0000912057-01-535388.txt : 20011019 0000912057-01-535388.hdr.sgml : 20011019 ACCESSION NUMBER: 0000912057-01-535388 CONFORMED SUBMISSION TYPE: 10-K PUBLIC DOCUMENT COUNT: 1 CONFORMED PERIOD OF REPORT: 20010630 FILED AS OF DATE: 20011015 FILER: COMPANY DATA: COMPANY CONFORMED NAME: AMERICAN ENERGY GROUP LTD CENTRAL INDEX KEY: 0000843212 STANDARD INDUSTRIAL CLASSIFICATION: CRUDE PETROLEUM & NATURAL GAS [1311] IRS NUMBER: 870448843 STATE OF INCORPORATION: NV FISCAL YEAR END: 0630 FILING VALUES: FORM TYPE: 10-K SEC ACT: 1934 Act SEC FILE NUMBER: 000-26402 FILM NUMBER: 1758802 BUSINESS ADDRESS: STREET 1: P O BOX 489 STREET 2: 1861 BROWN BLVD,STE 655 CITY: SIMONTON STATE: TX ZIP: 77476 BUSINESS PHONE: 2813462652 MAIL ADDRESS: STREET 1: PO BOX 489 CITY: SIMONTON STATE: TX ZIP: 77476 FORMER COMPANY: FORMER CONFORMED NAME: BELIZE AMERICAN CORP INTERNATIONALE DATE OF NAME CHANGE: 19941004 FORMER COMPANY: FORMER CONFORMED NAME: DIM INC DATE OF NAME CHANGE: 19920703 10-K 1 a2061084z10-k.txt 10-K UNITED STATES SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D.C. 20549 FORM 10-K ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the fiscal year ended June 30, 2001 Commission file number: 0-26402 THE AMERICAN ENERGY GROUP, LTD. (Exact name of Registrant as specified in its charter) Nevada 87-0448843 (State or other jurisdiction of (I.R.S. Employer incorporation or organization) Identification No.) 9441 Sam Houston Parkway Suite 110 Houston, Texas 77099 (Address of principal executive offices) (Zip code) 713-981-6114 (Registrant's telephone number including area code) --------------------------- Securities registered pursuant to Section 12(b) of the Act: None Securities registered pursuant to section 12(g) of the Act: Common Stock, Par Value $.001 Per Share --------------------------- Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes _X_ No ___ Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will no be contained, to the best of registrant's knowledge, is definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or in any amendment of this Form 10-K. [ ] The aggregate market value of the voting stock held by non-affiliates of the Registrant at October 10, 2001, was $8,551,538 (based on a value of $0.14 per share, the closing price of the Common stock as quoted on the NASD OTC market on such date). 61,082,415 shares of Common Stock, par value $.001 per share, were outstanding on October 10, 2001. THE AMERICAN ENERGY GROUP, LTD. INDEX TO FORM 10-K PART 1 Items 1 and 2. Business and Properties......................................... Item 3. Legal Proceedings............................................... Item 4. Submission of Matters to a Vote of Security Holders............. PART II Item 5. Market of Our Common Stock and Related Stockholder Matters...... Item 6. Selected Consolidated Financial Data............................ Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations....................................... Item 7A. Quantitative and Qualitative Disclosures About Market Risk...... Item 8. Financial Statements and Supplementary Data..................... Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure........................................ PART III Item 10. Directors and Executive Officers of the Registrant.............. Item 11. Executive Compensation.......................................... Item 12. Security Ownership of Certain Beneficial Owners and Management.. Item 13. Certain Relationships and Related Transactions.................. PART IV Item 14. Exhibits, Financial Statement Schedules, and Reports on Form 8-K........................................................ SIGNATURES...................................................................... In this report, the "Company", "we", "us" and "our" collectively refers to The American Energy Group, Ltd. and its wholly-owned subsidiaries. -------------------------------------------------------------------------------- SPECIAL NOTE ON FORWARD-LOOKING STATEMENTS -------------------------------------------------------------------------------- This report contains statements about the future, sometimes referred to as "forward-looking" statements. Forward-looking statements are typically identified by the use of the words "believe," "may," "will," "should," "expect," "anticipate," "estimate," "project," "propose," "plan," "intend" and similar words and expressions. We intend the forward-looking statements to be covered by the safe harbor provisions for forward-looking statements contained in Section 27A of the Securities Act and Section 21E of the Exchange Act. Statements that describe our future strategic plans, goals or objectives are also forward-looking statements. Readers of this report are cautioned that any forward-looking statements, including those regarding the Company or its management's current beliefs, expectations, anticipations, estimations, projections, proposals, plans or intentions, are not guarantees of future performance or results of events and involve risks and uncertainties, such as: - The future results of drilling individual wells and other exploration and development activities; - Future variations in well performance as compared to initial test data; - Future events that may result in the need for additional capital; - Fluctuations in prices for oil and gas; - Future drilling and other exploration schedules and sequences for various wells and other activities; - Uncertainties regarding future political, economic, regulatory, fiscal, taxation and other policies in Pakistan; and - Our future ability to raise working capital through equity placement, loans or strategic ventures to spread the costs of exploration, development and acquisition activities; and The forward-looking information is based on present circumstances and on our predictions respecting events that have not occurred, which may not occur or which may occur with different consequences from those now assumed or anticipated. Actual events or results may differ materially from those discussed in the forward-looking statements as a result of various factors, including the risk factors detailed in this report. The forward-looking statements included in this report are made only as of the date of this report. We are not obligated to update such forward-looking statements to reflect subsequent event or circumstances. PART I ITEMS 1. AND 2. BUSINESS AND PROPERTIES GENERAL AND HISTORICAL INFORMATION The American Energy Group, Ltd. (formerly Belize-American Corp. Internationale) (formerly Dim, Inc.)[hereinafter "Company"] was organized in the State of Nevada on July 21, 1987, as a wholly owned subsidiary of Dimension Industries, Inc. a Utah Corporation (hereinafter "Dimension"). At the time of organization, we issued 1,366,250 shares of voting Common Stock to Dimension, which was the sole stockholder. On April 28, 1989, our form S-18 filed with the Securities and Exchange Commission was declared effective. Dimension distributed the 1,366,250 shares it held to the stockholders of Dimension as a dividend. Also distributed were 1,566,250 warrants to purchase 1 share of voting Common Stock of the Company for each warrant held. The warrant offering expired on August 11, 1989. Exercise of the warrants by shareholders resulted in our issuing 1,547,872 shares of voting Common Stock. In 1987, we engaged in marketing an automobile carburetor modification kit. The efforts were not successful and were abandoned. From 1987 to 1990, we were inactive. In October, 1990, the shareholders approved a one for ten (1:10) reverse split of the voting Common Stock. In June, 1991, we obtained an Oil Prospecting License from the government of Belize. As a special meeting of shareholders, resolutions to change the name of the Company to "Belize-American Corp. Internationale", forward split the voting Common Stock ten for one (10:1) and a vote to ratify the Oil Prospecting License received a vote of approval. During 1991, we attempted various means to attract sufficient capital investment to develop the oil prospect in Belize, but was not successful. The license expired due to our lack of performance. From 1992 until 1994, our activities consisted of attempting to raise capital for a business venture and solicitation of other business enterprises for a possible merger. On September 22, 1994, we entered into an agreement with Simmons Oil Company, Inc., a Texas corporation (hereinafter "Simmons") whereby we issued 2,074,521 shares of Convertible Voting Preferred Stock to the shareholders of Simmons in order to acquire Simmons and two subsidiaries of Simmons, Simmons Drilling Company and Sequoia Operating Company. The agreement was effective September 30, 1994. Prior to the acquisition of Simmons, Simmons had acquired certain oil and gas properties located in Texas. Subsequent to the acquisition, we acquired additional oil and gas properties in the same general area through its subsidiaries. In April 1995, we acquired all of the outstanding shares of Hycarbex, Inc., a Texas corporation (hereinafter "Hycarbex") which that month had been awarded an oil and gas Concession comprised of approximately one million acres located in the Middle Indus Basis near Jacobabad, Pakistan,for 120,000 shares of our voting Common Stock, a 1% Overriding Royalty Interest in the revenues generated through the development of Hycarbex's Pakistan Concession, and an agreement to pay the sole shareholder $200,000 conditioned upon the success of that development. For accounting purposes, this acquisition was treated as a pooling of interests. We changed the name of Hycarbex, Inc. to Hycarbex-American Energy, Inc. and it is operating as our wholly owned subsidiary. In addition to the above acquisition consideration, we provided a $551,000 Financial Guarantee Bond to the Government of Pakistan to assure performance of Concession requirements. Under the terms of the Concession, the Pakistan Government retained a 5% interest in the Concession which was to be increased to 25% as to each well in which there was a commercial discovery. We performed subsequent seismic surveys and commenced the drilling of our first well, the Kharnak # 1 in calendar 1997. The initial well, while generating valuable geologic data, was unsuccessful. In early 1999, we commenced our second well, the David # 1, and abandoned the well prior to reaching target depth because of mechanical difficulties. A new well, the David # 1A was commenced in the vicinity within weeks of abandonment and this well was plugged and abandoned when dangerous levels of hydrogen sulfide gas were encountered. We performed additional seismic on the Concession in calendar 2000, after a drilling extension from the Pakistan Government, and commenced the third full well, the Jacobabad #3 in the latter part of calendar 2000. This well was plugged and abandoned as a noncommercial well in January, 2001. We further refined our geologic models using this additional seismic and the data obtained from the Jacobabad #3. Immediately prior to the end of the current fiscal year, the Jacobabad Concession was relinquished to the Pakistan Government in favor of a new concession, the Yasin Concession, which was awarded to us shortly after the end of the fiscal year. The Yasin Concession contains approximately 1,200 square kilometers and provides for the same drilling and financial terms as the Jacobabad Concession. The Yasin Concession contains acreage originally covered by the Jacobabad Concession which we viewed as desirable for its exploration potential. We began producing commercial quantities of oil on its Texas-based properties and emerged from the development stage during the year ended June 30, 1997. At that time, we were engaged in a program of drilling and reworking active and inactive developmental wells situated on the properties at the time of our acquisition. In June, 1997, we purchased oil and gas properties totaling approximately 1,400 acres in Texas. During the year ended June 30, 1999, we drilled eight developmental wells on these properties, of which seven wells are currently producing. One additional commercial well was completed in Texas after June 30, 1999, while the reactivation and reworking program continued at a very modest rate due to working capital considerations. Subsequent to the end of the current fiscal year, an additional producing well has been drilled and is currently being tested for other potential productive zones. OIL AND GAS DISCLOSURES RESERVES REPORTED TO OTHER AGENCIES No reserve estimates of proven net oil and gas reserves were filed with any other regulatory agency. PRODUCTION As of June 30, 2001, 2000 and 1999, the Company received oil revenues from 32, 22 and 14 wells, respectively. All of these wells produced oil only. There were no sales of natural gas during these periods.
2001 2000 1999 ---- ---- ---- Gross revenue from oil sales 1,806,335 1,823,276 417,136 Net barrels produced during the period 62,060 73,195 32,272 Average price received for sales oil, $/bbl 29.11 24.91 12.93 Average lifting costs, $/bbl 7.88 4.76 5.08
PRODUCTIVE WELLS AND ACREAGE Set forth below is a tabulation of productive oil wells owned by the Company as of June 30, 2001, 2000 and 1999. This summary includes oil wells which may currently be shut in and awaiting recompletion in order to restore commercial productivity. The Company has not had a commercially productive gas well since 1996. All of these wells are located on the Company's Texas properties.
2001 2000 1999 ---- ---- ---- Productive wells -- gross 108 108 105 Productive wells -- net 108 108 105 DEVELOPED ACREAGE 2001 2000 1999 ---- ---- ---- Texas (United States cost center) -- gross 152 152 172 Texas (United States cost center) -- net 152 152 147 Pakistan -- gross 0 0 0 Pakistan -- net 0 0 0 UNDEVELOPED ACREAGE 2001 2000 1999 ---- ---- ---- Texas (United States cost center) -- gross 2,372 2,372 2,372 Texas (United States cost center) -- net 2,372 2,372 2,372 Pakistan -- gross 1,000,000 1,000,000 1,000,000 Pakistan -- net 950,000 950,000 950,000
DRILLING ACTIVITY Set forth below is a tabulation of wells (gross and net wells reflecting the ratio of working interest ownership owned by the Company vs. 100% working interest in each well) completed during the years ended June 30, 2001, 2000 and 1999 in which the Company has participated and the results thereof for each of the three years.
