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SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K
(Mark one)
[x] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(D) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the Fiscal Year Ended August 31, 1995
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(D) OF
THE SECURITIES EXCHANGE ACT OF 1934
Commission File Number 0-9120
THE EXPLORATION COMPANY
(Exact name of Registrant as specified in its charter)
COLORADO 84-0793089
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
500 NORTH LOOP 1604 EAST, SUITE 250, SAN ANTONIO, TEXAS 78232
(Address of principal executive offices)
Registrant's telephone number, including area code: (210) 496-5300
Securities registered pursuant to Section 12(b) of the Act:
None
Securities registered pursuant to Section 12(g) of the Act:
Common Stock, par value $0.01 per share
Indicate by check mark whether the Registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
Registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes [X] No
Indicate by check mark if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K is not contained herein, and will not be contained, to
the best of registrant's knowledge, in definitive proxy or information
statements incorporated by reference in Part III of this Form 10-K or any
amendment to this Form 10-K. [X]
The aggregate market value of the voting stock (which consists solely of
shares of Common Stock) held by non-affiliates of the registrant is $9,028,858
based upon the average of the high and low bid price of such stock as reported
by the Nasdaq Small-Cap Market under the symbol TXCO on November 8, 1995.
The number of shares outstanding of the Registrant's Common Stock as of
November 8, 1995, was 5,527,970 of which 4,012,826 shares were held by
non-affiliates.
Documents Incorporated by Reference: None
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INDEX AND
CROSS REFERENCE SHEET
PART I Page
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Item 1. Business . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3
Item 2. Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14
Item 3. Legal Proceedings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17
Item 4. Submission of Matters to a Vote of Security Holders . . . . . . . . . . . . . . . . . . . . . . . . . . 17
PART II
Item 5. Market for Registrant's Common Equity and
Related Stockholder Matters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18
Item 6. Selected Financial Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18
Item 7. Management's Discussion and Analysis of Financial Condition and
Results of Operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19
Item 8. Financial Statements and Supplementary Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23
Item 9. Changes in and Disagreements with Accountants on Accounting and
Financial Disclosure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23
PART III
Item 10. Directors and Executive Officers of the Registrant . . . . . . . . . . . . . . . . . . . . . . . . . . 24
Item 11. Executive Compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24
Item 12. Security Ownership of Certain Beneficial Owners
and Management . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25
Item 13. Certain Relationships and Related Transactions . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27
PART IV
Item 14. Exhibits, Financial Statement Schedules, and
Reports on Form 8-K . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28
Signatures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 29
Audited Consolidated Financial Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . F-1
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PART I
ITEM 1. BUSINESS
GENERAL DEVELOPMENT OF BUSINESS
The Exploration Company (the "Company") was incorporated in the State of
Colorado on May 16, 1979, for the purpose of engaging in oil and gas
exploration, development and production. The Company became publicly held
through an offering of its common stock in November, 1979. During 1984,
Spectrum Resources, Inc. ("SRI") and others exchanged certain oil and gas
properties for approximately eighty-six percent (86%) of the outstanding common
stock of the Company. Following this transaction, new officers and directors
were elected and the corporate offices of the Company were moved to San Antonio,
Texas.
Throughout its history, the Company's primary focus has been oil and gas
exploration. It's business strategy has been to acquire undeveloped mineral
interests, develop drilling prospects internally and to selectively participate
with industry partners in prospects generated by other parties in their
exploration activities, and, from time to time, to offer portions of its
developed and undeveloped mineral interests for sale.
The Company finances its activities through a combination of debt financing,
equity offerings and internally generated cash flow. The Company also may use
its equity securities as all or part of the consideration for the operating
investments it may make. There is no assurance that the Company will have
funds available to it in the future, either from internal cash flows,
additional borrowings, equity offerings, or other sources, to continue the
timely development of its oil and gas mineral interests.
Through 1992, the Company's revenues have been derived principally from the
sale of natural gas and oil production from working, royalty and mineral
interests, as well as the sale of the mineral interests it acquires through its
leasing activities. In order to provide the Company downstream opportunities,
management entered the alternative fuels vehicles (AFV) conversion business
through the creation of its own alternative fuels division, ExproFuels, in late
1992. The alternative fuels division's focus includes the conversion of
internal combustion engines to run alternately on Liquid Petroleum Gas (LPG),
Compressed Natural Gas (CNG) or Liquefied Natural Gas (LNG), and the design,
installation and operation of alternate fuel refueling stations. Since its
inception, the ExproFuels division has initiated operations in Texas, Arizona,
and Louisiana (subsequently closed in 1995), while actively pursuing
international opportunities in Europe, Asia and Latin America. The Company
believes significant operating profits can ultimately be derived from the
alternative fuels arena and continues to aggressively seek out and evaluate
expansion opportunities worldwide for this area of interest. Since 1994,
gross revenues from the ExproFuels division have surpassed gross revenues from
oil and gas operations, although profitable operating levels have not been
attained.
PRINCIPAL AREAS OF ACTIVITY
OIL AND GAS OPERATIONS
The Company has been actively evaluating mineral interests in major oil and gas
producing basins in South Texas, North Dakota, Montana and Alberta, Canada,
acquiring leasehold acreage for its ongoing exploration programs and
participating in the drilling of oil and gas wells.
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South Texas - Maverick County / Zavala County
Glen Rose/Rodessa Interval: The Company has owned at least a fifty percent
interest in 50,000 contiguous acres in Maverick County, Texas since 1989. The
property is on the Chittim Anticline, a large regional structure, under which
hydrocarbons have been found in as many as six separate horizons. One of these
zones is the Lower Glen Rose or Rodessa interval. It is a carbonate formation
that has produced billions of cubic feet of natural gas from patch reefs within
the zone on or near the anticline. Past development of the field was halted
because of the inability of operators to accurately predict the location of
these porosity-bearing reefs. The Company applied a different processing
method to the seismic available in the area and discovered what appeared to be
a method of determining the location of these porosity intervals. Further
investigation revealed that every well drilled in the vicinity of existing
seismic lines with a good porosity zone had a certain signature pattern on the
seismic processing while every well which lacked the porosity zone did not have
this pattern.
Through 1993, the Company participated in the drilling of five wells to test
theories of being able to locate the patch reef using 2-D seismic. In all
cases the Company was successful in predicting the presence of, or absence of,
porosity-bearing patch reefs using seismic interpretations. Although only one
of the wells, the Paloma #1-84, was a successful gas producer, the Company
used the information gained from each well to refine its interpretation and
model of the patch reefs depositional environment. The #1-84 well has
continued producing, averaging approximately 550 thousand cubic feet per day in
September, 1995, with cumulative production of 676 mmcf to date.
In 1993, the Company ran 3-D seismic over 21.5 square miles (approximately
13,500 acres) of the Company's lease position. The extensive seismic grid
involves over 150 miles of seismic lines that have now been processed and
reviewed by the Company. The Company was extremely pleased that its seismic
analysis identified numerous patch reefs on the 13,500 acres that represent
only a third of the potentially productive 50,000 acres. The 3-D seismic
delineated the shape and aerial extent of the patch reefs and confirmed that
previous wells were not drilled in structurally favorable positions.
Using this newly acquired 3-D seismic information, the Company drilled its
first well using 3-D seismic, the Paloma #1-107, in the third quarter of 1994.
The well, which had nearly 50 feet of gas-bearing porosity, tested at rates in
excess of two million cubic feet per day and had an absolute open flow
potential of 44,000,000 cubic feet per day. Due to pipeline restrictions, the
Company has only been able to produce the well at a rate of 1.25 million cubic
feet per day, with cumulative production of 607 mmcf to date. The Company has
identified over twenty separate patch reefs that are on the 3-D seismic area.
The Company owns an additional 37,000 acres surrounding the 3-D seismic grid
that is known to contain additional patch reefs both from production and 2-D
seismic analysis.
In September, 1994 and February of 1995, the Company drilled its next two Glen
Rose wells, the Paloma #1-133, and the Paloma #1-89. Although both wells
confirmed the accuracy of the 3-D seismic information by locating the reefs,
they were filled with water and not hydrocarbons. While the Company's
engineers and geologists are 100% successful in locating Glen Rose patch reefs,
Company management continues to review technical data to improve its ability to
distinguish between water-filled reefs versus gas-filled reefs. The Company
continues to believe it has large development possibilities on its 50,000 acres
because it has successfully demonstrated that the new 3-D seismic modeling can
accurately predict the presence of porosity and gas bearing zones within the
Lower Glen Rose formation. Based upon the seismic that has been run to date,
the Company can expect to have numerous porosity bearing patch reefs scattered
across its extensive acreage position.
