi and Louisiana.  This agreement contemplates up to a 50 well drill program, which are exclusive to the participants, for Wilcox and Frio wells, at the Company’s option, within the defined area of mutual interest (“AMI”).  From these 50 prospects, Griffin and the participants will select all drill locations with the expectation that the wells will be drilled to depths sufficient to test prospectively for producible hydrocarbons from the top of the Frio Formation to the bottom of the Wilcox Formation.

These 50 wells are in addition to all wells drilled under the original 10-well agreement and also in addition to any development wells to be drilled at the Belmont Lake oil field discovery. The AMI includes over 200,000 gross acres located non-contiguously between Southwest Mississippi and North East Louisiana which include the approximately 32,000 acres of the Palmetto Point area but also include other areas.

The Company had contracted to assume a 40% gross interest in this AMI, meaning it was obligated to pay 40% of costs related to licensing, permitting, drilling, completion and all other related costs. Upon payment of 40% of the costs, the Company earned a net 32% of all production from all producible zones to the base of the Frio formation (Frio Targets); and, 30% of all production to the base of the Wilcox formation (Wilcox Targets).  All working interests are to be registered in the name of the Company.  This 50-well AMI is intended to be drilled in several stages.

The Company’s pro rate share of the first stage had a total cost $1.6 million. As of October 31 2007, the Company had placed $1,600,000 in trust to completely fund this initial commitment. During the drill program, an unrelated third party participant elected not to continue their participation in the program, and we assumed our pro-rata portion of their 10% gross working interest as our own, at no additional cost, bringing our total gross working interest in the seven (7) wells and their leases (Initial AMI Drilling Program), to 45%.

On June 21, 2007, the Company acquired an additional 10% from a third party for all rights, title and benefits excluding the seven wells drilled under the AMI Agreement between August 3, 2006 and June 19, 2007, specifically wells CMR-USA-39-14, Dixon #1, Faust #1 TEC F-1, CMR/BR F-14, RB F-1 Red Bug #2, BR F-33, and Randall #1 F-4, and any offset wells that could be drilled to any of these specified wells (Subsequent AMI Drilling Program). This brought our interest in the remaining 43 wells to 50% and we drilled 5 wells under this arrangement.

On April 3, 2009, the Company acquired an additional 10% working interest in the 38 exploration wells remaining to be drilled, bringing its total gross working interest to 60% in the 38 wells that remain to be drilled of this original 50-well option in over 140,000 acres surrounding Belmont Lake in all directions.

On August 28, 2009, the Company entered into four separate assignment agreements, three of which were with people or companies with related management. The Company received from these four parties proceeds of $371,608.57 to fund additional interests in this well. As a result, the Company has a 25.84% perpetual gross interest in the well (18.0% net revenue interest); as well as a 5.2% net revenue interest in the non-consent interest. The non-consent interest remains valid until such time as the well produces 500% of all costs and expenses back to the participants in the form of revenue, at which time the non-consent interest ends. Golden Aria Corp, a company with related management, has acquired from Lexaria a 6.16% perpetual gross interest in the 12-4 well; David DeMartini, a director of Lexaria, has acquired from Lexaria a 5% gross interest in the non-consent interest in the 12-4 well; and 0743868 BC Ltd. a company owned by the President of the Company, has acquired from Lexaria a 11.6% gross interest in the non-consent interest in the 12-4 well.

Initial AMI Drilling Program

The Company’s pro rate share of the first stage had a total cost $1.6 million. As of October 31 2007, the Company had placed $1,600,000 in trust to completely fund this initial commitment. During the drill program, an unrelated third party participant elected not to continue their participation in the program, and we assumed our pro-rata portion of their 10% gross working interest as our own, at no additional cost, bringing our total gross working interest in these seven (7) drilled wells and their leases, to 45%.

The Company successfully drilled and completed seven (7) wells under this drilling program.  Certain wells were placed into production.  

