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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-QSB
(Mark One)
þ | Quarterly Report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 for the quarterly period ended March 31, 2006; or |
o | Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 for the transition period from to . |
Commission File Number0-18596
American Natural Energy Corporation
(Exact name of small business issuer as specified in its charter)
Oklahoma | 73-1605215 | |
(State or other jurisdiction of | (I.R.S employer | |
incorporation of organization) | identification no.) |
One Warren Place, 6100 South Yale, Suite 300, Tulsa, Oklahoma 74136
(Address of principal executive offices, zip code)
(918) 481-1440
(Issuer’s Telephone Number, Including Area Code)
Check whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the issuer was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Yesþ Noo
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Yeso Noþ
APPLICABLE ONLY TO CORPORATE ISSUERS:
As of May 15, 2006, 51,497,674 shares of the Registrant’s Common Stock, $0.001 par value, were outstanding.
AMERICAN NATURAL ENERGY CORPORATION
QUARTERLY REPORT ON FORM 10-QSB
INDEX
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PART I — FINANCIAL INFORMATION
Item 1. Financial Statements
AMERICAN NATURAL ENERGY CORPORATION
Condensed Consolidated Balance Sheets (Unaudited)
AMERICAN NATURAL ENERGY CORPORATION
Condensed Consolidated Balance Sheets (Unaudited)
As of March 31, 2006 and December 31, 2005
March 31, 2006 | December 31, 2005 | |||||||
$ | $ | |||||||
ASSETS | ||||||||
Current assets: | ||||||||
Cash and cash equivalents | 1,251 | 185,268 | ||||||
Accounts receivable — joint interest billing | 185,790 | 625,963 | ||||||
Accounts receivable — oil and gas sales | 338,622 | 375,079 | ||||||
Accounts receivable — other | 9,810 | 9,769 | ||||||
Prepaid expenses | 69,466 | 129,376 | ||||||
Oil inventory | 12,679 | 11,283 | ||||||
Total current assets | 617,618 | 1,336,738 | ||||||
Proved oil and natural gas properties, net of accumulated depletion, depreciation, amortization and impairment of $19,521,747 and $19,353,778 | 2,593,149 | 2,625,550 | ||||||
Unproved oil and natural gas properties | 3,187,838 | 3,278,257 | ||||||
Equipment and other fixed assets, net of accumulated depreciation of $538,697 and $532,174 | 569,078 | 572,708 | ||||||
Deferred expenses, net of accumulated amortization of $161,515 and $93,707 | 161,079 | 208,887 | ||||||
Total assets | 7,128,762 | 8,022,140 | ||||||
LIABILITIES AND STOCKHOLDERS’ DEFICIT | ||||||||
Current liabilities: | ||||||||
Accounts payable and accrued liabilities | 3,155,692 | 3,686,485 | ||||||
Revenue payable | 3,657,261 | 3,273,800 | ||||||
Accrued interest | 20,036 | 12,404 | ||||||
Insurance note payable | — | 17,587 | ||||||
Notes payable (Note 4) | 1,124,503 | 1,252,361 | ||||||
Asset retirement obligation | 419,136 | 408,799 | ||||||
Taxes due on dissolution of subsidiary (Note 5) | 302,870 | 302,870 | ||||||
Current portion of convertible secured debentures, net of discount of $138,569 and $205,169 (Note 4) | 11,036,431 | 10,969,831 | ||||||
Total current liabilities | 19,715,929 | 19,924,137 | ||||||
Noncurrent notes payable (Note 4) | 69,325 | 142,259 | ||||||
Asset retirement obligations | 1,253,878 | 1,139,848 | ||||||
Total liabilities | 21,039,132 | 21,206,244 | ||||||
Commitments and contingencies (Note 5) | ||||||||
Stockholders’ deficit: | ||||||||
Common stock | ||||||||
Authorized — 250,000,000 shares with par value of $0.001 Issued and outstanding — 50,664,342 shares | 50,664 | 50,664 | ||||||
Additional paid-in capital | 19,973,090 | 19,973,090 | ||||||
Accumulated deficit, since January 1, 2002 (in conjunction with the quasi- reorganization stated capital was reduced by an accumulated deficit of $2,015,495) | (36,182,262 | ) | (35,471,289 | ) | ||||
Accumulated other comprehensive income | 2,248,138 | 2,263,431 | ||||||
Total stockholders’ deficit | (13,910,370 | ) | (13,184,104 | ) | ||||
Total liabilities and stockholders’ deficit | 7,128,762 | 8,022,140 | ||||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
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AMERICAN NATURAL ENERGY CORPORATION
Condensed Consolidated Statements of Operations (Unaudited)
For the three-month periods ended March 31, 2006 and March 31, 2005
2006 | 2005 | |||||||
$ | $ | |||||||
Revenues: | ||||||||
Oil and gas sales | 549,815 | 805,665 | ||||||
Operations income | 37,085 | 30,346 | ||||||
Interest and other income | 11 | 8 | ||||||
586,911 | 836,019 | |||||||
Expenses: | ||||||||
Lease operating expense | 108,931 | 121,310 | ||||||
Production tax expense | 36,981 | 65,657 | ||||||
General and administrative | 531,835 | 421,714 | ||||||
Foreign exchange gain | (15,293 | ) | (104,416 | ) | ||||
Interest and financing costs | 319,739 | 1,330,106 | ||||||
Depreciation, depletion and amortization — oil and gas properties | 238,511 | 361,752 | ||||||
Depreciation and amortization — other assets | 77,180 | 134,972 | ||||||
Total expenses | 1,297,884 | 2,331,095 | ||||||
Net loss | (710,973 | ) | (1,495,076 | ) | ||||
Other comprehensive income (loss) — net of tax: | ||||||||
Foreign exchange translation | (15,293 | ) | (104,416 | ) | ||||
Other comprehensive income (loss) | (15,293 | ) | (104,416 | ) | ||||
Comprehensive loss | (726,266 | ) | (1,599,492 | ) | ||||
Basic and diluted loss per share | (0.01 | ) | (0.04 | ) | ||||
Weighted average number of shares outstanding | ||||||||
Basic | 50,664,342 | 35,313,929 | ||||||
Diluted | 50,664,342 | 35,313,929 | ||||||
The accompanying notes are an integral part of these condensed consolidated financial statements.