Georgetown Interval: In addition to locating patch reefs, the investment in
the 3-D seismic data has proved to be valuable to the Company in locating
faults and fractures associated with production from the other five potentially
productive zones under the Maverick County leases. From its review of the data
from other strata, the Company has identified numerous drill sites targeting
various productive horizons. The Austin Chalk, Georgetown and Pearsall
intervals all produce on the lease from faults and fractures which have been
further defined using the comprehensive seismic data. Consequently, the
Company participated in drilling two wells into the Georgetown formation during
the 2nd and 4th quarter of 1995. The Paloma #1-89 was drilled in February to
test the Glen Rose
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but was plugged back to the Lower Georgetown interval and while initially
productive with gas, the well is shut-in awaiting a recompletion attempt to a
potentially more productive zone of the Upper Georgetown formation. The second
Georgetown test was a horizontal well, the Paloma #83-1H, drilled in June under
a farmout agreement with Edco Energy, Inc. and was completed in the Upper
Georgetown. While productive with gas, the #83-1H was shut-in at year end,
while Edco Energy and Company engineers analyze alternatives to enhance its
production of natural gas while laying a pipeline to the well.
Jurassic Interval: In September of 1994, the Company entered into an
agreement with TransTexas Gas Corporation to develop the deep Jurassic
formation under the Company's 50,000 acres. Under the terms of the agreement,
TransTexas was to drill a well of sufficient depth to test the Jurassic
(18,000'+) by September, 1995 in exchange for a 6.8% back in interest in the
well and over 238,000 acres in the overall prospect, plus other considerations.
Prior to the option's expiration, the Company, at TransTexas' request and for
additional consideration, agreed to extend the drilling period through
December, 1995. If drilling is successful, TransTexas will continue to earn
the right to exercise an option to purchase an interest in the Company's 50,000
acres as well as an interest in an additional 187,000 acres adjoining the
Company's leasehold from the base of the Sligo formation to the Jurassic
formation. Company management continues to feel that this arrangement provides
an affordable avenue to participate in the development of an extremely
expensive drilling project, as well as an excellent opportunity to increase its
technical understanding of, as well as its ownership position in, gross
leasehold acreage in the area of interest.
Leasehold Interest Acquisition: During 1995, the Company exercised a portion
of an option from one of its drilling partners, to increase its interest by
2.5% in its 33,000 acre Paloma Ranch leasehold. The increase in interest in
the Paloma Ranch from 50% to 52.5% includes the acreage held by TransTexas Gas
Corporation for the Jurassic project. Consideration for the purchase was
27,426 shares of the Company's common stock. The remaining portion of the
option, for an additional 12.5% interest, expires on April 1, 1996.
The Company continues to own additional leases in Zavala County, Texas. At
year-end, the Company had approximately 1,500 acres under lease in Zavala
County. Prospects for additional wells on the block have been generated by the
Company's geologist, although drilling capital for this project is not
available at this time. The leases are all held by production, with no
additional lease rental payments expected on this acreage in 1996. Company
management will continue to seek out partners to develop the remaining
prospects.
Montana / North Dakota - Williston Basin - Lodgepole Formation.
On August 31, 1995, the Company elected to exercise its option to purchase an
undivided 20% interest in oil and gas leases covering 56,858 gross acres,
28,258 net acres, in the Williston basin in North Dakota and Montana. The
Company purchased the interest from an affiliate of the Company's largest
shareholder. The Company has retained the option to purchase a 20% interest in
an additional 141,289 gross acres, 81,352 net acres. The purchase includes
over 13,500 miles of seismic lines across the basin covering many of the
purchased leases and identifies numerous Waulsortian mounds in the Lodgepole
formation.
Recent area discoveries by major and independent oil exploration companies have
testified before the North Dakota Industrial Commission of flows at rates in
excess of 8,000 barrels of oil per day from the reef-like mounds near
Dickinson, North Dakota. To date, six individual Waulsortian mounds have been
discovered. Additional wells have now been permitted farther from the original
discoveries and closer to the Company's acreage position. The geophysics that
the Company purchased includes seismic across the productive mounds which has
allowed the Company's geologists and geophysicists to predict where additional
mounds may be located. This seismic indicates potentially productive mounds in
many areas where the Company has oil and gas leases. A consulting geologist
from Bismarck, North Dakota, who is familiar with the area, evaluated one of
Duncan Oil's wells and estimated that it will ultimately produce approximately
5 million barrels of oil. This well may ultimately deliver over 50 million
dollars to its working interest owners net of operating costs and royalties.
Management is hopeful that its leasehold will ultimately contain several wells
of this magnitude which would increase the Company's cash flow considerably.
Significantly more geologic and geophysical analysis will need to be applied to
the newly acquired information before making the initial steps to drill the
quality locations the Company has identified.
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The Company acquired the interest for an initial downpayment of 186,731 shares
of its restricted common stock representing a value of $100.00 per net mineral
acre. Terms call for additional shares to be issued when an independent,
third party purchases a comparable interest in the block and thereby
establishes a final price to be paid by the Company. Management expects the
final component of this transaction to be concluded by the 2nd quarter of the
1996 fiscal year and believes this acquisition will have a significant and
positive impact on the Company's value if initial assessments prove to be
conclusive.
Canada - Alberta Leasehold
The Company continues to maintain its ownership in 4,065 acres in Alberta,
Canada approximately 75 miles northwest of Edmonton, Alberta which it acquired
in a stock transaction in 1992 from Canadian Synergy Oil & Gas, Ltd. Although
to date the Company has been unable to sell the leases or find a partner who
wishes to explore them, several parties have expressed an interest during 1995
and are pursuing alternatives with the Company.
Mineral Properties
The Company owns an 82.5% mineral interest in 3,804 acres in Uvalde and Kinney
Counties of Texas called the Holmgreen Ranch that contains large quantities of
rock asphalt. The property adjoining the ranch has produced rock asphalt
paving material since the late 1800's. Management commissioned a market study
in 1989 that concluded there was a market for an additional rock asphalt mine
but it would be marginally economic at that time. The study was based upon oil
prices of $20.00 per barrel of oil and the corresponding rock asphalt
equivalent price for synthetically manufactured material. As oil prices
increase and achieve stability at higher levels, the profit margin on an
operation of this nature should be improved. The Company will pursue the
possibility of developing a rock asphalt mine on the property once oil prices
have stabilized at this higher price. In the meantime, management is visiting
with companies who have techniques and processes which they believe may allow
the development of the asphalt as light oil. In September of 1992, Big Four
Ranch Corporation filed a lawsuit against the Company stating that it has a
prior claim to thirty-two and one-half percent (32.5%) of the minerals under
the Holmgreen Ranch which the Company acquired in September of 1988. The
Company continues to dispute this claim which is more fully described under
ITEM 3. LEGAL PROCEEDINGS.
EXPROFUELS OPERATIONS
The Exploration Company's focus includes the conversion of internal combustion
engines to run alternatively on Liquid Petroleum Gas (LPG), Compressed Natural
Gas (CNG) or Liquefied Natural Gas (LNG), and the installation and design of
alternative fuel refueling stations through ExproFuels, as well as traditional
oil and gas exploration and development. In late 1992, the Company's
management decided to enter the alternative fuels vehicles (AFV) conversion
business through its own alternative fuels division, ExproFuels. ExproFuels
was formed to provide downstream opportunities to The Exploration Company,
particularly as they relate to AFV conversions and vehicle refueling.
Since its inception, the ExproFuels division's business strategy has been to :
1- Provide state of the art internal combustion engine conversions
utilizing three natural gas based alternative fuels on a worldwide
basis: CNG, LNG or LPG.
2- Provide turnkey refueling solutions for the convenient and safe
delivery of alternative fuels.
3- Position the Company to participate in the ongoing business of
supplying alternative fuels to its expanding conversion customer
base.
4- Maintain an alternative fuel and equipment neutral position,
allowing the Company's marketing function complete flexibility in
responding to the diverse market opportunities with the "best fit"
fuel mix and equipment configuration available, as demanded by an
extremely specialized and constantly changing market place.