2001 2000 1999 ---- ---- ---- GROSS NET GROSS NET GROSS NET ----------------- ----------------- ------------------ Dry 1 1 0 0 0 0 Oil 0 0 8 8 8 7 Gas 0 0 0 0 0 0 ----------------- ----------------- ------------------ Totals 1 1 8 8 8 7 ================= ================= ==================
OIL AND GAS RESERVES The Company did not report reserves to any other agency of the U. S. government. The Company's proved reserves and PV-10 Value from its U.S. proved developed and undeveloped oil and gas properties have been estimated by Sigma Energy Corporation in Houston, Texas. The Company's Pakistan Probable Recoverable Reserves and PV-10 Value from its Pakistan undeveloped gas properties have been estimated by Martin Petroleum and Associates in Calgary, Alberta, Canada. The estimates of these independent petroleum engineering firms were based upon review of production histories and other geologic economic, ownership and engineering data provided by the Company. In accordance with SEC guidelines, the Company's estimates of future net revenue from the Company's proved and probable reserves and the present value thereof are made on the basis of oil and gas sales prices in effect as of the dates of such estimates and are held constant throughout the life of the properties, except where such guidelines permit alternate treatment. Future net revenues at June 30, 2001 on the Company's U.S. properties reflect a weighted average price of $25.58 per BOE vs. $23.00 in its June 30, 2000 estimates. The proved developed and undeveloped oil and gas reserve figures presented in this report are estimates based on reserve reports prepared by independent petroleum engineers. The estimation of reserves requires substantial judgment on the part of the petroleum engineers, resulting in imprecise determinations particularly with respect to new discoveries. Estimates of reserves and of future net revenues prepared by different petroleum engineers may vary substantially, depending, in part, on the assumptions made and may be subject to material adjustment. Estimates of proved undeveloped reserves, which comprise a substantial portion of the Company's reserves, are, by their nature, much less certain than proved developed reserves. The accuracy of any reserve estimate depends on the quality of available data as well as engineering and geological interpretation and judgment. Results of drilling, testing and production or price changes for produced hydrocarbons subsequent to the date of the estimate may result in changes to such estimates. The estimates of future net revenues in this report reflect oil and gas prices and production costs as of the date of estimation, without escalation, except where changes in prices were escalated under the terms of existing contracts. There can be no assurance that such prices will be real or that the estimated production volumes will be produced during the period specified in such reports. Since June 30, 1998, (the date of the Pakistan estimate) oil and gas prices have fluctuated significantly. The estimated reserves and future net revenues may be subject to material downward or upward revision based upon production history, results of future development, prevailing oil and gas prices and other factors. A material change in estimated proved reserves or future net revenues could have a material effect on the Company. UNITED STATES RESERVE ESTIMATES The following tables present total proved developed and proved undeveloped reserve volumes as of June 30, 2001, and June 30, 2000, and estimates of the future net revenues and PV-10 Value there from. There can be no assurance that the estimates are accurate predictions of future net revenues from oil reserves or their present value. ESTIMATED NET PROVED OIL RESERVES -- UNITED STATES PROPERTIES:
As of June 30 As of June 30 2001 2000 Proved Developed, Bbls 301,480 426,910 Proved Shut In, Bbls 181,766 275,600 Proved Undeveloped, Bbls 2,132,331 2,297,918 Total Estimated Proved Oil Reserves, Bbls 2,615,577 3,000,428
ESTIMATED FUTURE NET REVENUES -- UNITED STATES PROPERTIES: The present value of future net revenues (using discount factor of 10 percent per annum) before income taxes for the Company's proved developed and proved undeveloped oil reserves as of June 30, 2001 and 2000 are as follows:
As of June 30 As of June 30 2001 2000 Proved Developed PV-10, $ 3,271,165 5,081,728 Proved Shut In PV-10, $ 2,913,577 5,087,524 Proved Undeveloped PV-10, $ 18,261,372 30,745,768 Total 24,446,114 40,915,020
"Proved developed" oil and gas reserves are reserves that can be expected to be recovered from existing wells with existing equipment and operating methods. "Proved undeveloped" oil and gas reserves are reserves that are expected to be recovered from new wells on undrilled acreage, or from existing, wells where relatively major expenditures are required for recompletion. In recent years, the market for oil and gas has experienced substantial fluctuations, which have resulted in significant swings in the prices for oil and gas. The Company cannot predict the future of oil and gas prices or whether a future decline in prices will occur. Any such decline would have an adverse effect on the Company. PAKISTAN RESERVE ESTIMATES As previously reported and filed in a Form 8-K dated September 22, 1998, the Company retained Martin Petroleum and Associates to perform a preliminary reserve study on its Jacobabad Concession in the Middle Indus basin in central Pakistan. These reserves are not categorized as proven. Further, these reserves remain categorized by the company as unproven. However, management has determined that the independent estimates of Probable Recoverable Reserves in the preliminary reserve study represent material information which merited disclosure to the shareholders. These independent estimates also served as justification to management to continue further exploratory drilling on its Pakistan Concession and justification to management to bid for and obtain subsequent to year-end the Yasin Block Concession which is comprised of portions of the Jacobabad Concession acreage. CAUTIONARY NOTE REGARDING RESERVE ESTIMATES The estimation of reserves requires substantial judgment on the part of the petroleum engineers, resulting in imprecise determinations particularly with respect to new discoveries. Estimates of reserves and of future net revenues prepared by different petroleum engineers may vary substantially, depending, in part, on the assumptions made, and may be subject to material adjustment. Estimates of probable undeveloped reserves, which are a substantial portion of the Company's reserves, are, by their nature, much less certain than proved developed reserves. The accuracy of any reserve estimate depends on the quality of available data as well as engineering and geological interpretation and judgment. Results of drilling, testing and production or price changes subsequent to the date of the estimate may result in changes to such estimates. MARKET FACTORS AND EFFECTS OF COMPETITION AND REGULATION COMPETITION The oil and gas business is highly competitive in every phase. We compete with numerous companies and individuals in our exploration and production activities. Many on these competitors have far greater financial and technical resources with established multi-national operations. As a result, unless we obtain additional capital investment and /or join in partnerships and joint ventures, we may be prevented from participating in large drilling and acquisition programs. Since we are smaller and have limited resources in comparison to many of our competitors, our ability to compete for oil and gas properties is also limited. STATE AND LOCAL REGULATIONS: The various states have established statutes and regulations requiring permits for drilling, drilling bonds to cover plugging contingencies, and reporting requirements on drilling and production activities. Activities such as well location, method of drilling and casing wells, surface use and restoration, plugging and abandonment, well density, and other matters are all regulated by a governing body. Texas, the state in which we operate, has rules and regulations covering all of these matters. It also has regulations addressing a number of environmental and conservation matters, including the unitization and pooling of oil and gas properties. ENVIRONMENTAL REGULATIONS: Our activities are subject to numerous state and federal statutes and regulations concerning the storage, use and discharge of materials into the environment, and many other matters relating to environmental protection. These regulations may adversely affect our operations and cost of doing business. It is likely that these laws will become more stringent in the future. SAFETY AND HEALTH REGULATIONS: We must also conduct our operations in accordance with laws governing occupational safety and health. Currently, we do not foresee expending substantial amounts in order to comply with these regulations. FOREIGN LAWS AND REGULATIONS: We intend to commit a significant amount of our resources to develop our oil and gas Concession in Pakistan. There are inherent risks in operating a business in a foreign country, where unfamiliar laws and business practices may exist. The Company intends to minimize this risk by engaging appropriate professional and support personnel as the operations develop. MARKETING The availability of a ready market for our oil and gas production depends on numerous factors over which we have no control, including the cost and availability of alternative fuels, the extent of other production, costs and proximity of pipelines, regulations of governmental authorities and cost of compliance with environmental concerns. Our business is not seasonal, but increased consumer demand in certain months of the year can influence the price of our produced hydrocarbons upward, depending on the circumstances. Future prices are virtually impossible to predict. We do not have a significant share of any market segment and cannot set or influence the price of our products. While virtually 100% of our produced oil is sold to one purchaser, the availability of several other purchasers in the same market under comparable terms limits any risk associated with reliance upon a single purchaser. TITLE TO DOMESTIC PROPERTIES Our Texas-based properties are oil and gas leasehold interests which, according to their general terms, must be maintained by development operations or continuous hydrocarbon production without cessation or interruption, except for temporary cessation or interruption. Certain of our leases also require development of the covered acreage according to a specified schedule. The consequences of our non-compliance with these operational and developmental obligations are forfeiture of the particular lease, in the case of non-temporary cessation of operations and production of hydrocarbons, and forfeiture of portions of the lease or undeveloped geologic horizons within the covered acreage covered by a particular lease, in the case of non-compliance under leases which contain scheduled development requirements. TITLE TO PAKISTAN LICENSE The exploration license in the Republic of Pakistan held by our subsidiary, Hycarbex- American Energy, Inc., contains time sensitive development and rental funding obligations which, if not timely fulfilled, would likely result in a forfeiture of the concession. While the estimated potential recoverable hydrocarbon reserves under the acreage covered by the concession are not included within our stated reserves in our financial statements contained within this report, loss of the Pakistan concession as a result of our non-compliance would likely have a substantial adverse impact upon the market for the Company's securities. AVAILABILITY OF DOMESTIC MARKETS AND VOLATILE PRICING There is an existing and available market for the oil produced from our Texas-based properties. However, the prices which we obtain for our production are subject to market fluctuations which are affected by many factors, including supply and demand. We rely upon favorable pricing to meet our operational expenses. Extended periods of depressed oil prices could result in the inability to meet these operational expenses and could expose us to the risk of loss of our properties because of the financial inability to meet ongoing maintenance and development requirements. Numerous factors beyond our control which could affect pricing include: o the level of consumer product demand, o weather conditions, o domestic and foreign governmental regulations, o the price and availability of alternative fuels, o political conditions, o the foreign supply of oil and natural gas, o the price of foreign imports, and o overall economic conditions. AVAILABILITY OF INTERNATIONAL MARKETS AND VOLATILE PRICING We have not established production on our concession in the Republic of Pakistan. Should our further development result in a well or wells capable of producing hydrocarbons, sales of those hydrocarbons could not be made without connections to existing pipeline facilities. Our ability to generate a favorable return on our investment in Pakistan will be dependent upon market prices and conditions present at the time we achieve commercial production, if at all. ADVERSE OPERATING CONDITIONS The oil and gas business involves a variety of operating risks. We are faced with the risk that we will not find oil and natural gas at all or that we will not find oil and natural gas in reservoirs from which we can economically produce the oil and natural gas. The cost of drilling, completing and operating wells is substantial and uncertain. Numerous factors beyond our control may cause the curtailment, delay or cancellation of drilling operations, including: o unexpected drilling conditions, o pressure or irregularities in formations, o equipment failures or accidents, o adverse weather conditions, o compliance with governmental requirements, and o shortages or delays in the availability of drilling rigs or delivery crews and the delivery of equipment. In accordance with customary industry practice, we have maintained insurance against some, but not all, of the risks described above. We cannot assure you that any insurance will be adequate to cover the potential losses or liabilities. We also cannot predict the continued availability of insurance or the availability of insurance at premium levels that justify its purchase. NEED FOR ADDITIONAL FUNDS Since the production derived from our Texas-based properties is insufficient to meet our future capital requirements for both Texas and Pakistan operations, we will need additional financing to meet our projected operating capital requirements. We do not currently have a line of credit or other credit facility available to us to meet these cash requirements. Additional financing will be pursued, as needed, by seeking credit facilities, sales of our securities, sales of our assets and joint ventures. We cannot be certain that we will be successful in obtaining additional financing on favorable terms, if at all. FACILITIES AND PERSONNEL RESOURCES OFFICES We currently lease approximately 3,800 square feet of office space for use as corporate offices at 9441 Sam Houston Parkway, Houston, Texas, at a monthly rental of $2,391. The lease expires on August 31, 2004. We likewise maintain two office trailers of approximately 200 square feet each and one storage facility of approximately 400 square feet for our domestic field operations on certain of our oil and gas leases. Our right to install and maintain these trailers and storage buildings is included with the easements granted under the oil and gas leases and they do not incur a rental obligation. We likewise maintain an office in Islamabad Pakistan of approximately 2,400 square feet. EMPLOYEES We have 5 employees in our Houston, Texas corporate offices, three of which are management. We have 7 employees, including 2 management employees, working in our field operations and 11 employees in our Islamabad Pakistan office. None of our employees is represented by a union or collective bargaining organization. We consider our relationship with our employees to be satisfactory. ITEM 3. LEGAL PROCEEDINGS During the second quarter, we initiated litigation in Cause No. 115917 in the 240th Judicial District Court of Fort Bend County, Texas, against Northern Lights Energy, Ltd., ("Northern Lights") seeking judicial interpretation of the May 9, 2000 purchase agreement with Northern Lights' in which we sought a cancellation of Northern Lights' right to purchase the Texas oil and gas leases under the contract as a result of Northern Lights failure to consummate the purchase in a timely fashion. A cancellation would have resulted in the $750,000 advance made by Northern Lights Energy, Ltd. to us at the inception of the contract being treated as a loan, to be repaid to Northern Lights out of 25% of production in succeeding months. Under the terms of the original contract, if such "lender status" was ultimately elected by Northern Lights Energy, Ltd. in lieu of purchase, Northern Lights Energy was entitled to occupy the position as operator of the oil and gas leases until the loan was repaid. In that suit we likewise requested the Court to appoint a temporary receiver for the sole purpose of prudent management, operation and development of the Texas oil and gas leases during the pendency of the lawsuit. On October 27, 2000, an interim agreement was entered into by the litigants providing for operational safeguards and procedures and Northern Lights Energy, Ltd. continued to operate the properties, applying 25% of production to a sinking fund that would be applied as repayment of the $750,000 loan should the Court ultimately hold in our favor. In the fourth quarter we announced a settlement which would have permitted Northern Lights Energy, Ltd. to tender the agreed purchase price in installments. The settlement terms were made subject to the approval of the Canadian securities authorities which had jurisdiction over one of the defendants. The Canadian Venture Exchange declined approval of the settlement and subsequent to the end of the fiscal year the litigants restructured the settlement such that Northern Lights Energy, Ltd. relinquished its purchase rights under the contract and accepted a discounted cash sum in full repayment of the loan, thereby permitting us to reassume operational control of the Texas-based oil and gas leases. As of June 30, 2001, we were not a party to any other material legal proceedings, and to the best of our knowledge, no material legal proceedings have been threatened against us. ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS In the first quarter the proposal to sell the Texas-based oil and gas leases to Northern Lights Energy, Ltd. for four million dollars, or, if not consummated with Northern Lights, to an alternative purchaser under comparable terms, was submitted to a vote of shareholders by written consent. As of July 31, 2000, a date more than thirty days after the notice to the shareholders, the proposal was approved by the vote of 18,654,691 shares for the proposal, 140,440 shares against the proposal and 2,900 shares abstaining. PART II ITEM 5. MARKET OF OUR COMMON STOCK AND RELATED STOCKHOLDER MATTERS The price of the Common Stock of the Company is quoted in the "pink sheets" published by the National Quotation Bureau and the Bulletin Board, an inter-dealer quotation system operated by the National Association of Securities Dealers, Inc. under the symbol "AMEL". These over the counter market quotations may reflect inter-dealer prices, without retail mark-up, mark-down or commission and may not necessarily reflect actual transaction prices.
