___________________________________________________________________________
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
__________________________________
FORM 10-KSB
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
FOR THE FISCAL YEAR ENDED JUNE 30, 2000
COMMISSION FILE NUMBER 0-28814
ASPEN GROUP RESOURCES CORPORATION
(Name of Small Business Issuer as Specified in Its Charter)
Yukon, Canada 98-0164357
(State or other Jurisdiction (I.R.S. Employer
of Incorporation or Organization) Identification No.)
3300 Bank One Center
100 North Broadway
Oklahoma City, OK 73102
(Address of Principal Executive Offices) (Zip Code)
(405) 606-8500
(Issuer's Telephone Number, Including Area Code)
Securities registered under Section 12(b) of the Exchange Act: None
Securities registered under Section 12(g) of the Exchange Act:
Common Stock, without par value
(Title of Class)
Check whether the Issuer (1) has filed all reports required to be filed by
Section 13 or 15 (d) of the Exchange Act during the past 12 months (or for such
shorter period that the Issuer was required to file such reports) and (2) has
been subject to such filing requirements for the past 90 days.
Yes X No
Check if there is no disclosure of delinquent filers in response to Item
405 of Regulation S-B contained in this form, and no disclosure will be
contained, to the best of the Issuer's knowledge, in definitive proxy or
information statements incorporated by reference in Part III of this Form 10-KSB
or any amendment to this Form 10-KSB. [ ]
The Issuer's revenues for the fiscal year ended June 30, 2000, were
$3,481,718.
The Issuer had 127,159,006 shares of common stock outstanding as of
September 11, 2000.
The aggregate market value of the voting and non-voting common stock held
by non-affiliates of the Issuer, computed by reference to the average bid and
asked prices of such common stock as of September 11, 2000, was $31,184,627.
DOCUMENTS INCORPORATED BY REFERENCE
Proxy Statement for the 2000 Annual Meeting of Shareholders - Part III
_____________________________________________________________________________
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2000 ANNUAL REPORT (S.E.C. FORM 10-KSB)
INDEX
Securities and Exchange Commission
Item Number and Description
PART I
Page
Item 1 Business .............................................. 4
Item 2 Properties............................................. 11
Item 3 Legal Proceedings ..................................... 14
Item 4 Submission of Matters to a Vote of Security Holders ... 14
PART II
Item 5 Market for the Company's Common Stock and Related
Stockholder Matters ................................... 14
Item 6 Management's Discussion and Analysis or Plan of
Operation ............................................. 17
Item 7 Consolidated Financial Statements and Unaudited
Supplemental Information .............................. 20
Item 8 Changes in and Disagreements with Accountants on
Accounting and Financial Disclosure ................... 40
PART III
Item 9 Directors, Executive Officers, Promoters and Control
Persons of the Issuer; Compliance With Section 16(a)
of the Exchange Act ..................................... 40
Item 10 Executive Compensation .................................. 40
Item 11 Security Ownership of Certain Beneficial Owners and
Management .............................................. 40
Item 12 Certain Relationships and Related Transactions .......... 40
PART IV AND SIGNATURES AND EXHIBIT INDEX
Item 13 Exhibits, Financial Statements and Reports on Form
8-KSB .................................................. 40
Signatures ........................................................ 41
Exhibits Index .................................................... 42
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DEFINITIONS
As used in this document:
"Mcf" means thousand cubic feet
"MMcf" means million cubic feet
"Bcf" means billion cubic feet
"MMBtu" means million British thermal units, a measure of heating value
"Bbl" means barrel
"Mbo" means thousands of barrels of oil
"MMBbls" means million barrels
"Boe" means equivalent barrels of oil
"Mboe" means thousand equivalent barrels of oil
"MMBoe" means million equivalent barrels of oil
"Oil" includes crude oil and condensate
"NGLs" means natural gas liquids
"Bopd" means barrels of oil per day
DISCLOSURE REGARDING FORWARD-LOOKING STATEMENTS
THIS REPORT INCLUDES "FORWARD-LOOKING STATEMENTS" WHITIN THE MEANING OF
SECTION 27A OF THE SECURITIES ACT OF 1933, AS AMENDED, AND SECTION 21E OF THE
SECURITIES EXCHANGE ACT OF 1934, AS AMENDED, ALL STATEMENTS OTHER THAN
STATEMENTS OF HISTORICAL FACTS INCLUDED OR INCORPORATED BY REFERENCE IN THIS
REPORT, INCLUDING, WITHOUT LIMITATION, STATEMENTS REGARDING THE COMPANY'S FUTURE
FINANCIAL POSITION, BUSINESS STRATEGY, BUDGETS, PROJECTED COSTS AND PLANS AND
OBJECTIVES OF MANAGEMENT FOR FUTURE OPERATIONS, ARE FORWARD-LOOKING STATEMENTS.
IN ADDITION, FORWARD-LOOKING STATEMENTS GENERALLY CAN BE IDENTIFIED BY THE USE
OF FORWARD-LOOKING TERMINOLOGY SUCH AS "MAY," "WILL," "EXPECT," "INTEND,"
"PROJECT," "ESTIMATE," "ANTICIPATE," BELIEVE," OR "CONTINUE" OR THE NEGATIVE
THEREOF OR VARIATIONS THEREON OR SIMILAR TERMINOLOGY. ALTHOUGH THE COMPANY
BELIEVES THAT THE EXPECTATIONS REFLECTED IN SUCH FORWARD-LOOKING STATEMENTS ARE
REASONABLE, IT CAN GIVE NO ASSURANCE THAT SUCH EXPECTATIONS WILL PROVE TO HAVE
BEEN CORRECT. IMPORTANT FACTORS THAT COULD CAUSE ACTUAL RESULTS TO DIFFER
MATERIALLY FROM THE COMPANY'S EXPECTATIONS ("CAUTIONARY STATEMENTS") ARE
DISCLOSED UNDER "ITEM 1. BUSINESS - RISK FACTORS" AND ELSEWHERE IN THIS REPORT.
ALL SUBSEQUENT WRITTEN AND ORAL FORWARD-LOOKING STATEMENTS ATTRIBUTABLE TO THE
COMPANY, OR PERSONS ACTING ON ITS BEHALF, ARE EXPRESSLY QUALIFIED IN THEIR
ENTIRETY BY THE CAUTIONARY STATEMENTS. THE COMPANY ASSUMES NO DUTY TO UPDATE OR
REVISE ITS FORWARD-LOOKING STATEMENTS BASED ON CHANGES IN INTERNAL ESTIMATES OR
EXPECTATIONS OR OTHERWISE.
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PART I
ITEM 1. BUSINESS
General
Aspen Group Resources Corporation (referred to herein as either "Aspen" or
the "Company" and formerly known as "Cotton Valley Resources Corporation") is an
independent energy company engaged in the acquisition, exploitation,
development and operation of oil and gas properties with a geographic focus in
major oil and gas producing regions in the United States. The Company was
incorporated in the Province of Ontario, Canada, originally as Cotton Valley
Energy Limited, on February 15, 1995. From its inception through October 11,
1999, the Company was a development stage company engaged principally in
organization and capitalization activities and had not generated material net
revenues from operations.
On June 30, 1995 in a one-for-one share and warrant exchange, the Company
acquired all the issued and outstanding shares of Cotton Valley Energy
Corporation ("CV Energy"), a Nevada corporation. On June 14, 1996, the
Company completed an amalgamation with Arjon Enterprises, Inc. ("Arjon"), a
Province of Ontario, Canada corporation. As a result of the Arjon amalgamation,
the Company's name was changed to Cotton Valley Resources Corporation and its
shares of Common Stock began trading through the Canadian Dealing Network.
Arjon was a public Canadian company formed more than 50 years ago to operate a
gold mine. At the time of the amalgamation, Arjon had not engaged in business
for more than 25 years, it had no material liabilities, and its only asset was a
Cotton Valley Energy Limited debenture in the amount of $146,300. The
shareholders of Arjon received 686,551 shares of Common Stock in the
amalgamation.
In 1997 and 1998, the Company acquired and operated the N.E. Alden Field
oil and gas properties in Caddo County, Oklahoma and the oil and gas Means Unit
in Andrews County, Texas, through various subsidiaries. During December
1997 the Company sold $4.32 million of its 7% secured convertible debentures
(the "Convertible Debentures") to a group of nine investors (the "Holders").
Approximately $1.5 million of the proceeds were used to purchase oilfield
service equipment for the Mustang Service Companies.
Restructuring
During the fiscal year 1999, the Company experienced cash flow difficulty
as a result of a decline in oil and gas prices as well as the significant
reduction in demand for oilfield equipment and services. The Company was also
unable to complete the effectiveness of a registration statement under the
United States Securities and Exchange Act of 1933 (the "Exchange Act") for the
securities underlying certain Convertible Debentures and remained, for much of
the fiscal year of 1999, in default under the terms of the Convertible
Debentures. In response to these conditions, the Company, during the first
fiscal quarter, curtailed proposed capital projects and other business
operations and reduced its staff from over 40 employees to two field employees
on payroll plus two officers who worked throughout the year for deferred
salaries.
During January through April 1999 the Company entered into agreements with
over 50 vendors to whom it owed more than $750,000 to eliminate the debt through
the issuance of shares of Common Stock. As of June 30, 1999, the Company had
issued 4,000,000 shares of Common Stock at $0.25 per share reflecting the
reduction of approximately $1,300,000 of liabilities.
Since September 1998, the Company had been unable to draw development funds
under the Means Credit facility and consequently severely curtailed its efforts
at the Means Unit. As of September 23, 1999, the Company was in
default under the terms of the Means Credit facility for non-payment of
interest. On May 23, 2000, the Company entered into a release and settlement
with Triassic Energy Partners, L.P. in which Triassic released all claims
against the Company and its mortgage on the Means Field Properties in exchange
for a cash payment of $994,723 and the conveyance to Triassic of a one-half
percent override in the Means Field Properties.
On March 26, 1999 the Company assigned to the Holders of its then
outstanding $4.22 million of Convertible Debentures, substantially all of its
assets having a book value of approximately $13 million (the "Transferred
Assets") in exchange for a release from all obligations, including repayment
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and/or conversion, under the Convertible Debentures. Pursuant to an agreement
for conveyances in lieu of foreclosure between the Company, its subsidiaries
and the Holders, the Company is entitled to the return of all remaining
Transferred Assets and remaining cash from the sale of Transferred Assets once
the Holders have received $4.22 million (plus interest and certain expenses,
less revenues and less 50% of the proceeds from sales of shares of Common Stock
transferred to the Holders in payment of defaulted interest and as consideration
for waiver of certain defaults on the Convertible Debenture) from the sale of
Transferred Assets. In connection with the transaction the Company recorded a
pre-tax loss on disposition of assets of $9,807,576. On March 1, 2000 the
Company entered into a release and settlement agreement with the Holders in
which both parties mutually released all past, present and future claims against
each other.
Acquisitions
East Wood Acquisition. On September 16, 1999 (but effective July 1, 1999),
the Company acquired 50% of the outstanding common stock of East Wood Equity
Venture, Inc. upon the delivery of 25,000,000 shares of Common Stock and the
issuance of 21,230,897 special warrants where each Special Warrant was
convertible into one share of Common Stock immediately upon authorization of the
shareholders of the Company for the issuance of such additional shares of Common
Stock. On February 28, 2000, the shareholders of the Company approved the
issuance of the additional shares and the special warrants were converted into
shares of Common Stock. On February 28, 2000, the Company purchased the
remaining 50% of the outstanding capital stock of East Wood in exchange for the
issuance of 26,230,897 shares of Common Stock and the Company's promissory note
for $3,000,000.
East Wood is principally engaged in the business of the acquisition,
exploration, development, operation and sale of oil and gas properties. At the
time of the acquisition, the main concentration of East Wood's properties were
in Oklahoma with 335 wells and Texas with 30 wells. Approximately 81% are gas
wells and 19% are oil wells. Based on the most recent reserve reports, East
Wood's interest in its producing properties had undiscounted estimated proved
net producing reserves of over 475,000 barrels and 20 billion cubic feet of gas.
The proved undeveloped reserves have been estimated by engineers and geologists
to contain more than 60 billion cubic feet of gas and almost 1,500,000
barrels of oil.
Fer-scher Acquisition. On April 20, 2000 the Company acquired ownership
interests in 35 Oil and Gas Producing Properties and 239 net Mineral Acres in
exchange for the Company issuing 940,000 shares of restricted Common
Stock.
Briscoe Acquisition. Effective May 1, 2000, Aspen acquired a 55% undivided
interest in 171 properties located in 21 counties in Oklahoma, Texas, and Kansas
for $3,500,000. The average working interest is 49.77% and the average
revenue interest is 40.16%. Aspen operates all of the wells. The operations
overhead charges are estimated to provide additional income to Aspen in the
range of $30,000 per month.
Most of the wells were drilled in the late 70's and early 80's. The seller
had shut in several wells due to low prices in 1998-1999 and had not put them
back into production. The Company believes that it may be able to restore
several wells to profitable operations. Restorations will include pumping unit
installations, casing leak repairs, and other mechanical remediation. Several
wells appear capable of enhancement. Many wells are in multiple zone fields
that may provide additional development as studies are made. The Company
estimates that there are 12 additional drilling locations on the acreage held by
production.
The existing gas contracts are old, expiring "net back" contracts that are
being renegotiated. If successful, renegotiations to current gas prices should
add to the value of this acquisition.
This acquisition added 245 Mbo of oil PDP oil reserves and 7,536 Mmcf of
net gas reserves for an acquisition cost of $3.10/ Net Boe.
El Dorado Field Acquisitions. Aspen acquired a significant interest in
this field over the past six months through three separate acquisitions. The
total of the acquisitions increased Aspen's proven oil reserves by over
1,600,000 Bbls for an acquisition cost of $2.60/Bbl, including future
development costs expected to be $1.125 million. The leases are
strategically located within the mature El Dorado field. Discovered in 1915,
this field continues to be a major producing area of the United States. Several
producing horizons yet to be fully developed provide potential long-term
income source for the Company.
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Other Acquisitions. Besides the larger acquisitions mentioned, Aspen
consummated six additional acquisitions during the past year. Effective January
1, 2000, Aspen closed an acquisition from EDB Oil Properties for
$313,718 in stock. The acquisition included 49 producing, operated wells all in
Oklahoma. Current estimated net reserves are 397,239 Boe. Effective the same
date, Aspen closed smaller projects with SGH, Emmons Sebenius, Red
Terra, and Fer-scher. The total allocated cost of these four projects was
$562,105 in cash and stock. The current proved reserves for these projects is
60,334 Boe for an acquisition cost of $4.37 per Bbl after considering the value
for undeveloped acreage and underbalanced production acquired with the
properties.
Credit Facility
On April 28, 2000, Local Oklahoma Bank, N.A. loaned Aspen Energy Group,
Inc. amounts up to $25,000,000, as set forth in a Credit Agreement of that date.
The loan is subject to, and limited by, a borrowing base based primarily on the
value of the Company's oil and gas properties. The commitment of Local reduces
over time based upon a monthly commitment reduction. Currently, the borrowing
base is $12,160,000 and the amount currently outstanding is $11,803,000. The
loan accrues interest at a rate based upon Chase Manhattan Prime plus one half
of one percent per annum. The purposes of the loan were to finance the
Company's settlement with Triassic and to provide financing for the acquisition
and development of oil and gas properties.
Risk Factors
Holders of the Common Stock and future investors in the Company should be
aware of the following factors in evaluating their investment in Aspen.