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5- Establish a strong presence in selected U.S. markets prior to 1996
when many more strenuous Environmental Protection Agency and
Department of Energy mandates were originally scheduled to come
into effect.
The combination of expertise in vehicle conversions, refueling station
construction and fuel sales form the basis of an additional potentially
effective market niche: financing conversions and/or fuel stations through
savings generated using the selected alternative fuel. ExproFuels provides
alternative fuel vehicles conversions to a growing number of private fleets as
well as the large mandated governmental markets at a reasonable and competitive
cost and follows up these conversions with superior, ongoing service and
maintenance.
ExproFuels also offers a cost-free AFV conversion program to qualified fleets in
exchange for long-term fuel contracts. This program is intended to initiate the
heaviest fuel consumers into alternative fuels use in the least painful manner
possible, while providing ExproFuels a base from which to expand its fuel
service capabilities. Through detailed cost and savings analysis, ExproFuels
outlines a cost-savings plan for fleets which qualify for ExproFuels' long-term
fuel contract program. ExproFuels will assure the fleet operator's compliance
with current laws and anticipated standards. This program is set up so that the
customer's fuel price may be based on either a percentage of unleaded gasoline,
assuring a fixed fuel cost savings, or various other fuel pricing scenarios.
ExproFuels provides clients with information regarding tax credits, deductions,
pollution credits and other incentives being offered by various federal and
state programs.
ExproFuels is actively soliciting vehicle conversions, maintenance contracts
and fuel service contracts from fleets that are either mandated in the next 3
years to comply in the various alternative fuels and clean air legislation
initiatives or choose to convert their fleet for economic benefits.
In its first 2 full years of operation, the Company's customers have come to
include the U.S. Government, the Government of Uzbekistan, three U.S. states
and several state agencies including: the Texas Department of Transportation,
the Railroad Commission of Texas, the General Services Commission of Texas, the
Department of Transportation of the State of Louisiana (through Ecogas, Inc.),
and the Department of Administration for the State of Arizona. Additionally,
ExproFuels has converted vehicles or built refueling stations for parishes,
school districts, transit systems, utilities, municipalities, private fleets
and light industrial users.
Texas Operations
San Antonio Facilities: The first conversion center operated by the Company
was opened in May, 1993, in San Antonio, the Company's home base. At year end,
current vehicle conversion backlog stood at 17 units. Since its opening, the
center has converted over 300 vehicles to LPG, including buses, vans,
forklifts, industrial engines, and assorted automobiles and trucks. The
facility has designed and installed approximately 16 private use LPG fuel
stations, including 18,000 gal., 3,900 gal., 1,800 gal. and 1,000 gal. storage
capacities, as well as an industrial facility with a 30,000 gal. storage
capacity. Subsequent to year end, it was awarded a $260,000 contract for the
design and installation of a CNG fueling station for Kelly AFB, in San Antonio.
During 1995 the center completed a contract with the Texas Department of
Transportation (TXDOT) which included the conversion of 139 vehicles to LPG
totaling $257,000. Additional contracts call for the installation and
operation of 12 fueling facilities in numerous Texas towns and cities for TXDOT
fleet usage. The Company owns and maintains the equipment. Contract
provisions include a commitment to provide certain minimum amounts of LPG to
various locations on an annual basis. Based on recent monthly activity,
annual fuel sales to TXDOT are expected to be greater than 150,000 gallons.
Subsequent to year end, additional TXDOT contracts were awarded to the
Company, adding 60,000 gallons of fuel usage commitments over the next 2 years.
Dallas Facilities: The Dallas conversion center opened in May, 1994. Since
its opening, the center has converted over 50 vehicles, and its customers
include five municipalities and one commercial fleet. The Company continues to
develop its network of fueling sites for new fleet customers as well as for the
existing LPG, CNG and LNG-powered vehicles on the road today. The Dallas
center built the State of Texas' first unmanned LPG refueling station across
from Love Field in Dallas which is available for private fleet use. Each
vehicle operator is provided with an access card which turns on the pumps,
provides data to the customer regarding miles driven since last
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refueling and keeps track of the number of gallons used both by customer and
vehicle. Usage of the facility has been ahead of projections and the Company
is seeking additional locations for expansion in Dallas, Houston and
San Antonio.
In November, 1994, the Company was awarded a contract by the City of Plano to
convert 29 vehicles to LPG and to provide fuel and the use of refueling
equipment for one year, with a one year option for a minimum of 110,000
gallons. The ultimate value of the contract is estimated at $115,000, and by
year end, receipts under the contract had reached $58,000. The fully automated
fuel facility went on-line during the 2nd quarter of fiscal 1995, with all
conversions completed by the year end. The City of Plano is currently preparing
to issue bid specifications for conversion of an additional 80 city vehicles and
a second automated fueling facility was being negotiated with the Company to
provide fuel under the existing contract for those vehicles.
Arizona Operations
ExproFuels continued its expansion into Arizona with the opening of affiliated
centers in Phoenix and Tucson to convert vehicles and supply conversion kits
under a new contract which it has been awarded by the State of Arizona.
Arizona's new state mandates require the conversion of 40 percent of the
state's fleet of 9,000 vehicles to alternative fuels by December 31, 1995.
Learning from its Louisiana experience, the Company, during the 1st quarter of
1995, began offering its services through existing, locally owned automotive
repair facilities under a management agreement with Arizona based Environmental
Fuel Systems. The existing facilities provide traditional automotive repair
services to the motoring market place, while remaining available to the Company
when needed for conversions. During the 2nd quarter of 1995, the Company was
awarded a contract to convert a portion of the State of Arizona vehicle fleet.
At year end, the Arizona legislature has yet to fund the contracts;
consequently, the Company does not know exactly when the conversion work will
begin. Through year end, Arizona facilities had converted 45 vehicles owned
by 1 federal and 4 local governmental units to run on either CNG or LPG and
had been low bidder on a local government LPG fueling station, but has not yet
been awarded the contract. The Company is actively seeking more bidding
opportunities to expand its conversion and fueling business in Arizona.
Louisiana Operations
In early 1994, ExproFuels was selected as a subcontractor for Ecogas, Inc.
which was awarded a contract to convert up to 25% of the State of Louisiana's
vehicles to CNG. Under ExproFuels' contract with Ecogas, ExproFuels was to
convert approximately one-half of these vehicles. ExproFuels was obligated
under the contract to be able to convert at least 100 vehicles per month.
Therefore the Company opened its largest conversion center in New Orleans,
Louisiana in February 1994, prepared for large volumes of conversions, as
required under its contract obligations to Ecogas, Inc. Unfortunately, Ecogas
was never able to meet the conversion rates established in the contract and the
number of state vehicles submitted for conversion were not sufficient to
maintain profitable operations. A total of 94 vehicles were eventually
converted to CNG at the Company's facilities prior to the suspension of
operations. During the 2nd quarter of 1995, ExproFuels laid-off or relocated
all of its staff in New Orleans, distributed its inventory and equipment to its
Dallas and San Antonio conversion centers, and successfully subleased the New
Orleans conversion center to an unrelated business on a noncancellable basis,
with sublease base terms extending through the base period of the Company's
original building lease. The Company has established an affiliate
relationship with an existing, independent conversion facility in Baton Rouge,
Louisiana to provide an ongoing presence in the marketplace, while having a
minimal ongoing overhead expense.
International Operations
Throughout fiscal year 1995, the Company has continued to investigate
international opportunities which could offer its alternative fuels division
new areas of profitable operation. As a recognized leader in this new
industry, the Company continues to come to the attention of foreign based
public and private entities interested in bringing our expertise to their
countries. It is the Company's challenge to identify and successfully
participate in those foreign opportunities that offer new, profitable markets
for our proven technologies.
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In order to more fully address the growing international interest and market
opportunities in the alternative fuels industry, the Company has acquired
additional expertise in international sales development by the recruitment of
experienced industry personnel. The International Sales Manager of the largest
manufacturer of CNG fueling stations in the U.S. was hired to fill the new
position of Vice President for Marketing and Sales for the Company. This
individual brought with him extensive experience in establishing international
representation throughout Latin America, as well as establishing domestic U.S.
marketing channels for the leading manufacturer in the CNG fuel station
industry.