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AMERICAN NATURAL ENERGY CORPORATION
Condensed Consolidated Statements of Cash Flows (Unaudited)
For the three-month periods ended March 31, 2006 and March 31, 2005
2006 | 2005 | |||||||
$ | $ | |||||||
Cash flows from operating activities: | ||||||||
Net loss | (710,973 | ) | (1,495,076 | ) | ||||
Non cash items: | ||||||||
Depreciation, depletion and amortization | 315,691 | 496,724 | ||||||
Foreign exchange gain | (15,293 | ) | (104,416 | ) | ||||
Interest and financing costs | 66,601 | 1,185,517 | ||||||
Changes in working capital items: | ||||||||
Accounts receivables | 476,589 | 596,370 | ||||||
Oil inventory | (52 | ) | (1,404 | ) | ||||
Prepaid expenses | 59,910 | 30,019 | ||||||
Accounts payable, revenue payable and accrued liabilities | 375,424 | (117,120 | ) | |||||
Net cash provided by operating activities | 567,897 | 590,614 | ||||||
Cash flows from investing activities: | ||||||||
Purchase and development of oil and gas properties | (613,546 | ) | (878,782 | ) | ||||
Purchase of equipment and other fixed assets | (5,743 | ) | (26,449 | ) | ||||
Proceeds from sale of participation rights | 162,500 | — | ||||||
Net cash used in investing activities | (456,789 | ) | (905,231 | ) | ||||
Cash flows from financing activities: | ||||||||
Issuance of notes payable | — | 100,000 | ||||||
Payment of notes payable | (218,380 | ) | (12,910 | ) | ||||
Private placement costs | (20,000 | ) | — | |||||
Change in bank overdrafts outstanding | (56,745 | ) | — | |||||
Refund of issuance expenses from prior period | — | 4,724 | ||||||
Cash (used in) provided by financing activities | (295,125 | ) | 91,814 | |||||
Decrease in cash and cash equivalents | (184,017 | ) | (222,803 | ) | ||||
Cash beginning of period | 185,268 | 303,817 | ||||||
Cash end of period | 1,251 | 81,014 | ||||||
Supplemental disclosures: | ||||||||
Interest paid, net of capitalized interest | 246,580 | 144,519 | ||||||
Non cash financing and investing activities: | ||||||||
Change in accounts payable resulting from the purchase and development of oil and gas properties | 458,378 | 44,620 | ||||||
Principle amount of 8% debentures converted to common stock | — | 200,000 | ||||||
Accounts payable refinanced with notes payable | — | 270,000 |
The accompanying notes are an integral part of these condensed consolidated financial statements.
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American Natural Energy Corporation
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
1 | Significant accounting policies | |
The accounting policies and methods followed in preparing these unaudited condensed consolidated financial statements are those used by American Natural Energy Corporation (the “Company”) as described in Note 1 of the notes to consolidated financial statements included in the Annual Report on Form 10-KSB. However, the unaudited condensed consolidated financial statements for the three-month periods ended March 31, 2006 and 2005 do not conform in all respects to the disclosure and information that is required for annual consolidated financial statements. The year-end condensed consolidated balance sheet data was derived from audited financial statements, but does not include all disclosures required by accounting principles generally accepted in the United States of America. These interim condensed consolidated financial statements should be read in conjunction with the most recent annual consolidated financial statements of the Company. | ||
In the opinion of management, all adjustments, all of which are of a normal recurring nature, considered necessary for fair statement have been included in these interim condensed consolidated financial statements. Operating results for the three-month period ended March 31, 2006 are not indicative of the results that may be expected for the full year ending December 31, 2006. | ||
Stock-based compensation | ||
As discussed below in Note 6, the Company has a stock-based compensation plan, and effective January 1, 2006, accounts for stock options granted to employees under this plan in accordance with the provisions of Statement on Financial Accounting Standards (“SFAS”) No. 123 (Revised 2004),Share-Based Payment (“SFAS 123R”).Under the provisions of SFAS 123R, share-based compensation cost is measured at the grant date, based on the calculated fair value of the award, and is recognized as an expense over the grantee’s requisite service period (generally the vesting period of the equity grant). Prior to this, the Company accounted for its share-based compensation under Accounting Principles Board Opinion No. 25,Accounting for Stock Issued to Employees, (“APB 25”) and related interpretations and the disclosure requirements of SFAS 123,Accounting for Stock-Based Compensation,as amended by SFAS 148,Accounting for Stock-Based Compensation-Transition and Disclosure. The company elected to adopt the modified-prospective transition method as provided under SFAS 123R and, accordingly, results for prior periods have not been restated. | ||
Income tax expense | ||
SFAS 109,Accounting for Income Taxes, requires that the Company record a valuation allowance when it is more likely than not that a portion or all of its deferred tax asset will not be realized. As a result of such evaluation as of December 31, 2005 and March 31, 2006, the Company concluded that it is more likely than not that no benefit from deferred tax assets will be realized. Therefore, for all periods presented, a full valuation allowance was recorded, causing the effective income tax expense to be zero. | ||
Interest and financing costs | ||
Interest expense is recognized in the period incurred, and consists primarily of interest cost associated with the Company’s 8% convertible secured debentures (the “Debentures”) issued in October 2003. Interest cost on the Debentures includes interest expense at the stated rate and the accretion of a discount, which is determined using the effective interest method. Discount accretion during the three months ended March 31, 2006 and 2005 was $67,000 and $1,186,000, respectively. Additionally, upon conversion of the Debentures, |
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American Natural Energy Corporation
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
any unamortized balance of the discount associated with principal converted is included in interest cost, net of any amounts capitalized. A portion of interest cost consisting of all interest cost is capitalized on significant investments in unproved properties that were not being depreciated, depleted or amortized and on which exploration and development activities were in progress during the reporting period. The amount of interest cost to be capitalized is primarily determined using the weighted average interest rate on the outstanding borrowings. No interest was capitalized during the three months ended March 31, 2006. During the three months ended March 31, 2005, interest cost capitalized amounted to $100,000. | ||
New pronouncements | ||
In February 2006, the Financial Accounting Standards Board (“FASB”) issued Statement of Financial Accounting Standards No. 155,Accounting for Certain Hybrid Financial Instruments — an amendment of FASB Statements No. 133 and 140 (“SFAS No. 155”).SFAS No. 155 permits fair value remeasurement for any hybrid financial instrument that contains an embedded derivative that otherwise would require bifurcation and clarifies several other related issues. The provisions of SFAS No. 155 are effective for all financial instruments acquired or issued in the first fiscal year beginning after September 15, 2006. The Company has not evaluated what impact, if any, this standard will have on its financial position or results of operations. | ||
2 | Earnings (loss) per share | |