Limited Operating History; Capital Intensive Business; Need for Additional
Funds. From its inception in February 1995 through June 30, 1999, the Company
was engaged principally in organization and capitalization activities and did
not generate material net revenues from operations. The Company's business is
highly capital intensive requiring continuous development and acquisition of oil
and gas reserves. In addition, capital is required to operate and expand
the Company's oil field operations and purchase equipment. At June 30, 2000,
the Company had a working capital deficit of approximately $3.7 million. The
Company anticipates, based on its currently proposed plans and assumptions
relating to its operations, including borrowings from its line of credit,
together with cash expected to be generated from operations, that it will be
able to meet its cash requirements for at least the next 12 months. However,
if such plans or assumptions change or prove to be inaccurate, the Company could
be required to seek additional financing sooner than currently anticipated. The
Company has no commitments to obtain any additional debt or equity
financing and there can be no assurance that additional funds will be available,
when required, on terms favorable to the Company. Any future issuance's of
equity securities would likely result in dilution to the Company's then existing
shareholders while the incurring of additional indebtedness would result in
increased interest expense and debt service changes. See "Management's
Discussion and Analysis or Plan of Operations."
History of Losses. Although the Company's operations were profitable in
fiscal year 2000, the Company has historically incurred losses, including a loss
before income tax benefits of $13,324,086 in 1999. The Company's accumulated
deficit as of June 30, 2000 was $14,984,725. The Company has historically
funded its operating losses, acquisitions and expansion costs primarily through
a combination of private offerings of debt and equity securities, and proceeds
from the exercise of options and warrants.
Significant Capital Expenditures Necessary for Undeveloped Properties. The
Company has substantial oil and gas reserves which are classified as Proved
Undeveloped Reserves, meaning very little production currently exists.
Recovery of the Company's Proved Undeveloped Reserves will require significant
capital expenditures. Management estimates that aggregate capital expenditures
of approximately $17 million will be required to fully develop these
reserves, of which $7 million is expected to be incurred during the next 12
months. No assurance can be given that the Company's estimates of capital
expenditures will prove accurate, that its financing sources will be sufficient
to fully fund its planned development activities or that development activities
will be either successful or in accordance with the Company's schedule.
Additionally, any significant decrease in oil and gas prices or any significant
increase in the cost of development could result in a significant reduction in
the number of wells drilled and/or reworked. No assurance can be given that any
wells will produce oil or gas in commercially profitable quantities.
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Exploration and Development Risks; Waterflood Projects. The Company
intends to increase its development activities and development drilling of oil
and gas reserves. Even though development drilling carries less risk than
exploration drilling, there is risk that production will not be obtained and/or
that production will be insufficient to recover drilling and completion costs.
The cost of drilling, completing and operating wells is often uncertain. The
Company's drilling operations may be curtailed, delayed or canceled as a result
of numerous factors, including title problems, weather conditions, compliance
with governmental requirements and shortages or delays in the delivery of
equipment. Furthermore, completion of a well does not assure a profit on the
investment or a recovery of drilling, completion and operating costs.
There are certain risks associated with secondary recovery operations,
especially the use of waterflooding techniques, and drilling activities in
general. Part of the Company's inventory of development prospects consists of
waterflood projects. Waterflooding involves significant capital expenditures
and uncertainty as to the total amount of secondary reserves that can be
recovered. In waterflood operations, there is generally a delay between the
initiation of water injection into a formation containing hydrocarbons and any
increase in production that may result. The operating cost per unit of
production of waterflood projects is generally higher during the initial phases
of such projects due to the purchase of injection water and related costs, as
well as during the later stages of the life of the project as production
declines. The degree of success, if any, of any secondary recovery program
depends on a large number of factors, including the porosity of the formation,
the technique used and the location of injector wells.
Volatility of Oil and Gas Prices. The Company's revenues, profitability
and the carrying value of its oil and gas properties are substantially dependent
upon prevailing prices of, and demand for, oil and gas and the costs of
acquiring, finding, developing and producing reserves. The Company's ability to
maintain or increase its borrowing capacity, to repay current or future
indebtedness, and to obtain additional capital on favorable terms is also
substantially dependent upon oil and gas prices. Historically, the markets for
oil and gas have been volatile and are likely to continue to be volatile in the
future. Prices for oil and gas are subject to wide fluctuations in response to:
(i) relatively minor changes in the supply of, and demand for, oil and gas; (ii)
market uncertainty; and (iii) a variety of additional factors, all of
which are beyond the Company's control. These factors include domestic and
foreign political conditions, the price and availability of domestic and
imported oil and gas, the level of consumer and industrial demand, weather,
domestic and foreign government relations, the price and availability of
alternative fuels and overall economic conditions. Furthermore, the
marketability of the Company's production depends in part upon the availability,
proximity and capacity of gathering systems, pipelines and processing
facilities. Volatility in oil and gas prices could affect the Company's ability
to market its production through such systems, pipelines or facilities.
Substantially all of the Company's gas production is currently sold to gas
marketing firms or end users either on the spot market on a month-
to-month basis at prevailing spot market prices or under long-term contracts
based on current spot market prices. The Company normally sells its oil under
month-to-month contracts with a variety of purchasers. Accordingly, the
Company's oil and gas sales expose it to the commodities risks associated with
changes in market prices. During the past year, Aspen has entered into several
six month and one year fixed price contracts to protect the Company against
price declines.
Uncertainty of Estimates of Reserves and Future Net Cash Flows. This Annual
Report contains estimates of the Company's oil and gas reserves and the future
net cash flows from those reserves, which have been prepared or audited
by certain independent petroleum consultants. There are numerous uncertainties
inherent in estimating quantities of reserves of oil and gas and in projecting
future rates of production and the timing of development expenditures,
including many factors beyond the Company's control. The reserve estimates in
this Annual Report are based on various assumptions, including, for example,
constant oil and gas prices, operating expenses, capital expenditures and
the availability of funds, and, therefore, are inherently imprecise indications
of future net cash flows. Actual future production, cash flows, taxes,
operating expenses, development expenditures and quantities of recoverable oil
and gas reserves may vary substantially from those assumed in the estimates.
Any significant variance in these assumptions could materially affect the
estimated quantity and value of reserves set forth in this Annual Report.
Additionally, the Company's reserves may be subject to downward or upward
revision based upon actual production performance, results of future development
and exploration, prevailing oil and gas prices and other factors, many of which
are beyond the Company's control.
The present value of future net reserves discounted at 10% (the "PV-10") of
Proved Reserves referred to in this Annual Report should not be construed as the
current market value of the estimated Proved Reserves of oil and gas
attributable to the Company's properties. In accordance with applicable
requirements of the Commission, the estimated discounted future net cash flows
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from Proved Reserves are generally based on prices and costs as of the date of
the estimate, whereas actual future prices and costs may be materially higher or
lower. Actual future net cash flows also will be affected by: (i) the timing of
both production and related expenses; (ii) changes in consumption levels; and
(iii) governmental regulations or taxation. In addition, the calculation of the
present value of the future net cash flows using a 10% discount as required by
the Commission is not necessarily the most appropriate discount factor based on
interest rates in effect from time to time and risks associated with the
Company's reserves or the oil and gas industry in general. Furthermore, the
Company's reserves may be subject to downward or upward revision based upon
actual production, results of future development, supply and demand for oil and
gas, prevailing oil and gas prices and other factors. See "Properties--Oil and
Gas Reserves."
Under full cost accounting, the Company would be required to take a non-
cash charge against earnings to the extent capitalized costs of acquisition,
exploration and development (net of depletion and depreciation), less deferred
income taxes, exceed the PV-10 of its Proved Reserves and the lower of cost or
fair value of unproved properties after income tax effects. See "Management's
Discussion and Analysis or Plan of Operations."
Operating Hazards and Uninsured Risks; Production Curtailments. The
Company's oil and gas business involves a variety of operating risks, including,
but not limited to, unexpected formations or pressures, uncontrollable flows of
oil, gas, brine or well fluids into the environment (including groundwater
contamination), blowouts, fires, explosions, pollution and other risks, any of
which could result in personal injuries, loss of life, damage to properties and
substantial losses. Although the Company carries insurance at levels, which it
believes, are reasonable, it is not fully insured against all risks. The Company
does not carry business interruption insurance. Losses and liabilities arising
from uninsured or under-insured events could have a material adverse effect on
the financial condition and operations of the Company.
From time to time, due primarily to contract terms, pipeline interruptions
or weather conditions, the producing wells in which the Company owns an interest
have been subject to production curtailments. The curtailments range from
production being partially restricted to wells being completely shut-in. The
duration of curtailments varies from a few days to several months. In most
cases the Company is provided only limited notice as to when production will be
curtailed and the duration of such curtailments. The Company is not currently
experiencing any material curtailment of its production.
Laws and Regulations. The Company's operations are affected by extensive
regulation pursuant to various federal, state and local laws and regulations
relating to the exploration for and development, production, gathering and
marketing of oil and gas. Matters subject to regulation include discharge
permits for drilling operations, drilling and abandonment bonds or other
financial responsibility requirements, reports concerning operations, the
spacing of wells, unitization and pooling of properties, and taxation. From
time to time, regulatory agencies have imposed price controls and limitations on
production by restricting the rate of flow of oil and gas wells below actual
production capacity in order to conserve supplies of oil and gas.
Environmental Risks. Operations of the Company are also subject to
numerous environmental laws, including but not limited to, those governing
management of waste, protection of water, air quality, the discharge of
materials into the environment, and preservation of natural resources.
Noncompliance with environmental laws and the discharge of oil, gas, or other
materials into the air, soil or water may give rise to liabilities to the
government and third parties, including civil and criminal penalties, and may
require the Company to incur costs to remedy the discharge. Laws and
regulations protecting the environment have become more stringent in recent
years, and may in certain circumstances impose retroactive, strict, and joint
and several liability rendering entities liable for environmental damage without
regard to negligence or fault. From time to time the Company has agreed to
indemnify sellers of producing properties from whom the Company has acquired
reserves against certain liabilities for environmental claims associated with
such properties. There can be no assurance that new laws or regulations, or
modifications of or new interpretations of existing laws and regulations, will
not increase substantially the cost of compliance or otherwise adversely affect
the Company's oil and gas operations and financial condition or that material
indemnity claims will not arise against the Company with respect to properties
acquired by or from the Company. While the Company does not anticipate
incurring material costs in connection with environmental compliance and
remediation, it cannot guarantee that material costs will not be incurred.
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Dependence on Key Personnel. The Company depends to a large extent on the
services of Jack E. Wheeler, the Company's President, Chairman of the Board and
Chief Executive Officer, and Ronald L. Mercer, Executive Vice President and
Chief Operating Officer. The loss of the services of either of these
individuals could have a material adverse effect on the Company's operations.
The Company has entered into five year employment contracts with both
of these executive officers, and has obtained key personnel life insurance. The
Company believes that its success is also dependent on its ability to continue
to employ and retain skilled technical personnel.
Concentration of Voting Power. The Company's executive officers, directors
and their affiliates beneficially own approximately 25% of the Company's
outstanding Common Stock. As a result, officers, directors and their affiliates
will have the ability to exert significant influence over the business affairs
of the Company, including the ability to influence the election of directors and
results of voting on all matters requiring shareholder approval.
Conflicts of Interests. Certain officers, directors and related parties
have engaged in business transactions with the Company which were not the result
of arm's length negotiations between independent parties. Management believes
that the terms of these transactions were as favorable to the Company as those
that could have been obtained from unaffiliated parties under similar
circumstances. All future transactions between the Company and its affiliates
will be on terms no less favorable than could be obtained from unaffiliated
third parties and will be approved by a majority of the disinterested members of
the Board of Directors of the Company.
Public Market and Possible Volatility of Securities. The Common Stock is
traded on the OTC Bulletin Board and "over-the-counter" in Canada on the
Canadian Dealing Network ("CDN"). The trading price of the Common Stock
could be subject to wide fluctuations in response to quarter-to-quarter
variations in operating results, announcements of drilling results by the
Company and other events or factors. In addition, the U.S. stock market has
from time to time experienced extreme price and volume fluctuations which have
particularly affected the market price for many companies and which often have
been unrelated to the operating performance of these companies. These broad
market fluctuations may adversely affect the market price of the Company's
securities.
No Dividends. The Company's board of directors presently intends to retain
all of its earnings for the expansion of its business. The Company therefore
does not anticipate the distribution of cash dividends in the foreseeable
future. Any future decision of the Company's board of directors to pay cash
dividends will depend, among other factors, upon the Company's earnings,
financial position and cash requirements.
Exchange Rate Fluctuations. The Company is exposed to foreign exchange
risks since it has granted stock options and warrants denominated in Canadian
currency while the majority of its expenditures will be in United States
dollars. Any significant reduction in the value of the Canadian dollar may
decrease the value of funds in United States dollars the Company receives upon
exercise of warrants and options.
Competition
Competition in the oil and gas industry is intense generally. Aspen
believes that price is the determinative factor in competition for drilling
prospects, equipment and labor. Major and independent oil and gas companies and
syndicates actively bid for desirable oil and gas properties and equipment and
labor required to operate and develop them. Many of Aspen's competitors have
substantially greater financial resources and exploration and development
budgets than those of the Company. Therefore, competitors may be able to pay
more for desirable leases and to evaluate, bid for and purchase a greater number
of properties or prospects than the financial or personnel resources of the
Company will permit.
Markets
General. Oil and gas operating revenues are highly dependent upon prices
and demand for oil and gas. Numerous factors beyond Aspen's control can impact
the prices of its oil and gas. Decreases in oil and gas prices would have an
adverse effect on the Company's proved reserves, revenues, profitability and
cash flow. Aspen has not engaged in any crude oil and gas price swaps or other
hedging transactions to reduce its exposure to price fluctuations. The Company
may, however, engage in other similar transactions from time to time as
management deems advisable.
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Gas Sales. During fiscal year 2000, the Company sold its gas to many
different purchasers, one of which, Aurora Natural Gas, LLC, accounted for
approximately 18.48% of total revenues.
Oil Sales. Aspen sells its oil production under short-term and long-term
arrangements at prices no less than the purchaser's posted prices for the
respective areas less standard deductions. Management believes that numerous
buyers are available for the Company's oil. During fiscal year 2000, the
Company sold its oil to many different purchasers, one of which, Texas
Exploration Inc. accounted for more than 10.59% of the Company's gross revenues.
Regulation
Oil and gas exploration, production and related operations are heavily
regulated by federal and state authorities. Failure to comply with applicable
law can result in substantial penalties. The cost of regulatory compliance will
increase Aspen's cost of doing business and affect its profitability.
Regulation of oil and gas activities has changed many times. Consequently,
Aspen is unable to predict the future cost or impact of complying with such
laws. Texas requires drilling permits and bonds and operating reports and
imposes other burdens relating to oil and gas exploration and production. Texas
also requires conservation measures, including pooling of oil and gas
properties, establishing maximum production rates from oil and gas wells, and
spacing, plugging and abandoning wells. These laws limit the rate at which oil
and gas can be produced from Aspen's properties.
The transportation and sale of gas in interstate commerce is regulated by
United States law and the Federal Energy Regulatory Commission.
Operating Hazards and Uninsured Risks
The acquisition, development, exploration for, and production,
transportation and storage of, crude oil, gas liquids and gas involves a high
degree of risk, which even a combination of experience, knowledge and careful
evaluation may not be able to overcome. Aspen's operations are subject to all
of the risks normally incident to drilling gas and oil wells, operating and
developing gas and oil properties, transporting, processing, and storing gas,
including encountering unexpected formations or pressures, premature reservoir
declines, blow-outs, equipment failures and other accidents, craterings, sour
gas releases, uncontrollable flows of oil, gas or well fluids, adverse weather
conditions, pollution, other environmental risks, fires and spills. Oil
production requires high levels of investment and has particular economic risks,
such as retaining wall failure, fires, explosions, gaseous leaks, spills and
migration of harmful substances, any of which can cause personal injury, damage
to property, equipment and the environment, and result in the interruption of
operations. Aspen is also subject to deliverability uncertainties related to
the proximity of its reserves to pipeline and processing facilities and the
inability to secure space on pipelines that deliver oil and gas to commercial
markets. Although Aspen maintains insurance in accordance with customary
industry practice, it is not fully insured against all of these risks, nor are
all such risks insurable. Losses resulting from the occurrence of these
risks could have a material adverse impact on the Company.