Details of the drill program are outlined below:

In December 2006, the first well CMR-US 39-14 was found to have sufficient hydrocarbons to become economic.  USA 1-37 and BR F-33 had started intermittent production from November 2007.  The Company applied the full cost method to account for its oil and gas properties.

As at January 31, 2007, the Company abandoned Dixon #1 due to no economic hydrocarbons being present and $162,420 of drilling costs was added to the capitalized costs.  The Dixon #1 was the only Wilcox well the Company has drilled to date.  Every other well it has participated in located in Mississippi and Louisiana is a Frio well. Slightly deeper than the Frio targets, but also of the Cenozoic era, the Wilcox geologic formation is of the Eocene series, generally found at depths of less than 8,000 feet.

On June 2, 2007, the Company abandoned Randall #1 and $107,672 drilling costs were added to the capitalized costs in determination of depletion expense.

During August to October 2007, three additional wells, PP F-90, PP F-100, and PP F-111 were drilled in the area.  These Frio wells were abandoned due to modest gas shows and a total of $306,562 drilling costs was added to the capitalized costs in determination of depletion expense.

During December 2007, two additional wells, PP F-6A and PP F-83, were drilled and were plugged and abandoned due to non-economic gas shows.  A total of $247,086 drilling costs were added to the capitalized costs in determination of depletion expense.   

The results of the initial drill program are as follows:

Subsequent AMI Drilling Program

As of April 30, 2008, five additional wells were drilled under the 50-well AMI. Each of these wells encountered non commercial quantities of hydrocarbons and were plugged and abandoned.

Significant Acquisitions and Dispositions

Purchase of Significant Equipment

We do not intend to purchase any significant equipment (excluding oil and gas activities) over the twelve months other than office computers, furnishings, and communication equipment as required.

Corporate Offices

The address of our principal executive office is Suite 950, 1130 West Pender Street, Vancouver, British Columbia, V6E 4A4, for which we share 250 square feet of office space, which includes one executive office for a monthly rental of CAD$1,337. Our telephone number is (604) 602-1675. We have another office located in Kelowna, which for which we share 1,500 square feet of office space, which includes two executive offices. Our current locations provide adequate office space for our purposes at this stage of our development.

Employees

We primarily used the services of sub-contractors and consultants for manual labour exploration work and drilling on our properties. Our Director, Mr. David DeMartini is our technical advisor.

The Company has a consulting agreement with BKB Management Ltd., a corporation organized under the laws of the Province in British Columbia.  BKB Management Ltd. is a consulting company controlled by the chief financial officer and director for a consideration of CAD $4,500 per month plus GST.  

The Company has a consulting agreement with CAB Financial Services Ltd., a corporation organized under the laws of the Province of British Columbia.  CAB Financial Services is a consulting company controlled by the chairman of the board and the chief executive officer of the Company.  The consulting services provided by CAB Financial Services is on a continuing basis for a consideration of $8,000 per month plus GST.  CAB Financial Services Ltd. may terminate the agreement at any time by giving 30 days written notice of his intention to do so.

On September 9, 2009, the Company appointed Mr. David DeMartini to the Board of Directors.

We do not expect any material changes in the number of employees over the next 12 month period.  We do and will continue to outsource contract employment as needed.  However, with project advancement and if we are successful in our initial and any subsequent drilling programs we may retain additional employees.

Off-Balance Sheet Arrangements

We have no significant off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that are material to stockholders.

Critical Accounting Policies

Our financial statements and accompanying notes are prepared in accordance with generally accepted accounting principles used in the United States. Preparing financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenue, and expenses. These estimates and assumptions are affected by management's application of accounting policies. We believe that understanding the basis and nature of the estimates and assumptions involved with the following aspects of our financial statements is critical to an understanding of our financials.