Latin America/Europe: During the current year the Company has introduced its
technological knowledge and made its full level of services available to top
government officials and private sector interests in numerous countries,
including Mexico, Bolivia, Columbia, Venezuela, Ecuador, Peru and Central
America, as well as in Uzbekistan, Poland and Hungary. Many of these countries
or regions are in the early stages of the introduction of alternative fuels to
their motoring public. The ongoing privatization of state-owned oil and gas
industries in most of these countries offers a special window of opportunity for
the Company to participate in the development of in-country alternative fuels
infrastructure, conversions and associated operations. The Company is also
participating in industry trade shows, technical symposiums and other
opportunities to introduce itself to the marketplace in these developing
markets. The Company is currently in the process of establishing strategic
alliances or joint ventures with key industry participants in various countries
and feels strongly that significant revenue producing opportunities, currently
being developed, will be confirmed during the 2nd Quarter and initiated within
the current year.
Uzbekistan: In March, 1995, the Company signed a participation agreement with
the American Technical Institute (ATI) and American Engineering, Inc., both of
Memphis, Tennessee to provide project management, technical evaluation and
additional assistance for them in the development of a joint venture with the
government of Uzbekistan.
The purpose of the prospective joint venture with the Government of Uzbekistan
is to participate with that nation, on a profitable basis, in the conversion of
a majority of government owned motor vehicles to operate on CNG and to
develop, own and operate the CNG fueling infrastructure throughout that nation.
Numerous economic and environmental factors lead the Government of Uzbekistan
to aggressively support this venture. The primary factor is the significant
cost disparity between gasoline and natural gas in the region. Gasoline is
currently available through the Government at approximately $1.57 per gallon,
while abundant, domestically produced natural gas can be delivered to the
fueling stations at approximately $0.12 per equivalent gallon of gasoline. The
large cost savings provide a predictable source of funds for the significant
capital requirements of this national program.
The prospective venture will participate in the development of a manufacturing
industry for primary conversion components within Uzbekistan. Detailed studies
conducted over the 3rd and 4th quarters of 1995 support estimates of over
200,000 vehicle conversions and 300 refueling stations to be built during the
first 5 years of the venture. Revenue projections from a reduced portion of
the scheduled conversions are in excess of $200,000,000 to the joint venture.
In exchange for the option to acquire up to a 50% equity interest in the
developing joint venture, the Company agreed to provide certain levels of
equity funding, underwrite certain operating expenditures for the venture,
provide the services of certain employees and assist in attracting additional
industry participants to the venture. At year end the Company had earned a
10.82% equity interest in the venture, and had contributed a total of $150,000
in equity funds, plus a similar amount in underwritten expenditures. The
Company can increase its equity position up to 50% by investing up to a total
of $3,200,000 during the current fiscal year. The Company's level of
participation is dependent upon its ability to fund the project through various
phases and there is no assurance the additional investment funds will be
available to the Company in time to meet future funding requirements. The
Company believes that its equity position could generate significant new
revenues should the venture be moderately successful. In October, 1995, the
President of Uzbekistan signed a resolution authorizing key components required
for the ongoing viability of the venture. Although there are risks involved in
this project and additional investment will be necessary in addition to the
arranging of project financing, the potential profit is so great that the Board
of Directors has elected to increase the Company's efforts to bring this
project to a successful conclusion.
9
10
PRINCIPAL PRODUCTS AND COMPETITION
The Company's current principal products are natural gas and alternative fuels
vehicles conversions. The production and marketing of oil and gas are affected
by a number of factors which are beyond the Company's control, the effect of
which cannot be accurately predicted. These factors include crude oil imports,
actions by foreign oil-producing nations, the availability of adequate pipeline
and other transportation facilities, the marketing of competitive fuels and
other matters affecting the availability of a ready market, such as fluctuating
supply and demand. The Company sells all of its oil and gas under short term
contracts which can be terminated with less than 30 days notice. None of the
Company's production is sold under long-term contracts with specific
purchasers. Consequently, the Company is able to market its oil and gas
production to the highest bidder each month. The Company operates and directs
the drilling of oil and gas wells. It contracts service companies, such as
drilling contractors, cementing contractors, etc., for specific tasks. In some
wells, the Company only participates as a working interest or overriding
royalty interest owner.
During 1995, one purchaser of the Company's oil and gas production accounted
for 58% of that division's total oil and gas sales. In the event this major
customer declined to purchase future production, the Company believes that
alternative purchasers could be found for such production at comparable prices.
The oil and gas industry is highly competitive in the search for and
development of oil and gas reserves. The Company competes with a substantial
number of major integrated oil companies and other companies having materially
greater financial resources and manpower than the Company. These competitors,
having greater financial resources than the Company, have a greater ability to
bear the economic risks inherent in all phases of this industry. In addition,
unlike the Company, many competitors produce large volumes of crude oil which
may be used in connection with their operations. These companies also possess
substantially larger technical staffs which puts the Company at a significant
competitive disadvantage compared to others in the industry.
During 1995, the Company through its alternative division, ExproFuels,
converted gasoline-powered vehicles to run on LPG, CNG and LNG. ExproFuels
also built fuel stations and contracted to deliver fuel to clients. Several
other companies compete with ExproFuels in some or all of these markets. The
division's revenues, profitability and future rate of growth are substantially
dependent on its ability to increase its sales level primarily by winning bids
from various state, federal and local governmental agencies, municipalities and
school districts that have been mandated by various legislation to convert
their vehicle fleets to alternative fuels.
A few of these competitors are considerably larger than ExproFuels and have a
distinct advantage in bearing the economic risks which are inherent to this new
industry. The Company's ability to compete for the conversion of private
fleets depends on its ability to reduce costs and finance conversions for the
customer. ExproFuels' size allows it to control its cost of conversion;
however, its relatively small size limits its ability to finance clients.
Although the market is increasing, not many companies are involved in financing
conversions. ExproFuels has become more active in the conversion market by
keeping its costs low and being awarded bids in the mandated market.
During 1995, three purchasers of the Company's alternative fuels vehicles
conversion services and products accounted for 15%, 14% and 12%, respectively,
of that divisions total sales. In the event any or all these customers do not
continue as customers, the Company believes that additional customers will
continue to be found for such services and products at comparable prices. See
Note 11 to the Consolidated Financial Statements.
EMPLOYEES
As of August 31, 1995, the Company employed 13 full-time employees including
management. Additionally, consultants are employed by the Company on a
continuing basis. The Company believes its relations with its employees are
good. None of the Company's employees are covered by union contracts.
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GENERAL REGULATIONS
The extraction, production, transportation and sale of oil, gas and minerals as
well as the conversion of alternative fuels vehicles are regulated by both
state and federal authorities. The executive and legislative branches of
government at both the state and federal levels, have in the past and, it
appears, will continue to periodically propose and consider proposals for
establishment of controls on the development and use of alternative fuels,
energy conservation, environmental protection, taxation upon crude oil imports,
limitation of crude oil imports, as well as various other related programs. If
any proposals relating to the above subjects were to be enacted, the Company is
unable to predict what effect, if any, implementation of such proposals would
have upon the Company's operations. A listing of the more significant current
state and federal statutory authority for regulation of the Company's current
operations and business are provided herein below.
Federal Regulatory Controls
Oil and Gas Operations: Historically, the transportation and sale for resale
of natural gas in interstate commerce have been regulated pursuant to the
Natural Gas Act of 1938 (the "NGA"), the Natural Gas Policy Act of 1978 (the
"NGPA") and the regulations promulgated thereunder by the Federal Energy
Regulatory Commission ("FERC"). Maximum selling prices of certain categories
of natural gas sold in "first sales," whether sold in interstate or intrastate
commerce, were regulated pursuant to the NGPA. On July 26, 1989, the Natural
Gas Wellhead Decontrol Act (the "Decontrol Act") was enacted, which removed, as
of January 1, 1993, all remaining federal price controls from natural gas sold
in "first sales." The FERC's jurisdiction over natural gas transportation was
unaffected by the Decontrol Act.
Commencing in April 1992, the FERC issued Order Nos. 636, 636-A and 636-B
(collectively "Order No. 636"), which requires interstate pipelines to provide
transportation separate, or "unbundled," from the pipelines' sales of gas.