High Bid Low Bid Fiscal years ended June 30, 2001 First Quarter $0.66 $0.25 Second Quarter $1.28 $0.44 Third Quarter $0.72 $0.16 Fourth Quarter $0.29 $0.15 2000 First Quarter $2.46 $0.93 Second Quarter $2.06 $1.00 Third Quarter $1.25 $0.15 Fourth Quarter $1.01 $0.25
DIVIDENDS We have not declared, distributed or paid any cash dividends in the past. We do not expect that we will have sufficient net profit and cash flow in amounts that would allow a cash dividend to be paid to our shareholders in the foreseeable near term. RECENT SALES OF UNREGISTERED SECURITIES During the fiscal year we sold to private investors 9,840,075 shares of Common Stock, $.001 par value, at $0.30 per share, without registration under the Securities Act of 1933, as amended ("Securities Act"). We relied upon Section 4(2) of the Securities Act in claiming exemption from registration. All of the persons had full information concerning our business affairs and acquired the securities for investment purposes. The certificates representing the shares issued contain a restrictive legend prohibiting transfer without registration or the availability of an exemption from registration. All of the shares were made the subject of a Registration Statement on Form S-3 filed November 22, 2000, and amended March 8, 2001. The Registration Statement was not declared effective by the Securities and Exchange Commission as of June 30, 2001. In connection with the private placement, we also issued to the placement agent as a commission 796,929 Warrants to Purchase Common Stock at an exercise price of $0.36. ITEM 6. SELECTED CONSOLIDATED FINANCIAL DATA The following Selected Consolidated Financial Data presented under the captions "Statements of Earnings Data" and "Balance Sheet Data' for, and as of the end of, each of the years in the five year period ended June 30, 2001, are derived from the consolidated financial statements of The American Energy Group, Ltd, and Subsidiaries. The financial data for the four years ended June 30, 1996 through 1999 have been audited by Jones, Jensen & Company, Independent Public Accountants. The financial data for the years ended June 30, 2000 and 2001 have been audited by HJ & Associates, Inc. (previously Jones Jensen & Company). The selected consolidated financial data should be read in conjunction with the Consolidated Financial statements as of June 30, 2001 & 2000, and for each of the three years ended June 30, 2001, 2000 and 1999, the accompanying notes and the report thereon, which are included elsewhere in the respective Forms 10-K.
FOR THE YEARS ENDED JUNE 30, ---------------------------------------------------------------------------------- 2001 2000 1999 1998 1997 ------------ ------------ ------------ ------------ ------------ STATEMENT OF EARNINGS DATA ($) Oil & Gas sales............. $ 1,806,335 1,823,276 417,136 641,203 83,485 Lease Operating & Production Costs...... 811,757 592,502 163,838 258,032 83,826 Penalties 540,000 270,002 Legal & Professional........ 336,597 414,308 393,877 541,031 143,622 Administrative Labor....... 111,300 135,529 88,475 122,089 77,194 Depreciation and Amortization Expense...... 6,389,705 1,249,879 5,245,671 275,803 37,416 Warrant settlements 1,758,000 Other G & A............... 4,853,820 555,227 560,668 144,172 113,625 =========== ========== ========== ========== ========== Total Expenses.............. 14,801,179 3,217,447 6,452,529 1,341,127 455,683 Other Income & Expenses.. (279,248) (967,004) 64,212 48,851 (11,808) Extraordinary Item -0- -0- 123,082 17,343 ========== ========== ========== ========== Net Loss ................... (13,274,092) (2,361,175) (5,971,181) (527,991) (166,663) ========== ========== ========== ========== Basic Loss per Common Share (0.25) (0.07) (0.19) (0.020) (0.014) =========== ========== ========== ========== ========== Weighted Ave. Shares Outstanding.................. 52,566,109 33,653,953 31,133,813 26,252,631 11,548,539 =========== ========== ========== ========== ==========
BALANCE SHEET DATA Cash & Cash Equivalents $ 923,831 1,344,513 1,196,566 3,214,205 3,132,294 Working Capital (deficit) (3,267,255) (1,939,587) (592,850) 650,004 2,434,012 Total Assets 16,434,452 17,649,578 15,814,790 20,864,635 13,092,370 ========== =========== ========== ========== ========== Long Term Debt 1,095,919 1,226,243 544,551 698,677 1,792,318 Stockholders Equity $11,027,264 $12,955,628 $13,720,854 $14,929,139 10,457,095 =========== ----------- =========== =========== ==========
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS The following discussion of the historical financial condition and results of operations should be read in conjunction with the "Summary Consolidated Financial Data", the consolidated financial statements and related notes contained in this report. GENERAL STATEMENT OF ACTIVITIES AND METHOD OF ACCOUNTING As of June 30, 2001, we were engaged in our principal activity of developmental drilling of new wells and reworking operations on existing wells situated on our Texas-based oil and gas leases situated in Fort Bend County, Texas. Our wholly owned subsidiary, Hycarbex-American Energy, Inc., likewise held an oil and gas exploration license on a concession near Jacobabad, Pakistan during the year on which we drilled an unsuccessful exploration well. The Company utilizes the full cost method of accounting for its oil and gas properties. Under this method, all costs associated with the acquisition, exploration and development of oil and gas properties are capitalized in a "full cost pool". Costs included in the full cost pool are charged to operations as depreciation, depletion and amortization using the units of production method based on the ratio of current production to estimated proven reserves as defined by regulations promulgated by the U.S. Securities and Exchange Commission. Gain or loss on disposition of oil and gas properties is not recognized unless it would materially alter the relationship between the capitalized costs and estimated proved reserves. Disposition of properties are reflected in the full cost pool. The full cost method of accounting limits the costs the Company may capitalize by requiring the Company to recognize a valuation allowance to the extent that capitalized costs of its oil and gas properties in its full cost pool, net of accumulated depreciation, depletion and amortization and any related deferred income taxes, exceed the future net revenues of proved oil and gas reserves plus the lower of cost or estimated fair market value of non-evaluation properties, net of federal income tax. ADJUSTMENT TO FINANCIAL STATEMENTS FOR PRIOR PERIODS In our financial statements for the periods ending June 30, 1999 and June 30, 2000, we capitalized the dry hole costs associated with the unsuccessful drilling activities in Pakistan, rather than deducting them as an expense in the year incurred, on the belief that the results of our domestic and international activities could be viewed as a whole. Based upon applicable accounting principles, the lack of proven reserves in Pakistan requires that Pakistan be treated as a separate cost center and that the dry hole costs be expensed in the year incurred. This adjustment affects the previously reported losses for the period ending June 30, 1999 by increasing those losses by $5,216,832 from $754,349 to the corrected figure $5,971,181, and affects the previously reported losses for the period ending June 30, 2000 by decreasing those losses by $9,922,073 from $12,283,248 to the corrected figure $2,361,175. (See Note 10 to our Consolidated Financial Statements). The large increase in Other General and Administrative Expenses from $555,227 in the previous year to $4,853,820 for the current year is based largely upon the 6,050,000 shares of Common Stock issued to members of management and directors in November, 2000. The values attributed to these shares in the Financial Statements for purposes of calculating this expense line items were determined based upon the market value of the shares on the date of issue. TEXAS GULF COAST OPERATIONS As stated elsewhere in this report, we currently own and operate a total of 107 existing wellbores in two producing oil fields, the Blue Ridge Field and the Boling Dome Field, each of which are within fifty (50) miles of the Houston, Texas metropolitan area. Most of these existing wells were drilled by other oil companies prior to the Company's acquisition of the properties and were inactive at the time of such acquisition. During the fiscal year ended June 30, 2001, an average of thirty-three (33) of the Company's 107 wells were producing daily with varying production ranging from 2 barrels per day to 55 barrels per day. A small number of these producing wells flow without mechanical pumping but the majority require mechanical pumping assistance. The Company's intent was to workover, re-complete and drill new wells in these fields to generate funds for future oil and gas exploration in the domestic U.S. In the fourth quarter of the previous year, we redirected our focus and business plan toward Pakistan exploration due to its substantially greater potential for large scale hydrocarbon production based upon available geologic and geophysical data. We commenced, at that time, efforts to market our Texas-based properties both to generate cash resources and to limit dilution of the company's existing cash and personnel resources. In May 2000, after negotiations with several interested parties, we entered into a sales agreement with Northern Lights Energy, Ltd. to sell the properties for $4,000,000. A front-end advance of $750,000 was paid to us which we utilized for certain expenses of the transaction and for deposit requirements in Pakistan. Under the terms of the contract, if Northern Lights Energy failed to close for any reason, the $750,000 advance was to be treated as a loan and repaid out of 25% of production, with Northern Lights Energy controlling operations during the repayment period. Northern Lights subsequently failed to consummate the sales agreement and we instituted litigation to obtain certainty as to its lender, rather than purchaser, status. An interim agreement was entered into immediately providing for operating procedural safeguards during the pendency of the suit and further providing for the deposit of 25% of production to a sinking fund which would be applied to loan repayment in the event we were ultimately successful in the litigation. We entered into a settlement agreement in March, 2001, subject to certain approvals by the Canadian authorities regulating Northern Lights and the settlement was later disapproved by the agency. We experienced a moderate increase in overall daily production during this fiscal year as the result of field work in progress. However, the 25% of production designated for Northern Lights' loan repayment had an adverse effect on our net profits figure as reflected in the accompanying financial statements. During the fiscal year ending June 30, 2001, reworking operations continued under the direction of Northern Lights Energy, Ltd., and one (1) new well was drilled which was plugged and abandoned as a dry hole. On June 27, 2001, (three days prior to the end of the fiscal year) we underwent a change in management. Subsequent to the end of the fiscal year, after a complete reevaluation of these properties by the new management team, we restructured a final settlement with Northern Lights Energy in an effort to regain immediate control of our Texas-based oil and gas leases. On August 23, 2001, Northern Lights Energy, Ltd. relinquished its contractual purchase rights and accepted a discounted sum of $285,000 as full payment of the loan balance, after application of the prior sinking fund deposits. Subsequent to the end of the fiscal year, we sold 10% working interest in the Texas based oil and gas leases and equipment for $300,000 to Zaber Investments, L.L.C. and used the proceeds to make the settlement payment to Northern Lights. The remaining $15,000 not paid to Northern Lights were applied to field development expenses. Once we regained control of the Texas-based oil and gas leases and equipment, we elected to withdraw them from the sales market and then designed and implemented a program to increase productivity and make them self sufficient within the first six (6) months of this current fiscal year. Since July 1, 2001, the Company has drilled one (1) new well (Blakely B-72) which was completed as a producing well and is currently flowing oil. Continued testing is ongoing at present and additional potential oil zones revealed in the tests performed on this well will be explored in the future. In addition, our saltwater disposal well in the Blue Ridge Field has been repaired and will soon be put on line after regulatory approval, and our saltwater disposal well in the Boling Field is currently being repaired and is expected to be placed on line shortly. When these saltwater disposal wells are activated, we will no longer incur third party costs associated with hauling and disposing of saltwater from operations resulting in a savings of $15,000 to $20,000 per month, which will considerably lower our lifting costs. Field production has increased by approximately 100 BOPD since July 1, 2001. We anticipate that our domestic fields will continue to experience this increase in average daily production as additional existing wells are reactivated and new developmental wells are drilled. Our domestic operating budget for the coming fiscal year includes the drilling of 6 new wells, 30 recompletions, 24 workovers, 2 soak programs and 2 disposal wells. We are also planning to acquire 1 vacuum truck, 14 reconditioned motors, 2 equipment and storage buildings, 20,000 feet of tubing and 10,000 feet of sucker rods. We believe that the we must continue to raise additional capital through outside sources for this fiscal year for the reactivation and development programs to progress, even if oil prices remain stable at a favorable level. PAKISTAN OPERATIONS In the fiscal year ended June 30, 2001 we shot an additional 40km of seismic line in the vicinity of proposed drilling locations. Our technical team evaluated this newly acquired seismic data, along with geological and geophysical data derived from previously drilled wells to optimize the selection of future drill sites on the approximate one million acres (fifteen hundred square miles) comprising the Jacobabad concession. Based upon the preliminary testing of the initial well drilled Kharnhak #1, in 1998, the geological information obtained while drilling the David #1 and 1A wells and the newly acquired seismic data we selected the drillsite for the Jacobabad #3 well. The Jacobabad #3 well was drilled in Nov/Dec 2000 and plugged and abandoned as a dry hole. Although Jacobabad 3 did not result in a commercial success, we have demonstrated improved drilling and testing performance in this technically challenging environment, and have acquired important additional data that was used to further develop our geologic model of this portion of