Oil and Gas Properties

We utilize the full cost method to account for our investment in oil and gas properties. Accordingly, all costs associated with acquisition, exploration and development of oil and gas reserves, including such costs as leasehold acquisition costs, capitalized interest costs relating to unproved properties, geological expenditures, and tangible and intangible development costs including direct internal costs are capitalized to the full cost pool. As of April 30, 2010, we have properties with proven reserves and production and sales from these reserves has commenced.  Capitalized costs, including estimated future costs to develop the reserves and estimated abandonment costs, net of salvage, are being depleted on the units-of-production method using estimates of the proved reserves. Investments in unproved properties and major development projects including capitalized interest, if any, are not depleted until proved reserves associated with the projects can be determined. If the future exploration of unproved properties are determined uneconomical the amount of such properties are added to the capitalized cost to be depleted.  At April 30, 2010, management believes none of our unproved oil and gas properties were considered impaired other than as previously reported.

The capitalized costs included in the full cost pool are subject to a "ceiling test", which limits such costs to the aggregate of the estimated present value, using a ten percent discount rate, of the future net revenues from proved reserves, based on current economic and operating conditions plus the lower of cost and estimated net realizable value of unproven properties.

Sales of proved and unproved properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in the statement of operations.

Long-Lived Assets

In accordance with SFAS No. 144, “Accounting for the Impairment or Disposal of Long-Lived Assets", the carrying value of intangible assets and other long-lived assets is reviewed on a regular basis for the existence of facts or circumstances that may suggest impairment. We recognize impairment when the sum of the expected undiscounted future cash flows is less than the carrying amount of the asset. Impairment losses, if any, are measured as the excess of the carrying amount of the asset over its estimated fair value.

Revenue Recognition

Oil and natural gas revenues are recorded using the sales method whereby our Company recognizes oil and natural gas revenue based on the amount of oil and gas sold to purchasers when title passes, the amount is determinable and collection is reasonably assured. Actual sales of gas are based on sales, net of the associated volume charges for processing fees and for costs associated with delivery, transportation, marketing, and royalties in accordance with industry standards. Operating costs and taxes are recognized in the same period of which revenue is earned.

Going Concern

We have suffered recurring losses from operations. The continuation of our Company as a going concern is dependent upon our Company attaining and maintaining profitable operations and/or raising additional capital. The financial statements do not include any adjustment relating to the recovery and classification of recorded asset amounts or the amount and classification of liabilities that might be necessary should our Company discontinue operations.

The continuation of our business is dependent upon us raising additional financial support and/or attaining and maintaining profitable levels of internally generated revenue.  The issuance of additional equity securities by us could result in a significant dilution in the equity interests of our current stockholders. Obtaining commercial loans, assuming those loans would be available, will increase our liabilities and future cash commitments.

Recently Issued Accounting Standards

Accounting standards that have been issued or proposed by the FASB or other standards-setting bodies that do not require adoption until a future date are not expected to have a material impact on the Company’s financial statements upon adoption.

Results of Operations – Three Months Ended April 30, 2010 and 2009

The following summary of our results of operations should be read in conjunction with our financial statements for the quarter ended April 30, 2010, which are included herein.

Our operating results for the three months ended April 30, 2010, for the three months ended April 30, 2009 and the changes between those periods for the respective items are summarized as follows:

Our accumulated losses increased to $3,817,268 as of April 30, 2010. Our financial statements report a net loss of $162,523 for the three month period ended April 30, 2010 compared to a net loss of $213,257 for the three month period ended April 30, 2009. Our revenues have decreased primarily as a result of significant decreases in the prices of oil and gas and reduced amounts of oil and gas being produced.  Our losses have decreased primarily because of reduced oil and gas operating costs, insurance costs recorded and a decrease in professional fees for the same period of prior year. There has been a decrease in our general and administrative expenses, specifically decrease in professional fees, stock based compensation and insurance costs recorded.  The Company also recognized a decrease in depletion of its capitalized oil and gas expenditures $24,296 during the three months ended April 30, 2010, compared to $72,445 for the three months ended April 30, 2009.

Results of Operations – Six Months Ended April 30, 2010 and 2009

The following summary of our results of operations should be read in conjunction with our financial statements for the six months ended April 30, 2010, which are included herein.