Although Order No. 636 does not directly regulate the Company's activities, the
FERC has stated that it intends for Order No. 636 to foster increased
competition within all phases of the natural gas industry. It is unclear what
impact, if any, increased competition within the natural gas industry under
Order No. 636 will have on the Company's activities. Although Order No. 636,
as well as orders in the individual pipeline restructuring proceedings are
currently pending, the Company cannot predict the ultimate outcome of court
review. This review may result in the reversal, in whole or in part, of Order
No. 636.
In December 1992, the FERC issued Order No. 547, governing the issuance of
blanket marketer sales certificates to all natural gas sellers other than
interstate pipelines. The order applies to non-first sales that remain subject
to the FERC's NGA jurisdiction. The FERC intends Order No. 547, in tandem with
Order No. 636, to foster a competitive market for natural gas by giving natural
gas purchasers access to multiple supply sources at market-driven prices.
Order No. 547 may increase competition in markets in which the Company's
natural gas is sold. Additional proposals and proceedings that might affect
the natural gas industry are pending before Congress, the FERC and the courts.
The natural gas industry historically has been very heavily regulated;
therefore, there is no assurance that the less stringent regulatory approach
recently pursued by the FERC and Congress will continue.
ExproFuels: The Clean Air Act of 1970, as amended, requires that the
concentration of pollutants in exhaust gases from the nation's cars, trucks and
buses fall below prescribed pollution limits. Emission standards for different
types of vehicles were established for carbon monoxide, hydrocarbons and
nitrogen oxides. The Clean Air Act authorized the Environmental Protection
Agency (EPA) to establish maximum concentration levels for the designated
pollutants to protect public health. The EPA subsequently established these
levels for six pollutants: carbon monoxide, nitrogen oxides, ozone,
particulate matter, sulfur dioxide and lead. The Act requires that states,
where the concentrations exceed the standards, develop plans to control these
emissions and to reduce these contaminates. States which do not comply face
possible bans on new source construction, freezes on federal grants and
reduction in highway funds. If states fail to implement an adequate plan, the
EPA may implement its own control measures which include downtown parking
restrictions, staggered working hours, and gasoline rationing, as well as many
other actions.
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12
The Clean Air Act Amendments of 1990 clarified how areas would be designated as
non-attainment areas for ozone, carbon monoxide and particulate matter in
accordance with the severity of the air pollution problem. In November 1991,
the EPA identified 98 non-attainment areas for ozone, 42 areas for carbon
monoxide and 71 areas for particulate matter. Additional areas may be added if
their air quality declines below the standards. Because automobiles, trucks
and buses are one of the biggest contaminators, the Company has recognized the
need for businesses and state and local governments to convert their vehicles
to run on clean fuels such as liquefied petroleum gas (LPG), compressed natural
gas (CNG) or liquefied natural gas (LNG). The Company believes that these
regulations will be strong motivators to these entities to convert their
vehicles thereby increasing activity in this newly emerging industry in which
the Company is participating through its alternative fuels division,
ExproFuels. For example, beginning with 1998 models, fleets with 10 or more
vehicles capable of being centrally refueled in the 22 smoggiest cities (the
serious, severe and extreme ozone nonattainment areas plus Denver, Colorado for
carbon monoxide nonattainment) must begin to buy clean fuel vehicles.
Beginning in the model-year 1998, 30 percent of new passenger cars and most
categories of light trucks and vans bought for these fleets must be clean fuel
vehicles. The percentage rises to 50 percent in 1999 and 70 percent in 2000.
For heavy-duty vehicles including school buses and delivery vans, the phase-in
stays a constant 50 percent of new purchases beginning in 1998. Past history
has shown that mandates of this type are generally met by the purchase of new
gasoline or diesel vehicles and converting them to run on alternative fuels.
Also under the amendments to the Clean Air Act are mandates for the
Environmental Protection Agency (EPA) which began testing urban bus fleets in
1994. If it is found that the buses are not meeting the new standards in use,
the EPA may mandate a switch to cleaner fuels in 48 cities with populations of
more than 750,000.
The Energy Policy Act of 1992 also provides federal mandates for AFV. The
primary aim of the Act is to reduce dependence of the United States on crude
oil imports. The Act directly affects light-duty federal, state and some
private fleets of at least 20 vehicles that can be centrally refueled and are
operated in metropolitan areas with populations of 250,000 or more. The
minimum federal fleet requirements for light-duty AFV are as follows: 5,000 in
1993; 7,500 in 1994; 10,000 in 1995; 25% in 1996; 33% in 1997; 50% in
1998; and 75% for 1999 and thereafter. In addition, federal fleets are
mandated to use commercial fueling facilities that offer alternative fuels to
the public as much as practicable. Purchases of light-duty vehicles by state
governments are required to be AFV in the following amounts: 10% in 1996; 15%
in 1997; 25% in 1998; 50% in 1999; and 75% in 2000 and thereafter. Private
sector companies that make alternative fuels, such as natural gas companies,
are required to introduce AFV into their fleets as follows: 30% in 1996; 50%
in 1997; 70% in 1998; and 90% in 1999 and thereafter. Executive Order 12844,
issued in April 1993, requires federal agencies to acquire, subject to the
availability of funds and life-cycle costs, AFV in numbers that exceed by 50%
the requirements for 1993 through 1995 set forth in the Energy Policy Act of
1992.
State Regulatory Controls
Oil and Gas Operations: In each state where the Company conducts or
contemplates conducting oil and gas activities, such activities are subject to
various regulations. In general, the regulations relate to the extraction,
production, transportation and sale of oil and natural gas, the issuance of
drilling permits, the methods of developing new production, the spacing and
operation of wells, the conservation of oil and natural gas reservoirs and
other similar aspects of oil and gas operations. In particular, the State of
Texas (where the Company conducts the majority of its oil and gas operations)
regulates the rate of daily production allowable from both oil and gas wells on
a market demand or conservation basis. At the present time, none of the
Company's production has been curtailed due to reduced allowables. The Company
knows of no newly proposed regulations which will significantly curtail its
production.
ExproFuels: The Clean Air Act Amendments of 1990 have caused at least sixteen
states to pass legislation requiring the purchase or conversion of vehicles to
run on clean fuels. Most of these require certain percentages of the state's
own vehicle fleet to be converted by various dates. In addition, some states
have mandated that school buses and metro transit systems convert percentages
of their fleets within given time frames. Texas, for example, has legislated
that school districts which operate more than 50 buses, state agencies with
more than 15 vehicles and local transit authorities are not allowed to purchase
or lease vehicles which cannot operate on an approved alternative fuel after
September 1, 1993. By September 1, 1997, 50% of these fleets must be
converted; and by
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September 1, 2001, 90% must be operating on alternative fuels. In addition,
Texas Senate Bill 769 requires that local government fleets of more than 15
vehicles and private fleets of more than 25 vehicles in non-attainment areas
must convert their vehicles. Under HB 2575, Arizona has mandated that 40% of
the state's fleet of vehicles must be converted to alternative fuels by December
31, 1995 and 90% by December 31, 1997. Additionally, large cities are required
to convert city-owned vehicles and school buses under the following schedule:
18% by 1996; 25% by 1997; 50% by 1999; and 75% by 2001. In Louisiana, Acts
927 and 954 require that 30% of the state's vehicles be converted to alternative
fuels by September 1, 1994; 50% by September 1, 1996; and 80% by September 1,
1998. Many states have similar legislation which either legislates that
conversions occur or gives incentives to help with the conversions although
punitive actions have not always followed non-compliance.
In March, 1995 SB 200 was passed by the Texas Legislature which significantly
affects certain sectors of the alternative fuels industry. The bill
reclassified reformulated gasoline as an alternative fuel, in recognition of
its cleaner, less polluting attributes. While effectively diminishing the
effect of upcoming deadlines on state regulatory mandates on some public and
private sector fleets operating in Texas, it established higher standards of
allowable emissions for certain public fleets, such as state agencies and
public transportation fleets.
The Company believes that this legislation will not significantly impact its
alternative fuel division, ExproFuels, which is actively involved in helping
these public sector entities convert their vehicles to meet these mandated
quotas. Additionally, the Company is closely monitoring the legislative
developments in Arizona where it also operates. As of year end, the Company
was not aware of any Arizona legislation which would significantly dilute that
state's mandate and related deadlines effecting the alternative fuel vehicles
industry, while there is no assurance that new legislation will not be
forthcoming in some future date which could adversely effect the Company's
ability to conduct its business in Arizona.