Employees
At September 11, 2000, the Company had 27 full-time employees of which 2
were management. The Company has experienced no work stoppages and management
considers its relations with employees to be good. The Company uses contract
services in its field operations and employs independent consultants, as needed,
to evaluate Company prospects, reserves and other oil and gas assets for
potential acquisitions.
Facilities
The Company occupies approximately 9,454 square feet of office space at
3300 Bank One Center, Oklahoma City, Oklahoma 73102, under a five year lease
that expires on September 30, 2004. Monthly base rent is $8,744.95. The
Company leases a storage yard in Odessa, Texas.
Recent Developments
Effective August 1, 2000, the Company purchased approximately 400 oil and
gas properties from Old Dominion Oil Corporation for a cash purchase price of
$500,000.
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On August 22, 2000, effective May 1, 2000, the Company purchased from
L.C.B. Resources, Inc. its equipment and certain oil and gas interests.
L.C.B. also agreed to lease its equipment yard to the Company for a period
of 10 years. As consideration for the above, L.C.B. is to receive 4,000,000
restricted shares of Common Stock.
On August 7, 2000, the Company acquired the oil and gas operations of
Crawford Oil Company and Leiker-Crawford Oil Company for a cash purchase price
of $1,375,000. This purchase includes wells, leases, equipment, licenses,
instruments and production. The Company financed the acquisition with credit
available under its credit agreement.
ITEM 2. PROPERTIES
List of Properties
Means (Queen Sand) Unit. The Aspen Means (Queen Sand) Unit consists of
approximately 2,600 acres on six leases in north central Andrews County, Texas.
Production began in 1954 and secondary recovery was initiated in 1960. The
Company purchased the leases in 1996 for the purpose of instituting a 20-acre
infill redevelopment program. An engineering report, as of June 30, 2000,
estimates that the Means (Queen Sand) Unit contains net proved undeveloped
reserves of 3,092,000 MMBbls. The Company estimates that it will require a
capital investment of approximately $11.92 million to develop this property.
During fiscal year 2000 the Company purchased, and delivered to the Means Unit,
or the nearby city of Odessa, Texas, approximately $600,000 of equipment to be
used in the waterflood project.
MidContinent. Aspen's position in the MidContinent Area of the United
States is significant, with interest in over 1,000 wellbores. Most of these
wells are included within the area's major oil and gas fields. Development in
this area, including the Morrow, Atoka, Red Fork, and Granite Wash formations,
continues to be an important part of the area's exploitation for energy
reserves. With leasehold in approximately 500,000 gross acres, Aspen's
development opportunities create a favorable position for long-term growth.
The Company's current drilling activity is concentrated in the Morrow and
Granite Wash development of the Anadarko Basin, the Travis Peak development of
SE Texas, the Atoka development of the Arkoma Basin, and the Cromwell
development of SE Oklahoma. These areas are mature geological trends. The
development of these fields is relatively low risk which is an important
characteristic of Aspen's capital employment plan.
El Dorado Field. The El Dorado Field of South East Kansas has a
long history of oil production and development. Aspen acquired interests in 140
wells within the past year in this field. Current company gross production is
approximately 200 Bopd from several different horizons including the
Mississippi, the Viola, the Admire, and the Simpson. Third party engineers have
identified several development opportunities on these leases.
Other Mid Continent Fields. Aspen's producing properties have little
concentration within geologic fields other than those mentioned. This diversity
is believed to provide a relatively secure base of value.
Title of Properties
Aspen follows industry practice when acquiring undeveloped properties on
minimal title investigation. A title opinion is obtained before drilling begins
on the properties. Title opinions cover most of Aspen's properties. The
Company's properties are subject to royalty interests, liens incident to
operating agreements, liens for current taxes and other burdens that Aspen
believes do not materially interfere with their use or value. Aspen may incur
additional expenses in obtaining titles or doing remedial work on the titles,
but in the opinion of management these expenses would not be material.
Oil and Gas Reserves
Aspen's reserves consist primarily of proved and probable reserves located
in the States of Oklahoma, Kansas and Texas. Reserve estimates were made using
industry-accepted methodology including extrapolation of performance trends,
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volumetrics, material balance and statistical analysis of analogs. The
evaluator's professional judgment and experience were used to select the most
appropriate method and to determine the reasonableness of the results. The
estimates were made in accordance with oil and gas reserve definitions
promulgated by the U.S. Securities and Exchange Commission (the "SEC").
The following table summarizes Aspen's estimated net proved oil and gas
reserves as of June 30, 2000 as estimated by American Energy Advisors, Inc.
TOTAL RESERVES
ITEM Oil Bbls Gas Mcf Mboe
RESERVES
Proved producing
Oil (Bbl) 1,293,315 16,376,056 4,022,657
Proved nonproducing
Oil (Bbl) 9,750 2,241,949 383,408
Proved undeveloped
Oil (Bbl) 4,069,316 14,865,060 6,546,826
Total Proved
Oil (Bbl) 5,372,381 33,483,065 10,952,891
ESTIMATED FUTURE NET REVENUES
BEFORE INCOME TAXES
Proved producing $ 78,114,965
Proved nonproducing 9,766,380
Proved undeveloped 142,082,833
Total $229,964,178
ESTIMATED FUTURE NET REVENUES
BEFORE INCOME TAXES DISCOUNTED AT 10%
Proved producing $ 37,469,338
Proved nonproducing 3,810,053
Proved undeveloped 67,651,339
Total $108,930,730
- - Prices based on $29.85 per Bbl of oil and $4.07 per MMBtu of gas.
The reserve data set forth in this Annual Report is only an estimate.
Numerous uncertainties are inherent in estimating oil and gas reserves and their
values, including many factors beyond the control of the producer. Reserve
engineering is a subjective process of estimating underground accumulations of
oil and gas that cannot be measured in an exact manner. The accuracy of any
reserve estimate is a function of the quality of available data and of
engineering and geological interpretation and judgment. As a result, estimates
of different engineers often vary. In addition, estimates of reserves are
subject to revision by the results of later drilling, testing and production.
Accordingly, reserve estimates often differ from the quantities of oil and gas
ultimately recovered. The meaningfulness of estimates is highly dependent upon
the accuracy of the assumptions upon which they are based.
In general, oil and gas production declines as reserves are depleted.
Except to the extent that Aspen acquires proven reserves or succeeds in
exploring and developing its own reserves, or both, Aspen's proven reserves will
decline as they are produced. Aspen's future oil and gas production is,
therefore, highly dependent upon its ability to acquire or develop additional
reserves.
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Drilling Activity
With gas prices remaining strong during the year, the gas dominated Mid-
Continent Region of Oklahoma and Texas was the focus of Aspen's exploitation and
development during the fiscal year. Aspen initiated an aggressive
development program during which it participated in the drilling of 7 wells in
Texas and 21 wells in Oklahoma for a total of 28 new wells with 28 economic
completions. This 100% completion success rate resulted in Aspen
participating in 3.20608 gross wells and 2.564864 net wells for a total drilling
cost of approximately $510,000. In addition to the exploitation drilling
program, Aspen also participated in the successful recompletion and/or rework of
24 wells during the year.
These drilling activities during the year resulted in Aspen adding net
proved reserves of 1,465,975 Mcf and 22,199 Mbo, or 266,529 Mboe for a finding
cost of $1.91 per Boe which is significantly below the industry average. The
present discounted value added to Aspen's present worth for these new wells is
over $3,550,000.
The Company has budgeted $7,000,000 for the drilling of over 60 wells
during the upcoming year. Reflective of this effort, since June 30, 2000, the
Company is currently participating in the drilling of 4 new wells and the
completion of 7 wells. There are 9 additional wells in which Aspen has approved
the drilling AFE's and should commence drilling operations on each of these new
wells within the next 60 days. Additionally, the Company has received 16 new
well proposals, which are currently being evaluated by its technical staff.
Oil and Gas Wells
The following table sets forth the number of productive oil and gas wells
in which the Company had a working interest at June 30, 2000. During fiscal year
2000, the average price received for oil and gas sales was $17.15 per Boe,
and the average cost of production was $4.72 per Boe, where Boe is defined as
the barrel of oil equivalent using 6 Mcf of gas to one barrel of oil. The full
cost pool was amortized at the rate of $5.29 per Boe.
PRODUCTIVE WELLS
Gross (1) Net (2)
Location Oil Gas Total Oil Gas Total
___________________________________________________________________
Kansas 116 7 123 56 3 59
Oklahoma 39 609 648 8 117 125
Texas 4 65 69 5 16 21
---- --- ---- --- --- ----
Total 164 700 864 59 136 205
===================================================
________________________
(1) The number of gross wells is the total number of wells in which a
working interest is owned.
(2) The number of net wells is the sum of fractional working interests owned
in gross wells expressed as whole numbers and fractions thereof.
Oil and Gas Acreage
The following table summarizes the Company's developed and undeveloped
leasehold acreage at June 30, 2000.
DEVELOPED UNDEVELOPED
-------------------------------------------------
490,240 116,187 2,894 2,688
Gross(1) Net(2) Gross(1) Net(2)
Kansas 4,760 4,062 0 0
Oklahoma 458,680 100,560 294 294
Texas 26,800 11,565 2,600 2,600
____________________
(1) The number of gross acres is the total number of acres in which a
working interest is owned.
(2) The number of net acres is the sum of fractional working interests owned
in gross acres expressed as whole numbers and fractions thereof.
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ITEM 3. LEGAL PROCEEDINGS
The Company is not currently party to any legal proceedings which would
have a material adverse effect on the Company.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matters were submitted to shareholders during the fourth quarter of the
fiscal year.
PART II
ITEM 5. MARKET FOR THE COMPANY'S COMMON STOCK AND RELATED STOCKHOLDER
MATTERS
Market Investments
The Common Stock began trading through the CDN on June 24, 1996, under the
symbol "CVZC." The following table sets forth the high and low bid information
for the Company's Common Stock in United States dollars as reported on the CDN
for the periods indicated. The information in the table reflects inter-dealer
prices, without retail mark-up, mark-down or commission, and may not necessarily
represent actual transactions. From December 31, 1997 to June 30, 2000, there
were no significant trades on the CDN.
High Low
July 1 - September 30, 1999 $0.55 $0.10
October 1 - December 31, 1999 $0.29 $0.11
January 1 - March 31, 2000 $0.56 $0.11
April 1 - June 30, 2000 $0.59 $0.229
July 1,2000 - September 11, 2000 $0.39 $0.175
The Company's Common Stock began trading through the NASD Electronic
Bulletin Board on January 14, 1997 under the symbol "CTVYF." On July 1, 1997,
the Company's symbol was changed to "CTVY." The Company's Common Stock was not
traded through the NASD Electronic Bulletin Board after October 17, 1997 until
June 2, 1999 when the Common Stock returned to trading on the NASD Electronic
Bulletin Board under the symbol "KTNV." At present, the Common Stock trades on
the NASD Electronic Bulletin Board under the symbol "ASRG." The following
table sets forth the high and low transaction information for the Common Stock
in U.S. currency as reported on the Electronic Bulletin Board for the periods
indicated.
High Low
June 2 - June 30, 1999 $0.31 $0.13
July 1 - September 30, 1999 $0.30 $0.13
October 1 - December 31, 1999 $0.30 $0.13
January 1 - March 31, 2000 $0.48 $0.13
April 1 - June 30, 2000 $0.52 $0.25
July 1 - September 11, 2000 $0.38 $0.17
On October 17, 1997, the Common Stock was listed on the American Stock
Exchange under the symbol "KTN." On May 21, 1999 the American Stock Exchange
ceased trading the Common Stock. The following table sets forth the
high and low sales prices for the Common Stock for the periods indicated.
High Low
July 1 - September 30, 1998 $1.19 $0.50
October 1 - December 31, 1998 $0.63 $0.22
January 1 - March 30, 1999 $0.38 $0.15
April 1 - May 21, 1999 $0.40 $0.16
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Holders. As of September 11, 2000, there were approximately 800 record
holders of the Company's Common Stock.
Dividends
The Company has not previously paid any cash dividends on its Common Stock
and does not anticipate or contemplate paying dividends on the Common Stock in
the foreseeable future. It is the present intention of management to utilize
all available funds for the development of the Company's business. In addition,
the Company may not pay any dividends on common equity unless and until all
dividend rights on outstanding preferred stock, if any, have been satisfied.
The only other restrictions that limit the ability to pay dividends on common
equity or that are likely to do so in the future, are those restrictions imposed
by law or by certain credit agreements. Dividends paid to non-Canadian
residents would be subject to Canadian withholding tax.
Recent Sales of Unregistered Securities
During the year ended June 30, 2000, the Company issued securities in
transactions not requiring registration in reliance upon exemptions from the
registration requirements of the Securities Act of 1933 (the "Securities Act").
The price of the securities issued in the following transactions was determined
in each instance by the Board of Directors based primarily upon the then current
bid prices of the Common Stock of the Company on the date(s) of agreements for
issuance in its principal trading market and the restriction on the
transferability of such securities. The unregistered sale of these securities
above were made in reliance upon Section 4(2) of the Securities Act, which
provide exemptions for transactions not involving a public offering. The
Company determined that the purchasers of these securities were sophisticated
investors who had the financial ability to assume the risk of their total
investment, acquired them for their own account and not with a view to any
distribution thereof to the public. The certificates evidencing the securities
sold to United States residents bear legends stating that the shares are not to
be offered, sold or transferred other than pursuant to an effective registration
statement under the Securities Act or an exemption from such registration
requirements.
East Wood Transaction. As described previously in "Item 1. Business-East
Wood Acquisition", the Company acquired East Wood Equity Venture, Inc. through
the issuance of stock. The acquisition was completed in two segments, with the
acquisition of 50% of the outstanding stock of East Wood acquired on September
16, 1999, effective July 1, 1999, and the remaining 50% acquired on February 28,
2000. The shareholders of East Wood acquired in the aggregate 72,461,794 shares
of Common Stock together with a $3,000,000 promissory note. The estimated value
of the East Wood shares acquired by the Company was, as of the various
acquisition dates, $14,929,010.
Other Acquisitions. In other acquisitions of oil and gas properties during
the fiscal year, the Company issued a total of 4,415,000 shares of Common Stock
to the owners of such properties in exchange for properties valued at
$1,224,440. These acquisition issuances took place at the times and for the
estimated consideration set forth below:
Number
Issuance Date of Shares Consideration
4/19/00 1,825,000 $313,718
5/26/00 650,000 243,750
5/29/00 940,000 323,172
6/30/00 1,000,000 343,800
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Capital-Raising Placements. During the fiscal year, the Company issued a
total of 8,387,381 shares of Common Stock to investors in exchange for an
aggregate gross investment (exclusive of costs) of $1,540,114. These
issuances took place at the times and for the consideration set forth below:
Number Warrants/
Issuance Date of Shares Options Issued Purchase Price
9/16/99 1,200,000 1,200,000(1) $300,000
12/31/99 1,122,857 1,122,857(2) 196,500
2/22/00 4,000,000 4,000,000(3) 600,000
3/20/00 600,000(4) 180,000
3/24/00 1,464,524(4) 263,614
_______________
(1) Expire 9/30/02; exercise price $.30 per share; warrants remain
outstanding for 720,000 shares.
(2) Expire 6/15/01; exercise price $.18 per share; warrants remain
outstanding for 433,333 shares.
(3) Expire 6/15/01; exercise price $.18 per share; warrants remain
outstanding for 2,300,000 shares.
(4) Exercise of warrant/option granted in private placement.