Our operating results for the six months ended April 30, 2010, for the six months ended April 30, 2009 and the changes between those periods for the respective items are summarized as follows:

As at April 30, 2010, we had $1,089,758 in current liabilities.  Our net cash used in operating activities for the six months ended April 30, 2010 was $172,229 compared to $162,543 used in the six months ended April 30, 2009. Our accumulated losses increased to $3,817,268 as of April 30, 2010. Our financial statements report a net loss of 445,338 for the six month period ended April 30, 2010 compared to a net loss of $376,116 for the six month period ended April 30, 2009. Our losses have increased primarily as a result of increased professional fees, stock based compensation, and foreign exchange conversion. The Company also recognized cost of revenue in oil and gas properties of $114,484 during the six months ended April 30, 2010, compared to $305,498 for the six months ended April 30, 2009.

Our total liabilities as of April 30, 2010 were $1,164,758 as compared to total liabilities of $1,031,547 as of October 31, 2009. The increase is due to a loan made to the Company by the CEO/Chairman.

Liquidity and Financial Condition

Working Capital

Cash Flows

Operating Activities

Net cash used in operating activities was $172,229 for the six months ended April 30, 2010 compared with net cash used in operating activities of $162,543 in the same period in 2009.

 Investing Activities

Net cash used in investing activities was Nil in the six months ended April 30, 2010 compared to net cash used in investing activities was $103,205 in the same period in 2009. The decrease in use of cash of in investing activities is mainly attributable to a decrease in oil and gas property exploration and development costs.

Financing Activities

Net cash provided in financing activities was $258,400 in the six months ended April 30, 2010 compared to net cash used by financing activities of $205,909 in the same period in 2009. This is attributable to the private placement completed on December 24, 2009, a loan made to the Company, and a payment of a short term loan on November 14, 2008.

Oil and gas sales volume comparisons for the Quarter ended April 30, 2010 compared to the quarter ended April 30 , 2009

For the six-month period ended April 30, 2010, the Company had $107,423 in revenues compared to $196,425 in revenues for the same six-month period in the prior year.  The decrease in revenues is largely attributed to lower production and the significantly reduced price of oil and gas due to global economic events.

Item 4.  Controls and Procedures

Management’s Report on Disclosure Controls and Procedures

We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in our reports filed under the Securities Exchange Act of 1934, as amended, is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission's rules and forms, and that such information is accumulated and communicated to our management, including our president and chief executive officer (also our principal executive officer) and our chief financial officer (also our principal financial and accounting officer) to allow for timely decisions regarding required disclosure.

As of April 30, 2010, the end of our quarter covered by this report, we carried out an evaluation, under the supervision and with the participation of our president and chief executive officer (also our principal executive officer) and our chief financial officer (also our principal financial and accounting officer), of the effectiveness of the design and operation of our disclosure controls and procedures. Based on the foregoing, our president and chief executive officer (also our principal executive officer) and our chief financial officer (also our principal financial and accounting officer) concluded that our disclosure controls and procedures were effective as of the end of the period covered by this annual report.  

Management’s Report on Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting. Responsibility, estimates and judgments by management are required to assess the expected benefits and related costs of control procedures. The objectives of internal control include providing management with reasonable, but not absolute, assurance that assets are safeguarded against loss from unauthorized use or disposition, and that transactions are executed in accordance with management’s authorization and recorded properly to permit the preparation of financial statements in conformity with accounting principles generally accepted in the United States. Our management assessed the effectiveness of our internal control over financial reporting as of April 30, 2010. In making this assessment, our management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”) in Internal Control-Integrated Framework. Our management has concluded that, as of April 30, 2010, our internal control over financial reporting is effective in providing reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with US generally accepted accounting principles. Our management reviewed the results of their assessment with our Board of Directors.

This annual report does not include an attestation report of our Company’s registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by our Company’s registered public accounting firm pursuant to temporary rules of the Securities and Exchange Commission that permit our Company to provide only management’s report in this annual report.