Environmental Regulation
Oil and Gas Operations: The Company's extraction, production and drilling
operations are subject to environmental protection regulations established by
federal, state and local agencies. To the best of its knowledge, the Company
presently believes that it is in compliance with the applicable environmental
regulations established by the agencies with jurisdiction over its operations.
The Company is acutely aware that the applicable environmental regulations
currently in effect could have a material detrimental effect upon its earnings,
capital expenditures or prospects for profitability. The Company's competitors
are subject to the same regulations and therefore, the existence of such
regulations does not appear to have any material effect upon the Company's
position with respect to its competitors. The Texas Legislature has mandated
in Senate Bill 1103 a regulatory program for the management of hazardous wastes
generated during crude oil and natural gas exploration and production, gas
processing, oil and gas waste reclamation and transportation operations. The
disposal of these wastes, as governed by the Railroad Commission of Texas, is
becoming an increasing burden on the industry and could severely impact the
ability of the Company to continue as an operator in the future.
ExproFuels: The Clean Air Act of 1970 and the Clean Air Act Amendments of
1990 have made improving the air quality in the United States a major goal. To
this end, the EPA has established maximum permitted levels for six major air
pollutants: carbon monoxide, nitrogen oxide, ozone, particulate matter, sulfur
dioxide and lead. Certain metropolitan areas have been designated as
non-compliance areas. These areas have been classified as marginal, moderate
or severe depending upon the level of contamination. The EPA has established a
time schedule for each of these classifications to be brought within compliance
with the Act. ExproFuels, the Company's alternative fuels division, is
converting vehicles to run on LPG, CNG or LNG which lowers the level of the
pollutants being emitted in the non-attainment area because these alternative
fuels are much cleaner-burning fuels than gasoline. ExproFuels is,
consequently, subject to the EPA standards for emissions from vehicles which
have been converted. Some states have adopted their own standards; most of
these have adopted those of the California Air Resources Board (CARB) which has
been a leader in defining acceptable limits for pollutants. ExproFuels must
also comply with the applicable state regulations regarding the conversion of
vehicles and the sale of alternative fuels.
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Federal and State Tax Considerations
ExproFuels: In October of 1992, Congress passed the Comprehensive National
Energy Policy Act which encourages the use of natural gas by providing a
deduction for a portion of the incremental cost of motor vehicles that are
propelled by clean burning fuels. The amount of the deduction depends on the
gross vehicle weight and ranges from $50,000 for heavy trucks and buses, $5,000
for medium weight trucks and $2,000 for other motor vehicles. The Act also
allows a deduction for the cost of qualified clean fuel vehicle refueling
property, defined as property used to refuel clean-fuel vehicles at the point
where the fuel is delivered. The aggregate cost that may be taken into account
in determining the amount of the deduction may not exceed $100,000 at any
location. The deductions apply to properties placed in service after June 30,
1993. At least twenty-four states have enacted their own legislation to give
additional incentives to companies desiring to convert or purchase natural gas
vehicles. These incentives vary considerably from state to state. Arizona
reduces the license tax and gives a tax credit of $1,000 for alternative fuel
vehicles purchased in 1994, 1995 and 1996. Oklahoma gives a state income tax
credit of up to $1,500 and has provided interest free loans of up to $1,500,000
to local government and school districts to convert vehicles. Louisiana
provides that 20% of the conversion costs can be deducted as a tax credit.
Texas has legislated that propane and natural gas are exempt from the recent
increase of $0.05 per gallon motor fuels tax.
ITEM 2. PROPERTIES
PHYSICAL PROPERTIES
The Company's administrative offices are located at 500 North Loop 1604 East,
Suite 250, San Antonio, Texas. These offices, consisting of approximately
5,700 square feet, are leased through February 28, 1997 at $5,756 per month.
In addition, the alternative fuels division, ExproFuels, leases four
facilities, as follows:
Approximate Monthly
Location Type Square Feet Rental Expiration
---------- ---- ------------- -------- ----------
San Antonio, Texas conversion 5,000 $2,500 May 1996
New Orleans, Louisiana conversion 15,000 4,200 February 1997
Dallas, Texas conversion 7,000 1,900 May 1997
Dallas, Texas fueling 8,200 400 July 1996
The New Orleans facility has been closed by the Company, and the facility has
been subleased under a noncancellable lease, expiring February, 1997, for
$4,500 per month.
Management believes the facilities are suitable to accommodate anticipated
growth of the ExproFuels division in these cities over the next several fiscal
years. While no additional conversion center locations are anticipated to be
leased in other cities during the next fiscal year, the Company is seeking
additional fuel station sites.
Oil and Gas Properties
All the Company's oil and gas properties, reserves and activities are located
onshore in the continental United States, except for 4,065 acres of undeveloped
oil and gas leases in Canada. There are no quantities of oil or gas subject to
long-term supply or similar agreements with foreign government authorities.
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Proved Reserves, Future Net Revenue and
Present Value of Estimated Future Net Revenues
The following unaudited information as of August 31, 1995, relates to the
Company's estimated proved oil and gas reserves, estimated future net revenues
attributable to such reserves and the present value of such future net revenues
using a 10% discount factor. Estimates of proved developed oil and gas
reserves attributable to the Company's interest at August 31, 1995 and 1994 are
set forth in Note 10 of the audited financial statements set forth in this
Annual Report on Form 10-K.
Present Value of Estimated Future Net Revenues from proved developed oil and
gas reserves as of August 31, 1995, are as follows:
Present Value of
Years Ending Estimated Future
August 31 Net Revenues
------------ ---------------
1996 $ 252,372
1997 200,543
1998 152,927
1999 116,557
2000 88,912
-
Thereafter 410,729
-----------
TOTAL $ 1,222,040
===========
The present value of estimated future net revenues is computed in accordance
with SEC requirements. These amounts were computed by applying current prices
for oil and gas, giving effect only to those escalations in prices of gas which
are currently contractually defined, and deducting estimated future
expenditures to develop and produce the proved reserves and applying a discount
factor of 10%.
Proved oil and gas reserves are the estimated quantities of crude oil, natural
gas liquids 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. No reserve
estimates have been filed with or included in reports to any federal or foreign
government authority or agency, other than the Securities and Exchange
Commission, since the Company's latest Form 10-K filing.
Production
The following table summarizes the Company's net oil and gas production,
average sales prices and average production costs per unit of production for
the periods indicated.
Years Ended August 31
1995 1994 1993
----- ------ ------
Oil:
Production in Barrels 2,598 2,479 561
Average sales price per Barrel $16.89 $14.55 $17.98
Gas:
Production in MCF 177,238 82,656 20,450
Average Sales Price per MCF $ 1.62 $ 2.23 $ 1.89
Average cost of production per equivalent Barrel (1) $ 1.32 $ 1.80 $ 6.97
(1) Oil and gas were combined by converting gas to barrel equivalent
on the basis of 6 Mcf of gas = 1 barrel of oil. Production costs
include direct lease operations and production taxes.
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Producing Properties - Wells and Acreage
The following table sets forth the Company's producing wells and developed
acreage assignable to such wells at August 31, 1995:
Productive Wells
----------------------------------------------------------------------------
Developed Acreage Oil Gas Total
------------------ -------------------- ------------------- ----------------
Gross Net Gross Net Gross Net Gross Net
----- --- ----- --- ----- --- ----- ---
2,080 509 5 .86 8 2.04 13 2.9
Productive wells consist of producing wells and wells capable of production,
including shut-in wells and wells awaiting pipeline connections to commence
deliveries and oil wells awaiting connection to production facilities.
A "gross well" or "gross acre" is a well or acre in which a working interest is
held. The number of gross wells or gross acres is the total number of wells or
acres in which working interest are owned. A "net well" or "net acre" is
deemed to exist when the sum of fractional ownership interest in gross wells or
gross acres equals one. The number of net wells or net acres is the sum of
fractional working interests owned in gross wells or gross acres expressed as
whole numbers and fractions thereof.