Basic earnings (loss) per share is computed by dividing net income or loss (the numerator) by the weighted average number of shares outstanding during the period (the denominator). The computation of diluted earnings per share is the same as for basic earnings per share except the denominator is increased to include the weighted average additional number of shares that would have been outstanding if previously granted stock options had been exercised, unless the effects are anti-dilutive. | ||
A reconciliation of the numerators and denominators used in calculating basic and diluted earnings per share for each period presented is as follows: |
Three Months Ended March 31, | ||||||||
2006(1) | 2005(1) | |||||||
$ | $ | |||||||
Numerator — net loss | ||||||||
Basic | (710,973 | ) | (1,495,076 | ) | ||||
Diluted | (710,973 | ) | (1,495,076 | ) | ||||
Denominator — weighted average number of shares outstanding | ||||||||
Basic | 50,664,342 | 35,313,929 | ||||||
Diluted | 50,664,342 | 35,313,929 |
(1) | Does not include 1,600,000 outstanding potentially dilutive options at a weighted average price of $0.50 per share, and the effects of 74,500,000 common shares issuable upon conversion of 8% debentures due to the net loss. |
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American Natural Energy Corporation
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
3 | Liquidity and Capital Resources | |
The Company has no current borrowing capacity with any lender. The Company has sustained substantial losses during the first quarter of 2006 and during the year ended December 31, 2005, totaling approximately $711,000 and $6.2 million, respectively, and has a working capital deficiency and an accumulated deficit at March 31, 2006 which leads to questions concerning the ability of the Company to meet its obligations as they come due. The Company also has a need for substantial funds to develop its oil and gas properties and repay borrowings as well as to meet its other current liabilities. | ||
The accompanying financial statements have been prepared on a going concern basis which contemplates continuity of operations, realization of assets and liquidation of liabilities in the ordinary course of business. As a result of the losses incurred and current negative working capital, there is no assurance that the carrying amounts of assets will be realized or that liabilities will be liquidated or settled for the amounts recorded. The ability of the Company to continue as a going concern is dependent upon adequate sources of capital and the Company’s ability to sustain positive results of operations and cash flows sufficient to continue to explore for and develop its oil and gas reserves and pay its obligations. | ||
In the ordinary course of business, the Company makes substantial capital expenditures for the exploration and development of oil and natural gas reserves. Historically, the Company has financed its capital expenditures, debt service and working capital requirements with the proceeds of debt and private and public offering of its securities. Cash flow from operations is sensitive to the prices the Company receives for its oil and natural gas. A reduction in planned capital spending or an extended decline in oil and gas prices could result in less than anticipated cash flow from operations and an inability to sell more of its common stock or refinance its debt with current lenders or new lenders, which would likely have a further material adverse effect on the Company. | ||
Management’s strategy is to obtain additional financing or industry partners. Certain covenants included in the 8% convertible secured debentures in the amount of $11,175,000 due September 30, 2006, limit the amount of additional indebtedness the Company can incur to $2 million. It is management’s intention to raise additional debt or equity financing to either repay or refinance these debentures and to fund its operations and capital expenditures. Failure to obtain additional financing can be expected to adversely affect the Company’s ability to pay its obligations, further the development of its properties, including the ExxonMobil area of mutual interest (the “AMI”), grow revenues, oil and gas reserves and achieve and maintain a significant level of revenues, cash flows, and profitability. There can be no assurance that the Company will obtain this additional financing at the time required, at rates that are favorable to the Company, or at all. Further, any additional equity financing that is obtained may result in material dilution to the current holders of common stock. | ||
4 | Notes Payable and Long Term Debt | |
8% Convertible secured debentures | ||
On October 21, 2003 and October 31, 2003, the Company completed financing transactions of $11.695 million and $305,000, respectively, by issuing the Debentures. The Debentures were repayable on September 30, 2005 with interest payable quarterly commencing December 31, 2003 at 8% per annum. At the dates of issuance, the outstanding principal of the Debentures was convertible by the holders into common shares of the Company at any time prior to maturity at a conversion price of $0.45 per share, subject to antidilution |
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American Natural Energy Corporation
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
adjustment, and the Debentures are redeemable by the Company at any time after October 1, 2004 if the weighted average price per share on the TSX Venture Exchange for a 20 consecutive trading day period prior to the date notice of redemption is given has exceeded 166 2/3% of the conversion price. A finder’s fee in the amount of $360,000 was paid to Middlemarch Partners Limited of London, England in connection with the financing. The Debentures are collateralized by substantially all of ANEC’s assets. The Debentures have covenants limiting unsecured borrowings to $2 million and restricting the payment of dividends and capital distributions.
During the third quarter of 2004, the company completed a Rights Offering. Due to the antidilution adjustment provisions contained in the Debenture Agreement, such transaction changed the conversion price of the debentures from $0.45 to $0.43 per share and as a result changed the related Beneficial Conversion Feature by $858,000. The change in the Beneficial Conversion Feature caused the effective rate of the debentures to increase from 55% to 62%.
In June 2005, the Debentures were amended with approval by approximately 86% of the Debentureholders. The amendments extended the maturity date of the Debentures by one year to September 30, 2006, reduced through the maturity date of the Debentures the per share price at which the principal of the Debentures could be converted into shares of Common Stock to $0.15 per share, and provided for the partial release of the lien collateralizing the Debentures in the event a third party entered into an agreement with the Company pursuant to which the third party is granted the right to drill one or more wells on Company properties and commenced that drilling activity. Under the amendments, 74,500,000 shares may be issued upon full conversion of the Debentures at the reduced conversion price. On June 23, 2005, stockholders of the Company voted to amend the Certificate of Incorporation to increase the number of shares of Common Stock of the Company from 100 million to 250 million and adjust par value from $0.01 to $0.001 per share. This increase in authorized shares, along with the approval of the TSX Venture Exchange to the transactions, provided final approval of the Debenture amendments.
The amendments to the Debentures resulted in the extinguishment of debt and recognition of a loss of $1,147,000. At the date of the amendment and at March 31, 2006, $11,175,000 in Debentures was outstanding. As a result of the extinguishment and recognition of loss, these Debentures were recorded at their fair market value on June 23, 2005 reflecting the present value of future cash flows and the option value of the underlying convertible shares.