Inherent limitations on effectiveness of controls

Internal control over financial reporting has inherent limitations which include but is not limited to the use of independent professionals for advice and guidance, interpretation of existing and/or changing rules and principles, segregation of management duties, scale of organization, and personnel factors. Internal control over financial reporting is a process which involves human diligence and compliance and is subject to lapses in judgment and breakdowns resulting from human failures. Internal control over financial reporting also can be circumvented by collusion or improper management override. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements on a timely basis, however these inherent limitations are known features of the financial reporting process and it is possible to design into the process safeguards to reduce, though not eliminate, this risk. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation. Projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Changes in Internal Control over Financial Reporting

There have been no changes in our internal controls over financial reporting that occurred during the quarter ended April 30, 2010 that have materially or are reasonably likely to materially affect, our internal controls over financial reporting.

PART II

OTHER INFORMATION

Item 1.

Legal Proceedings

We know of no material, existing or pending legal proceedings against our company, nor are we involved as a plaintiff in any material proceeding or pending litigation. There are no proceedings in which any of our directors, executive officers or affiliates, or any registered or beneficial stockholder, is an adverse party or has a material interest adverse to our interest.

Item 1A.   Risk Factors

Much of the information included in this quarterly report includes or 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. 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 as outlined below. 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".

Prospective investors should consider carefully the risk factors set out below.

We have had negative cash flows from operations.

To date we have had negative cash flows from operations and we have been dependent on sales of our equity securities and debt financing to meet our cash requirements and have incurred losses totaling approximately $445,338 for the six month period ending April 30, 2010, and cumulative losses of $3,817,268 to April 30, 2010. As of April 30, 2010 we had negative working capital of $646,540 as a result of past financing activities.  We do expect positive cash flow from operations at some point; however there is no assurance that actual cash requirements will not exceed our estimates, or that our sales projections will be realized as estimated. In particular, additional capital may be required in the event that:

- drilling and completion costs for further wells increase beyond our expectations; or

- commodity prices for our production decline beyond our expectations; or

- production levels do not meet our expectations; or

- we incur higher well plug and abandonment costs than currently expected; or

- we encounter greater costs associated with general and administrative expenses or offering costs.

The occurrence of any of the aforementioned events could adversely affect our ability to meet our business plans.   

We will depend almost exclusively on outside capital to pay for the continued exploration and development of our properties. Such outside capital may include the sale of additional stock and/or commercial borrowing. Capital may not continue to be available if necessary to meet these continuing development costs or, if the capital is available, that it will be on terms acceptable to us. The issuance of additional equity securities by us would result in a significant dilution in the equity interests of our current stockholders. Obtaining commercial loans, assuming those loans would be available, will increase our liabilities and future cash commitments.

If we are unable to obtain financing in the amounts and on terms deemed acceptable to us, we may be unable to continue our business and as a result may be required to scale back or cease operations for our business, the result of which would be that our stockholders would lose some or all of their investment.

A decline in the price of our common stock could affect our ability to raise further working capital and adversely impact our operations.

A prolonged decline in the price of our common stock could result in a reduction in the liquidity of our common stock and a reduction in our ability to raise capital. Because our operations have been primarily financed through the sale of equity securities, a decline in the price of our common stock could be especially detrimental to our liquidity and our continued operations. Any reduction in our ability to raise equity capital in the future would force us to reallocate funds from other planned uses and would have a significant negative effect on our business plans and operations, including our ability to develop new products and continue our current operations. If our stock price declines, we may not be able to raise additional capital or generate funds from operations sufficient to meet our obligations.

We have a history of losses and fluctuating operating results.

From inception through to April 30, 2010, we have incurred aggregate losses of approximately $3,817,268. Our loss from operations for the six-month period ended April 30, 2010 was $445,338. There is no assurance that we will operate profitably or will generate positive cash flow in the future. In addition, our operating results in the future may be subject to significant fluctuations due to many factors not within our control, such as the unpredictability of world prices and market for oil and gas, the demand for our production, and the level of competition and general economic conditions. If we cannot generate positive cash flows in the future, or raise sufficient financing to continue our normal operations, then we may be forced to scale down or even close our operations. Until such time as we generate significant revenues, we expect an increase in development costs and operating costs. Consequently, we expect to continue to incur operating losses and negative cash flow until we receive significant commercial production from our properties.