Stock for Services and Indebtedness. During the fiscal year, the Company
issued a total of 13,946,633 shares of Common Stock in exchange for various
services, including salaries and consultant services, and prior indebtedness
having an estimated aggregate value of $2,362,133 plus cash in connection with
the exercise of warrants and options in the aggregate amount of $162,000. Dates
of issuance and the estimated value of the services rendered/indebtedness
settled is set forth below:
Number Warrants/ Debt/Value
Issuance Date of Shares Options Issued Services
8/25/99 3,125,000 $500,000
8/27/99 600,000 96,000
8/27/99 2,000,000(1) (1)
9/14/99 1,000,000 218,750
9/14/99 300,000 48,000
9/16/00 800,000 128,000
9/16/00 120,000(3) (3)
9/29/99 553,333(6) 166,000(6)
12/31/99 543,333(6) 163,000(6)
12/31/99 112,286(4) (4)
1/26/00 1,000,000 125,000
2/1/00 100,000(2) (2)
2/23/00 400,000(5) (5)
2/29/00 593,333(6) 178,000(6)
3/09/00 400,000(6) 60,000(6)
3/15/00 400,000(6) 72,000(6)
3/29/00 120,000(6) 30,000(6)
4/1/00 320,518 55,800
4/17/00 2,600,000 334,360
5/1/00 1,281,115 256,223
5/31/00 310,001(6) 93,000(6)
_______________
(1) Expire 8/27/00; exercise price of $.30 per share. All of these options
were exercised and none remain outstanding.
(2) Expire five years after vesting; vest in quarterly increments of 25,000
shares; all options remain outstanding.
(3) Expire 9/30/01; exercise price of $.25 per unit consisting of one share
(total of 120,000 shares) and one warrant (total of 120,000 shares)
exercisable at $.30 per share until 9/20/02; option has been fully
exercised and warrant for 120,000 shares remains outstanding.
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(4) Expire 6/15/01; exercise price of $.175 per unit consisting of one share
(total of 112,286 shares) and one warrant (total of 112,286 shares)
exercisable at $.18 per share until 6/15/01; the option has not been
exercised.
(5) Expire 6/15/01; exercise price of $.15 per unit consisting of one share
(total of 400,000 shares) and one warrant (total of 400,000 shares)
exercisable at $.18 per share; option and warrant have been fully
exercised.
(6) Exercise of warrant/option. Amount shown under "Debt/Value Services"
represents exercise price.
Other Stock Option Grants. On February 22, 2000, stock options were granted
to employees and directors to acquire a total of 8,000,000 shares at an exercise
price of $.235 per share. All of these options are currently outstanding.
ITEM 6. MANAGEMENT'S DISCUSSION AND ANALYSIS OR PLAN OF OPERATION
Fiscal Year 2000 as Compared to Fiscal Year 1999
During the fiscal year ended June 30, 2000, the Company had net earnings of
$94,116 on revenues of $3,481,718 as compared with a net loss of $11,479,086 on
revenues of $980,966 for the fiscal year ended June 30, 1999. During
1999, the Company recorded a loss on disposal of assets of $9,807,576 and
provided for further loss of $1,262,000 in respect of impairment in the value of
oil and gas properties. These two items comprise 96.4% of the 1999 loss.
Revenue for the 2000 fiscal year was $3,481,718 compared to $980,966 for
1999, an increase of $2,500,752 or 254.9%. This increase is attributable to an
1200.3% increase in oil and gas sales offset by decreased equipment sales.
During the 2000 year, the Company ceased its equipment sales operations. The
increase in oil and gas sales is a result of the acquisition of oil and gas
properties and higher energy prices.
Expenses for the 2000 fiscal year amounted to $2,709,973 compared to
$2,478,161 for 1999, an increase of $231,812 or 9.4%. The increase is
attributable to:
a decrease in equipment sales related expenses of $592,475 resulting
from the cessation of this business activity,
a decrease in general and administrative expenses of $869,219 mostly
related to the elimination of penalties associated with a failure to
register certain convertible debentures in 1999,
more than offset by an increase of $737,757 in oil and gas production
costs related to increased oil and gas sales,
an increase of $956,720 in depreciation and depletion directly related to
increased oil and gas sales.
Operating income was $771,745 in 2000 compared to an operating loss of
$1,497,195 in 1999 as a result of increased sales.
Interest and financing expense for the 2000 fiscal year was $665,362
compared to $399,289 in 1999, an increase of $266,073 or 66.6%. This increase
is attributable to bank debt incurred and a note payable given in
connection with the acquisition and development of oil and gas properties.
Fiscal Year 1999 as Compared to Fiscal Year 1998
During the fiscal year ended June 30, 1999, the Company had a net loss of
$11,479,086 on revenues of $980,966 as compared with a net loss of $830,600 on
revenues of $1,825,852 for the fiscal year ended June 30, 1998. The impairment
results from a loss on disposal of assets of $9,807,576 in connection with
release of liabilities under the Convertible Debentures, a write-down of
$1,262,000 against the remaining oil and gas properties and significantly
lower oil and gas sales due to lower oil and gas prices during fiscal year 1999.
In fiscal 1998 the Company had a gain from the purchase and sale of a Canadian
property.
Oil and gas sales decreased 68% from 835,684 for the fiscal year ended June
30, 1998 to $266,232 for the fiscal year ended June 30, 1999, reflecting a drop
in oil prices from an average of $14.68 per barrel to $11.32 per barrel, a
drop in gas prices from an average of $2.47 per Mcf to $1.28 per Mcf and a drop
in volumes from approximately 28,000 barrels to approximately 12,000 barrels and
from approximately 181,000 Mcf to approximately 106,000 Mcf. Oil and gas
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production costs decreased 65% for the fiscal year ended June 30, 1998,
reflecting reduced staffing and maintenance costs. The prices dropped as a
result of national and international market forces outside the control of the
Company. To react to falling prices and revenues, the Company reduced its field
supervision, operations and maintenance staff from approximately 20 contract
service personnel and employees to a field staff of five contract service
personnel and employees directly supervised by the president of the Company. The
Company also ceased working over wells and reduced the amount of chemicals
injected into wells. The reduction in field personnel and the reduction in
direct operating expenses for maintenance and workovers caused maintenance costs
to be reduced, but it also caused approximately three-quarters of the reductions
in volumes. The remaining reductions in volumes were derived from natural
decline.
General and administrative costs were $1,498,795 for the fiscal year ended
June 30, 1999, an increase of $168,434 or 12.7% more that the $1,330,361
incurred for the fiscal year ended June 30, 1998. A substantial portion of the
increase was due to increased penalties (in the amount of approximately
$120,000) with respect to non-registration of the Convertible Debentures.
(Beginning June 1, 1998, a penalty of 1% of the outstanding principal amount of
the Convertible Debentures was incurred every month through December 31, 1998,
because the Company failed to have a registration statement effective on or
before May 31, 1998.) In addition, the Company allocated that portion of its
general and administrative expenses that were directly associated with oil and
gas acquisition and development activities during the fiscal year ended June 30,
1998 to oil and gas properties, in the approximate amount of $300,000.
Only a small amount (approximately $60,000) of such costs were allocated during
the fiscal year ended June 30, 1999 because the Company had limited such
activities during the period.
The Company recognized an income tax benefit of $1,845,000 for the fiscal
year ended June 30, 1999 as compared to recognition of an income tax benefit of
$467,678 for the fiscal year ended June 30, 1998. This is directly related to
the size of the loss before income taxes during such periods, except that the
amount for the period ended June 30, 1999 is limited to the amount of deferred
income taxes carried by the Company on its balance sheet as of June 30, 1998.
Liquidity and Capital Resources
On June 30, 2000, the Company had cash of $319,246 and a working capital
deficit of $3,687,384 calculated by subtracting current liabilities of
$5,869,447 from current assets of $2,182,063. Included in the working capital
deficit is a $3,000,000 note payable that management expects will be paid within
the next 12 months.
The Company intends to fund its 2001 development activities from the
proceeds of private placements of equity instruments, exercise of outstanding
options and warrants, traditional bank debt and institutional reserves based
financing. There is no assurance the Company will be successful in these
efforts.
Other Matters
In June 1998, the Financial Accounting Standards Board (FASB) issued
Statement of Financing Accounting Standards (SFAS) No. 133, Accounting for
Derivative Instruments and Hedging Activities which establishes
accounting and reporting standards for derivative instruments, including certain
derivative instruments embedded in other contracts (collectively referred to as
derivatives), and for hedging activities. SFAS No. 133 is effective for all
fiscal quarters of all fiscal years beginning after June 15, 2000, with earlier
application encouraged. The Company does not anticipate a material impact on
its financial position or results of operations.
In June 2000, the FASB issued SFAS No. 138, Accounting for Certain
Derivative Instruments and Certain Hedging Activities. This statement amends
the accounting and reporting standards of SFAS No. 133 for certain instruments
and certain hedging activities. SFAS No. 138 also amends SFAS No. 133 for
decisions made by the Board relating to the Derivative Implementation Group
(DIG) process. Certain decisions arising from the DIG process that required
specific amendments to SFAS No. 133 are incorporated in this Report. The
statement is effective concurrently with SFAS No. 133 according to the
provisions of paragraph 48 of SFAS No. 133. The Company does not anticipate a
material impact on its financial position or results of operations.
In December 1999, the Securities and Exchange Commission issued Staff
Accounting Bulletin No. 101 which summarizes certain of the staff's views in
applying generally accepted accounting principles to revenue recognition in
18
<PAGE>
financial statements. The Company does not anticipate a material impact on its
financial position or results of operations.
In April 2000, the FASB issued Financial Interpretation Number (FIN) 44,
Accounting for Certain Transactions Involving Stock Compensation--an
Interpretation of Accounting Principles Board No. 25. FIN 44 clarifies the
application of Opinion No. 25. This Interpretation was effective immediately
and all issues are to be handled prospectively. The adoption of FIN 44 did not
have a material impact on the Company's financial position or results of
operations.
Estimated Reserves
A slight majority of Aspen's oil and gas properties are proved undeveloped
reserves. Aspen emphasizes that reserve estimates of new discoveries or
undeveloped properties are more imprecise than those of producing oil and gas
properties. Accordingly, these estimates are expected to change materially as
future information becomes available.
19
<PAGE>
ITEM 7. FINANCIAL STATEMENTS
CONTENTS
Page
Independent Auditor's Report........................................ 21
Consolidated Financial Statements
Consolidated Balance Sheet...................................... 22
Consolidated Statements of Operations........................... 23
Consolidated Statement of Changes in Stockholders' Equity....... 24
Consolidated Statements of Cash Flows........................... 27
Notes to Consolidated Financial Statements...................... 28
20
<PAGE>
INDEPENDENT AUDITOR'S REPORT
Board of Directors
Aspen Group Resources Corporation
We have audited the accompanying consolidated balance sheet of Aspen Group
Resources Corporation and subsidiaries as of June 30, 2000 and the related
consolidated statements of operations, changes in stockholders' equity and cash
flows for each of the two years in the period ended June 30, 2000. These
financial statements are the responsibility of the Company's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall 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 financial position of Aspen Group
Resources Corporation and subsidiaries as of June 30, 2000, and the results of
their operations and their cash flows for each of the two years in the period
ended June 30, 2000, in conformity with generally accepted accounting
principles.
LANE GORMAN TRUBITT L.L.P.