The Company has agreed to file a registration statement and post-effective amendment under the U.S. Securities Act of 1933, as amended (the “U.S. Securities Act”), to enable, upon effectiveness of the registration statement and post-effective amendment, the resale of the shares to be issued on conversion of the Debentures.
Notes payable
On February 2, 2005, the Company entered into a $100,000 unsecured short-term note with a NYP floating interest rate with Citizens Bank of Oklahoma. The maturity date of the note is July 6, 2006 with interest payments due monthly and all unpaid accrued interest and principal due at maturity.
On August 24, 2005, the Company entered into a note payable with Parker Drilling Company for $507,000, which included the conversion of an accounts payable balance of $486,000 due to Parker Drilling Company. Monthly payments of $25,000 which include interest at the rate of 7% per annum are to be made through June 2007.
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American Natural Energy Corporation
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
On September 7, 2005, the Company converted its $86,000 accounts payable balance to Eaton Oil Tools to a note payable. Beginning September 15, 2005, twelve monthly payments of $7,435 will be made with the final payment including all interest accrued at the rate of 6.5% per annum. | ||
On November 16, 2005, the Company agreed to convert its $420,000 accounts payable balance to Ambar Drilling Fluids to a note payable. Beginning November 16, 2005, interest is accrued at 4% per annum with payment of principal balance and interest due on or before May 16, 2006. | ||
On October 15, 2005, the Company converted its $309,000 accounts payable balance to Leam Drilling Services to a note payable. Monthly payments of $26,697 which include interest at the rate of 8% per annum are to be made through September 2006. | ||
On November 14, 2005, the Company converted its $26,000 accounts payable balance to Mitchell Industries to a note payable. A down payment of $5,112 was tendered upon execution of the note. Monthly payments of $4,172 which include interest at the rate of 8% per annum are to be made through April 2006. This note has been paid in full subsequent to March 31, 2006. | ||
On December 16, 2005, the Company converted its $99,000 accounts payable balance to Patterson Services to a note payable. Monthly payments of $8,710 which include interest at the rate of 10% per annum are to be made through December 2006. | ||
5 | Commitments and contingencies | |
Citizens Bank of Oklahoma, N.A. has issued an irrevocable standby letter of credit, dated January 12, 2006 and expiring July 12, 2006, in the amount of $125,000 drawn in favor of RLI Insurance Company securing a surety bond in favor of the Louisiana Office of Conservation for plugging and abandonment obligations which may occur as a result of drilling operations in St. Charles Parish, Louisiana. | ||
The Company agreed that the Class 7 creditors to the ANEC/Couba Reorganization Plan (“Plan”) would receive a contingent payable from future production of the properties in the amount of approximately $4.9 million. The contingent payable is in the form of a net profits interest (“NPI”), the size of which is determined by the location of wells that may be drilled in the future. Wells existing at the effective date of the Plan receive an NPI of 50%, new wells drilled on acreage transferred by the Plan to the Company will receive an NPI of 15% and new wells drilled within the boundaries of a seismic shoot previously owned by Couba will receive an NPI of 6%. The Company is entitled to recover all capital and operating costs prior to the NPI becoming payable. At a minimum, the Class 7 creditors are to receive an overriding royalty interest that is in payment of the contingent payable. The Company is accounting for any contingent purchase price payments to the Class 7 creditors as additions to the full cost pool as production occurs. | ||
The Company agreed that, after repayment to the Company of 200% of all costs of bankruptcy, drilling, development and field operations from net revenues of the Bayou Couba Lease and the 23.5 square mile area of mutual interest, including payments made by the Company to all creditors of all classes under the plan, the former holders of equity securities of Couba will be entitled to a working interest in the wells in the Bayou Couba Lease equal to 25% of the working interest obtained by the Company directly from Couba at the time of confirmation and as a result of the plan of reorganization of Couba and a 25% interest in the Company’s interest in the 23.5 square mile area of mutual interest held by the Company on the effective date of the plan. |
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American Natural Energy Corporation
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
Effective January 31, 2005, the Company made application with applicable Canadian authorities to dissolve and terminate Gothic Resources Inc. (“Gothic”). In conjunction with the application for dissolution, the prior tax returns and tax status of Gothic are being reviewed by the Canada Customs and Revenue Agency (“CRA”). While no final determination, claim or assessment has been made by CRA, the Company has accrued $302,870 (Cdn$353,000) as an estimate of taxes due on dissolution of Gothic relating to questions by CRA on paid up capital and imputed interest. Additional amounts which may be assessed as a result of the review by CRA are uncertain and no estimate can be made of any additional exposure by the Company at this time. | ||
On March 8, 2006, the Company executed a letter of intent with TransAtlantic Petroleum Corporation (“TransAtlantic”) to purchase TransAtlantic’s interests in the Company’s Bayou Couba project, St. Charles Parish, Louisiana (“Bayou Couba”) and the Company’s 8% Convertible Secured Debentures in the principal amount of $3.0 million (the “Debentures”) held by TransAtlantic. The Company agreed to pay a total of $3.8 million for TransAtlantic’s Bayou Couba assets and the Debentures. Closing is anticipated to occur within 90 days with an effective date as of the first day of the month in which the transaction closes. The transaction is subject to the Company securing financing to effect the transaction, the negotiation, preparation and execution of a mutually acceptable definitive agreement and the approval of the respective Boards of both companies. | ||
The Company is a defendant in a number of legal proceedings which it considers to be routine litigation that is incidental to its business. The Company does not expect to incur any material liability as a consequence of such litigation. | ||
6 | Stock-based compensation | |
On January 1, 2006, the Company adopted FAS 123(R), which requires companies to measure the cost of employee services received in exchange for an award of equity instruments based on the grant date fair value of the award. The Company has elected to use the modified prospective application method such that FAS 123(R) applies to new awards, the unvested portion of existing awards and to awards modified, repurchased or canceled after the effective date. The Company has equity incentive plans that provide for the issuance of stock options. These plans are discussed more fully in the Company’s Form 10-KSB for the year ended December 31, 2005. All options expire five years from the date of grant. Generally, stock options granted to employees and directors vest ratably over two years from the grant date. No new stock options have been granted subsequent to January 1, 2006. The Company recognizes stock-based compensation expense over the vesting period of the individual grants. | ||
Prior to January 1, 2006, the Company accounted for its long-term equity incentive plans under the intrinsic value method described in APB Opinion No. 25, “Accounting for Stock Issued to Employees” and related interpretation. The Company, applying the intrinsic value method, did not record stock-based compensation cost for stock options issued to employees and directors because the exercise price of the stock options equaled the market price of the underlying stock at the date of grant. | ||
For the three months ended March 31, 2006, the Company recognized compensation costs of $469 related to stock options issued prior to January 1, 2006. There is no unrecognized compensation costs related to stock options not yet vested as all stock options are vested at March 31, 2006 | ||
The fair value of stock options granted in 2005 was estimated on the date of the grant using a Black-Scholes valuation model that uses the following weighted average assumptions: |
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American Natural Energy Corporation
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
Notes to Condensed Consolidated Financial Statements (Unaudited)
March 31, 2006 and 2005
Weighted average life, in years | 5.00 | |||
Risk-Free interest rate | 3.60 | % | ||
Expected volatility | 107.3 | % | ||
Expected Dividend Rate | None |
The Company utilizes authorized but unissued shares when a stock option is exercised.