We have a limited operating history and if we are not successful in continuing to grow our business, then we may have to scale back or even cease our ongoing business operations.

We have limited history of revenues from operations and have limited significant tangible assets. We have yet to generate positive earnings and there can be no assurance that we will ever operate profitably. The success of our company is significantly dependent on a successful acquisition, drilling, completion and production program. Our company’s operations will be subject to all the risks inherent in the establishment of a developing enterprise and the uncertainties arising from the absence of a significant operating history. We may be unable to locate recoverable reserves, extract the reserves economically, and/or operate on a profitable basis.

Trading of our stock may be restricted by the SEC's "Penny Stock" regulations, which may limit a stockholder's ability to buy and sell our stock.

The U.S. Securities and Exchange Commission has adopted regulations which generally define "penny stock" to be any equity security that has a market price (as defined) less than $5.00 per share or an exercise price of less than $5.00 per share, subject to certain exceptions. Our securities are 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 $5,000,000 or individuals with a net worth in excess of $1,000,000 or annual income exceeding $200,000 or $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. 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 stock that is subject to these penny stock rules. Consequently, these penny stock rules may affect the ability of broker-dealers to trade our securities. We believe that the penny stock rules discourage investor interest in and limit the marketability of, our common stock.

The Financial Industry Regulatory Authority, or FINRA, has adopted sales practice requirements which may also limit a stockholder's ability to buy and sell our stock.

In addition to the "penny stock" rules described above, 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, FINRA believes that there is a high probability that speculative low priced securities will not be suitable for at least some customers.  FINRA requirements make it more difficult for broker-dealers to recommend that their customers buy our common stock, which may limit your ability to buy and sell our stock and have an adverse effect on the market for our shares.

Trading in our common shares on the OTC Bulletin Board is limited and sporadic making it difficult for our shareholders to sell their shares or liquidate their investments.

Our common shares are currently listed for public trading on the OTC Bulletin Board. The trading price of our common shares has been subject to wide fluctuations. Trading prices of our common shares may fluctuate in response to a number of factors, many of which will be beyond our control. The stock market has generally experienced extreme price and volume fluctuations that have often been unrelated or disproportionate to the operating performance of companies with no current business operation. There can be no assurance that trading prices and price earnings ratios previously experienced by our common shares will be matched or maintained. These broad market and industry factors may adversely affect the market price of our common shares, regardless of our operating performance.

In the past, following periods of volatility in the market price of a company's securities, securities class-action litigation has often been instituted. Such litigation, if instituted, could result in substantial costs for us and a diversion of management's attention and resources.

Because of the early stage of development and the nature of our business, our securities are considered highly speculative.

Our securities must be considered highly speculative, generally because of the nature of our business and the early stage of its development. We have largely been engaged in the business of exploring and until only recently attempting to develop commercial reserves of oil and gas. Only our Mississippi properties have commenced production. Accordingly, we have generated revenues but we have not realized a profit from our operations to date and there is little likelihood that we will generate significant revenues or realize any profits in the short term. Any profitability in the future from our business will be dependent upon attaining adequate levels of internally generated revenues through locating and developing economic reserves of oil and gas, which itself is subject to numerous risk factors as set forth herein. Since we have not generated significant revenues, we will have to raise additional monies through either securing industry reserve based debt financing, or the sale of our equity securities or debt, or combinations of the above in order to continue our business operations.

As our properties are in the exploration and early development stage there can be no assurance that we will establish commercial discoveries and/or profitable production programs on these properties.

Exploration for economic reserves of oil and gas is subject to a number of risk factors. Few properties that are explored are ultimately developed into producing oil and/or gas wells. Our Mississippi properties are in the production and development stages only.