Dallas, Texas
August 21, 2000
21
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
June 30, 2000
ASSETS
<TABLE>
<S> <C>
Current Assets
Cash $ 319,246
Accounts receivable
Trade 1,297,730
Other 161,593
Materials and supplies inventory 77,305
Prepaid expenses 326,189
-------------
Total current assets 2,182,063
-------------
Proved Oil & Gas Properties (full cost method) 40,266,932
net of accumulated depletion of $1,795,148
Office Furniture and Equipment
net of accumulated depreciation of $87,722 254,291
Other Assets 71,380
---------------
Total Assets $ 42,774,666
===============
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities
Accounts payable
Trade $ 423,198
Revenue distribution 277,049
Accrued expenses 99,831
Accrued interest 144,593
Accrued salaries 4,776
---------------
949,447
Current maturities of long-term debt 1,920,000
Note payable 3,000,000
---------------
Total current liabilities 5,869,447
---------------
Long-Term Debt, less Current Maturities 7,870,560
Stockholders' Equity
Preferred stock, no par value, authorized-unlimited,
issued-none -
Common stock, no par value, authorized-unlimited,
Issued - 126,384,006 shares 43,410,125
Less subscriptions for 857,744 shares (214,436)
Warrants and beneficial conversion feature 823,695
Accumulated deficit (14,984,725)
----------------
Total stockholders' equity 29,034,659
----------------
Total Liabilities and Stockholders' Equity $ 42,774,666
================
</TABLE>
See accompanying notes to these financial statements
22
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
Years ended June 30, 2000 and 1999
<TABLE>
2000 1999
<S> <C> <C>
REVENUE
Oil and gas sales $ 3,461,803 $ 266,232
Equipment sales 19,915 683,708
Other income - 31,026
-------------- -------------
Total revenues 3,481,718 980,966
-------------- -------------
EXPENSES
Oil and gas production 953,991 216,234
Cost of equipment sold 10,357 281,850
Operating expenses - 320,982
General and administrative 629,576 1,498,795
Depreciation and depletion 1,116,049 159,329
Other expenses - 971
-------------- -------------
Total expenses 2,709,973 2,478,161
-------------- -------------
EARNINGS (LOSS) FROM OPERATIONS 771,745 (1,497,195)
OTHER INCOME (EXPENSE)
Interest and financing expense (665,362) (399,289)
Gain (loss) on disposal of assets - (9,807,576)
Provision for inventory losses - (359,664)
Provision for oil & gas property loss - (1,262,000)
Interest income - 159
Other income 236,992 1,479
-------------- -------------
Total other (428,370) (11,826,891)
-------------- -------------
EARNINGS (LOSS) BEFORE INCOME
TAXES AND MINORITY INTERESTS 343,375 (13,324,086)
INCOME TAX BENEFIT - 1,845,000
-------------- -------------
NET EARNINGS (LOSS) BEFORE
MINORITY INTERESTS 343,375 (11,479,086)
MINORITY INTERESTS 249,259 -
------------- -------------
NET EARNINGS (LOSS) $ 94,116 $ (11,479,086)
============= =============
NET EARNINGS (LOSS) PER SHARE $ - $ (.57)
WEIGHTED AVERAGE SHARES 83,676,588 20,036,818
</TABLE>
See accompanying notes to these financial statements
23
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS' EQUITY
Years ended June 30, 2000 and 1999
<TABLE>
COMMON STOCK
SHARES AMOUNT
------------- -----------
<S> <C> <C>
BALANCES, June 30, 1998 17,273,278 $ 21,119,482
Issuance of shares in September and 132,889 66,445
November 1998 for services
($.50 per share)
Issuance of shares in September 1998 30,000 7,500
for services ($.25 per share)
Conversion of debenture in September 1998 428,366 100,000
($.2334 per share)
Issuance of shares in October 1998 to 1,994,840 494,555
Debenture holders in payment of interest,
penalty and waiver fees ($.25 per share)
Issuance of shares in November 1998 for 130,000 32,500
services ($.25 per share)
Issuance of shares in November 1998 140,000 35,000
for services ($.25 per share)
Issuance of shares in December 1998 for 205,000 51,250
Compensation ($.25 per share)
Issuance of shares in January 1999 for 650,000 112,500
services ($.15/$.25 per share)
Issuance of shares in March 1998 for 120,000 80,000
services ($.75/$.25 per share)
Issuance of shares and warrants in private 1,628,825 356,305
offering which closed in March 1999
($.22 per share)
Issuance of shares in June 1999 in connection 100,000 25,000
with sale of Sears Ranch Property
($.25 per share)
Issuance of shares in June 1999 for services 340,000 68,000
($.20 per share)
Issuance of shares in June 1999 for notes 4,000,000 1,000,000
and accounts payable ($.25 per share)
Common stock subscriptions receivable - -
($.25 per share)
Net loss - -
------------ -----------
BALANCES, June 30, 1999 27,173,198 23,548,537
------------ -----------
</TABLE>
--------------------------------------------------------------------------
<TABLE>
COMMON STOCK
SUBSCRIBED
SHARES AMOUNT
----------- ------------
<S> <C> <C>
BALANCES, June 30, 1998 - $ -
Issuance of shares in September and - -
November 1998 for services
($.50 per share)
Issuance of shares in September 1998 - -
for services ($.25 per share)
Conversion of debenture in September 1998 - -
($.2334 per share)
Issuance of shares in October 1998 to - -
Debenture holders in payment of interest,
penalty and waiver fees ($.25 per share)
Issuance of shares in November 1998 for - -
services ($.25 per share)
Issuance of shares in November 1998 - -
for services ($.25 per share)
Issuance of shares in December 1998 for - -
Compensation ($.25 per share)
Issuance of shares in January 1999 for - -
services ($.15/$.25 per share)
Issuance of shares in March 1998 for - -
services ($.75/$.25 per share)
Issuance of shares and warrants in private - -
offering which closed in March 1999
($.22 per share)
Issuance of shares in June 1999 in connection - -
with sale of Sears Ranch Property
($.25 per share)
Issuance of shares in June 1999 for services - -
($.20 per share)
Issuance of shares in June 1999 for notes and - -
accounts payable ($.25 per share)
Common stock subscriptions receivable 857,744 (214,436)
($.25 per share)
Net loss - -
----------- ----------
BALANCES, June 30, 1999 857,744 (214,436)
----------- ----------
</TABLE>
-------------------------------------------------------------------------
<TABLE>
SPECIAL SHARES
SHARES AMOUNT
------------ ------------
<S> <C> <C>
BALANCES, June 30, 1998 - $ -
Issuance of shares in September and - -
November 1998 for services
($.50 per share)
Issuance of shares in September 1998 - -
for services ($.25 per share)
Conversion of debenture in September 1998 - -
($.2334 per share)
Issuance of shares in October 1998 to - -
Debenture holders in payment of interest,
penalty and waiver fees ($.25 per share)
Issuance of shares in November 1998 for - -
services ($.25 per share)
Issuance of shares in November 1998 - -
for services ($.25 per share)
Issuance of shares in December 1998 for - -
Compensation ($.25 per share)
Issuance of shares in January 1999 for - -
services ($.15/$.25 per share)
Issuance of shares in March 1998 for - -
services ($.75/$.25 per share)
Issuance of shares and warrants in private - -
offering which closed in March 1999
($.22 per share)
Issuance of shares in June 1999 in connection - -
with sale of Sears Ranch Property
($.25 per share)
Issuance of shares in June 1999 for services - -
($.20 per share)
Issuance of shares in June 1999 for notes and - -
accounts payable ($.25 per share)
Common stock subscriptions receivable - -
($.25 per share)
Net loss - -
--------- --------
BALANCES, June 30, 1999 - -
--------- --------
</TABLE>
-------------------------------------------------------------------------
<TABLE>
WARRANTS
AND
BENEFICIAL
CONVERSION ACCUMULATED
FEATURE DEFICIT
------------- -------------
<S> <C> <C>
BALANCES, June 30, 1998 $ 823,695 $ (3,599,755)
Issuance of shares in September and - -
November 1998 for services
($.50 per share)
Issuance of shares in September 1998 - -
for services ($.25 per share)
Conversion of debenture in September 1998 - -
($.2334 per share)
Issuance of shares in October 1998 to - -
Debenture holders in payment of interest,
penalty and waiver fees ($.25 per share)
Issuance of shares in November 1998 for - -
services ($.25 per share)
Issuance of shares in November 1998 - -
for services ($.25 per share)
Issuance of shares in December 1998 for - -
Compensation ($.25 per share)
Issuance of shares in January 1999 for - -
services ($.15/$.25 per share)
Issuance of shares in March 1998 for - -
services ($.75/$.25 per share)
Issuance of shares and warrants in private - -
offering which closed in March 1999
($.22 per share)
Issuance of shares in June 1999 in connection - -
with sale of Sears Ranch Property
($.25 per share)
Issuance of shares in June 1999 for services - -
($.20 per share)
Issuance of shares in June 1999 for notes and - -
accounts payable ($.25 per share)
Common stock subscriptions receivable - -
($.25 per share)
Net loss - (11,479,086)
----------- ------------
BALANCES, June 30, 1999 823,695 (15,078,841)
----------- ------------
</TABLE>
-------------------------------------------------------------------------
<TABLE>
TOTAL
--------------
<S> <C>
BALANCES, June 30, 1998 $ 18,343,422
Issuance of shares in September and 66,445
November 1998 for services
($.50 per share)
Issuance of shares in September 1998 7,500
for services ($.25 per share)
Conversion of debenture in September 1998 100,000
($.2334 per share)
Issuance of shares in October 1998 to 494,555
Debenture holders in payment of interest,
penalty and waiver fees ($.25 per share)
Issuance of shares in November 1998 for 32,500
services ($.25 per share)
Issuance of shares in November 1998 35,000
for services ($.25 per share)
Issuance of shares in December 1998 for 51,250
Compensation ($.25 per share)
Issuance of shares in January 1999 for 112,500
services ($.15/$.25 per share)
Issuance of shares in March 1998 for 80,000
services ($.75/$.25 per share)
Issuance of shares and warrants in private 356,305
offering which closed in March 1999
($.22 per share)
Issuance of shares in June 1999 in connection 25,000
with sale of Sears Ranch Property
($.25 per share)
Issuance of shares in June 1999 for services 68,000
($.20 per share)
Issuance of shares in June 1999 for notes and 1,000,000
accounts payable ($.25 per share)
Common stock subscriptions receivable (214,436)
($.25 per share)
Net loss (11,479,086)
-------------
BALANCES, June 30, 1999 9,078,955
-------------
</TABLE>
See accompanying notes to these financial statements
24
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS' EQUITY
Years ended June 30, 2000 and 1999
<TABLE>
COMMON STOCK
SHARES AMOUNT
------------- -----------
<S> <C> <C>
Issuance of shares in August 1999 3,125,000 $ 500,000
to related parties for settlement
of debt ($.16 per share)
Issuance of shares in August 1999 for 600,000 96,000
services related to the acquisition
of oil and gas properties ($.16 per share)
Exercise of warrants in September 1999 for 533,333 88,533
services related to the acquisition of oil
and gas properties ($.16 per share)
Issuance of shares in September 1999 for 1,000,000 218,750
services related to the acquisition
of oil and gas properties ($.22 per share)
Issuance of shares in September 1999 for 300,000 48,000
services related to the acquisition
of oil and gas properties ($.16 per share)
Issuance of shares and warrants in 1,200,000 300,000
private offering which closed in
September 1999 ($.25 per share)
Issuance of shares and special warrants in 46,230,897 5,895,840
September 1999 for the acquisition of East
Wood ($.13 per share)
Issuance of shares in September 1999 for 800,000 128,000
services related to the acquisition of
oil and gas properties ($.16 per share)
Costs related to sales of stock - (39,448)
Exercise of warrants in December 1999 543,333 86,933
for services related to the acquisition
of oil and gas properties ($.16 per share)
Issuance of shares and warrants in private 1,122,857 196,500
offering which closed in December 1999
($.18 per share)
Costs related to sales of stock - (95,470)
Issuance of shares in January 2000 for 1,000,000 125,000
services related to the acquisition
of oil and gas properties ($.13 per share)
Issuance of shares and warrants in private 4,000,000 600,000
offering which closed in February 2000
($.15 per share)
Issuance of shares in February 2000 for 26,230,897 9,033,170
the acquisition of East Wood
($.34 per share)
Exercise of warrant in February 2000 for 593,333 203,988
services related to the acquisition
of oil and gas properties ($.34 per share)
</TABLE>
------------------------------------------------------------------------
<TABLE>
COMMON STOCK
SUBSCRIBED
SHARES AMOUNT
----------- ------------
<S> <C> <C>
Issuance of shares in August 1999 - $ -
to related parties for settlement
of debt ($.16 per share)
Issuance of shares in August 1999 for - -
services related to the acquisition
of oil and gas properties ($.16 per share)
Exercise of warrants in September 1999 for - -
services related to the acquisition of oil
and gas properties ($.16 per share)
Issuance of shares in September 1999 for - -
services related to the acquisition
of oil and gas properties ($.22 per share)
Issuance of shares in September 1999 for - -
services related to the acquisition
of oil and gas properties ($.16 per share)
Issuance of shares and warrants in - -
private offering which closed in
September 1999 ($.25 per share)
Issuance of shares and special warrants in - -
September 1999 for the acquisition of East
Wood ($.13 per share)
Issuance of shares in September 1999 for - -
services related to the acquisition of
oil and gas properties ($.16 per share)
Costs related to sales of stock - -
Exercise of warrants in December 1999 - -
for services related to the acquisition
of oil and gas properties ($.16 per share)
Issuance of shares and warrants in private - -
offering which closed in December 1999
($.18 per share)
Costs related to sales of stock - -
Issuance of shares in January 2000 for - -
services related to the acquisition
of oil and gas properties ($.13 per share)
Issuance of shares and warrants in private - -
offering which closed in February 2000
($.15 per share)
Issuance of shares in February 2000 for - -
the acquisition of East Wood
($.34 per share)
Exercise of warrant in February 2000 for - -
services related to the acquisition
of oil and gas properties ($.34 per share)
</TABLE>
--------------------------------------------------------------------------
<TABLE>
SPECIAL SHARES
SHARES AMOUNT
------------ ------------
<S> <C> <C>
Issuance of shares in August 1999 - $ -
to related parties for settlement
of debt ($.16 per share)
Issuance of shares in August 1999 for - -
services related to the acquisition
of oil and gas properties ($.16 per share)
Exercise of warrants in September 1999 for - -
services related to the acquisition of oil
and gas properties ($.16 per share)
Issuance of shares in September 1999 for - -
services related to the acquisition
of oil and gas properties ($.22 per share)
Issuance of shares in September 1999 for - -
services related to the acquisition
of oil and gas properties ($.16 per share)
Issuance of shares and warrants in - -
private offering which closed in
September 1999 ($.25 per share)
Issuance of shares and special warrants in - -
September 1999 for the acquisition of East
Wood ($.13 per share)
Issuance of shares in September 1999 for - -
services related to the acquisition of
oil and gas properties ($.16 per share)
Costs related to sales of stock - -
Exercise of warrants in December 1999 - -
for services related to the acquisition
of oil and gas properties ($.16 per share)
Issuance of shares and warrants in private - -
offering which closed in December 1999
($.18 per share)
Costs related to sales of stock - -
Issuance of shares in January 2000 for - -
services related to the acquisition
of oil and gas properties ($.13 per share)
Issuance of shares and warrants in private - -
offering which closed in February 2000
($.15 per share)
Issuance of shares in February 2000 for - -
the acquisition of East Wood
($.34 per share)
Exercise of warrant in February 2000 for - -
services related to the acquisition
of oil and gas properties ($.34 per share)
</TABLE>
---------------------------------------------------------------------------
<TABLE>
WARRANTS
AND
BENEFICIAL
CONVERSION ACCUMULATED
FEATURE DEFICIT
------------- -------------
<S> <C> <C>
Issuance of shares in August 1999 $ - $ -
to related parties for settlement
of debt ($.16 per share)
Issuance of shares in August 1999 for - -
services related to the acquisition
of oil and gas properties ($.16 per share)
Exercise of warrants in September 1999 for - -
services related to the acquisition of oil
and gas properties ($.16 per share)
Issuance of shares in September 1999 for - -
services related to the acquisition
of oil and gas properties ($.22 per share)
Issuance of shares in September 1999 for - -
services related to the acquisition
of oil and gas properties ($.16 per share)
Issuance of shares and warrants in - -
private offering which closed in
September 1999 ($.25 per share)
Issuance of shares and special warrants in - -
September 1999 for the acquisition of East
Wood ($.13 per share)
Issuance of shares in September 1999 for - -
services related to the acquisition of
oil and gas properties ($.16 per share)
Costs related to sales of stock - -
Exercise of warrants in December 1999 - -
for services related to the acquisition
of oil and gas properties ($.16 per share)
Issuance of shares and warrants in private - -
offering which closed in December 1999
($.18 per share)
Costs related to sales of stock - -
Issuance of shares in January 2000 for - -
services related to the acquisition
of oil and gas properties ($.13 per share)
Issuance of shares and warrants in private - -
offering which closed in February 2000
($.15 per share)
Issuance of shares in February 2000 for - -
the acquisition of East Wood
($.34 per share)
Exercise of warrant in February 2000 for - -
services related to the acquisition
of oil and gas properties ($.34 per share)
</TABLE>
-------------------------------------------------------------------------
<TABLE>
TOTAL
--------------
<S> <C>
Issuance of shares in August 1999 $ 500,000
to related parties for settlement
of debt ($.16 per share)
Issuance of shares in August 1999 for 96,000
services related to the acquisition
of oil and gas properties ($.16 per share)
Exercise of warrants in September 1999 for 88,533
services related to the acquisition of oil
and gas properties ($.16 per share)
Issuance of shares in September 1999 for 218,750
services related to the acquisition
of oil and gas properties ($.22 per share)
Issuance of shares in September 1999 for 48,000
services related to the acquisition
of oil and gas properties ($.16 per share)
Issuance of shares and warrants in 300,000
private offering which closed in
September 1999 ($.25 per share)
Issuance of shares and special warrants in 5,895,840
September 1999 for the acquisition of East
Wood ($.13 per share)
Issuance of shares in September 1999 for 128,000
services related to the acquisition of
oil and gas properties ($.16 per share)
Costs related to sales of stock (39,448)
Exercise of warrants in December 1999 86,933
for services related to the acquisition
of oil and gas properties ($.16 per share)
Issuance of shares and warrants in private 196,500
offering which closed in December 1999