Undeveloped Acreage
As of August 31, 1995, the Company owned, by lease or in fee, the following
undeveloped acres, all of which are located in the Continental United States or
Canada, as follows:
Est. FY 1996
United States Gross Acres Net Acres Delay Rentals
------------- ----------- --------- -------------
Texas 55,408 38,695 $ 86,000
North Dakota 56,858 5,369 1,800
Montana 7,280 83 0
Canada
------
Alberta 4,065 3,309 6,476
------- ------ --------
Totals 123,611 47,456 $ 94,276
======= ====== =========
A Texas lease containing approximately 33,000 acres also has a requirement to
drill a well every 90 days to keep the lease in effect since the primary term
of the lease has expired. The Company is presently drilling under the terms of
the lease and hopes to be able to keep the lease in force by continuous
development during the year.
Drilling Activity
The Company participated in the drilling of three exploratory wells during the
last fiscal year on the Paloma Ranch in Maverick County, Texas. The Paloma
#1-133 was drilled using the Company's 3-D seismic to test the Glen Rose
formation. Although the well found over 100 feet of porosity bearing reef, the
patch reef was full of water so the well was plugged and abandoned.
Subsequently, the Company drilled the Paloma #1-89 which was also a Glen Rose
test located using the 3-D seismic on the Paloma Ranch. Unfortunately, this
reef was also full of water;
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therefore, no completion attempt was made in the Glen Rose formation. However,
casing was cemented through the Georgetown formation and a completion attempt
will be made in the Upper Georgetown at a later date. Edco Energy, Inc. and the
Company drilled the Paloma "A"83-1H during the last quarter of the year using
2-D seismic data to locate Georgetown faults. Two separate laterals were
drilled in the Upper Georgetown interval in hopes of improving production over
typical Georgetown completions. The well has been completed but produces only
150 mcfd, indicating that the wellbore is either damaged or the formation has
very low permeability. Management will evaluate the well over the next few
months to determine whether or not production can be increased by additional
capital expenditures.
Mineral Properties
The Company owns an 82.5% mineral interest and leases 17.5% of the minerals and
100% of the surface interest related to mining operations in and to the 3,809
acres Holmgreen Ranch in Kinney and Uvalde Counties of Texas. Delay rental
costs are expected to be $3,809 in 1996. This property contains in excess of
one billion tons of rock asphalt which is used as road building material in the
area. A marketing study which the Company commissioned in 1989 indicates that
the property is marginally economic at current oil prices. Increased oil
prices or increased asphalt markets would make the reserves very valuable to
the Company. Management has visited with companies who are interested in
developing the reserves either by conventional mining of rock asphalt or by the
use of technologies and processes which may allow the production of the asphalt
as light oil. The Company is disputing a claim against this property which is
more fully described under ITEM 3. LEGAL PROCEEDINGS.
ITEM 3. LEGAL PROCEEDINGS
In September, 1992, Big Four Ranch Corporation (Big Four) field suit against
the Company, Spectrum Resources, Inc. (SRI), and Holmgreen Ranch Corporation
(Holmgreen) alleging that Big Four had a prior claim to a 32.5% mineral
interest in the Holmgreen Ranch. The Company owns 82.5% of the minerals under
the ranch and has a mining lease on the surface and remaining 17.5% which were
purchased by Big Four from Continental Federal, a Federal Savings and Loan
Association. Big Four alleges that Continental Federal had received a final
deficiency judgment against Holmgreen prior to the time Holmgreen transferred
the interest to SRI. The Company in turn purchased its interest from SRI on
September 9, 1988 in exchange for shares of the Company's common stock. The
Company has denied the allegations contained in the suit. Because the Company
has a lease on all of Big Four Ranch's mineral and surface interest in the
Holmgreen Ranch, which was ratified by Continental Federal, Big Four's
predecessor-in-title, the Company does not believe that an adverse decision
would have a material effect on the Company's ability to develop the property.
This matter is currently set for trial on January 12, 1996, in the 239th
Judicial District Court of Brazoria County, Texas.
There are no other legal proceedings involving the Company.
ITEM 4. SUBMISSION OF MATTERS TO VOTE OF SECURITY HOLDERS
No matter was submitted to a vote of security holders of the Company during the
fourth quarter of the fiscal year ended August 31, 1995.
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PART II
ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER
MATTERS
The following is a range of high and low bid prices for the Company's common
stock for each quarter of the last two years based upon bid prices reported by
the National Association of Securities Dealers Quotations system under the call
symbol "TXCO":
Range of Bid Prices
-------------------
Quarter ended: High Low
-------------- ------ -----
August 1995 $ 3.59 $ 2.50
May 1995 4.00 2.75
February 1995 2.93 2.37
November 1994 3.31 2.56
August 1994 $ 3.00 $ 2.25
May 1994 4.25 2.37
February 1994 3.56 2.37
November 1993 3.62 2.87
As of September 30, 1995, there were approximately 1,900 holders of record of
the Company's Common Stock. The transfer agent for the Company is Bank of
Boston, Boston, Massachusetts. The Company has not paid any cash dividends on
its Common Stock and does not expect to do so in the foreseeable future.
ITEM 6. SELECTED FINANCIAL DATA
The following selected financial information is derived from and qualified in
its entirety by the Consolidated Financial Statements of the Company and the
Notes thereto as set forth in this Annual Report on Form 10-K commencing on
page F-1.
Years Ended August 31
-------------------------------------------------------------------------------------
1995 1994 1993 1992 1991
---- ------ ------ -------- -------
Operating Revenues $ 1,104,604 $ 1,058,073 $ 116,716 $ 144,761 $ 294,154
Loss before extraordinary items (2,153,365) (1,550,953) (2,277,144) (1,337,992) (597,398)
Loss per common share before
extraordinary items (1) (0.44) (0.36) (0.64) (0.44) (0.21)
Total Assets 4,592,892 3,152,988 2,629,741 2,788,497 3,478,480
Long-term obligations (2) 2,349,849 715,598 277,752 22,865 141,374
Shareholders' equity 1,377,747 1,613,121 1,214,297 1,974,440 2,406,958
Weighted average shares
outstanding (1) 4,863,961 4,267,363 3,533,973 3,016,922 2,885,770
(1) Amounts reflect 1 for 50 reverse common stock split as of March 29, 1993.
(2) Excludes current portion of long-term obligations.
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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
The following is a discussion of the Company's financial condition and results
of operations. This discussion should be read in conjunction with the
Consolidated Financial Statements of the Company and Notes thereto.
CAPITAL RESOURCES AND LIQUIDITY
In fiscal year 1995, the Company was successful in raising funds under a
convertible note payable and indenture of trust agreement which was initially
started in the 4th quarter of fiscal 1994. During this year, the Company raised
$1,689,697 in funds under this long term debt agreement, increasing to
$1,764,697 the total amount raised under this agreement. Although the
debentures offering raised a significant amount of needed capital for the
Company, the funds were not received as timely as was projected. The delay in
obtaining the funds reduced management's ability to initiate its intended
development activities as planned. The Company also raised $508,000 from sales
of Common Stock in fiscal 1995 and $261,000 from the sale of oil and gas
properties. Proceeds were utilized to fund the Company's cash loss from
operations of $2,030,000, payment of interest of $180,000, payments on current
portion of debt and capital leases of $142,000 and for capital expenditures of
$545,000. The capital expenditures included approximately $290,000 to develop
oil and gas properties in Maverick County, $105,000 for equipment purchases for
use in the U.S. operations of ExproFuels, and $150,000 for ExproFuels growing
participation in international operations through its joint venture investment
in CNG, International, LLC.
At August 31, 1995, the Company had current assets of $1,199,000 and current
liabilities of $865,000, resulting in $334,000 in working capital, as compared
to a working capital deficit of $360,000 at August 31, 1994. However, the
Company had a deficit of "quick" assets (cash and receivables) to current
liabilities of $443,000 at year end 1995 compared to a deficit of $554,000 at
year end 1994. Management hopes to raise additional funds during 1996 to
improve the Company's liquidity. Management is working with a European
investment group that has successfully raised capital for Luxello Properties,
Inc., now Organic Solutions, which was a company spun-off from the Company in
1986. The group has indicated it will use its best efforts to raise up to
three million dollars for the Company over the next few months. Management is
expectant that the group will be successful as evidenced by their previous
successes.
In fiscal year 1994, the Company's investment advisor, KRI Growth Stocks,
successfully completed a $1,000,000 private placement which it had begun earlier
during the 1993 fiscal year by raising an additional $330,000. On September 21,
1993, the Company prepared a $2,500,000 offering pursuant to Regulation S and
entered into a best efforts agreement with VenBanc, Inc. to raise the funds.