the Middle Indus Basin. Soon after plugging the Jacobabad #3 well the concession was completely reevaluated to determine areas on our Jacobabad Concession that had good hydrocarbon potential. For strategic reasons, we elected to release the Jacobabad Concession back to the Pakistan government and nominate specific highly potential hydrocarbon areas for bidding with the expectation of being awarded the desired acreage areas. Subsequently we applied and bid for three (3) concessions closely associated with the released Jacobabad Concession. In August 2001 we were officially awarded the Yasin Concession (1211.68 sq. km) in the Sindh Province of Pakistan. Dr. Iftikhar Zahid, Hycarbex's Vice President of Administration and Resident Director signed the Concession Agreement August 11, 2001 in Islamabad with representatives of the President of Pakistan. Hycarbex has committed USD $2,400,000.00 over the course of the next three years to explore and test this concession. At least 100 km of new 2-D seismic will be shot, 150 km of older vintage 2-D data will be evaluated, and one exploration well will be drilled to test the Sui Main Limestone formation for potential gas. Hycarbex-American Energy Inc. has also bid and applied for two additional Pakistan concessions in the area. The Bahadurpur Concession 211.62 sq. Km is east of the Yasin Concession and north of Pakistan Petroleum Ltd. Block 22 Concession. The Miro Khan Concession (4764.87 sq. km.) is immediately to the west of the Yasin Concession on the west flank of Hycarbex's prior Jacobabad Concession. We are currently awaiting for the oil ministry to finalize the concession agreements for these two (2) blocks and to make its official awards. Subsequent to the end of the fiscal year, we announced that a new exploration well will be commenced within the next year, in order to fulfill Hycarbex's exploration commitment with the Government of Pakistan. The well location will be determined after performance and evaluation of additional seismic expected to be conducted in the second and third quarters of the coming fiscal year. NEED FOR ADDITIONAL FUNDS Since the production derived from our Texas-based properties is insufficient to meet our future capital requirements for both Texas and Pakistan operations, we will need additional financing to meet our projected operating capital requirements. We do not currently have a line of credit or other credit facility available to us to meet these cash requirements. Our cash position is critical given the Concession requirements in Pakistan and given future development requirements under certain of our Texas oil and gas leases. We intend to continue to explore and pursue all available sources of working capital through potential loans, sales of securities, sales of assets, joint venture affiliations, and other transactions in order to meet its anticipated near term needs. There can be no assurance that these efforts will continue to prove successful. In the event that additional capital raising efforts by the Company are unsuccessful, the likely effects would be an ultimate forfeiture of the Pakistan concession and a slowdown or postponement of scheduled reactivation and development activities on those Texas properties. RESULTS OF OPERATIONS GLOSSARY Bbl or Barrel: Forty-two (42) United States gallons liquid volume, usually used herein in reference to crude oil or other liquid hydrocarbons. BOE or Barrel of Oil Equivalent: Generally, the conversion of gas to oil at a ratio of 6,000 cubic feet of gas to one Bbl of oil. Oil and gas are added together for total BOE. BOPD: Barrels of oil per day. Developmental Well: A well which is drilled to and completed in a known producing formation adjacent to a producing well in a previously discovered field and in a stratigraphic horizon known to be productive. Exploration: The search for economic deposits of minerals, petroleum and other natural earth resources by any geological, geophysical, or geochemical technique. Exploratory Well: A well drilled either in search of a new, as-yet undiscovered oil or gas reservoir or to greatly extend the known limits of a previously discovered reservoir, as indicated by reasonable interpretation of available data, with the objective of completing in that reservoir. Field: A geographic area in which a number of oil or gas wells produce from a continuous reservoir. Mcf: One thousand cubic feet of natural gas. Net Acres or Net Wells: The sum of fractional working interests owned in gross acres or gross wells. By way of example, a 50% working interest in 100 gross acres is equivalent to 50 net acres. Operator: The person or company actually operating an oil or gas well. PV-10 Value: The present value, employing a 10% discount factor, of the future net revenues computed using current prices from the production of proven reserves. REVENUES AND EXPENSES In the fiscal year ended June 30, 2001, the Company incurred a net operating loss of $13,274,092, with oil sales of $1,806,335, as compared to a net operating loss of $2,361,175 on oil sales of $1,823,276 in the prior fiscal year ended June 30, 2000, and as compared to a net operating loss of $5,971,181 on oil sales of $417,136 in the fiscal year ended June 30, 1999. This reflects a minimal decrease in revenues for the year ended June 30, 2001 over the year ended June 30, 2000, and an increase of four hundred thirty seven percent (437%) over the year ended June 30, 1999 . The increases noted above resulted from the increases in barrels of oil sold and the sale of those barrels at prices which were significantly higher than those received during fiscal 1998. The average price per barrel of oil sold by the Company in the fiscal years ending June 30, 2000 and 1999 was $24.91 and 12.93, respectively, as compared to $29.11 per barrel in the fiscal year ending June 30, 2001. Lease operating costs incurred during the years ended June 30, 2001, 2000 and 1999 were $811,757, $592,502, and $163,838, respectively. The significant increase for the year ended June 30, 2001 over the previous two fiscal years was a direct result of the increased production in barrels of oil as previously discussed under "Oil and Gas Disclosures". Depreciation and amortization expense incurred during the years ended June 30, 2001, 2000 and 1999 was $6,389,705, $1,249,879 and $5,245,671, respectively. The fluctuation in these accounts is a direct result of the drilling of dry holes incurred in the Pakistan cost center which, upon dry hole determination, are included in the amortization base of that cost center. As there are currently no proven reserves in this cost center, the cost of these dry holes are immediately written off. OTHER INCOME AND EXPENSES Interest income earned during the years ended June 30, 2001, 2000 and 1999 was $15,466, $5,850, and $73,969, respectively. The decrease in interest income earned is a direct result of the decrease in cash held by the company during the years ended June 30, 2001 and 2000. Interest expense incurred during the years ended June 30, 2001, 2000 and 1999 was $229,887, $123,800, and $6,877, respectively. The significant increase in interest expense incurred during the year ended June 30, 2001 and 2000 is a direct result of $1,500,000 note payable financing agreement entered into by the Company during the year ended June 30, 2000. During the year ended June 30, 2000 the Company incurred debt issue costs in the amount of $846,992 of which $798,372 was related to the cost of warrants to the Debtor. NET INCOME The Company, with the inclusion of other income, foreign and domestic administrative expenses, asset impairment loss, and including interest, reported a net loss of $13,274,092 in the fiscal year ended June 30, 2001, versus a net loss of $2,361,175 in the prior fiscal year ended June 30, 2000 and a net loss of $5,971,181 for the year ended June 30, 1999. Total Assets/Shareholder's Equity In the fiscal year ended June 30, 2001, Total Assets of the Company decreased to $16,434,452, In the year ended June 30, 2000, Total Assets were $17,649,578. The decrease of $1,215,126 is mainly attributed to the decrease in cash and receivables of $480,521 and capitalized oil and gas properties of $608,945 and increases in other assets, including development of the Pakistan concession, cash and accounts receivable in the amount of $2,491,097 Net Shareholders Equity decreased to $11,027,264 as of June 30, 2001, from $12,955,628 as of June 30, 2000. The Company incurred certain long term convertible debt in the amount of $1,500,000 in the quarter ended September 30, 1999, which debt is convertible at the option of the holder at the rate of one Common share for each one dollar of principal converted. A contractual provision within the lending documents required the Company to initiate a registration with the Securities & Exchange Commission of the underlying Common shares by December 16, 1999. The Company has not complied with this registration requirement, triggering a financial penalty of $45,000 per month beginning January 20, 2000, and continuing until such time that the registration is accomplished. The Company has elected to pay the penalty sum in common stock as permitted in the lending documents and will continue to incur this monthly penalty until the registration is completed. Late registration penalties equal to three percent (3%) per month of the stock purchased, payable in cash or stock at our election, are also applicable to certain private placement investors from the current fiscal year commencing 120 days after their respective acquisition dates. ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK We do not have to trade in derivative financial instruments and we do not have firmly committed sales transactions. We have not entered into hedging arrangements and do not have any delivery commitments. While hedging arrangements reduce exposure to losses as a result of unfavorable price changes, they also limit the ability to benefit from favorable market price changes. Our major market risk exposure is in the pricing applicable to our oil and natural gas production. The prices realized are primarily driven by prevailing domestic prices for crude oil. Historically, these prices have been volatile and unpredictable. Pricing volatility is expected to continue. Oil prices we received during the fiscal year ranged from a monthly low of $25.52 per barrel to a monthly high of $33.60 per barrel. A significant decline in the price of oil could have a material adverse effect on our financial condition and results of operations. ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA Our financial statements and supplementary financial data, which begins on page F-1, are included elsewhere in this report. ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE Not applicable. PART III ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
Name Age Position Georg von Canal 52 Chairman of the Board/President William M. Aber, Jr. 57 Director, Vice President and Chief Executive Officer Dean C. Smith 54 Chief Financial Officer Linda F. Gann 43 Secretary
GEORG VON CANAL CHAIRMAN OF THE BOARD OF DIRECTORS AND PRESIDENT Georg von Canal is an independent Corporate Finance Consultant and has represented interests of major American Energy shareholders since March 1998. Prior to his present occupation, he was an Investment Manager, Corporate Finance, with APAX Partners & Co., Germany and Switzerland, (now Atrium AG) and a Managing Partner of Transconnect Group, Munich, a business consultancy and investment company. Mr. Von Canal holds a first class PhD in Economics from the University of St. Gallen, Switzerland. He joined the Board of Directors in March 2000. WILLIAM M. ABER, JR. BOARD MEMBER, VICE PRESIDENT AND CHIEF EXECUTIVE OFFICER William M. Aber, Jr. was appointed to the Board and as Vice President and Chief Executive Officer on June 27, 2001. Mr. Aber is co-founder, President and Chairman of the Board of several oil and gas related companies in Houston, Texas. He holds a Masters Degree in physics from Sam Houston State University. He has previously worked for Getty Oil Company and Strata Energy where he gained valuable domestic exploration experience. Since 1987, Mr. Aber has been involved in oil and gas exploration worldwide. Mr. Aber has served as an exploration advisor and consultant to Hycarbex-American Energy, Inc. since 1997. DEAN C. SMITH CHIEF FINANCIAL OFFICER Dean C. Smith was appointed Chief Financial Officer on June 27, 2001. Mr. Smith is Treasurer and sits on the Board of an oil and gas consulting firm and an oil and gas investment group in Houston, Texas. He completed his education at Centenary College of Louisiana and Northwestern Univesity of Louisiana. He has been actively involved in the oil and gas industry for 14 years. LINDA F. GANN SECRETARY Linda F. Gann was appointed Secretary of the Company on June 18, 1998. She has been employed by the Company since January, 1995, where she has held various positions including Office Manager, Accounting Supervisor, and Assistant to the President. Prior to her employment with the company, she was employed by Igloo Corporation, where she was Production Manager. She had previously worked for Guaranty National Bank in Accounting and Commercial Customer Service. Ms. Gann has pursued various course work in attempting to obtain a college degree, subject to the constraints of her workload and responsibilities at the Company. SECTION 16(a) COMPLIANCE Section 16(a) of the Securities Exchange Act of 1934 requires our directors and officers to file periodic reports with the SEC reporting their direct and indirect ownership and changes in ownership of our securities. To the best of our knowledge, all Section 16(a) requirements have been complied with during the year ending June 30, 2001. ITEM 11. EXECUTIVE COMPENSATION Summary Compensation Table:
ANNUAL COMPENSATION LONG TERM COMPENSATION ------------------- ---------------------- AWARDS PAYOUTS ------ ------- OTHER SECURITIES NAMEE AND ANNUAL RESTRICTED UNDERLYING PRINCIPAL COMPEN- STOCK LTIP POSITION YEAR SALARY(L) BONUS SATION AWARDS OPTIONS/SARS PAYOUTS =========== ===== ========= ===== ========= ====== ============ ======== Charles 2001 $ 65,528.04 -0- -0- -0- 1,650,000 -0- Valceschini CEO Linda 2001 $ 26,604.07 -0- -0- -0- 150,000 -0- Gann Secretary
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT The Company has two classes of voting equity securities, Common and Convertible Preferred, which are combined to accumulate the total voting shares of the Company. The following table sets forth certain information as of October 10, 2001, with respect to the beneficial ownership of shares of common stock by (i) each person who is known to the Company to beneficially own more than 5% of the outstanding shares of common stock, (ii) each director of the Company, (iii) each executive officer of the Company and (iv) all executive officers and directors of the Company as a group. Unless otherwise indicated, each stockholder has sole voting and investment power with respect to the shares shown.