($.18 per share)
Costs related to sales of stock (95,470)
Issuance of shares in January 2000 for 125,000
services related to the acquisition
of oil and gas properties ($.13 per share)
Issuance of shares and warrants in private 600,000
offering which closed in February 2000
($.15 per share)
Issuance of shares in February 2000 for 9,033,170
the acquisition of East Wood
($.34 per share)
Exercise of warrant in February 2000 for 203,988
services related to the acquisition
of oil and gas properties ($.34 per share)
</TABLE>
See accompanying notes to these financial statements
25
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS' EQUITY
Years ended June 30, 2000 and 1999
<TABLE>
COMMON STOCK
SHARES AMOUNT
------------- -----------
<S> <C> <C>
Exercise of warrants in March 2000 400,000 $ 60,000
($.15 per share)
Exercise of warrants in March 2000 400,000 72,000
($.18 per share)
Exercise of warrants in March 2000 600,000 180,000
($.30 per share)
Exercise of warrants in March 2000 1,464,524 263,614
($.18 per share)
Exercise of options in March 2000 120,000 30,000
($.25 per share)
Costs related to sales of stock - (97,520)
Issuance of shares in April 2000 for 320,518 55,800
services ($.15 - $.26 per share)
Issuance of shares in April 2000 for 600,000 84,360
services ($.14 per share)
Issuance of shares in April 2000 for 2,000,000 250,000
services ($.13 per share)
Issuance of shares in April 2000 for 1,825,000 313,718
the acquisition of oil and gas
properties ($.17 per share)
Issuance of shares in April 2000 to 1,281,115 256,223
related parties for settlement of
debt ($.20 per share)
Issuance of shares in May 2000 for 650,000 243,750
the acquisition of oil and gas
properties ($.38 per share)
Issuance of shares in May 2000 for 940,000 323,172
the acquisition of oil and gas
properties ($.35 per share)
Exercise of warrants in June 2000 310,001 96,875
($.31 per share)
Issuance of shares in June 2000 for 1,000,000 343,800
the acquisition of oil and gas
properties ($.34 per share)
Net earnings - -
------------ ------------
BALANCES, June 30, 2000 126,384,006 $43,410,125
============= ============
</TABLE>
-----------------------------------------------------------------------
<TABLE>
COMMON STOCK
SUBSCRIBED
SHARES AMOUNT
----------- ------------
<S> <C> <C>
Exercise of warrants in March 2000 - $ -
($.15 per share)
Exercise of warrants in March 2000 - -
($.18 per share)
Exercise of warrants in March 2000 - -
($.30 per share)
Exercise of warrants in March 2000 - -
($.18 per share)
Exercise of options in March 2000 - -
($.25 per share)
Costs related to sales of stock - -
Issuance of shares in April 2000 for - -
services ($.15 - $.26 per share)
Issuance of shares in April 2000 for - -
services ($.14 per share)
Issuance of shares in April 2000 for - -
services ($.13 per share)
Issuance of shares in April 2000 for - -
the acquisition of oil and gas
properties ($.17 per share)
Issuance of shares in April 2000 to - -
related parties for settlement of
debt ($.20 per share)
Issuance of shares in May 2000 for - -
the acquisition of oil and gas
properties ($.38 per share)
Issuance of shares in May 2000 for - -
the acquisition of oil and gas
properties ($.35 per share)
Exercise of warrants in June 2000 - -
($.31 per share)
Issuance of shares in June 2000 for - -
the acquisition of oil and gas
properties ($.34 per share)
Net earnings - -
------------ ------------
BALANCES, June 30, 2000 857,744 $ (214,436)
============= ============
</TABLE>
-----------------------------------------------------------------------
<TABLE>
SPECIAL SHARES
SHARES AMOUNT
------------ ------------
<S> <C> <C>
Exercise of warrants in March 2000 - $ -
($.15 per share)
Exercise of warrants in March 2000 - -
($.18 per share)
Exercise of warrants in March 2000 - -
($.30 per share)
Exercise of warrants in March 2000 - -
($.18 per share)
Exercise of options in March 2000 - -
($.25 per share)
Costs related to sales of stock - -
Issuance of shares in April 2000 for - -
services ($.15 - $.26 per share)
Issuance of shares in April 2000 for - -
services ($.14 per share)
Issuance of shares in April 2000 for - -
services ($.13 per share)
Issuance of shares in April 2000 for - -
the acquisition of oil and gas
properties ($.17 per share)
Issuance of shares in April 2000 to - -
related parties for settlement of
debt ($.20 per share)
Issuance of shares in May 2000 for - -
the acquisition of oil and gas
properties ($.38 per share)
Issuance of shares in May 2000 for - -
the acquisition of oil and gas
properties ($.35 per share)
Exercise of warrants in June 2000 - -
($.31 per share)
Issuance of shares in June 2000 for - -
the acquisition of oil and gas
properties ($.34 per share)
Net earnings - -
------------ ------------
BALANCES, June 30, 2000 - $ -
============= ============
</TABLE>
-----------------------------------------------------------------------
<TABLE>
WARRANTS
AND
BENEFICIAL
CONVERSION ACCUMULATED
FEATURE DEFICIT
------------- -------------
<S> <C> <C>
Exercise of warrants in March 2000 $ - $ -
($.15 per share)
Exercise of warrants in March 2000 - -
($.18 per share)
Exercise of warrants in March 2000 - -
($.30 per share)
Exercise of warrants in March 2000 - -
($.18 per share)
Exercise of options in March 2000 - -
($.25 per share)
Costs related to sales of stock - -
Issuance of shares in April 2000 for - -
services ($.15 - $.26 per share)
Issuance of shares in April 2000 for - -
services ($.14 per share)
Issuance of shares in April 2000 for - -
services ($.13 per share)
Issuance of shares in April 2000 for - -
the acquisition of oil and gas
properties ($.17 per share)
Issuance of shares in April 2000 to - -
related parties for settlement of
debt ($.20 per share)
Issuance of shares in May 2000 for - -
the acquisition of oil and gas
properties ($.38 per share)
Issuance of shares in May 2000 for - -
the acquisition of oil and gas
properties ($.35 per share)
Exercise of warrants in June 2000 - -
($.31 per share)
Issuance of shares in June 2000 for - -
the acquisition of oil and gas
properties ($.34 per share)
Net earnings - 94,116
------------ ------------
BALANCES, June 30, 2000 $ 823,695 $(14,984,725)
============= ============
</TABLE>
-----------------------------------------------------------------------
<TABLE>
TOTAL
--------------
<S> <C>
Exercise of warrants in March 2000 $ 60,000
($.15 per share)
Exercise of warrants in March 2000 72,000
($.18 per share)
Exercise of warrants in March 2000 180,000
($.30 per share)
Exercise of warrants in March 2000 263,614
($.18 per share)
Exercise of options in March 2000 30,000
($.25 per share)
Costs related to sales of stock (97,520)
Issuance of shares in April 2000 for 55,800
services ($.15 - $.26 per share)
Issuance of shares in April 2000 for 84,360
services ($.14 per share)
Issuance of shares in April 2000 for 250,000
services ($.13 per share)
Issuance of shares in April 2000 for 313,718
the acquisition of oil and gas
properties ($.17 per share)
Issuance of shares in April 2000 to 256,223
related parties for settlement of
debt ($.20 per share)
Issuance of shares in May 2000 for 243,750
the acquisition of oil and gas
properties ($.38 per share)
Issuance of shares in May 2000 for 323,172
the acquisition of oil and gas
properties ($.35 per share)
Exercise of warrants in June 2000 96,875
($.31 per share)
Issuance of shares in June 2000 for 343,800
the acquisition of oil and gas
properties ($.34 per share)
Net earnings 94,116
------------
BALANCES, June 30, 2000 $29,034,659
============
</TABLE>
See accompanying notes to these financial statements
26
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
Years ended June 30, 2000 and 1999
<TABLE>
2000 1999
<S> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES
Net earnings (loss) $ 94,116 $ (11,479,086)
Adjustments to reconcile net
earnings (loss) to net cash
provided by (used by) operating
activities:
Deferred income tax benefit - (1,845,000)
Depreciation and depletion 1,116,049 159,329
Amortization 112,954 143,041
Common stock and warrants issued
for services and other expenses 28,800 947,750
Loss on disposal of assets - 9,807,576
Provision for inventory losses - 359,664
Provision for oil & gas property loss - 1,262,000
Change in assets and liabilities net
of effects from purchase of
East Wood Equity Venture, Inc.
Accounts receivable (1,031,451) 343,368
Prepaid expenses (140,283) 219,119
Accounts payable and accrued
liabilities (397,696) 136,335
Materials and supplies inventory 20,345 434,045
Other - (55,785)
------------ -----------
Net cash provided by (used by)
operating activities (197,166) 432,356
------------ -----------
CASH FLOWS FROM INVESTING ACTIVITIES
Proceeds from sale of oil and gas
properties 241,989 12,500
Oil and gas properties purchased (5,201,091) (81,874)
Other (950) -
Exploration and development costs
capitalized (646,614) (1,070,510)
Acquisition of office furniture
and equipment (170,032) (31,883)
------------ -----------
Net cash used by investing activities (5,776,698) (1,171,767)
------------ -----------
CASH FLOWS FROM FINANCING ACTIVITIES
Sale of common stock and exercise of
warrants 1,702,114 381,305
Cash acquired in acquisition 66,816 -
Costs related to sale of stock and
issuance of notes payable (232,438) (247,102)
Issuance of notes payable and
long-term debt 10,081,425 451,518
Repayment of notes payable and
long-term debt (5,333,890) -
Advances from (repayments to)
related parties - 77,011
------------ ------------
Net cash provided by financing activities 6,284,027 662,732
------------ ------------
NET INCREASE (DECREASE) IN CASH 310,163 (76,679)
CASH - Beginning of period 9,083 85,762
------------ -----------
CASH - End of period $ 319,246 $ 9,083
============ ===========
SUPPLEMENTAL INFORMATION
Cash paid for interest $ 584,285 $ 315,215
Conversion of debt and other
liabilities to common stock 756,223 100,000
Oil and gas property acquired
with note payable 3,000,000 -
Oil and gas properties acquired
with common stock 16,497,200 -
Issuance of common stock for
acquisition consulting fees 748,329 -
Prepaid expenses acquired with
common stock 361,360 -
Extinguishment of convertible debentures - 4,220,000
Issuance of common stock for notes
and accounts payable net of
subscriptions receivable of $214,436 - 785,564
Purchase of East Wood Equity Venture, Inc.
Current assets, net of cash acquired $ 374,850 $ -
Oil and gas properties, net 5,804,002 -
Office furniture and equipment, net 15,748 -
Liabilities assumed (4,965,234) -
-------------- -------------
$ 1,229,366 $ -
============== =============
</TABLE>
See accompanying notes to these financial statements
27
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. NATURE OF OPERATIONS
The Company was incorporated under the laws of Ontario as Cotton Valley Energy
Limited (CVEL) on February 15, 1995. It acquired all of the shares of Cotton
Valley Energy Corporation (CVEC), a Nevada corporation, on June 30, 1995 in a
one-for-one share and warrant exchange. CVEC was also incorporated in February
1995. CVEL had no substantive activity, so the acquisition of CVEC was accounted
for as a recapitalization of CVEL with the net assets of CVEC. These
consolidated financial statements have been prepared as if the Company had
acquired CVEC at the Company's inception.
On June 14, 1996, the Company merged with Arjon Enterprises, Inc. (Arjon), an
Ontario corporation and reporting issuer in Ontario. As a result of that merger
the Company's name was changed to Cotton Valley Resources Corporation and a new
capital structure was established. Transactions in the accompanying financial
statements are reflected as if the resulting capital structure was in existence
since inception. Arjon had no business activities and its only asset consisted
of convertible debentures of the Company in the principal amount of $146,300.
The Company accounted for the transaction as an issuance of stock for the net
monetary assets of Arjon accompanied by a recapitalization. Former Arjon
shareholders received 686,551 common shares (representing approximately
7.5% of the then outstanding common shares) of the Company.
On April 30, 1996, the Company organized Cotton Valley Operating Company, a
Texas corporation (CV Operating) to operate the Company's oil and gas
properties. The Company on February 25, 1997, organized Cotton Valley Energy,
Inc., an Oklahoma corporation (CVEI) to acquire and operate the N.E. Alden Field
properties in Caddo County, Oklahoma. CVEI commenced operations on March 3,
1997. Aspen Energy Corporation, a Nevada corporation (Aspen), was an inactive
subsidiary of the Company, formed on May 1, 1996, which was used to accommodate
the merger of Aspen Energy Corporation, a New Mexico corporation (Old
Aspen) into Aspen on July 31, 1997. The principal asset of Old Aspen was its
interest in the Means Unit in Andrews County, Texas (Means Unit). On May 27,
1998, Aspen organized Cotton Valley Means, Inc. as a Texas corporation (CV
Means) and transferred all of its interest in the Means Unit to CV Means to
facilitate a $10 million financing relating to the development of this property.
In addition to CV Energy, CV Operating, CVEI, Aspen and CV Means, the Company
organized Mustang Well Servicing Company, a Nevada corporation (Mustang Well
Servicing), Mustang Oilfield Equipment Company, a Nevada corporation (Mustang
Equipment), and Mustang Horizontal Services, Inc., a Nevada corporation (Mustang
Horizontal) (collectively, Mustang Service Companies). All of the Company's
subsidiaries are wholly owned by the Company, except for CV Means, which is a
wholly-owned subsidiary of Aspen. On February 28, 2000 the Company's name was
changed to Aspen Group Resources Corporation.
The Company was in the development stage through June 30, 1999. The year ended
June 30, 2000 is the first year during which it was considered an operating
company. The Company's principal business activity is to acquire, explore, and
develop oil and gas properties.
The recoverability of amounts capitalized for oil and gas properties is
dependent upon the identification of economically recoverable reserves, together
with obtaining the necessary financing to exploit such reserves and the
achievement of profitable operations.
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Oil and Gas Properties
The Company follows the full-cost method of 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 into a "full-cost pool". A separate full cost pool is
established for U.S. and non-U.S. properties.
All capitalized costs of oil and gas properties, including the estimated future
costs to develop proved reserves, are amortized on the unit-of-production method
using estimates of proved reserves. Costs directly associated with the
acquisition and evaluation of unproved properties are excluded from the
amortization base until the related properties are evaluated. Such unproved
28
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
properties are assessed periodically and a provision for impairment is
made to the full-cost amortization base when appropriate.
Sales of oil and gas properties are credited to the full-cost pool unless the
sale would have a significant effect on the amortization rate. Abandonments of
properties are accounted for as adjustments to capitalized costs with no
loss recognized. Oil and gas drilling and workover equipment used primarily on
the Company's properties are included in the full cost pool.
The net capitalized costs are subject to a "ceiling test" which limits such
costs to the aggregate of the estimated present value of future net revenues
from proved reserves discounted at ten percent based on current economic and
operating conditions. A provision for an oil and gas property loss of
$1,262,000 was recognized in fiscal 1999.
Revenue Recognition
Revenue is accrued and recognized in the month the oil and gas is produced
and sold.
Inventories
Inventories, which consist primarily of oilfield equipment and supplies held for
resale, are stated at the lower of cost or market using the first-in, first-out
(FIFO) method.
Office Furniture and Equipment
Office equipment is recorded at cost and depreciated on a straight-line basis
over the estimated useful lives of the assets, which range from three to ten
years.
Debenture Financing Costs
Debenture financing costs are being amortized ratably over the life of the
related debenture.
Foreign Currency Translation
The Company's assets and principal activities are in the United States and its
functional currency is the U.S. dollar. The effects of exchange rate changes on
transactions denominated in Canadian dollars or other currencies are
charged to operations. Foreign exchange gains or losses were insignificant for
all periods presented.
Income Taxes
Income taxes are provided for the tax effects of transactions reported in the
financial statements and consist of taxes currently due, if any, plus net
deferred taxes related primarily to differences between the bases of assets and
liabilities for financial and income tax reporting. Deferred tax assets and
liabilities represent the future tax return consequences of those differences,
which will either be taxable or deductible when the assets and liabilities are
recovered or settled. Deferred tax assets include recognition of operating
losses that are available to offset future taxable income and tax credits that
are available to offset future income taxes. Valuation allowances are
recognized to limit recognition of deferred tax assets where appropriate. Such
allowances may be reversed when circumstances provide evidence that the deferred
tax assets will more likely than not be realized.
Net Earnings (Loss) Per Share
Per share information is based on the weighted average number of common stock
and common stock equivalent shares outstanding. As required by the Securities
and Exchange Commission rules, all warrants, options, and shares issued within a
year prior to the initial filing of a registration statement are assumed to be
outstanding for each year presented for purposes of the earnings (loss) per
share calculation. Dilutive earnings per share for the years ended June 30,
2000 and 1999 are the same as basic earnings per share because the exercise of
potentially dilutive securities does not have a significant effect on dilutive
earnings per share.
Cash Flow Statement
For purposes of the statements of cash flows, the Company considers all highly
liquid debt instruments purchased with an original maturity of three months or
less to be cash equivalents.
Stock-Based Compensation
Statement of Financial Accounting Standards No. 123 - Accounting for Stock-Based
Compensation (SFAS 123), which was effective for the Company beginning with its
1997 fiscal year, requires recognition of compensation expense for grants of
29
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
stock, stock options, and other equity instruments based on fair value. If the
grants are to employees, companies may elect to disclose only the pro forma
effect of such grants on net income and earnings per share in the notes to
financial statements and continue to account for the grants pursuant to APB
Opinion No. 25, Accounting for Stock Issued to Employees. The Company has
elected the pro forma disclosure alternative for employee grants.