The potential profitability of oil and gas ventures depends upon factors beyond the control of our company.

The potential profitability of oil and gas properties is dependent upon many factors beyond our control. For instance, world prices and markets for oil and gas are unpredictable, highly volatile, potentially subject to governmental fixing, pegging, controls, or any combination of these and other factors, and respond to changes in domestic, international, political, social, and economic environments. Additionally, due to worldwide economic uncertainty, the availability and cost of funds for production and other expenses have become increasingly difficult, if not impossible, to project. These changes and events may materially affect our financial performance.

Adverse weather conditions can also hinder drilling operations. A productive well may become uneconomic in the event water or other deleterious substances are encountered which impair or prevent the production of oil and/or gas from the well. In addition, production from any well may be unmarketable if it is impregnated with water or other deleterious substances. The marketability of oil and gas, which may be acquired or discovered, will be affected by numerous factors beyond our control. These factors include the proximity and capacity of oil and gas pipelines and processing equipment, market fluctuations of prices, taxes, royalties, land tenure, allowable production and environmental protection. These factors cannot be accurately predicted and the combination of these factors may result in our company not receiving an adequate return on invested capital.

Competition in the oil and gas industry is highly competitive and there is no assurance that we will be successful in acquiring the leases.

The oil and gas industry is intensely competitive. We compete with numerous individuals and companies, including many major oil and gas companies, which have substantially greater technical, financial and operational resources and staff. Accordingly, there is a high degree of competition for desirable oil and gas leases, suitable properties for drilling operations and necessary drilling equipment, as well as for access to funds. We cannot predict if the necessary funds can be raised or that any projected work will be completed. Our budget does not anticipate the potential acquisition of additional acreage in Mississippi although this may change at any time without notice.  This acreage may not become available or if it is available for leasing, that we may not be successful in acquiring the leases. There are other competitors that have operations in these areas and the presence of these competitors could adversely affect our ability to acquire additional leases.

The marketability of natural resources will be affected by numerous factors beyond our control, which may result in us not receiving an adequate return on invested capital to be profitable or viable.

The marketability of natural resources, which may be acquired or discovered by us, will be affected by numerous factors beyond our control. These factors include market fluctuations in oil and gas pricing and demand, the proximity and capacity of natural resource markets and processing equipment, governmental regulations, land tenure, land use, regulation concerning the importing and exporting of oil and gas and environmental protection regulations. The exact effect of these factors cannot be accurately predicted, but the combination of these factors may result in us not receiving an adequate return on invested capital to be profitable or viable.

Oil and gas operations are subject to comprehensive regulation, which may cause substantial delays or require capital outlays in excess of those anticipated causing an adverse effect on our company.

Oil and gas operations are subject to federal, state, and local laws relating to the protection of the environment, including laws regulating removal of natural resources from the ground and the discharge of materials into the environment. Oil and gas operations are also subject to federal, state, and local laws and regulations, which seek to maintain health and safety standards by regulating the design and use of drilling methods and equipment. Various permits from government bodies are required for drilling operations to be conducted; no assurance can be given that such permits will be received. Environmental standards imposed by federal, provincial, or local authorities may be changed and any such changes may have material adverse effects on our activities. Moreover, compliance with such laws may cause substantial delays or require capital outlays in excess of those anticipated, thus causing an adverse effect on us. Additionally, we may be subject to liability for pollution or other environmental damages, which it may elect not to insure against due to prohibitive premium costs and other reasons. To date we have not been required to spend any material amount on compliance with environmental regulations. However, we may be required to do so in future and this may affect our ability to expand or maintain our operations.

Exploration and production activities are subject to certain environmental regulations, which may prevent or delay the commencement or continuance of our operations.