NUMBER PERCENT NAME TYPE OF SHARES OF CLASS CURRENT OFFICERS AND DIRECTORS William M. Aber Common 908,910 1.5% Dean C. Smith Common 401,250 0.7% Linda F. Gann (FN 5) Common 75,600 0.1% All current officers and Directors as a group (four persons) Common 1,385,760 2.3%
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS During the fiscal year, Calvert D. Crary, a principal in the organization serving as our investment banker, purchased 100,000 shares of our Common Stock at $0.30 as an individual investor in the private placement. Mr. Crary's shares were purchased for the same price and under the same terms as the other private placement investors. PART IV 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K (a) EXHIBITS The Financial Statement Schedules required herein are included as set forth as Exhibit A and beginning on page F-1 (b) REPORTS ON FORM 8-K None. SIGNATURES Pursuant to the requirements of Section 13 of 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, on October 12, 2001. /s/Georg von Canal President and Chairman of the Board /s/William M. Aber, Jr. Vice-President, Chief Executive Officer and Director /s/Dean C. Smith Chief Financial Officer THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES CONSOLIDATED FINANCIAL STATEMENTS JUNE 30, 2001 AND 2000 F-1 C O N T E N T S Independent Auditors' Report................................................ F-3 Consolidated Balance Sheets................................................. F-4 Consolidated Statements of Operations....................................... F-6 Consolidated Statements of Stockholders' Equity............................. F-7 Consolidated Statements of Cash Flows....................................... F-9 Notes to the Consolidated Financial Statements............................. F-11
F-2 INDEPENDENT AUDITORS' REPORT To the Stockholders and Board of Directors The American Energy Group, Ltd. and Subsidiaries Houston, Texas We have audited the accompanying consolidated balance sheets of The American Energy Group, Ltd. and Subsidiaries as of June 30, 2001 and 2000 and the related consolidated statements of operations, stockholders' equity and cash flows for the years ended June 30, 2001, 2000 and 1999. These consolidated financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We conducted our audits in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the consolidated financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall consolidated financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the consolidated financial position of The American Energy Group, Ltd. and Subsidiaries as of June 30, 2001 and 2000 and the consolidated results of their operations and their cash flows for the years ended June 30, 2001, 2000 and 1999, in conformity with accounting principles generally accepted in the United States of America. The accompanying consolidated financial statements have been prepared assuming that the Companies will continue as going concerns. As discussed in Note 1 to the consolidated financial statements, the Companies have suffered recurring losses to date, which raises substantial doubt about their ability to continue as going concerns. Management's plans with regard to these matters are also described in Note 1. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty. As discussed in Note 10 to the consolidated financial statements, certain errors were discovered by management during the current year resulting in the understatement of previously reported amounts in Oil and Gas Properties and an overstatement in the Accumulated Deficit account as of June 30, 2000 and the overstatement of previously reported net loss for the year ended June 30, 2000 and the understatement of previously reported net loss for the year ended June 30, 1999. Accordingly, adjustments have been made to the above mentioned accounts. HJ & Associates, LLC Salt Lake City, Utah October 8, 2001 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Consolidated Balance Sheets ASSETS ------
JUNE 30, ----------------------------- 2001 2000 ------------- -------------- (As Restated) CURRENT ASSETS Cash (Note 1) $ 923,831 $ 244,513 Restricted cash (Note 1) - 1,100,000 Receivables 104,108 163,947 Other current assets 16,075 19,660 ------------- -------------- Total Current Assets 1,044,014 1,528,120 ------------- -------------- OIL AND GAS PROPERTIES USING FULL COST ACCOUNTING (Notes 1 and 2) Properties being amortized 16,687,542 24,725,831 Properties not subject to amortization - 357,749 Accumulated amortization (1,515,171) (9,302,264) ------------- -------------- Net Oil and Gas Properties 15,172,371 15,781,316 ------------- -------------- OTHER PROPERTY AND EQUIPMENT (Note 1) Drilling and related equipment 387,267 384,679 Vehicles 139,801 139,801 Office equipment 52,835 48,933 Accumulated depreciation (417,456) (353,718) ------------- -------------- Net Other Property and Equipment 162,447 219,695 ------------- -------------- OTHER ASSETS Debt issuance costs, net (Note 1) 48,620 113,447 Investments 1,900 1,900 Deposits 5,100 5,100 ------------- -------------- Total Other Assets 55,620 120,447 ------------- -------------- TOTAL ASSETS $ 16,434,452 $ 17,649,578 ============= ==============
The accompanying notes are an integral part of these consolidated financial statements. F-4 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Consolidated Balance Sheets (Continued) LIABILITIES AND STOCKHOLDERS' EQUITY
JUNE 30, --------------------------- 2001 2000 ------------ ------------- (As Restated) CURRENT LIABILITIES Accounts payable $ 1,729,235 $ 1,287,337 Accrued liabilities 649,557 1,242,329 Deposit payable (Note 2) 483,080 750,000 Current portion of capital lease obligations (Note 4) 1,280 2,627 Current portion of notes payable and long-term debt (Note 3) 1,448,117 185,414 ------------ ------------- Total Current Liabilities 4,311,269 3,467,707 ------------ ------------- LONG-TERM LIABILITIES Notes payable and long-term debt (Note 3) 1,094,290 1,220,000 Capital lease obligations (Note 4) 1,629 6,243 ------------ ------------- Total Long-Term Liabilities 1,095,919 1,226,243 ------------ ------------- Total Liabilities 5,407,188 4,693,950 ------------ ------------- COMMITMENTS AND CONTINGENCIES (Note 8) STOCKHOLDERS' EQUITY (Notes 5, 6 and 7) Convertible voting preferred stock; par value $0.001 per share; authorized 15,000,000 shares; 41,499 and 41,499 shares issued and outstanding, respectively 42 42 Common stock; par value $0.001 per share; authorized 80,000,000 shares; 59,991,665 and 35,297,881 shares issued and outstanding, respectively 59,992 35,298 Capital in excess of par value 36,724,103 25,403,069 Accumulated deficit (25,756,873) 12,482,781) ------------ ------------- Total Stockholders' Equity 11,027,264 12,955,628 ------------ ------------- TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY $ 16,434,452 $ 17,649,578 ============ =============
The accompanying notes are an integral part of these consolidated financial statements. F-5 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Consolidated Statements of Operations
For the Years Ended June 30, ------------------------------------------------- 2001 2000 1999 ------------- -------------- -------------- (As Restated) (As Restated) REVENUE Oil and gas sales $ 1,806,335 $ 1,823,276 $ 417,136 ------------- ------------- -------------- Total Revenue 1,806,335 1,823,276 417,136 ------------- ------------- -------------- EXPENSES Lease operating and production costs 811,757 592,502 163,838 Penalties 540,000 270,002 - Legal and professional 336,597 414,308 393,877 Administrative labor 111,300 135,529 88,475 Depreciation and amortization expense 6,389,705 1,249,879 5,245,671 Warrant settlements (Note 6) 1,758,000 - - Other general and administrative 4,853,820 555,227 560,668 ------------- ------------- -------------- Total Expenses 14,801,179 3,217,447 6,452,529 ------------- ------------- -------------- NET OPERATING LOSS (12,994,844) (1,394,171) (6,035,393) ------------- ------------- -------------- OTHER INCOME (EXPENSES) Interest income 15,466 5,850 73,969 Interest expense (229,887) (123,800) (6,877) Debt issuance costs (64,827) (846,992) - Unrealized gain on investment - 1,480 - Gain (loss) on sale of assets - (3,542) (2,880) ------------- ------------- -------------- Total Other Income (Expenses) (279,248) (967,004) 64,212 ------------- ------------- -------------- NET LOSS $ (13,274,092) $ (2,361,175) $ (5,971,181) ============= ============= ============== BASIC LOSS PER COMMON SHARE $ (0.25) $ (0.07) $ (0.19) ============= ============= ============== WEIGHTED AVERAGE NUMBER OF SHARES OUTSTANDING 52,566,109 33,653,953 31,133,813 ============= ============= ==============
The accompanying notes are an integral part of these consolidated financial statements. F-6 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Consolidated Statements of Stockholders' Equity For the Years Ended June 30, 2001, 2000 and 1999 (As Restated - See Note 10)
Convertible Voting Common Stock Preferred Stock Capital in ----------------------------- ------------------------------ Excess of Accumulated Shares Amount Shares Amount Par Value Deficit ------------- ------------- ------------- --------------- ----------------- ------------ Balance, June 30, 1998 28,927,872 $ 28,928 535,462 $ 535 $ 19,050,101 $(4,150,425) Common stock issued for cash at approximately $2.32 per share 1,663,572 1,664 - - 3,853,336 - Common stock issued upon conversion of preferred shares 2,167,330 2,167 (433,467) (433) (1,734) - Common stock issued for oil and gas properties at $3.50 per share 194,000 194 - - 678,805 - Common stock issued in lieu of accounts payable at $3.51 per share 39,441 39 - - 138,425 - Common stock issued for services at approximately $2.18 per share 138,223 138 - - 301,030 - Cancellation of common stock (252,050) (252) - - 252 - Offering costs related to sales of common stock - - - - (333,135) - Additional expense recorded upon granting of warrants - - - - 122,400 - Net (loss) for the year ended June 30 1999 - - - - - (5,971,181) ------------- ------------- ------------- --------------- ----------------- ------------ Balance, June 30, 1999 32,878,388 32,878 101,995 102 23,809,480 (10,121,606) Preferred stock issued for cash at $1.00 per share - - 400,000 400 399,600 - Common stock issued for cash at $0.75 per share 133,334 134 - - 99,866 - Common stock issued upon conversion of preferred shares 1,702,500 1,702 (460,496) (460) (1,242) - Common stock issued in satisfaction of penalty fee at an average price of $0.46 per share (Note 3) 583,659 584 - - 269,418 - Offering costs related to sale of preferred stock - - - - (58,933) - Additional expense recorded upon granting of warrants - - - - 884,880 - Net (loss) for the year ended The accompanying notes are an integral part of these consolidated financial statements. F-7 June 30, 2000 - - - - - (2,361,175) ------------- ------------- ------------- --------------- -------------- -------------- Balance, June 30, 2000 35,297,881 $ 35,298 41,499 $ 42 $ 25,403,069 $(12,482,781) ------------- ------------- ------------- --------------- -------------- --------------
The accompanying notes are an integral part of these consolidated financial statements. F-8 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Consolidated Statements of Stockholders' Equity For the Years Ended June 30, 2001, 2000 and 1999 (As Restated - See Note 10)
Convertible Voting Common Stock Preferred Stock Capital in ---------------------------- --------------------------- Excess of Accumulated Shares Amount Shares Amount Par Value DEFICIT ------------ ------------- ---------- --------------- ------------- -------------- Balance, June 30, 2000 35,297,881 $ 35,298 41,499 $ 42 $ 25,403,069 $ (12,482,781) Common stock issued for cash and warrants at $0.30 per share 13,780,083 13,780 - - 4,120,245 - Common stock issued in satisfaction of penalty fee at an average price of $0.51 per share (Notes 3 and 6) 711,740 712 - - 359,288 - Common stock issued upon retirement of warrants at $0.80 per share (Note 6) 2,197,500 2,197 - - 1,755,803 - Common stock issued to directors for services and expenses at an average price of $0.43 per share 6,050,000 6,050 - - 2,607,948 - Common stock issued in conversion of debt at an average price of $0.40 per share 1,293,661 1,294 - - 520,392 - Common stock issued for services rendered at an average price of $0.43 per share 457,500 457 - - 198,143 - Common stock issued in conversion of debt and services at $0.66 per share 4,692,746 4,693 - - 3,092,518 - Common stock canceled pursuant to court decree (Note 6) (321,146) (321) - - 235,321 - Common stock repurchased and canceled (Note 6) (4,168,300) (4,168) - - (1,090,122) - Offering costs related to sale of common stock - - - - (478,502) - Net (loss) for the year ended June 30, 2001 - - - - - (13,274,092) ------------ ----------- ---------- --------------- -------------- --------------- Balance, June 30, 2001 59,991,665 $ 59,992 41,499 $ 42 $ 36,724,103 $ (25,756,873) ============ =========== ========== =============== ============== ================
The accompanying notes are an integral part of these consolidated financial statements. F-9 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Consolidated Statements of Cash Flows
For the Years Ended June 30, ------------------------------------------------------------- 2001 2000 1999 ----------------- ----------------- ------------- (As Restated) (As Restated) CASH FLOWS FROM OPERATING ACTIVITIES Net loss $ (13,274,092) $ (2,361,175) $ (5,971,181) Adjustments to reconcile net loss to net cash provided (used) by operating activities: Depreciation and amortization 6,436,152 1,300,997 5,297,010 Less amount capitalized to oil and gas properties (46,447) (51,118) (51,339) Common stock issued for services rendered 5,909,809 - 301,168 Common stock issued for retirement of warrants 1,758,000 - - Amortization of note payable discount 174,843 - - Loss on sale of asset - 3,542 - Additional expense for warrants - 884,880 122,400 (Gain) loss on investment - (1,480) - Changes in operating assets and liabilities: (Increase) decrease in receivables 59,839 (90,781) (64,182) (Increase) decrease in receivables-related party - 1,626 (1,626) (Increase) decrease in other current assets 3,585 (6,058) 99,516 (Increase) in other assets 64,827 (113,447) - (Increase) decrease in deposits - - (2,250) Increase (decrease) in accounts payable 963,584 (11,815) (929,264) Increase (decrease) in accrued liabilities and other current liabilities (264,692) 1,567,725 (72,490) ----------------- ----------------- ----------------- Net Cash Provided (Used) by Operating Activities 1,785,408 1,122,896 (1,272,238) ----------------- ----------------- ----------------- CASH FLOWS FROM INVESTING ACTIVITIES Sale of assets - 10,000 2,880 Expenditures for oil and gas property development (5,717,022) (2,730,795) (3,934,076) Expenditures for other property and equipment (2,589) (9,327) (181,944) ----------------- ----------------- ----------------- Net Cash (Used) by Investing Activities (5,719,611) (2,730,122) (4,113,140) ----------------- ----------------- ----------------- CASH FLOWS FROM FINANCING ACTIVITIES Proceeds from notes payable and long-term liabilities - 1,740,000 - Proceeds from issuance of preferred and common stock 4,134,025 500,000 3,855,000 Expenditures for offering costs (478,502) (58,933) (333,135) Payments on notes payable and long-term liabilities (142,002) (425,894) (154,126) ----------------- ----------------- ----------------- Net Cash Provided by Financing Activities 3,513,521 1,755,173 3,367,739 ----------------- ----------------- ----------------- NET INCREASE (DECREASE) IN CASH (420,682) 147,947 (2,017,639) CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR 1,344,513 1,196,566 3,214,205 ----------------- ----------------- ----------------- CASH AND CASH EQUIVALENTS AT END OF YEAR $ 923,831 $ 1,344,513 $ 1,196,566 ================= ================= =================
The accompanying notes are an integral part of these consolidated financial statements. F-10 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Consolidated Statements of Cash Flows (Continued)
For the Years Ended JUNE 30, ----------------------------------------------------------- 2001 2000 1999 ----------------- ----------------- --------------- (As Restated) (As Restated) CASH PAID FOR: Interest $ 9,601 $ 3,800 $ 41,805 Income taxes $ - $ - $ - NON-CASH FINANCING ACTIVITIES: Common stock issued for acquisition of oil and gas properties $ - $ - $ 678,999 Common stock issued to retire notes payable and accounts payable $ 756,686 $ - $ 138,464 Notes payable and capital lease obligations for acquisition of other property and equipment $ 3,901 $ - $ - Common stock issued in satisfaction of penalty fees $ 360,000 $ 270,002 $ - Common stock repurchased for note payable $ 1,094,290 $ - $ -