Use of Estimates
The preparation of the Company's consolidated financial statements in conformity
with generally accepted accounting principles requires the Company to make
estimates and assumptions that affect the amounts reported in these financial
statements and accompanying notes. Actual results could differ from those
estimates. Significant assumptions are required in the valuation of proved oil
and gas reserves, which as described above may affect the amount at which oil
and gas properties are recorded. It is at least reasonably possible those
estimates could be revised in the near term and those revisions could be
material.
Principles of Consolidation
The consolidated financial statements include the accounts of the Company and
its wholly-owned subsidiaries. All material intercompany accounts and
transactions of consolidated subsidiaries have been eliminated in
consolidation.
Reclassifications
Certain reclassifications have been made to the prior years financial statements
to conform to the current year presentation.
Accounting Pronouncements
In June 1998, the Financial Accounting Standards Board (FASB) issued Statement
of Financial Accounting Standards (SFAS) No. 133, Accounting for Derivative
Instruments and Hedging Activities which establishes accounting and reporting
standards for derivative instruments, including certain derivative instruments
embedded in other contracts (collectively referred to as derivatives), and for
hedging activities. SFAS No. 133 is effective for all fiscal quarters of all
fiscal years beginning after June 15, 2000, with earlier application encouraged.
The Company does not anticipate a material impact on its financial position or
results of operations.
In June 2000, the FASB issued SFAS No. 138, Accounting for Certain Derivative
Instruments and Certain Hedging Activities. This statement amends the accounting
and reporting standards of SFAS No. 133 for certain instruments and certain
hedging activities. SFAS No. 138 also amends SFAS No. 133 for decisions made by
the Board relating to the Derivative Implementation Group (DIG) process. Certain
decisions arising from the DIG process that required specific amendments to SFAS
No. 133 are incorporated in this Statement. The statement is effective
concurrently with SFAS No. 133 according to the provisions of paragraph 48 of
SFAS No. 133. The Company does not anticipate a material impact on its
financial position or results of operations.
In December 1999, the Securities and Exchange Commission issued Staff Accounting
Bulletin No. 101 which summarizes certain of the staff's views in applying
generally accepted accounting principles to revenue recognition in financial
statements. The Company does not anticipate a material impact on its financial
position or results of operations.
In April 2000, the FASB issued Financial Interpretation Number (FIN) 44,
Accounting for Certain Transactions Involving Stock Compensation--an
Interpretation of Accounting Principles Board No. 25. FIN 44 clarifies the
application of Opinion No. 25. This Interpretation was effective immediately and
all issues are to be handled prospectively. The adoption of FIN 44 did not have
a material impact on the Company's financial position or results of operations.
3. OIL AND GAS PROPERTIES
East Wood Equity Venture, Inc.
During August 1999 the Company organized a Texas corporation Aspen Energy Group,
Inc (AEG) as a wholly-owned subsidiary. On September 16, 1999 AEG entered into
an agreement, effective July 1, 1999, to acquire 50% of the outstanding equity
30
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
shares of East Wood Equity Venture, Inc. (East Wood), an oil and gas company, in
exchange for the Company issuing 25,000,000 shares of common stock, and
21,230,897 special warrants (each exercisable for one share). On February 28,
2000, the Company acquired the remaining 50% of the outstanding equity shares of
East Wood for 26,230,897 shares of common stock and issuance of a note payable
in the amount of $3,000,000. For financial statement purposes the acquisition
was accounted for as a purchase and, accordingly East Wood's results are
included in the consolidated financial statements since the date of acquisition.
The aggregate purchase price was approximately $17.9 million, which exceeded the
net assets of East Wood by approximately $16.6 million. The excess was
allocated to oil and gas properties and will be amortized.
The following unaudited pro forma data summarize the results of operations for
the years ended June 30, 2000 and 1999 as if the acquisition had been completed
on July 1, 1998, the beginning of the 1999 fiscal year.
Pro Forma Information 2000 1999
----------- -------------
Net sales $ 3,481,718 $ 1,936,131
Net earnings (loss) $ 343,375 $(11,362,024)
Net earnings (loss) per share $ - $ (.57)
These pro forma amounts do not purport to be indicative of the results that
would have actually been obtained if the acquisition had occurred on July 1,
1998 or that may be obtained in the future.
Mercer Oil and Gas Co.
Effective April 1, 2000, the Company entered into a share purchase agreement to
acquire 100% of Mercer Oil and Gas Company (Mercer), an oil and gas company, for
1,000,000 shares. Mercer is a company affiliated with an officer of the
Company. Prior to the closing of the share purchase agreement, the Company
purchased certain oil and gas property interests of Mercer for $300,000 in cash.
For financial statement purposes the acquisition was accounted for as a
purchase. The aggregate purchase price was $343,800. The pro forma effects of
the acquisition has no effect on revenues, earnings or per share amounts as
Mercer had no results of operations prior to the date of acquisition.
4. NOTES PAYABLE AND LONG-TERM DEBT
On April 28, 2000, the Company entered into a credit agreement with a bank under
which it may borrow up to $25,000,000 limited to the borrowing base as
determined by the lender. The commitment amount was $12,160,000 at June 30,
2000. At June 30, 2000, there was $9,790,560 of outstanding borrowings under
this agreement. Interest on outstanding borrowings currently accrues at the
bank's base rate of interest plus one-half percent (base rate is 9.5% at June
30, 2000). The agreement also provides for a commitment fee of one-half
percent per annum on the average unused portion of the commitment. A facility
fee of one-half percent is assessed for increases in the commitment amount. The
facility is secured by the Company's oil and gas properties. Under the terms of
the credit agreement, the Company is required to maintain certain financial
ratios and other financial conditions. At June 30, 2000, the Company was in
compliance with those loan covenants.
Interest is payable monthly and the credit agreement requires monthly commitment
reductions as determined by lender. The monthly commitment reduction amount as
of June 30, 2000 was $160,000. The credit agreement matures on April 10, 2004.
Annual required commitment reductions of the credit agreement for the four years
subsequent to June 30, 2000 based on the current monthly commitment reduction
amount are $1,920,000, $1,920,000, $1,920,000 and $4,030,560 for fiscal years
ending June 30, 2001, 2002, 2003 and 2004, respectively.
In connection with the acquisition of certain oil and gas properties, the
Company, on February 28, 2000, issued a $3,000,000 convertible 9% note payable.
All unpaid principal and interest is due on or before December 31, 2000;
provided that at any time the Company proposes to pay this note payable, the
payees have the right, at their sole option, to receive all or any portion of
the amount outstanding by the issuance to the payees of 20,000,000
common stock of the Company.
Sale of Convertible Debentures
On December 30, 1997, the Company completed the private placement of $4,320,000
Convertible Debentures to a group of nine institutional investment firms. The
31
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Convertible Debentures were due December 31, 2001 and were secured by equipment
and other assets of the Company. Interest was payable annually at 7%. The
Convertible Debentures were convertible into shares of the Company's Common
Stock and Debenture Warrants, subject to adjustment upon certain events. During
October 1998, the Company and each Convertible Debentureholder agreed
to certain amendments to the Convertible Debentures and related documents,
including a waiver of the event of default. As consideration for the waiver,
the Company issued a total of 400,000 shares on a pro rata basis to each
Convertible Debentureholder. Additionally, the Company issued and delivered to
the Convertible Debentureholders approximately 1.6 million shares of common
stock in lieu of accrued interest and penalties of approximately $400,000 on the
Convertible Debentures for December 30, 1997 through December 31, 1998.
A beneficial conversion feature was recognized and measured by allocating a
portion of the proceeds equal to the intrinsic value of that feature to
stockholders' equity. The estimated fair value of $479,162 has been recorded as
a discount to the note and was amortized from the issue date to the date the
debenture was scheduled to become convertible.
On March 26, 1999 the Company assigned to the holders (Holders) of its then
outstanding $4.22 million of Convertible Debentures, assets (Transferred Assets)
having a book value of approximately $13 million in exchange for a release from
all obligations, including repayment and/or conversion, under the Convertible
Debentures. The obligations under the Convertible Debentures were assumed by
Mustang Well Servicing Company (MWSC) and the Company's ownership interest in
MWSC was transferred to an unrelated third party. Pursuant to an agreement
for conveyances in lieu of foreclosure between the Company, its subsidiaries and
the holders of the Convertible Debentures, the Company is entitled to the return
of all remaining Transferred Assets (well servicing equipment, horizontal
drilling equipment, certain oil and gas leases plus the remaining working
interest in the Company's Cheneyboro leases in Navarro County, Texas) and
remaining cash from the sale of Transferred Assets once the Holders have
received $4.22 million (plus interest and certain expenses, less revenues and
less 50% of the proceeds from sales of certain shares of common stock) from the
sale of the Transferred Assets. In connection with the transaction the Company
has recorded a pre-tax loss on disposition of assets of approximately
$9,808,000.
Means Credit Facility
On June 12, 1998, CV Means entered into a credit agreement with Triassic Energy
Partners, L.P. (Triassic), an affiliate of Cambrian Capital Corporation whereby
CV Means could borrow up to $10,000,000 on a multiple-advance, non-revolving
basis (Means Credit Facility).
As of June 30, 1999, the Company had drawn down $451,518 for working capital
and $388,600 for Means Unit property development purposes. A $10 million
promissory note dated June 12, 1998 with interest payable monthly
at the prime rate of Citibank N.A., New York, New York plus 2% was issued to
Triassic by CV Means in accordance with the terms of the Means Credit Facility.
As security for the Means Credit Facility, CV Means granted a security interest
in substantially all the assets of CV Means, including the Means Unit and all
income generated thereby. As further security for the Means Credit Facility,
Aspen, the sole shareholder of CV Means, pledged all the outstanding shares of
CV Means to Triassic.
At June 30, 1999, the entire amount of the note payable, $840,118, was included
in current liabilities as the Company was in default under the terms of the
Means Credit Facility. On May 23, 2000, the accrued interest and outstanding
principal balance of the note totaling $994,723 was paid.
5. STOCKHOLDERS' EQUITY
During the year ended June 30, 2000, the Company initiated three private
placement of its common stock, with warrants attached as set forth below.
The Company sold 1,200,000 shares and 1,200,000 warrants exercisable
for $.30 per share until September 30, 2002 for proceeds of $300,000.
The Company sold 1,122,857 shares and 1,122,857 warrants exercisable
for $.18 per share until June 15, 2001 for proceeds of $196,500.
32
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The Company sold 4,000,000 shares and 4,000,000 warrants exercisable
for $.18 per share until June 15, 2001 for proceeds of $600,000.
In fiscal year 2000, additional options and warrants were granted as set forth
below.
Option to acquire 120,000 units (one common share and one common share
purchase warrant) for $.25 per share through September 30, 2001 were
granted in connection with a private placement. This option was exercised
in fiscal 2000 and the common share purchase warrants were issued and are
exercisable for $.30 per share through September 30, 2002.
Option to acquire 112,286 units (one common share and one common share
purchase warrant) for $.18 per share through June 15, 2001 were granted
in connection with a private placement.
Option to acquire 400,000 units (one common share and one common share
purchase warrant) for $.18 per share through June 15, 2001 were granted
in connection with a private placement. This option was exercised in
fiscal 2000 and the common share purchase warrants were issued and
are exercisable for $.18 per share through June 15, 2001.
Options to acquire 2,000,000 shares for $.16 - $.31 per share through
August 27, 2000 were granted in connection with an acquisition.
Option to acquire 100,000 shares for $.14 per share through February 1,
2006 were granted in connection with services rendered.
Option to acquire 8,000,000 shares for $.24 per share through February 22,
2003 were granted to certain officers, employees and directors.
During the year ended June 30, 1999, the Company initiated a private placement
of its common stock, with warrants attached. The Company sold 1,628,825 shares
and 1,628,825 warrants exercisable for $0.22 per share until March 31, 2002 for
net proceeds of $356,305.
In fiscal year 1999, additional options and warrants were granted as set forth
below.
Option to acquire 150,000 shares for $.25 per share through December 31,
2001 were granted to certain non-employee directors.
The following tables summarizes the option and warrant activity for the years
ended June 30, 2000 and 1999:
June 30, 2000 June 30, 1999
Weighted Weighted
Average Average
Number of Exercise Number of Exercise
Shares Price Shares Price
--------- -------- --------- --------
Outstanding, beginning of year 5,563,800 $ 1.10 3,908,975 $ 1.87
Granted to:
Employees, officers and
directors 8,000,000 .24 150,000 .25
Others 9,575,143 .20 1,628,825 .22
Expired/canceled (3,749,629) .74 (124,000) 2.60
Exercised (4,984,524) .22 - -
----------- ----------
Outstanding, end of year 14,404,790 .43 5,563,800 1.10
=========== ==========
33
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
All outstanding warrants and options, except for 150,000 options, were
exercisable at June 30, 2000. If not previously exercised, warrants and options
outstanding at June 30, 2000 will expire as follows:
Weighted
Average
Number of Exercise
Year Ending June 30, Shares Price
--------------------- --------- --------
2001 4,130,619 $ .36
2002 2,154,171 1.05
2003 8,020,000 .29
2004 - -
2005 25,000 .14
2006 75,000 .14
---------
Total 14,404,790
==========
Presented below is a comparison of the weighted average exercise prices and
market price of the Company's common stock on the measurement date for all
warrants and stock options granted during fiscal years 2000 and 1999:
2000 1999
Number of Exercise Market Number of Exercise Market
Shares Price Price Shares Price Price
--------- -------- ------ --------- -------- ------
Fair value equal to
exercise
price 13,803,334 $ .22 $ .22 1,778,825 $ .22 $ .22
Fair value greater
than exercise
price - $ - $ - - $ - $ -
Exercise price
greater than fair
value 3,771,809 $ .22 $ .18 - $ - $ -
Pro Forma Stock-Based Compensation Disclosures - The Company applies APB Opinion
25 and related interpretations in accounting for its stock options and warrants
which are granted to employees. Accordingly, compensation cost has not been
recognized for grants of options and warrants to employees and directors unless
the exercise prices were less than the fair value of the Company's common stock
on the grant dates. Had compensation cost been determined based on the fair
value at the grant dates for awards under those plans consistent with the method
of FASB 123, the Company's net earnings (loss) and earnings (loss) per share
would have been changed to the pro forma amounts indicated below. The fair
values generated by the Black-Scholes model may not be indicative of the future
benefit, if any, that may be received by the option or warrant holder.
Year Ended June 30,
2000 1999
-------------------------
Net earnings (loss) applicable
to common stockholders:
As reported $ 94,116 $ (11,479,086)
Pro forma $ (1,544,760) $ (11,499,526)
Net earnings (loss) per common share:
As reported $ - $ (.57)
Pro forma $ (.02) $ (.57)
34
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The fair value of each non employee option granted in 1999 and each employee
option and warrant granted in 1998 was estimated on the date of grant using the
Black-Scholes option-pricing model with the following assumptions:
Year Ended June 30,
2000 1999
-----------------------
Expected volatility 128% 99%
Risk-free interest rate 5.5% 5.5%
Expected dividends - -
Expected terms (in years) 5.0 5.0
6. RELATED PARTY TRANSACTIONS
Effective April 1, 2000, the Company acquired ownership interests in 35 oil and
gas producing properties and 239 net mineral acres from a company affiliated
with an officer of the Company for 940,000 shares of common stock. The stock
was recorded at $343,800.
During fiscal 2000, the Company issued 3,125,000 shares of common stock in
settlement of $500,000 of accrued salaries and advances from related parties,
and 1,281,115 shares of common stock in settlement of a $256,223 note
payable to a related party.
Legal expenses of $14,000 were paid to a firm of which an officer of the Company
is a stockholder during fiscal 2000.