The following table illustrates the effect on net income and earnings per share in the comparable quarter of the prior year as if the fair value based method under FASB Statement 123 had been applied to all outstanding vested and unvested awards in that period.
$ | ||||
Net loss, as reported | (1,495,076 | ) | ||
Less: Total stock-based employee compensation expense determined under fair value based method for all awards, net of related tax effects | (7,031 | ) | ||
Pro forma net loss | (1,502,107 | ) | ||
Loss per share | ||||
Basic and diluted-as reported | (0.04 | ) | ||
Basic and diluted-pro forma | (0.04 | ) | ||
There was no stock option activity in the first quarter of 2006 or 2005. At March 31, 2006 there were 1,600,000 options outstanding and exercisable with a weighted average exercise price of $0.50. The weighted average remaining contractual term for these options at March 31, 2006 was 2.8 years. These options had no intrinsic value at March 31, 2006. | ||
7 | Subsequent events | |
In April and May 2006, Debentureholders converted $125,000 of the company’s 8% Convertible Secured Debentures to 833,332 shares of common stock, pursuant to the terms of the instruments’ indenture. |
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Item 2. Management’s Discussion and Analysis or Plan of Operation
General
We are engaged in the acquisition, development, exploitation and production of oil and natural gas. Our revenues and profitability can be expected to be dependent, to a significant extent, upon prevailing spot market prices for oil and natural gas and upon the quantities of oil and natural gas we produce and sell. Prices for oil and natural gas are subject to wide fluctuations in response to changes in supply of and demand for oil and natural gas, market uncertainty and a variety of additional factors that are beyond our control. Such factors include political conditions, weather conditions, government regulations, the price and availability of alternative fuels and overall economic conditions.
Our financial statements have been prepared on a going concern basis which contemplates continuity of operations, realization of assets and liquidation of liabilities in the ordinary course of business. We have sustained substantial losses in years 2005 and 2004, of approximately $6.2 and $14.9 million, respectively, and have a net loss of $711,000 in the three month period ended March 31, 2006, and have a working capital deficiency and an accumulated deficit at March 31, 2006 which lead to questions concerning our ability to meet our obligations as they come due. We also have a need for substantial funds to pay current liabilities and to develop our oil and gas properties. We have financed our activities using debt and equity financings and drilling participations, and we have no bank or other line of credit or other financing agreement providing borrowing availability with a commercial lender. Our cash flow from operations is sensitive to the prices we receive for our oil and natural gas and the quantities of oil and gas we produce. A reduction in planned capital spending or an extended decline in oil and gas prices could result in less than anticipated cash flow from operations and a lessened ability to sell more of our common stock or refinance our debt with current lenders or new lenders, which would likely have a further material adverse effect on us. The uncertainty as to whether or not we can raise additional capital in the future is likely to have an effect on our future revenues and operations if we are unable to raise that additional capital.
As a result of the losses incurred and current negative working capital and other matters described above, there is no assurance that the carrying amounts of our assets will be realized or that liabilities will be liquidated or settled for the amounts recorded. Our ability to continue as a going concern is dependent upon adequate sources of capital and the ability to sustain positive results of operations and cash flows sufficient to continue to explore for and develop our oil and gas reserves. See the discussion under the caption “How We Have Financed Our Activities”.
The independent registered public accounting firm’s report on our financial statements as of and for the year ended December 31, 2005 includes an explanatory paragraph which states that we have sustained substantial losses in 2005 and 2004 and have a working capital deficiency and an accumulated deficit at December 31, 2005, that raise substantial doubt about our ability to continue as a going concern.
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A Comparison of Operating Results For The Three Months Ended March 31, 2006 and March 31, 2005
We incurred a net loss of $711,000 during the three months ended March 31, 2006 compared to a net loss of $1,495,000 for the three months ended March 31, 2005. During the three months ended March 31, 2006, our revenues were comprised of oil and gas sales and operations income totaling $587,000 compared with oil and gas sales and operations income of $836,000 during the same period of 2005. Our oil and gas sales and operations income for the three months ended March 31, 2006 were lower as a result of decreased production which was partially offset by higher oil and gas prices. Our net average daily production for the three-month period ended March 31, 2006 decreased by 45% over the same period of the prior year, from 651 (180 net) barrels of oil equivalent per day to 488 (100 net) barrels of oil equivalent per day. Oil and gas sales were favorably affected by higher average realized prices, which increased by 30%, from an average of $47.16 per barrel of oil equivalent for the three months ended March 31, 2005 to $61.21 per barrel of oil equivalent for the three months ended March 31, 2006. Production from our existing wells is subject to fluctuation from time to time based upon the zones of the wells where we are obtaining production.
Our total expenses were $1,298,000 for the three months ended March 31, 2006 compared to $2,331,000 for the three months ended March 31, 2005. Our general and administrative expenses during the three months ended March 31, 2006 were $532,000 compared to $422,000 during the three months ended March 31, 2005. These expenses increased in 2006 largely because of an increase in professional services provided us during 2006 compared to 2005.