The accompanying notes are an integral part of these consolidated financial statements. The accompanying notes are an integral part of these consolidated financial statements. F-11 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 1 - ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES a. Organization The American Energy Group, Ltd. (the Company) was incorporated in the State of Nevada on July 21, 1987 as Dimension Industries, Inc. Since incorporation, the Company has had several name changes including DIM, Inc. and Belize-American Corp. Internationale with the name change to The American Energy Group, Ltd. effective November 18, 1994. Effective September 30, 1994, the Company entered into an agreement to acquire all of the issued and outstanding common stock of Simmons Oil Company, Inc. (Simmons), a Texas Corporation, in exchange for the issuance of certain convertible voting preferred stock (see Note 5). The acquisition included wholly owned subsidiaries of Simmons, Sequoia Operating Company, Inc. and Simmons Drilling Company, Inc. The acquisition was recorded at the net book value of Simmons of $1,044,149 which approximates fair value. During the year ended June 30, 1995, the Company incorporated additional subsidiaries including American Energy-Deckers Prairie, Inc., The American Energy Operating Corp., Tomball American Energy, Inc., Cypress-American Energy, Inc., Dayton North Field-American Energy, Inc. and Nash Dome Field-American Energy, Inc. In addition, in May 1995, the Company acquired all of the issued and outstanding common stock of Hycarbex, Inc. (Hycarbex), a Texas corporation, in exchange for 120,000 shares of common stock of the Company, a 1% overriding royalty on the Pakistan Project (see Note 2) and a future $200,000 production payment if certain conditions are met. The acquisition was accounted for as a pooling-of-interests on the date of the acquisition. The fair value of the assets and liabilities assumed approximated the fair value of the 120,000 shares issued of $60,000 as of the date of the acquisition. Accordingly, book value of the assets and liabilities assumed was $60,000. In April 1995, the name of that company was changed to Hycarbex-American Energy, Inc. All of these companies are collectively referred to as "the Companies". The Company and its subsidiaries (the Companies) are principally in the business of acquisition, exploration, development and production of oil and gas properties. b. Going Concern The accompanying consolidated financial statements have been prepared assuming the Companies will continue as going concerns. The Companies have experienced recurring losses and negative cash flows from operations which raise substantial doubt about the Companies' ability to continue as going concerns. F-12 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 1 - ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued) b. Going Concern (Continued) The recovery of assets and continuation of future operations are dependent upon the Companies' ability to obtain additional debt or equity financing, and their ability to generate revenues sufficient to continue pursuing their business purpose. Management is actively pursuing additional equity and debt financing sources to finance future operations and anticipates a significant increase in production and revenues from oil and gas production during the coming year. c. Accounting Methods The Company's consolidated financial statements are prepared using the accrual method of accounting. The Company has elected a June 30 year-end. Oil and Gas Properties- The full cost method is used in accounting for oil and gas properties. Accordingly, all costs associated with acquisition, exploration, and development of oil and gas reserves, including directly related overhead costs, are capitalized. In addition, depreciation on property and equipment used in oil and gas exploration and interest costs incurred with respect to financing oil and gas acquisition, exploration and development activities are capitalized in accordance with full cost accounting. Capitalized interest for the years ended June 30, 2001 and 2000 was $10,000 and $40,000, respectively. In addition, depreciation capitalized during the years ended June 30, 2001 and 2000 totaled $46,447 and $51,118, respectively. All capitalized costs of proved oil and gas properties subject to amortization are being amortized on the unit-of-production method using estimates of proved reserves. Investments in unproved properties and major development projects not subject to amortization are not amortized until proved reserves associated with the projects can be determined or until impairment occurs. If the results of an assessment indicate that the properties are impaired, the amount of the impairment is added to the capitalized costs to be amortized. As of June 30, 2001, proved oil and gas reserves had been identified on some of the Companies oil and gas properties with revenues generated and barrels of oil produced from those properties. Accordingly, amortization totaling $6,372,414 and $1,223,166 has been recognized in the accompanying consolidated financial statements for the years ended June 30, 2001 and 2000, respectively, on proved and impaired or abandoned oil and gas properties. F-13 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 1 - ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued) d. Principles of Consolidation The consolidated financial statements include the Company and its wholly-owned subsidiaries as detailed previously. All significant intercompany accounts and transactions have been eliminated in consolidation. e. Cash Equivalents The Company considers all highly liquid investments with a maturity of three months or less when purchased to be cash equivalents. f. Property and Equipment and Depreciation Property and equipment are stated at cost. Depreciation on drilling and related equipment, vehicles and office equipment is provided using the straight-line method over expected useful lives of five to seven years. For the years ended June 30, 2001, 2000 and 1999, the Companies incurred total depreciation of $63,738, $77,831 and $69,055, respectively. In accordance with full cost accounting, $46,447 and $51,118 of depreciation was capitalized as costs of oil and gas properties for the years ended June 30, 2001 and 2000, respectively, as previously discussed. g. Basic Loss Per Share of Common Stock
For the Years Ended June 30, -------------------------------------------------- 2001 2000 1999 -------------- ------------- --------------- Loss (numerator) $ (13,274,092) $ (2,361,175) $ (5,971,181) Shares (denominator) 52,566,109 33,653,953 31,133,813 -------------- ------------- --------------- Per share amount $ (0.25) $ (0.07) $ (0.19) ============== ============= ===============
The basic loss per share of common stock is based on the weighted average number of shares issued and outstanding during the period of the consolidated financial statements. Stock warrants and preferred shares prior to conversion are not included in the basic calculation because their inclusion would be antidilutive, thereby reducing the net loss per common share. F-14 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 1 - ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued) h. Concentrations of Risk From time to time, the cash balances in the Companies U.S. bank accounts exceed Federally insured limits. At June 30, 2001 and 2000, the balances in excess of the limits were approximately $-0- and $38,285, respectively. In addition, the Company had balances held in Pakistan banks that are not federally insured. The balances of $833,098 and $1,206,228 as of June 30, 2001 and 2000, respectively, held in Pakistan are subject to potential risks based on government intervention. i. Foreign Operations A significant portion of the operations of the Companies relate to an oil and gas concession located in the country of Pakistan (see Note 2). Pakistan has experienced recently, or are experiencing currently, economic or political instability. Hyperinflation, volatile exchange rates and rapid political and legal change, often accompanied by military insurrection, have been common in these and certain other merging markets in which the Companies are conducting operations. The Companies may be materially adversely affected by possible political or economic instability in Pakistan. The risks include, but are not limited to terrorism, military repression, expropriation, changing fiscal regimes, extreme fluctuations in currency exchange rates, high rates of inflation and the absence of industrial and economic infrastructure. Changes in drilling or investment policies or shifts in the prevailing political climate in Pakistan could adversely affect the Companies business. Operations may be affected in varying degrees by government regulations with respect to production restrictions, price controls, export controls, income and other taxes, expropriation of property, maintenance of claims, environmental legislation, labor, welfare benefit policies, land use, land claims of local residents, water use and well safety. The effect of these factors cannot be accurately predicted. j. Use of Estimates The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. F-15 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 1 - ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued) k. Debt Issuance Costs In connection with the receipt of the $1,100,000 note payable, the Company incurred costs of $162,067. The Company capitalized these costs and amortizes these costs over the term of the note payable (2.5 years) as follows:
JUNE 30, -------------------------- 2001 2000 ------------ ----------- Total costs incurred $ 162,067 $ 162,067 Accumulated amortization (113,447) (48,620) ------------ ----------- Net Debt Issuance Costs $ 48,620 $ 113,447 ============ ===========
l. Long Lived Assets All long lived assets are evaluated for impairment per SFAS 121 whenever events or changes in circumstances indicate that the carrying value of an asset may not be recoverable. Any impairment in value is recognized as an expense in the period when the impairment occurs. In addition, pursuant to the full cost method used in accounting for oil and gas properties, the capitalized oil and gas property costs are subject to the full cost ceiling test to determine if the value of proved reserves and other mineral assets in the respective cost center are adequate to recover the unamortized costs in the full cost pool. If the Company determines that the capitalized costs exceed the full cost ceiling, the excess is charged to expense and separately disclosed during the year in which the excess occurs. m. Changes in Accounting Principle The Companies have adopted the provisions of FASB Statement No. 138 "Accounting for Certain Derivative Instruments and Hedging Activities, (an amendment of FASB Statement No. 133.)" Because the Companies had adopted the provisions of FASB No. 133, prior to June 15, 2000, this statement is effective for all fiscal quarters beginning after June 30, 2000. The adoption of this principle had no material effect on the Company's consolidated financial statements. F-16 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 1 - ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued) m. Changes in Accounting Principles (Continued) The Companies have adopted the provisions of FASB Statement No. 140 "Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities (a replacement of FASB Statement No. 125.)" This statement provides accounting and reporting standard for transfers and servicing of financial assets and extinguishments of liabilities. Those standards are based on consistent application of a financial-components approach that focuses on control. Under that approach, the transfer of financial assets, the Company recognized the financial and servicing assets it controls and the liabilities it has incurred, derecognizes financial assets when control has been surrendered, and derecognizes liabilities when extinguished. This statement provides consistent standards for distinguishing transfers of financial assets that are sales from transfers that are secured borrowings. This statement is effective for transfers and servicing of financial assets and extinguishments of liabilities occurring after March 31, 2001. This statement is effective for recognition and reclassification of collateral and for disclosures relating to securitization transactions and collateral for fiscal years ending after December 15, 2000. The adoption of this principle had no material effect on the Company's consolidated financial statements. The Companies have adopted the provisions of FIN 44 "Accounting for Certain Transactions Involving Stock Compensation (an interpretation of APB Opinion No. 25.)" This interpretation is effective July 1, 2000. FIN 44 clarifies the application of Opinion No. 25 for only certain issues. It does not address any issues related to the application of the fair value method in Statement No. 123. Among other issues, FIN 44 clarifies the definition of employee for purposes of applying Opinion 25, the criteria for determining whether a plan qualifies as a noncompensatory plan, the accounting consequence of various modifications to the terms of a previously fixed stock option or award, and accounting for an exchange of stock compensation awards in a business combination. The adoption of this principle had no material effect on the Company's consolidated financial statements. n. Pronouncements Issued Not Yet Adopted In July, 2001, the Financial Accounting Standards Board issued two statements - Statement 141, BUSINESS COMBINATIONS, and Statement 142, GOODWILL AND OTHER INTANGIBLE ASSETS, which will potentially impact the Company's accounting for its reported goodwill and other intangible assets. Statement 141: o Eliminates the pooling method for accounting for business combinations. o Requires that intangible assets that meet certain criteria be reported separately from goodwill. THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements F-17 June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 1 - ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued) n. Pronouncements Issued Not Yet Adopted (Continued) o Requires negative goodwill arising from a business combination to be recorded as an extraordinary gain. Statement 142: o Eliminates the amortization of goodwill and other intangibles that are determined to have an indefinite life. o Requires, at a minimum, annual impairment tests for goodwill and other intangible assets that are determined to have an indefinite life. Upon adoption of these Statements, the Company is required to: o Re-evaluate goodwill and other intangible assets that arose from business combinations entered into before July 1, 2001. If the recorded other intangibles assets do not meet the criteria for recognition, they should be reclassified to goodwill. Similarly, if there are other intangible assets that meet the criteria for recognition but were not separately recorded from goodwill, they should be reclassified from goodwill. o Reassess the useful lives of intangible assets and adjust the remaining amortization periods accordingly. o Write-off any remaining negative goodwill. The Company has not yet completed its full assessment of the effects of these new pronouncements on its financial statements and so is uncertain as to the impact. The standards generally are required to be implemented by the Company in its 2002 consolidated financial statements. o. Equity Securities Equity securities issued for services rendered have been accounted for at the fair market value of the securities on the date of issuance. p. Restricted Cash The Company was required under the concession agreement discussed in Note 2 to have on deposit with its bank a total of $2,200,000 to cover the minimum expenditure obligation with respect to the replacement well and the exploration well for the second renewal period. As of June 30, 2000, $1,100,000 was on deposit with the bank in Pakistan that was to be used for these purposes, which was classified as restricted cash in the accompanying consolidated balance sheet. THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) F-18 NOTE 1 - ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued) q. Income Taxes At June 30, 2001, the Companies had net operating loss carryforwards of approximately $7,400,000 that may be offset against future taxable income from the year 2002 through 2021. No tax benefit has been reported in the June 30, 2001 consolidated financial statements since the potential tax benefit is offset by a valuation allowance of the same amount. The income tax benefit differs from the amount computed at federal statutory rates of approximately 38% as follows:
For the Years Ended June 30, ----------------------------- 2001 2000 -------------- ------------- Income tax benefit at statutory rate $ 1,925,000 $ (6,300) Change in valuation allowance (1,925,000) 6,300 -------------- ------------- $ - $ - ============== =============
Deferred tax assets are comprised of the following:
For the Years Ended June 30, ----------------------------- 2001 2000 -------------- ------------- Income tax benefit at statutory rate $ 2,812,000 $ 887,000 Valuation allowance (2,812,000) (887,000) -------------- ------------- $ - $ - ============== =============