7. INCOME TAXES
The Company's deferred tax assets (liabilities) consist of the following:
June 30,
2000 1999
Deferred tax liabilities: Difference
in bases of oil and gas properties acquired $ - $ (1,598,000)
Costs capitalized for books and deducted
for tax (797,000) (759,000)
-------------- -------------
Total deferred tax liabilities (797,000) (2,357,000)
Deferred tax asset (net operating loss
carryforwards) 6,232,000 5,204,000
Less valuation allowance (5,435,000) (2,847,000)
--------------- -------------
Net deferred tax liability $ - $ -
=============== ==============
The difference from the expected income tax expense for the year ended June 30,
2000 at the statutory federal tax rate of 34% and the actual income tax expense
is primarily the result of net operating loss carryforwards. The difference
from the expected income tax benefit for the year ended June 30, 1999 at the
statutory federal tax rate of 34% and the actual income tax benefit is primarily
the result of deferred tax assets which more likely than not, will not be
realized.
At June 30, 2000, the Company has available net operating loss carryforwards of
approximately $18,331,000 to reduce future taxable income. These carryforwards
expire from 2001 to 2019.
8. CONCENTRATION OF CREDIT RISK AND FAIR VALUE OF FINANCIAL INSTRUMENTS
Financial instruments that potentially subject the Company to concentrations of
credit risk consist principally of cash and accounts receivable. The Company
maintains its cash with banks primarily in Oklahoma City, Oklahoma. The terms
of these deposits are on demand to minimize risk. The Company has not
experienced any losses related to these cash deposits and believes it is not
exposed to any significant credit risk.
35
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Accounts receivable consist of uncollateralized receivables from domestic and
international customers primarily in the oil and gas industry. To minimize risk
associated with international transactions, all sales are denominated in
U.S. currency. The Company routinely assesses the financial strength of it
customers. The Company considers accounts receivable to be fully collectible;
accordingly, no allowance for doubtful accounts is required. If amounts
become uncollectible, they will be charged to operations when that determination
is made. The Company had one customer that accounted for approximately 18% of
gas sales revenue and one customer that accounted for approximately 11% of oil
sales revenues for the year ended June 30, 2000.
Fair value of financial instruments are estimated to approximate the related
book value, unless otherwise indicated, based on market information available to
the Company.
9. COMMITMENTS AND CONTINGENCIES
Leases
The Company conducts its operations utilizing leased facilities under long-term
lease agreements, classified as operating leases. The Company also leases
certain equipment and vehicles under operating leases. Certain leases
provide that the Company pay taxes, maintenance, insurance and certain other
operating expenses and contain purchase options.
Future minimum lease payments in the aggregate required by noncancellable
operating leases with initial or remaining terms in excess of one year are
$224,756, $232,693, $221,088, $127,389 and $27,066 for fiscal years ending June
30, 2001, 2002, 2003, 2004 and 2005, respectively. Total rent
expense, all of which was minimum rentals, for fiscal 2000 and 1999 was
approximately $111,200 and $91,000, respectively and is net of sublease
rentals of $44,600 in 2000.
Litigation
The Company, in the normal course of business, is a party to a number of
lawsuits and other proceedings. The Company's management does not expect that
the results in these lawsuits and proceedings will have a material
adverse effect on the financial position or results of operations of the
Company.
Guarantee of Debt
The Company is the guarantor of certain obligations of Hat Creek Exploration in
the aggregate amount of $4,000,000 in connection with the purchase of certain
oil and gas properties. The note payable is dated May 4, 2000, bears interest
at 8%, and is payable in monthly installments over nine years. The debt is
expected to be paid with proceeds from the revenue interest in the oil and gas
properties. In the opinion of management, the ultimate disposition of this
guarantee will not have a material adverse effect on the Company's consolidated
financial condition, results of operations or future cash flows.
Letters of Credit
At June 30, 2000, the Company had $125,940 of outstanding letters of credit.
Employment Contracts
The Company maintains employment contracts with two officers through 2005 that
provide for a minimum annual salary, benefits and incentives based on the
Company's earnings. The contracts provide for lump sum severance payments,
certain benefits and accelerated vesting of options upon termination
of employment under certain circumstances or a change of control, as defined.
At June 30, 2000, the total commitment, excluding incentives, was $1,148,000.
Environmental Matters
The Company is engaged in oil and gas exploration and production and may become
subject to certain liabilities as they relate to environmental cleanup of well
sites or other environmental restoration procedures as they relate to the
drilling of oil and gas wells and the operation thereof. Although environmental
assessments are conducted on all purchased properties, in the Company's
acquisition of existing or previously drilled well bores, the Company may not be
aware of what environmental safeguards were taken at the time such wells were
drilled or during such time the wells were operated. Should it be determined
that a liability exists with respect to any environmental clean up or
restoration, the liability to cure such a violation could fall upon
36
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
the Company. No claim has been made, nor is the Company aware of any liability,
which it may have, as it relates to any environmental clean up, restoration or
the violation of any rules or regulations relating thereto.
Year 2000
The Company's computer systems and products successfully transitioned to the
Year 2000 with no significant problems. The Company will continue to monitor
latent problems that could surface at key dates or events in the
future. It is not anticipated that there will be any significant problems
related to these dates or events. To date, the Company has not incurred
material costs associated with Year 2000 compliance or any disruption with
vendors or operations. Furthermore, the Company believes that any future costs
associated with Year 200 compliance efforts will not be material.
10. SUPPLEMENTAL INFORMATION (UNAUDITED)
Costs incurred by the Company with respect to its oil and gas producing
activities are set forth below.
Years Ended June 30,
2000 1999
----------------- --------------
Exploration activities $ - $ 26,500
Proved property acquisition cost 29,954,437 81,874
Development costs 646,614 677,501
Drilling & well service equipment
acquisition cost - -
Drilling & well service equipment
tooling out cost - -
----------------- --------------
Total $ 30,601,051 $ 785,875
================= ==============
11. OIL AND GAS RESERVE INFORMATION (UNAUDITED)
Proved oil and gas reserves are the estimated quantities of crude oil,
condensate and natural gas which geological and engineering data demonstrate
with reasonable certainty to be recoverable in future years from known
reservoirs under existing economic and operating conditions. Proved developed
oil and gas reserves are reserves that can be expected to be recovered through
existing wells with existing equipment and operating methods. The following
estimated net interests in proved reserves are based upon subjective
engineering judgments and may be affected by the limitations inherent in such
estimation. The process of estimating reserves is subject to continual
revision as additional information becomes available as a result of drilling,
testing, reservoir studies and production history. There can be no assurance
that such estimates will not be materially revised in subsequent periods.
The Company emphasizes that reserve estimates of new discoveries or undeveloped
properties are more imprecise than those of producing oil and gas properties.
The Company's reserves are substantially from undeveloped properties.
Accordingly, these estimates are expected to change materially as future
information becomes available. The Company's reserves were estimated by
independent petroleum engineers. All of the Company's reserves are located
onshore in the continental United States. The recoverability of the proved
undeveloped reserves is dependent upon obtaining financing to exploit the
reserves.
37
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The following table sets forth proved oil and gas reserves at June 30, 2000,
1999 and 1998 together with changes therein:
Oil and Natural
Condensate Gas
(BBLS) (MCF)
-------------- -------------
Balance at June 30, 1998 5,770,000 12,761,000
Purchase of minerals in place - -
Production (12,000) (106,000)
Sales/disposal of minerals
in place (2,438,000) (10,353,000)
Revision of prior estimates (192,000) (2,302,000)
-------------- -------------
Balance at June 30, 1999 3,128,000 -
============== =============
Purchase of minerals in place 2,278,000 34,449,000
Production (34,000) (966,000)
Sales/disposal of minerals in place - -
Revision of prior estimates - -
-------------- -------------
Balance at June 30, 2000 5,372,000 33,483,000
============== =============
Proved developed reserves at June 30:
1999 36,000 -
-------------- -------------
2000 1,293,000 16,376,000
============== =============
The standardized measure of discounted future net cash flows at June 30, 2000
and 1999 relating to proved oil and gas reserves is set forth below. The
assumptions used to compute the standardized measure are those prescribed by
the Financial Accounting Standards Board and as such, do not necessarily reflect
the Company's expectations of actual revenues to be derived from those reserves
nor their present worth. The limitations inherent in the reserve quantity
estimation process described above are equally applicable to the standardized
measure computations since these estimates are the basis for the valuation
process.
Standardized measure of discounted future net cash flows relating to proved
reserves:
At June 30,
2000 1999
-------------- --------------
Future cash inflows $ 324,553,000 $ 53,178,000
Future production costs (76,939,000) (17,657,000)
Future development costs (17,650,000) (11,260,000)
--------------- ---------------
Future net cash flows, before income tax 229,964,000 24,261,000
Future income tax expenses (72,642,000) (7,278,000)
--------------- ---------------
Future net cash flows 157,322,000 16,983,000
10% discount to reflect timing of net
cash flows (82,801,000) (5,661,000)
--------------- ---------------
Standardized measure of discounted
future net cash flows $ 74,521,000 $ 11,322,000
=============== ===============
38
<PAGE>
ASPEN GROUP RESOURCES CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Changes in standardized measure of discounted future net cash flows relating to
proved reserves:
At June 30,
2000 1999
-------------- --------------
Standardized measure, beginning of period $ 11,322,000 $ 25,733,000
Net change in prices and production costs 43,006,000 746,000
Accretion of discount (77,140,000) 1,197,000
Sales of oil and gas, net of production costs (2,508,000) (118,000)
Sales and disposition of reserves in place - (22,795,000)
Purchase of reserves, net of future development
Costs 152,455,000 -
Development costs which reduced future
development costs 647,000 -
Revisions of quantity estimates 12,103,000 (2,705,000)
Change in timing of production and other - -
Net changes in income taxes (65,364,000) 9,264,000
---------------- ---------------
Standardized measure, end of period $ 74,521,000 $ 11,322,000
================ ===============
12. SUBSEQUENT EVENT
On August 7, 2000, the Company signed an agreement to acquire the oil and gas
operations of Crawford Oil Company and Leiker-Crawford Oil Company for a cash
purchase price of $1,375,000. This purchase includes wells, leases, equipment,
licenses, instruments and production. The Company financed the acquisition
with credit available under its credit agreement (see Note 4).
13. EARNINGS PER SHARE
The following data show the amounts used in computing earnings (loss) per share
and the effect on income and the weighted average number of shares of dilutive
potential common stock.
At June 30,
2000 1999
-------------- --------------
Net earnings (loss) $ 94,116 $ (11,479,086)
Effect of dilutive securities - -
-------------- --------------
Net earnings (loss) after effect of
dilutive securities $ 94,116 $ (11,479,086)
============== ==============
Weighted average number of common shares
used in basic earnings per share 83,676,588 20,036,818
Effect of dilutive securities
Stock options and warrants 884,895 -
------------- ---------------
Weighted average number of common shares and
dilutive potential commons stock used in
diluted earnings per share 84,561,483 20,036,818
============= ===============
Options and warrants to purchase approximately 9,266,000 shares of the Company's
common stock, with exercise prices of ranging from $.25 to $3.50, were excluded
from the June 30, 2000 diluted earnings (loss) per share calculation because
their effects were antidilutive.
39
<PAGE>
ITEM 8. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
There are not and have not been any disagreements between the Company and
its accountants on any matter of accounting principles or practices or
financial statement disclosure.
PART III
Information required in response to Items 9, 10, 11 and 12 will appear in
the Company's proxy statement to be filed within 120 days of the year end
covered hereby, and will be incorporated by reference into this Annual Report.
PART IV
ITEM 13. EXHIBITS, FINANCIAL STATEMENTS AND REPORTS ON FORM 8-KSB
(a)(1) Financial Statements: See Index to Consolidated Financial
Statements on page 20.
(a)(2) Exhibits: See Exhibit Index on page 42.
(b) During the last quarter of the fiscal year ending June 30, 2000,
the Company filed a Report on Form 8-KSB reporting actions taken
at the Company's Annual Meeting of Stockholders, which included
election of directors, appointment of auditors, approval of the
exercise of certain special warrants to acquire stock, approval
of an amendment to the Company's 1997 stock compensation plan,
approval of future private placements of the Company's common
stock for the purposes of acquisitions and providing
additional funding to the Company upon consent of 75% of the
directors of the Company and approval in a change in the name
of the Company to "Aspen Group Resources Corporation."
40
<PAGE>
SIGNATURES
Pursuant to the requirements of Section 13 or Section 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
September 25, 2000.
ASPEN GROUP RESOURCES CORPORATION(Registrant)
By: /s/ Jack E. Wheeler
Jack E. Wheeler
Chairman of the Board, President
and Chief Executive Officer
(Principal Executive Officer)
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons in the capacities and on
the dates indicated:
Signature Title Date
/s/ Jack E. Wheeler Chief Executive Officer September 25, 2000
Jack E. Wheeler and Director
/s/ James E. Hogue Director September 25, 2000
James E. Hogue
/s/ Anne Holland Director September 25, 2000
Anne Holland
/s/ Wayne T. Egan Director September 25, 2000
Wayne T. Egan
/s/ Randall B. Kahn Director September 25, 2000
Randall B. Kahn
41
<PAGE>
ASPEN GROUP RESOURCES CORPORATION
EXHIBITS INDEX
Exhibit
Number Description
------------ --------------------------------------------------
3(a)(1)* Articles of Amalgamation
3(a)(2)* Amendment to Articles of Amalgamation
3(b)* Bylaws
4* Description of the Common Stock
21 Subsidiaries
23 Consent of American Energy Advisors
27 Financial Data Schedule
*Previously filed and incorporated by reference herein.
EXHIBIT 21
SUBSIDIARIES
(i) Aspen Energy Corporation, a New Mexico corporation (inactive)
(ii) Aspen Energy Group, Inc., a Nevada corporation
(iii) Aspen Minerals Group, Inc., a Nevada corporation
(iv) Cotton Valley Energy, Inc., an Oklahoma corporation (inactive)
(v) Cotton Valley Means, Inc., a Texas corporation (inactive)
(vi) Cotton Valley Operating Company, a Texas corporation (inactive)
(vii) East Wood Equity Ventures, Inc., a Colorado corporation
EXHIBIT 23
CONSENT OF INDEPENDENT PETROLEUM ENGINEERS
We hereby consent to the reference of our name in the Annual report on Form 10-
KSB of Aspen Group Resources
Corporation for the year ended June 30, 2000, to which this consent is an
exhibit.
/s/ American Energy Advisor
42
<PAGE>
EXHIBIT 27
[ARTICLE] 5
[LEGEND]
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM THE
CONSOLIDATED STATEMENTS OF OPERATIONS AND THE CONSOLIDATED BALANCE SHEET
AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO THE JUNE 2000 10-KSB.
[/LEGEND]
<TABLE>
<S> <C>
[PERIOD-TYPE] YEAR
[FISCAL-YEAR-END] JUN-30-2000
[PERIOD-END] JUN-30-2000
[CASH] 319,246
[SECURITIES] 0
[RECEIVABLES] 1,297,730
[ALLOWANCES] 0
[INVENTORY] 77,305
[CURRENT-ASSETS] 2,182,063
[PP&E] 42,404,093
[DEPRECIATION] 1,882,870
[TOTAL-ASSETS] 42,774,666
[CURRENT-LIABILITIES] 5,869,447
[BONDS] 7,870,560
[PREFERRED-MANDATORY] 0
[PREFERRED] 0
[COMMON] 44,019,384
[OTHER-SE] (14,984,725)
[TOTAL-LIABILITY-AND-EQUITY] 42,774,666
[SALES] 3,481,718
[TOTAL-REVENUES] 3,481,718
[CGS] 2,080,397
[TOTAL-COSTS] 0
[OTHER-EXPENSES] 392,584
[LOSS-PROVISION] 0
[INTEREST-EXPENSE] 665,362
[INCOME-PRETAX] 94,116
[INCOME-TAX] 0
[INCOME-CONTINUING] 94,116
[DISCONTINUED] 0
[EXTRAORDINARY] 0
[CHANGES] 0
[NET-INCOME] 94,116
[EPS-BASIC] 0
[EPS-DILUTED] 0
</TABLE>