In general, our exploration and production activities are subject to certain federal, state and local laws and regulations relating to environmental quality and pollution control. Such laws and regulations increase the costs of these activities and may prevent or delay the commencement or continuance of a given operation. Compliance with these laws and regulations has not had a material effect on our operations or financial condition to date. Specifically, we are subject to legislation regarding emissions into the environment, water discharges and storage and disposition of hazardous wastes. In addition, legislation has been enacted which requires well and facility sites to be abandoned and reclaimed to the satisfaction of state authorities. However, such laws and regulations are frequently changed and we are unable to predict the ultimate cost of compliance. Generally, environmental requirements do not appear to affect us any differently or to any greater or lesser extent than other companies in the industry.

We believe that our operations comply, in all material respects, with all applicable environmental regulations.

Our operating partners maintain insurance coverage customary to the industry; however, we are not fully insured against all possible environmental risks.

Exploratory and development drilling involves many risks and we may become liable for pollution or other liabilities, which may have an adverse effect on our financial position.

Drilling operations generally involve a high degree of risk. Hazards such as unusual or unexpected geological formations, power outages, labor disruptions, blow-outs, sour gas leakage, fire, inability to obtain suitable or adequate machinery, equipment or labour, and other risks are involved. We may become subject to liability for pollution or hazards against which it cannot adequately insure or which it may elect not to insure. Incurring any such liability may have a material adverse effect on our financial position and operations.

Any change to government regulation/administrative practices may have a negative impact on our ability to operate and our profitability.

The laws, regulations, policies or current administrative practices of any government body, organization or regulatory agency in the United States, Canada, or any other jurisdiction, may be changed, applied or interpreted in a manner which will fundamentally alter the ability of our company to carry on our business.

The actions, policies or regulations, or changes thereto, of any government body or regulatory agency, or other special interest groups, may have a detrimental effect on us. Any or all of these situations may have a negative impact on our ability to operate and/or our profitably.

Our By-laws contain provisions indemnifying our officers and directors against all costs, charges and expenses incurred by them.

Our By-laws contain provisions with respect to the indemnification of our officers and directors against all costs, charges and expenses, including an amount paid to settle an action or satisfy a judgment, actually and reasonably incurred by him, including an amount paid to settle an action or satisfy a judgment in a civil, criminal or administrative action or proceeding to which he is made a party by reason of his being or having been one of our directors or officers.  

Investors' interests in our company will be diluted and investors may suffer dilution in their net book value per share if we issue additional shares or raise funds through the sale of equity securities.

Our constating documents authorize the issuance of 200,000,000 shares of common stock with a par value of $0.001. In the event that we are required to issue any additional shares or enter into private placements to raise financing through the sale of equity securities, investors' interests in our company will be diluted and investors may suffer dilution in their net book value per share depending on the price at which such securities are sold. If we issue any such additional shares, such issuances also will cause a reduction in the proportionate ownership and voting power of all other shareholders. Further, any such issuance may result in a change in our control.

Our By-laws do not contain anti-takeover provisions, which could result in a change of our management and directors if there is a take-over of our company.

We do not currently have a shareholder rights plan or any anti-takeover provisions in our By-laws. Without any anti-takeover provisions, there is no deterrent for a take-over of our company, which may result in a change in our management and directors.

As a result of a majority of our directors and officers are residents of other countries other than the United States, investors may find it difficult to enforce, within the United States, any judgments obtained against our company or our directors and officers.

Other than our operations offices in Vancouver and Kelowna, British Columbia, we do not currently maintain a permanent place of business within the United States. In addition, a majority of our directors and officers are nationals and/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.   

 Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3.

Defaults Upon Senior Securities

None.

Item 4.

Submission of Matters to a Vote of Securities Holders

None.

Item 5.

Other Information

Due to the implementation of British Columbia Instrument 51-509 on September 30, 2008 by the British Columbia Securities Commission, we have been deemed to be a British Columbia based reporting issuer.  As such, we are required to file certain information and documents at www.sedar.com.

Item 6.

Exhibits

* Filed herewith.

**Certain parts of this document have not been disclosed and have been filed separately with the Secretary, Securities and Exchange Commission, and is subject to a confidential treatment request pursuant to Rule 24b-2 of the Securities Exchange Act of 1934.

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.