Interest and financing costs decreased from $1,330,000 for the three months ended March 31, 2005 to $320,000 for the three months ended March 31, 2006. While debt outstanding was higher at March 31, 2006 compared to the same period for 2005, interest expense decreased as a result of amending our Debentures. Prior to the amendment, interest expense reflected the amortization of a beneficial conversion feature related to the issuance in October 2003 of our 8% Convertible Debentures. On the dates the Debenture transaction was completed, the closing price for our Common Stock was $0.70 per share. Because the conversion price was less than the market price on the dates the transaction was completed, a beneficial conversion feature of $6.7 million was attributed to the Debentures. An additional beneficial conversion feature of $858,000 was recorded in the third quarter of 2004 resulting from issuance of shares of our common stock pursuant to a Rights Offering. Due to antidilution provisions contained in the Debenture Agreement, the issuance of shares of common stock changed the conversion price of the debentures from $0.45 to $0.43 per share resulting in the additional beneficial conversion feature. Such amount was amortized to interest expense over the life of the Debentures prior to the amendment. In June 2005, the Debentures were amended with approval by approximately 86% of the Debentureholders. The amendments extended the maturity date of the Debentures by one year to September 30, 2006, reduced through the maturity date of the Debentures the per share price at which the principal of the Debentures could be converted into shares of Common Stock to $0.15 per share, and provided for the partial release of the lien collateralizing the Debentures in the event a third party entered into an agreement with us pursuant to which the
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third party is granted the right to drill one or more wells on our properties and commenced that drilling activity.
Under the amendments, 74,500,000 shares may be issued upon full conversion of the Debentures at the reduced conversion price. On June 23, 2005, our stockholders voted to amend the Certificate of Incorporation to increase the number of shares of Common Stock we are authorized to issue from 100 million to 250 million and adjust the par value from $0.01 to $0.001 per share. This increase in authorized shares, along with the approval of the TSX Venture Exchange to the transactions, provided final approval of the Debenture amendments. As a result of the amendment, a loss on extinguishment of debt of $1,147,000 was recognized and the Debentures were recorded on June 23, 2005 at their fair market value, reflecting the present value of future cash flows and the option value of the underlying convertible shares. Costs associated with the amendment totalling $303,000 are being amortized to interest expense over the remaining life of the Debentures.
Lease operating expenses of $109,000, production taxes of $37,000 and depletion, depreciation and amortization of $316,000 during the three months ended March 31, 2006 changed from $121,000, $66,000, and $497,000, respectively, during the three months ended March 31, 2005. Lease operating expenses remained consistent. Production taxes decreased as a result of lower production. The decrease in depletion, depreciation and amortization is due to higher reserves and lower production in the first quarter of 2006 compared to the same period of 2005 which results in a lower per unit rate of depletion.
During the three months ended March 31, 2006, we had a foreign exchange gain of $15,000, compared to a foreign exchange gain of $104,000 for the three months ended March 31, 2005. The foreign exchange gain recognized during the three months ended March 31, 2006 and 2005 was caused by the strengthening of the US dollar against the Canadian dollar.
Liquidity and Capital Resources
A Comparison of Cash Flow For The Three Months Ended March 31, 2006 and March 31, 2005
Our net cash provided by operating activities was $568,000 for the three months ended March 31, 2006 as compared to net cash provided by operating activities of $591,000 for the three months ended March 31, 2005, a decrease of $23,000. Changes in working capital items had the effect of increasing cash flows from operating activities by $912,000 and $508,000 during the three months ended March 31, 2006 and 2005, respectively, because accounts receivable turnover exceeded that of accounts payable, revenues payable and accrued liabilities.
We used $457,000 of cash in investing activities during the three months ended March 31, 2006 compared to net cash used of $905,000 in 2005. The 2005 cash used in investing activities includes $879,000 for the purchase and development of oil and gas properties and $26,000 for the purchase of fixed assets compared to $614,000 and $6,000, respectively, in 2006.
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Additionally in the first quarter of 2006, we had proceeds from the sale of participation rights of $163,000. The expenditures in 2006 are primarily the result of the change in accounts payable resulting from the development of oil and gas properties in prior periods. The 2005 expenditures are primarily a result of recompletions of wells drilled in prior periods.
We used $295,000 of net cash in financing activities for the three months ended March 31, 2006 compared to $92,000 of net cash provided by financing activities for the same period in 2005. For the three months ended March 31, 2006, net cash outflows from financing activities was primarily a result of payment of notes. Cash inflows provided by financing activities during the three months ended March 31, 2005 were primarily a result of a short-term bank loan in the amount of $100,000, partially offset by scheduled payments on certain of our obligations.
A decline in production from our drilling program has decreased revenues during the year ended December 31, 2005 and the first three months of 2006. To date, our production has not been sufficient to fund our operations and drilling program. We have funded our capital expenditures and operating activities through a series of private and public debt and equity transactions and through an increase in vendor payables and note payables. At March 31, 2006, we do not have any available borrowing capacity.
We have substantial needs for funds to develop our oil and gas prospects and opportunities identified in the AMI we share with ExxonMobil Corp. Any capital expenditures we currently intend to make will be funded from our available cash flows. To the extent additional funds are required to fully exploit and develop our unproved properties and the ExxonMobil Corp. AMI, it is management’s plan to raise additional capital through the private or public sale of our equity securities, borrowings, or the sale of interests in our drilling activities; however, we currently have no firm commitment from any potential investors and such additional capital may not be available to us in the future.
At March 31, 2006, we have no other commitments to expend additional funds for drilling activities for the rest of 2006.
How We Have Financed Our Activities
Our activities since 2002 have been financed primarily from sales of debt and equity securities and drilling participations.
On October 21, 2003 and October 31, 2003, we completed financing transactions of $11.695 million and $305,000, respectively, by issuing our Convertible Secured Debentures (the “Debentures”). Initially, the Debentures were repayable on September 30, 2005 with interest payable quarterly commencing December 31, 2003 at 8% per annum. At the dates of issuance, the outstanding principal of the Debentures was convertible by the holders into our common shares at any time prior to maturity at a conversion price of $0.45 per share, subject to antidilution adjustment. The Debentures are redeemable by us at any time after October 1, 2004 if the weighted average price per share of our common stock on the TSX Venture Exchange for a
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20 consecutive trading day period prior to the date notice of redemption is given has exceeded 166 2/3% of the conversion price. The Debentures are collateralized by substantially all of our assets. The Debentures have covenants limiting unsecured borrowings to $2 million and restricting the payment of dividends and capital distributions. A finder’s fee in the amount of $360,000 was paid to Middlemarch Partners Limited of London, England in connection with the financing.