Due to the change in ownership provisions of the Tax Reform Act of 1986, net operating loss carryforwards for Federal income tax reporting purposes are subject to annual limitations. Should a change in ownership occur, net operating loss carryforwards may be limited as to use in future years. F-19 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 2 - OIL AND GAS PROPERTIES At the time the Company acquired Simmons Oil Company, Inc. and its subsidiaries, those companies had ownership interests in oil and gas prospects located in Texas. These properties contained oil and gas leases on which existing wells had been shut-in and abandoned and had additional sites available for further exploration and development. During the years ended June 30, 2001 and 2000, the Companies expended funds in exploration and development activities and work over of existing wells on those properties and other oil and gas properties acquired during those years. On March 10, 1995, American Energy - Deckers Prairie, Inc., a wholly-owned subsidiary of the Company, entered into an agreement with an unrelated entity to accept the transfer of all rights, title and interest to certain oil and gas leases located in the State of Texas along with all personal property and equipment located on and used in connection with those leases. In exchange, American Energy - Deckers Prairie, Inc. assumed all contractual covenants related to those oil and gas leases. The selling entity had previously sold working interests in these oil and gas leases totaling from 33% to 48% depending on the property. As part of the acquisition agreement, American Energy - Deckers Prairie, Inc. agreed to purchase the working interests from the individual holders for the amount of their original investment plus interest at 7% from the date of their investment, evidenced by a "Drilling Investor Note" to each investor, due and payable on September 15, 1995. Each working interest holder has the option to retain his working interest or sell it to American Energy - Deckers Prairie, Inc. At June 30, 1997, the Companies had been unable to satisfy this obligation and the financial guaranty bond securing the payment of the Drilling Investor Notes had not been enforced, although the Companies intended to satisfy this obligation. Most of the obligation was settled during the year ended June 30, 1998 by issuing 140,383 shares of common stock valued at $325,278. Accordingly, the value of the acquisition of these working interest has been included in the accompanying consolidated financial statements as part of the cost of oil and gas properties along with the corresponding remaining liability (See Note 3). F-20 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 2 - OIL AND GAS PROPERTIES (Continued) On April 6, 1995, Hycarbex entered into a concession agreement with and was issued an exploration license by the President and the Federal Government of the Islamic Republic of Pakistan. This agreement and license related to an oil and gas property known as the "Jacobabad Block" (Block 2768-4) or the Pakistan concession and entitled Hycarbex to a 95% working interest in the property. The exploration license was originally issued for a period of three years which was subsequently extended for an additional year. During the first year Hycarbex expended the minimum required $26,000 for processing and interpreting data already available. In the second year which was included in the year ended June 30, 1997, Hycarbex performed the minimum seismic work, evaluating and interpreting the data from the work performed. As part of the agreement, Hycarbex was to drill one exploratory well prior to April 1998 to an agreed upon depth. During May 1998, the Company obtained preliminary results of its first Middle Indus Basin exploratory well in Pakistan. The well was spudded during March 1998 and was drilled to total depth during May 1998. A second exploratory well was drilled during the year ended June 30, 1999. This well was subsequently plugged because of encountered downhole and mechanical conditions short of the target depth. As a result, the well bore was plugged and the drill site moved. A replacement well was spudded on April 5, 1999 which also was plugged due to encountering a combination of dangerous levels of hydrogen sulfide gas and loss of circulation while drilling and testing the well. The well was plugged to prevent possible further release of dangerous gas. The Company intended to pursue further plans for the drilling of another exploratory well upon completion of geological and geophysical analysis of the test results. Having completed its three years of work requirements and initial license term, the Company, per the provisions of the original exploration license, relinquished 20% of the acreage originally held under the concession, thereby retaining approximately one million acres for further exploration and development. The concession agreement also required Hycarbex to provide a bank guaranty for $551,000 which was done by an unrelated surety company. That surety company received common stock of the Company as compensation for providing the bond. Effective May 29, 1999, the Government of Pakistan granted an additional six-month extension in the existing terms of the Jacobabad Exploration License so as to enable the Company to drill a substitute well for the previously abandoned wells with a commitment and obligation to expend an additional $1,100,000. The Company was granted a second renewal of the license to November 28, 2000 to drill an exploration well. This second renewal period was dependent on the Company fulfilling its obligations of drilling the replacement well. The Companies were unable to comply with the requirements of the extension for the replacement well. Accordingly, the Jacobabad Concession was relinquished during the year ended June 30, 2001. Subsequent to June 30, 2001, the Companies were awarded a new concession in Pakistan (the "Yasin Concession") in the Sindh Province of Pakistan. The Companies committed $2,400,000 over the course of the next three years to explore and test the concession (see Note 9). All costs related to the relinquished Jacobabad Concession were fully amortized as of June 30, 2001 and written off. THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements F-21 June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 2 - OIL AND GAS PROPERTIES (Continued) In May 1997, the Companies entered into an agreement to acquire certain oil and gas properties and equipment in the state of Texas for a total of $1,000,000 from an unrelated party. $75,000 cash was paid with the balance of $925,000 to be paid over a maximum of four years with a minimum of $175,000 the first year and $250,000 per year thereafter until paid in full (see Note 3). This liability may be paid during each year in the form of $10,000 per drill site and certain royalty payments. During the year ended June 30, 1997, the Companies received $800,000 as a joint venture investment in certain of the Companies oil and gas properties. In June 1997, the Companies entered into agreements representing $500,000 of the joint venture investors to repurchase their interests for a total of 250,000 shares of common stock and notes payable totaling $389,000 (see Notes 6 and 3, respectively). During the year ended June 30, 1998, the Companies acquired the remaining $300,000 joint venture interest for 150,000 shares of common stock (valued at $1.50 per share) and a note payable of $121,564 with additional payments made to that individual prior to the consummation of that transaction. On May 9, 2000, the Companies entered into an Asset and Stock Purchase and Sale Agreement with Northern Lights Energy, Ltd. (Northern Lights) to sell the U.S. oil, gas and mineral leases, all related equipment to operate such leases, and 100% of the outstanding stock of the operating subsidiary, The American Energy Operating Corp., for a total of $4,000,000. As of June 30, 2000, a total of $750,000 of the $4,000,000 had been received by the Company which was originally recorded in the accompanying consolidated balance sheet as a deposit on the sale of assets. Northern Lights was unable to pay the remaining $3,250,000 pursuant to the agreement. Effective July 1, 2001, Northern Lights relinquished its purchase rights in the U.S. operations. During the year ended June 30, 2001, the Companies had repaid a portion of the $750,000 advance through royalty payments to Northern Lights, leaving a balance outstanding at June 30, 2001 of $483,080. Subsequent to June 30, 2001 when the purchase rights were relinquished, Northern Lights accepted a negotiated sum of $285,000 as full payment of the remaining deposit owed (see Note 9). NOTE 3 - NOTES PAYABLE AND LONG-TERM DEBT The following is a summary of notes payable and long-term debt as of June 30, 2001 and 2000:
2001 2000 ------------ ------------ Note payable bearing no interest; payable $175,000 the first year and $250,000 annually thereafter until paid in full; secured by certain oil and gas assets $ - $ 132,140 Original issue discount note payable with a face value of $1,500,000 bearing no interest, due March 17, 2002, secured by certain oil and gas properties (see note below) 1,500,000 1,500,000 ------------ ------------ Balance forward $ 1,500,000 $ 1,632,140 ------------ ------------
THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) F-22 NOTE 3 - NOTES PAYABLE AND LONG-TERM DEBT (Continued)
2001 2000 ------------ ------------ Balance forward $ 1,500,000 $ 1,632,140 Note payable to Company's former President, non-interest bearing, due on demand, unsecured. 30,000 30,000 Convertible subordinated promissory note due to a related company, interest at 6% per annum due annually on January 1, principal due April 30, 2011, convertible into shares of common stock at $0.43 per share, prepayment premiums of 1) 8% of principal balance if paid between 2nd and 5th anniversary date, 2) 5% of principal balance if paid between 6th and 8th anniversary date and 3) 2% of principal balance if paid after the 8th anniversary date. 1,094,290 - 7% notes payable, due September 15, 1995, secured by working interest in oil and gas properties 38,117 38,117 ------------ ------------ Total notes payable and long-term debt 2,662,407 1,700,257 Less: unamortized discount (120,000) (294,843) ------------ ------------ Net notes payable and long-term debt 2,542,407 1,405,414 Less: current portion (1,448,117) (185,414) ------------ ------------ Long-Term Debt $ 1,094,290 $ 1,220,000 ============ ============
In connection with the $1,500,000 note payable, the Company has the right to call the loan at its face value of $1,500,000. When the Company calls the note, the investor has 20 days to exercise the conversion of the note into shares of common stock at $1.00 per share or receive payment of funds. The Company originally agreed to arrange third party escrow of 2,000,000 free-trading shares of common stock to secure the Company's covenant to register the stock. If the shares were not registered within 90 days, the Company further agreed to pay a penalty of 3% of the face value of the note, in either common stock or cash for each full month the Registration Statement is not declared effective. Accordingly, the Company issued 711,740 and 583,659 shares of common stock valued at $360,000 and $270,002 as a result of this penalty fee for the years ended June 30, 2001 and 2000, respectively. F-23 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 3 - NOTES PAYABLE AND LONG-TERM DEBT (Continued) The following are the scheduled annual repayments of notes payable and long-term debt:
YEAR ENDING JUNE 30, -------------------- 2002 $ 1,448,117 2003 - 2004 - 2005 - 2006 - 2007 and thereafter 1,094,290 --------------- $ 2,542,407 ===============
Discounts on non-interest bearing notes payable have been determined using an imputed interest rate ranging from 10% to 15%. These discounts have been reflected as reductions in notes payable and long-term debt in the accompanying consolidated financial statements. NOTE 4 - CAPITAL LEASE OBLIGATIONS The Company entered into a lease agreement during the year ended June 30, 2001 relating to office equipment which has been accounted for as a capital lease. The lease has a term of 36 months with a total monthly lease payment of $122. The following are the scheduled annual payments on the capital lease:
YEAR ENDING JUNE 30, -------------------- 2002 $ 1,467 2003 1,467 2004 245 2005 - 2006 - --------------- Total minimum lease commitments 3,179 Less: amount representing interest (270) --------------- Total capital lease obligations 2,909 Less: current portion (1,280) --------------- Total Long-Term Capital Lease Obligations $ 1,629 ===============
F-24 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 5 - CONVERTIBLE VOTING PREFERRED STOCK On September 22, 1994, the board of directors of the Company approved the issuance of 2,074,521 shares of the authorized preferred stock of the Company, to be issued in a series, to be known as the "Convertible Voting Preferred Stock, $.025 Non-Cumulative Dividend". A corresponding certificate of issuance was filed with the State of Nevada. Holders of these shares are entitled to a noncumulative, preferential dividend of $.025 per share per annum, when declared by the board of directors, payable from the surplus, net profits or assets of the Company. At any time after September 30, 1999, the board of directors of the Company may elect to redeem this Convertible Voting Preferred Stock at a redemption price of $0.50 per share. Each share of this Convertible Voting Preferred Stock shall be convertible into five shares of the common stock of the Company. Under the conversion privileges of these shares, the holder may elect to convert 20% of the Convertible Voting Preferred Stock prior to September 30, 1995 and an additional 20% every year thereafter until September 30, 1999. The right to convert shall terminate if not exercised before September 30, 1999. At June 30, 2001, the remaining 41,499 preferred shares are no longer convertible. The Company has the right to redeem these shares for $0.50 per share. Each share of this Convertible Voting Preferred Stock shall be entitled to one shareholder vote. These 2,074,521, shares were issued pursuant to the acquisition by the Company of Simmons Oil Company, Inc. and its subsidiaries. One share of Convertible Voting Preferred Stock was issued for every four shares of common stock of Simmons Oil Company, Inc. During the years ended June 30, 2000, 1999 and 1998, holders of shares of the Convertible Voting Preferred Stock elected to convert their shares into common stock of the Company in accordance with the conversion provisions. Accordingly, 60,496 shares of convertible voting preferred stock were converted into 302,500 shares of the Company's common stock in 2000, 433,467 shares of convertible voting preferred stock were converted into 2,167,330 shares of the Company's common stock in 1999 and 540,096 shares of convertible voting preferred stock were converted into 2,700,485 shares of the Company's common stock in 1998 (Note 6). During the year ended June 30, 2000, the Company issued 400,000 Series F Convertible Preferred Shares for total proceeds of $400,000. These 400,000 preferred shares were later converted into 1,400,000 shares of common stock at a conversion ratio of 3.5 common shares. NOTE 6 - COMMON STOCK During the year ended June 30, 1999, 433,466 shares of convertible voting preferred stock were converted into 2,167,330 shares of common stock. During the year ended June 30, 2000, 60,496 shares of convertible voting preferred stock were converted into 302,500 shares of common stock, and 400,000 shares of Series F convertible preferred stock were converted into 1,400,000 shares of common stock (see Note 5). F-25 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 6 - COMMON STOCK (Continued) As discussed in Note 2, an unrelated foreign entity assumed the investment obligations of another entity in December 1995. In January 1996, the Companies received $500,000 from that foreign entity. In accordance with the terms of the original and assumption agreement, the $500,000 should be applied toward the acquisition of 500,000 shares of the Company's common stock. This foreign entity defaulted on the performance of the funding commitments and the 500,000 shares of common stock associated with this transaction were canceled. During the year ended June 30, 1998, the Company entered into a settlement agreement with the original investors of the $500,000 and the Company issued 350,000 shares of its common stock in a preliminary settlement. 252,050 of these shares were subsequently canceled during the year ended June 30, 1999. During the year ended June 30, 1999, the Company sold 1,663,572 shares of common stock for which the Company received $3,855,000 at an average of $2.32 per share. The Company incurred costs associated with the sale of common stock of $333,135 which has been reflected as a reduction on capital in excess of par value in the accompanying consolidated financial statements. 194,000 shares of common stock were issued in conjunction with the buyout of certain joint venture interests in oil and gas properties during the year ended June 30, 1999. These shares have been valued at $3.50 per share or $678,999. 