In June 2005, the Debentures were amended with approval by approximately 86% of the Debentureholders. The amendments extended the maturity date of the Debentures by one year to September 30, 2006, reduced through the maturity date of the Debentures the per share price at which the principal of the Debentures could be converted into shares of common stock to $0.15 per share, and provided for the partial release of the lien collateralizing the Debentures in the event a third party entered into an agreement with us pursuant to which the third party is granted the right to drill one or more wells on our properties and commenced that drilling activity. Under the amendments, 74,500,000 shares of our common stock may be issued upon full conversion of the Debentures at the reduced conversion price. On June 23, 2005, our stockholders voted to amend our Certificate of Incorporation to increase the number of shares of common stock we are authorized to issue from 100 million shares to 250 million shares and reduced the par value from $0.01 to $0.001 per share. This increase in authorized shares, along with the approval of the TSX Venture Exchange to the transactions, provided final approval of the Debenture amendments.
Out of the proceeds from the sale of the Debentures in 2003, we used approximately $5.9 million for the repayment of secured debt, approximately $2.1 million for the payment of accounts payable and used the balance primarily for exploration and development of our Bayou Couba oil and gas leases within the ExxonMobil Joint Development Project in St. Charles Parish, Louisiana. In addition, we paid out of the proceeds a $1.7 million production payment owing to TransAtlantic. TransAtlantic retained a 10% participation right in our AMI with ExxonMobil which we granted in March 2003 as partial consideration for the $2.0 million financing entered into at that time. On both October 21 and 31, 2003, the dates the transaction was completed, the closing sale prices for our shares were $0.70 on the TSX Venture Exchange.
Purchasers of the Debentures included TransAtlantic, $3.0 million principal amount, and Quest Capital Corp., $500,000 principal amount. Mr. Brian Bayley, who has been a Director of our company since June 2001, is also President and Chief Executive Officer of Quest Capital Corp. and a Director of TransAtlantic. Quest Capital Corp. is engaged in merchant banking activities in Canada and elsewhere which includes providing financial services to small and mid-cap companies operating primarily in North America. Quest Investment Corporation is a predecessor company of Quest Capital Corp.
In connection with the Debenture financing and under the terms of the transaction, two persons were designated to serve as Directors of our company. Pursuant to these terms, Mr. Jules Poscente, Chairman and Director of Eurogas Corp. of Calgary, Alberta and Gerry Curtis of Bermuda were elected to our Board of Directors. Mr. Curtis died March 24, 2006 and a successor director has not been named.
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In August 2004, we completed the sale, pursuant to the issuance of stock purchase rights to all our stockholders, of 6,941,414 shares of our common stock for gross proceeds of $1,665,939. After deducting the expenses of the offering, $1,433,287 of the net proceeds was applied to our oil and natural gas well drilling activities, including the re-drilling of the ExxonMobil Fee 2 well.
During the third quarter of 2005, we completed a private sale of 12,193,333 shares of our common stock for gross proceeds of $1,463,000 ($1,428,000 net). Additionally, 2,170,000 shares were issued as payment for professional services in the amount of $250,000 relating to restructuring of our Debentures. The net proceeds were used for working capital and the drilling of 3 wells.
On October 19, 2005 we executed the definitive Exploration and Development Agreement (the “Agreement”) with Dune Energy, providing for the creation of an area of mutual interest covering an area of approximately 31,367 acres. A preliminary agreement which provided for the execution of a definitive agreement was entered into on September 12, 2005.
Pursuant to the terms of the Agreement, Dune Energy agreed to pay us a prospect fee in the amount of $1.0 million, of which $225,000 was paid on September 14, 2005, $225,000 was paid on September 30, 2005, $225,000 was paid on October 19, 2005, $162,500 was paid on November 30, 2005 and $162,500 was paid on January 10, 2006. In the event we and Dune Energy elect to complete the first two exploratory wells drilled pursuant to the Agreement, upon the receipt by Dune Energy of a log from either of those two wells, Dune Energy will pay to us an additional prospect fee of $500,000.
The area of mutual interest created by the Agreement, in which we have agreed with Dune Energy to share all rights, title and interest owned or acquired on an equal basis, includes our Bayou Cuba lease acreage of approximately 1,319 acres, the acreage covered by our development agreement with ExxonMobil of approximately 11,486 acres which are included in the 31,367 acre area, as well as any additional acreage offered to us or Dune Energy by ExxonMobil as the result of the acquisition of additional 3-D seismic data by the parties under the terms of the Agreement. If either party acquires any interests in lands included in the area of mutual interest created by the Agreement, the acquiring party is required to notify the non-acquiring party which will have the opportunity to participate in the acquisition by paying its proportionate share of the price for such properties.
Under the terms of the Agreement, we agreed to share with Dune Energy our 3-D seismic data covering an area of approximately 23.138 square miles within the area of mutual interest. We agreed with Dune Energy to initiate discussions with ExxonMobil to acquire additional 3-D seismic data with each party to pay equally for the cost of acquiring the data. The Agreement provides that either party can propose drilling prospects with the non-proposing party given the right to participate in the drilling prospect and pay its proportionate share of all drilling and completion costs. We will be the operator of each drilling prospect and completed well, subject to the rights of ExxonMobil under its development agreement with us. The Agreement will remain in effect so long as our development agreement with ExxonMobil remains in effect. The Agreement excludes certain specified existing wells which we own, certain of our litigation
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rights, and our production facility and equipment and personal property. Our interest in the area of mutual interest created by the Agreement is subject to the terms of other agreements to which we are a party.
During the year ended December 31, 2005, we converted an aggregate of approximately $1.74 million of accounts payable and other current obligations into notes payable. At December 31, 2005, $1.39 million principal amount of such notes were outstanding, of which $1.25 million is due on various dates through December 31, 2006 and the balance is due on various dates through June 2007.
Future Capital Requirements and Resources
Since 2001, we have funded our capital expenditures and operating activities through a series of debt and equity capital-raising transactions, drilling participations and, during the last two quarters of 2004 and all of 2005, through an increase in vendor payables and notes payable. At March 31, 2006, we do not have any available borrowing capacity under existing credit facilities and our current assets are $618,000 compared with current liabilities of $19.7 million. Our current liabilities include approximately $11.2 million of secured indebtedness, including the related fully amortized discount, due in September 2006 and accounts payable, revenues payable, notes payable, and other current obligations aggregating to approximately $8.7 million. We have substantial needs for funds to pay our outstanding payables and debt due during 2006. In addition, we have substantial need for capital to develop our oil and gas prospects and opportunities identified in our ExxonMobil AMI. Any capital expenditures for drilling purposes during 2006 we expect will be funded from the sale of drilling participations and equity capital. It is management’s plan to raise additional capital through the sale of interests in our drilling activities or other strategic transaction; however, we currently have no firm commitment from any potential investors and such additional capital may not be available to us in the future.