39,441 shares of common stock were issued in lieu of outstanding accounts payable during the year ended June 30, 1999. These shares have been valued at $3.51 per share or $138,464. In addition, 138,223 shares of common stock were issued for services rendered. These shares have been valued at $2.18 per share or $301,168. In conjunction with a settlement arrangement, the Company canceled 252,050 shares of common stock originally issued. During the year ended June 30, 2000, the Company issued 133,334 shares of common stock at $0.75 per share for a total of $100,000. As discussed in Note 3, the Company issued 583,659 shares of common stock valued at $270,002 as a result of a penalty fee related to a late Registration filing for certain shares of stock. During the year ended June 30, 2001, the Company issued 13,780,083 shares of common stock and 946,929 warrants for $0.30 per share for a total of $4,134,025. Offering costs of $478,502 were paid or accrued related to the 13,780,083 shares issued. As discussed in Note 3, the Company issued 711,740 shares of common stock valued at $360,000 as a result of a penalty fee related to a late registration filing for certain shares of stock. F-26 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 6 - COMMON STOCK (Continued) During the year ended June 30, 2001, the Company entered into certain Warrant Exchange Agreements. Pursuant to the agreements, the Company issued 2,197,500 shares of common stock valued at $1,758,000 in exchange for the cancellation of 6,680,000 warrants. The shares issued were valued at $0.80 per share based upon the trading price of the shares on the date they were issued. The Company also issued a total of 6,050,000 shares of common stock valued at $2,613,998 to certain directors of the Company in lieu of services rendered and expenses paid on behalf of the Company. In addition, the Company issued 1,293,661 shares of common stock in conversion of outstanding debt totaling $521,686, 457,500 shares of common stock for services rendered totaling $198,600 and 4,692,746 shares of common stock in conversion of debt and services rendered totaling $3,097,211. Pursuant to a court decree and settlement agreement signed during the year ended June 30, 2001, the Company canceled a total of 321,146 shares of common stock. As part of the settlement agreement, outstanding debt of $235,000 was also released. Accordingly, the transaction and cancellation of shares was recorded as contributed capital of $235,000. The Company also converted 4,168,300 shares of common stock owned by certain officers of the Company to a convertible subordinated promissory note in the amount of $1,094,290 (Note 3), bearing interest at 6% per annum. The promissory note is convertible into common shares of the Company at a conversion rate of $0.43 per share, adjusted accordingly for any stock splits or dividends effected by the Company subsequent to the original issued date of the note. NOTE 7 - COMMON STOCK WARRANTS The Company applies Accounting Principles Board ("APB") 25, "Accounting for Stock Issued to Employees," and related interpretations in accounting for all stock option plans. Under APB 25, compensation cost is recognized for stock options and warrants granted to employees when the option/warrant price is less than the market price of the underlying common stock on the date of grant. FASB Statement 123, "Accounting for Stock-Based Compensation" ("SFAS No. 123") requires the Company to provide proforma information regarding net income and net income per share as if compensation costs for the Company's stock option plans and other stock awards had been determined in accordance with the fair value based method prescribed in SFAS No. 123. The Company estimates the fair value of each stock award at the grant date by using the Black-Scholes option pricing model. Under the provisions of SFAS No. 123 for warrants granted to employees, the Company's net loss for the years ended June 30, 2001, 2000 and 1999 would have been unchanged from the reported net loss. F-27 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 7 - COMMON STOCK WARRANTS (Continued) However, under the provisions of SFAS No. 123 for non-employees, the Company recorded additional expense of $-0-, $884,880, and $122,400 for the years ended June 30, 2001, 2000 and 1999 as a result of warrants granted to non-employees based upon the Black-Scholes pricing model. Under the Black-Scholes method, the U.S. treasury rate was used as the risk-free interest rate, the expected life of the warrants was 2 months to seven years, the volatility used was based upon the historical price per share of shares sold, and there were no expected dividends. A summary of the status of the Company's stock warrants as of June 30, 2001 and changes during the year ended June 30, 2001 are presented below:
WEIGHTED WEIGHTED AVERAGE AVERAGE STOCK EXERCISE GRANT DATE WARRANTS PRICE FAIR VALUE ------------ ----------- ----------- Outstanding, June 30, 2000 11,035,000 $ 2.65 $ 0.06 Granted 796,929 0.36 0.00 Expired/Canceled (7,955,000) 3.08 0.00 Exercised - - - ------------ ----------- ----------- Outstanding, June 30, 2001 3,876,929 1.31 0.16 ------------ ----------- ----------- Exercisable, June 30, 2001 3,876,929 $ 1.31 $ 0.16 ============ =========== ===========
The following summarizes the exercise price per share and expiration date of the Company's outstanding warrants to purchase common stock at June 30, 2001;
NUMBER OF SHARES EXPIRATION DATE EXERCISE PRICE ---------------- --------------- -------------- 150,000 9/17/04 $ 0.360 50,000 11/4/04 2.310 80,000 5/1/05 1.250 80,000 6/18/05 3.970 168,530 7/24/05 0.360 28,166 7/29/05 0.360 25,000 8/4/05 4.000 187,333 9/29/05 0.360 22,500 10/1/05 0.360 135,000 12/9/05 4.030 390,400 1/5/06 0.360 450,000 1/6/06 3.000 185,000 5/4/06 1.560 125,000 5/17/06 1.500 1,600,000 12/27/06 1.000 75,000 2/14/07 0.750 125,000 3/17/07 0.500 ----------- Balance outstanding, June 30, 2001 3,876,929 ===========
F-28 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 7 - COMMON STOCK WARRANTS (Continued) In conjunction with the sale of common stock discussed in Note 6, the Company has issued warrants for 9,325,000 shares of common stock. These warrants have been issued with a grant date of August 12, 1996, exerciseable at $1.50 per share until June 1, 1998 at which time the exercise price increased to $3.00 per share until August 12, 1999, at which time the warrants expired. During the year ended June 30, 1998, a total of 2,610,000 of these warrants were exercised at $1.50 per share, leaving a remaining balance of 6,715,000 warrants, exercisable at $3.00 per share, unexercised at June 30, 1998. An additional 135,000 of these warrants were exercised at $3.00 per share during the year ended June 30, 1999. The remaining balance of 6,580,000 warrants exercisable at $3.00 per share expired unexercised on August 12, 1999. During the year ended June 30, 1998, the Company established a three member "Disclosure Committee" comprised of certain of the Company's attorneys and market relations consultants. Each of these parties have received 50,000 warrants, making a total of 150,000 warrants issued, exercisable at $1.25 per share which expire in May, 2005. Also during the year ended June 30, 1998, the Company engaged certain technical and market relations professional consultants in various contracts. In conjunction with retaining their services, the Company issued 200,000 warrants ranging in exercise prices from $2.31 to $3.97 per share which expire in May, 2005. During the year ended June 30, 1999, the Company issued 845,000 warrants ranging in exercise prices from $1.50 to $4.03 per share. These warrants were issued to various consultants for services rendered and to certain employees as a bonus. During the year ended June 30, 2000, the Company issued 225,000 warrants ranging in exercise prices from $0.75 to $1.00 per share. These warrants were issued to various consultants for services rendered. In addition, the Company issued 1,500,000 warrants exercisable at $1.00 per share which expired unexercised after 60 days. The Company also issued an additional 1,600,000 warrants exercisable at $1.00 per share. 400,000 expire on September 15, 2001, 400,000 expire on September 15, 2002, 400,000 expire on September 15, 2003 and 400,000 expire on September 15, 2004. During the year ended June 30, 2001, the Company granted a total of 796,929 warrants to purchase common stock at an exercise price of $0.36 per share to the placement agent pursuant to the issuance of common shares for cash. As discussed in Note 6, the Company issued 2,197,500 shares of common stock during the year ended June 30, 2001 in exchange for the cancellation of 6,680,000 warrants. An additional 1,275,000 warrants were canceled during the year, bringing the total outstanding warrants at June 30, 2001 at 3,876,929. F-29 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 8 - COMMITMENTS AND CONTINGENCIES As discussed in Note 2, the Companies defaulted on the payment of the Drilling Investor Notes due and payable September 15, 1995 related to the acquisition of oil and gas leases in Harris County, Texas. These notes were secured by a financial guarantee bond, but there is no assurance that the bond can be enforced. The ultimate effect on the Companies and outcome of the satisfaction of this obligation cannot be determined. The Company leases office space in Simonton, Texas at a monthly cost of $1,033 plus utilities. The lease expired during November 2000 at which time the Company leased the space on a month-to-month basis at $1,200 per month. The Companies have minimum lease and royalty obligations associated with their oil and gas properties of $77,300 annually, see also Note 2. During the year ended June 30, 1997, the Board of Directors authorized the establishment of a Management Royalty Pool equal to 1% of the revenues from domestic oil and gas production. The beneficiaries and their ownership in this pool are subject to variance based upon certain performance criterion. NOTE 9 - SUBSEQUENT EVENTS Subsequent to June 30, 2001, the following significant transactions occurred: a. As discussed in Note 2, on August 11, 2001, the Companies were awarded a new Concession Agreement and Exploratory License in Pakistan known as the Yasin Concession, in the Sindh Providence of Pakistan. The Company has committed $2,400,000 over the next three years to explore and test the concession. The Company has also bid and applied for two additional Pakistan concessions in the same area. The Bahadurpur Concession is east of the Yasin Concession and the Miro Khan Concession is west of the Yasin Concession. The Jacobabad Concession was released to the Pakistan government in favor of the newly awarded concession. b. As discussed in Note 2, effective July 1, 2001, the Company finalized its settlement with Northern Lights Energy, Ltd. and Northern Lights relinquished its purchase rights in the U.S. operations. Northern Lights also accepted a negotiated sum of $285,000 as full payment of the remaining deposit owed. The Company has no further plans to sell its U.S. properties. c. The Company entered into a Purchase and Sale Agreement with Zaber Investments, LLC, a company controlled by an officer of the Company, to sell a 10% interest in certain operating wells and assets in the United States for $300,000. The proceeds of this agreement were used to make the settlement payment to Northern Lights, as mentioned above. d. In August 2001, the Company moved its corporate headquarters and signed a lease agreement for its new office space. The monthly cost is $2,391 and the lease expires on August 31, 2004. e. The Company replaced most of its corporate officers and management and has begun restructuring the focus and objectives of the Company. THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES Notes to the Consolidated Financial Statements F-30 June 30, 2001, 2000 and 1999 (As Restated - See Note 10) NOTE 10 - CORRECTION OF CERTAIN ERRORS The Company has restated its consolidated financial statements to reflect adjustments made to properly record the capitalized costs related to the dry holes in Pakistan, to eliminate the impairment reserve on the U.S. properties and to properly record warrants granted during the years ended June 30, 2000 and 1999 pursuant to the Black-Scholes pricing model. These adjustments decreased the previously reported net loss for the year ended June 30, 2000 by $9,922,073 but increased the net loss for the year ended June 30, 1999 by $5,216,832. A summary of the changes is as follows:
ORIGINALLY AS REPORTED RESTATED DIFFERENCE -------------- ------------- ------------- June 30, 1999 Net loss $ (754,349) $ (5,971,181) $ (5,216,832) Loss per share (0.024) (0.19) (0.166) Total assets 23,456,438 15,814,790 (7,641,648) Total stockholders' equity 21,362,502 13,720,854 (7,641,648) June 30, 2000 Net loss $ (12,283,248) $ (2,361,175) $ 9,922,073 Loss per share (0.365) (0.07) 0.295 Total assets 14,484,273 17,649,578 3,165,305 Total stockholders' equity 9,790,323 12,955,628 3,165,305
F-31 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES S.F.A.S. 69 Supplemental Disclosures (Unaudited) June 30, 2001 and 2000 (As Restated - See Note 10) S.F.A.S. 69 SUPPLEMENTAL DISCLOSURES (1) Capitalized Costs Relating to Oil and Gas Producing Activities
JUNE 30, ------------------------------------- 2001 2000 ---------------- ----------------- Proved oil and gas producing properties and related lease and well equipment $ 439,785 $ 1,481,220 Accumulated depreciation and depletion (690,864) (386,857) ---------------- ----------------- Net Capitalized Costs $ (251,079) $ 1,094,363 ================ =================
(2) Costs Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities
FOR THE YEARS ENDED JUNE 30, ------------------------------------- 2001 2000 ---------------- ----------------- Acquisition of Properties Proved $ - $ - Unproved - - Exploration Costs 3,549,675 1,249,575 Development Costs 439,785 1,481,220
The Company does not have any investments accounted for by the equity method. (3) Results of Operations for Producing Activities
FOR THE YEARS ENDED JUNE 30, ------------------------------------- 2001 2000 ---------------- ----------------- Sales $ 1,806,335 $ 1,823,276 Production costs (811,757) (592,502) Depreciation and depletion (690,864) (386,857) ---------------- ----------------- Results of operations for producing activities (excluding corporate overhead and interest costs) $ 303,714 $ 843,917 ================ =================
F-33 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES S.F.A.S. 69 Supplemental Disclosures (Unaudited) June 30, 2001 and 2000 (As Restated - See Note 10) S.F.A.S. 69 SUPPLEMENTAL DISCLOSURES (CONTINUED) (4) Reserve Quantity Information
Oil Gas BBL MCF ----------- ----------- Proved developed and undeveloped reserves: Balance, June 30, 2000 3,000,428 - Change in estimates (322,791) - Production (62,060) - ----------- ----------- Balance, June 30, 2001 2,615,577 - =========== =========== Proved developed reserves: Oil Gas BBL MCF ----------- ----------- Beginning of the year ended June 30, 2001 702,508 - End of the year ended June 30, 2001 483,247 -
During the year ended June 30, 2001, the Company had reserve studies and estimates prepared on the various properties acquired and developed. The difficulties and uncertainties involved in estimating proved oil and gas reserves makes comparisons between companies difficult. Estimation of reserve quantities is subject to wide fluctuations because it is dependent on judgmental interpretation of geological and geophysical data. (5) Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves The standardized measure of discounted future net cash flows is computed by applying year-end prices of oil and gas (with consideration of price changes only to the extent provided by contractual arrangements) to the estimated future production of proved oil and gas reserves, less estimated future expenditures (based on year-end costs) to be incurred in developing and producing the proved reserves, less estimated future income tax expenses (based on year-end statutory tax rates, with consideration of future tax rates already legislated) to be incurred on pretax net cash flows less tax basis of the properties and available credits, and assuming continuation of existing economic conditions. The estimated future net cash flows are then discounted using a rate of 10 percent a year to reflect the estimated timing of the future cash flows. F-34 THE AMERICAN ENERGY GROUP, LTD. AND SUBSIDIARIES S.F.A.S. 69 Supplemental Disclosures (Unaudited) June 30, 2001 and 2000 (As Restated - See Note 10) S.F.A.S. 69 SUPPLEMENTAL DISCLOSURES (CONTINUED) (5) Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves (Continued) At June 30, 2001
THE AMERICAN ENERGY GROUP LTD. AND SUBSIDIARIES --------------- Future cash inflows $ 66,906,486 Future production and development costs (23,024,705) --------------- Future net inflows before income taxes 43,881,781 Future income tax expense (4,342,494) --------------- Future net cash flows 39,539,287 10% annual discount for estimated timing of cash flows (15,093,173) --------------- Standardized measure of discounted future net cash flows $ 24,446,114 ===============
The above schedules relating to proved oil and gas reserves, standardized measure of discounted future net cash flows and changes in the standardized measure of discounted future net cash flows have their foundation in engineering estimates of future net revenues that are derived from proved reserves and with the assumption of current pricing and current costs of production for oil and gas produces in future periods. These reserve estimates are made from evaluations conducted by Carl F. Pomeroy and Don Jacks, P.E. registered professional engineers, of such properties and will be periodically reviewed based upon updated geological and production data. Estimates of proved reserves are inherently imprecise. The above standardized measure does not include any restoration costs due to the fact the Company does not own the land. Subsequent development and production of the Company's reserves will necessitate revising the present estimates. In addition, information provided in the above schedules does not provide definitive information as the results of any particular year but, rather, helps explain and demonstrate the impact of major factors affecting the Company's oil and gas producing activities. Therefore, the Company suggests that all of the aforementioned factors concerning assumptions and concepts should be taken into consideration when reviewing and analyzing this information. F-35