At March 31, 2006, we have no commitments for additional capital to fund drilling activities during 2006. Any capital expenditures will be funded from monies raised through industry participations, or, if available, borrowings or equity capital. We currently have no borrowing capacity with any lender and no firm commitment from any potential investors and such additional capital may not be available to us in the future.
Our business strategy requires us to obtain additional financing and our failure to do so can be expected to adversely affect our ability to further the development of our ExxonMobil AMI, grow our revenues, oil and gas reserves and achieve and maintain a significant level of revenues and profitability. There can be no assurance we will obtain this additional funding. Such funding may be obtained through the sale of drilling participations, joint ventures, equity securities or by incurring additional indebtedness. Without such funding, our revenues will continue to be limited and it can be expected that our operations will not be profitable. In addition, any additional equity funding that we obtain may result in material dilution to the current holders of our common stock.
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We intend, as opportunities arise, to evaluate the acquisition and development of additional leasehold interests. We are unable at this time to state whether or where any such additional properties may be acquired, to estimate the purchase price for any properties we may acquire or to state the terms on which financing for these purposes can be obtained.
New Accounting Standards
In February 2006, the Financial Accounting Standards Board (“FASB”) issued Statement of Financial Accounting Standards No. 155,Accounting for Certain Hybrid Financial Instruments — an amendment of FASB Statements No. 133 and 140 (“SFAS No. 155”).SFAS No. 155 permits fair value remeasurement for any hybrid financial instrument that contains an embedded derivative that otherwise would require bifurcation and clarifies several other related issues. The provisions of SFAS No. 155 are effective for all financial instruments acquired or issued in the first fiscal year beginning after September 15, 2006. We have not evaluated what impact, if any, this standard will have on our financial position or results of operations.
Cautionary Statement for Purposes of the “Safe Harbor” Provisions of the Private Securities Litigation Reform Act of 1995
With the exception of historical matters, the matters we discussed below and elsewhere in this Report are “forward-looking statements” as defined under the Securities Exchange Act of 1934, as amended that involve risks and uncertainties. The forward-looking statements appear in various places including under the headings Item 1. Financial Information and Item 2. Management’s Discussion and Analysis or Plan of Operation. These risks and uncertainties relate to our ability to repay or extend the maturity of our Debentures in September 2006, our ability to raise capital and fund our oil and gas well drilling and development plans, our ability to fund the repayment of our current liabilities, and our ability to attain and maintain profitability and cash flow and continue as a going concern, our ability to increase our reserves of oil and gas through successful drilling activities and acquisitions, our ability to enhance and maintain production from existing wells and successfully develop additional producing wells, our access to debt and equity capital and the availability of joint venture development arrangements, our ability to remain in compliance with the terms of any agreements pursuant to which we borrow money and to repay the principal and interest when due, our estimates as to our needs for additional capital and the times at which additional capital will be required, our expectations as to our sources for this capital and funds, our ability to successfully implement our business strategy, our ability to identify and integrate successfully any additional producing oil and gas properties we acquire and operate such properties profitably, our ability to maintain compliance with covenants of our loan documents and other agreements pursuant to which we issue securities or borrow funds and to obtain waivers and amendments when and as required, our ability to borrow funds or maintain levels of borrowing availability under our borrowing arrangements, our ability to meet our intended capital expenditures, our statements and estimates about quantities of production of oil and gas as it implies continuing production rates at those
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levels, proved reserves or borrowing availability based on proved reserves and our future net cash flows and their present value.
Readers are cautioned that the risk factors described in our Annual Report on Form 10-KSB for the year ended December 31, 2005 and other reports filed with the Commission, as well as those described elsewhere in this Report, in some cases have affected, and in the future could affect, our business plans and actual results of operations and could cause our actual consolidated results during 2006 and beyond, to differ materially from those expressed in any forward-looking statements made by or on our behalf.
Our common shares have no trading market in the United States, and there can be no assurance as to the liquidity of any markets that may develop for our common shares, the ability of the holders of common shares to sell their common shares in the United States or the price at which holders would be able to sell their common shares. Any future trading prices of the common shares will depend on many factors, including, among others, our operating results and the market for similar securities.
ITEM 3. CONTROLS AND PROCEDURES
Under the supervision and with the participation of our management, including Michael K. Paulk, our President, and Steven P. Ensz, our Vice President, Finance, we have evaluated our disclosure controls and procedures as of the end of the period covered by this report, and, based on their evaluation, Mr. Paulk and Mr. Ensz have concluded that these controls and procedures are effective. There were no changes in our internal controls over financial reporting during the quarter ended March 31, 2006 that has materially affected, or is reasonably likely to materially affect, the company’s internal control over financial reporting.
Disclosure controls and procedures are our controls and other procedures that are designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act are recorded, processed, summarized and reported, within the time periods specified in the Securities and Exchange Commission’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including Mr. Paulk and Mr. Ensz, as appropriate, to allow timely decisions regarding required disclosure.
PART II — OTHER INFORMATION
Item 6. Exhibits
31.1 | Certification of President and Chief Executive Officer Pursuant to Rule 13a-14(a)(1) |
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31.2 | Certification of Chief Financial Officer Pursuant to Rule 13a- 14(a)(1) | ||
32.1 | Certification of President and Chief Executive Officer Pursuant to Section 1350 (furnished, not filed)(1) | ||
32.2 | Certification of Chief Financial Officer Pursuant to Section 1350 (furnished, not filed)(1) |
(1) | Filed or furnished herewith. |
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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934 the Registrant has duly caused this Report to be signed on its behalf by the undersigned thereunto duly authorized.
AMERICAN NATURAL ENERGY CORPORATION | ||||
(Registrant) | ||||
Date: May 17, 2006 | /S/ Michael K. Paulk | |||
Michael K. Paulk | ||||
President and Chief Executive Officer | ||||
/S/ Steven P. Ensz | ||||
Steven P. Ensz | ||||
Principal Financial and Accounting Officer |
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