VenBanc was only partially successful as it raised $673,000 through May 10,
1994, when the Company officially closed the offering. The Company also issued
$500,000 of convertible debentures. Further, existing shareholders exercised
outstanding warrants for 97,500 shares of stock which raised $244,000 in cash,
and a private placement of 86,000 shares of stock raised $248,000 in cash. In
summary, the Company was successful in raising $1,995,000 (net of expenses)
during the 1994 fiscal year. Proceeds were utilized to fund the Company's 1994
cash loss from operations of $1,017,000, to retire long-term debt of $380,021
and for capital expenditures of $593,000. The capital expenditures included
$363,000 spent to develop the Company's oil and gas properties in Maverick
County and $230,000 for equipment purchases in the expanding ExproFuels
division.
At August 31, 1994, the Company had current assets of $464,000 and current
liabilities of $824,000, resulting in a working capital deficit of $360,000.
This compares to a working capital deficit of $1,000,000 at August 31, 1993.
This improvement was primarily attributable to the raising of cash from the
sale of stock and long-term debt borrowings as described above, as well as from
the cancellation of accrued payroll in amount of $322,000 by the Company's
president.
During the fiscal year ended August 31, 1993, the Company financed its
operations by selling 446,000 shares of its common stock for $892,000. This
capital infusion, along with $200,000 in borrowings, allowed the Company
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to continue limited development of its oil and gas properties, to commence
operations in its alternative fuel division, ExproFuels, and to fund cash
losses from operations for 1993 of $701,000.
The major components of the Company's plans, and the requirements for
additional capital at August 31, 1995, include the following:
Oil and Gas Division
To accelerate development of its 50,000 acre Maverick County leasehold interest
by drilling, approximately 36 well sites have been identified using 21.5 square
miles of 3-D seismic data acquired by the Company in 1993. During 1996, the
Company plans to drill a minimum of 3 additional wells, in keeping with lease
renewal requirements, with the first well to spud in the 2nd quarter of fiscal
1996. The Company's share of the cost of each well is approximately $240,000
for a completed well and $120,000 for a dry hole. The Company has an option to
increase its interest in 33,000 acres of its Maverick County leasehold by up to
12.5% though April, 1996, and expects to exercise 7.5% of its option in the 1st
quarter of fiscal 1996. Delay rentals required to maintain the Company's
interest in its undeveloped leasehold acreage are estimated to be $94,000 in
1996.
ExproFuels Division
Capital requirements to sustain ExproFuels growth are projected to be at least
$500,000 in capital expenditures and an additional $500,000 in working capital
such as accounts receivable and inventory. These plans provide for new Company
owned fuel station installations to be opened during fiscal year 1996, as well
as continuing, ongoing international marketing efforts in Europe, Asia and
Latin America. These expenditures will be in the form of capital investments
in foreign joint ventures or in general and administrative expenditures in
support of such activities.
Summary of Capital Resources and Liquidity
The ability of the Company to carry out some or all of these plans will depend
on its ability to raise additional capital and ultimately to achieve ongoing
profitable operations. Although the Company believes it will be able to raise
the funds required to meet its current obligations during fiscal year 1996,
there are no assurances that the funds to sustain operations or fund the
Company's capital needs or debt service requirements will be available. The
continuation of depressed oil and gas prices, an inability to establish
significant additional oil and gas production or insufficient growth towards
profitability for the alternative fuels division could have a material and
direct effect on the Company's cash flow from operations and anticipated levels
of working capital, and could force the Company to revise its planned capital
expenditures and challenge the viability of continuing in its two industry
segments. These factors, among others, raise substantial doubt about the
Company's ability to continue as a going concern. Nevertheless, the Company's
management believes that its current capital raising efforts will ultimately be
successful enabling the Company to meet its obligations.
RESULTS OF OPERATIONS
1995 Compared to 1994
Oil and Gas Division
Revenues from oil and gas sales in 1995 increased to $304,000 from $209,000 in
1994, primarily as a result of the Paloma #1-107 gas well having production
for a full year. Exploration expenses increased by 93,000 from 1994 to 1995
due to the drilling of one dry hole during the year, the Paloma #1-133, plus
the write off of the portion of the drilling cost of the Paloma #1-89 below
its final completion horizon in the Upper Georgetown interval. Depletion
increased by $52,000 from 1994 to 1995 due to increased production volumes from
the first full year of the Paloma # 1-107, as mentioned above. Depletion per
equivalent barrel of production remained almost unchanged, increasing to $3.17
per barrel in 1995 from $3.14 per barrel in 1994. The Company again recognized
an impairment of $171,505 on its Holmgreen Ranch mineral interest.
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General and administrative costs increased by $288,000 from 1994 to 1995. The
significant components of the increase included a $200,000 one time charge in
1995 for marketing services, and increases in public expense of $26,000 and
consulting fees expense of $31,000.
ExproFuels Division
ExproFuels division revenues experienced a net decrease of $48,000 from 1994 to
1995. Components of this net decrease were a $49,000 decrease in conversion
sales and a $65,000 decrease in fuel station construction that was partially
offset by a $66,000 increase in alternate fuel sales. Lower conversion sales
were primarily the result of the closing of the New Orleans conversion
facilities. Lower fuel station construction revenues reflect the Company's
decision to build more Company owned fuel stations to support its growing fuel
sales. Alternative fuels sales increased significantly due to the first full
year of operation of Company owned fuel stations in Plano and Dallas, as well
as additional fuel stations place in operation during 1995 under the Texas
Department of Transportation contract.
Costs of sales increased by $361,000 from 1994 to 1995 due to higher than
expected costs associated with the New Orleans location operations, both while
it was in operation and in association with its closing. Additionally, higher
start-up cost in the Arizona operations are reflected entirely in 1995, while
revenues have been limited to date in this new market.
Other costs included a decrease of $145,000 due to the one time charge, in
1994, for writing off of the Company's previously acquired technological
rights. General and administrative expense decreased by $146,000 from 1994 to
1995. Included in this change are declines in consulting services of $18,000,
rent expenses of $ 32,000, general shop supplies, tools and equipment
maintenance of $42,000 and payroll overhead of $30,000.
Summary
In total, revenues from operations increased by $46,000 from 1994 to 1995.
This slight revenue increase was significantly offset by the increase in total
costs and expenses of $544,000 from 1994 to 1995, resulting in the overall
increase in loss from operation of $460,000 for the year.
Other non-operating expense changes consisted primarily of an increase in
interest expense of $154,000 from 1994 to 1995, due directly to the completion
during the year of borrowings under the convertible note payable and indenture
of trust, with such borrowings increasing by $1,690,000 from 1994 to 1995.
As a result of the above, net losses, before extraordinary item, increased by
$603,000 for the year ended August 31, 1995.
1994 Compared to 1993
Oil and Gas Division
Oil and gas sales increased during fiscal year 1994 to $209,000, an increase of
$148,000 over 1993. This significant increase is primarily attributable to the
production from the Paloma #1-107 as well as from the Paloma #1-84 which was
completed during 1993 and had a full year of production during 1994. The
#1-107, which was completed during the third quarter of 1994, has nearly fifty
feet of gas-bearing porosity within the Glen Rose formation. The well was
flowed at rates in excess of 2,000,000 cubic feet of gas per day and had an
absolute open flow potential of 44 million cubic feet of gas per day. The
decrease in exploration expenses for 1994 to $58,000 compared to $187,000 in
1993 reflects that no dry holes were drilled during 1994, no significant
seismic expenses were incurred, and delay rentals were reduced by approximately
$34,000 on the Paloma leasehold as production requirements were achieved by the
Company under terms of its lease. Depletion expense for 1994 increased by
approximately $45,000 due to the Company's increased production volumes during
the year. Abandoned leases and equipment decreased from $1,305,000 in 1993 to
$31,000 in 1994. This significant decrease is due to the fact
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that only 1,265 acres of the Company's Canadian leases were dropped during 1994
as opposed to significant abandonments in Canada and Zavala and Maverick County,
Texas during 1993.
Because the Company's efforts to economically develop its Holmgreen Ranch
mineral property have been unsuccessful to date, coupled with the uncertainty
of when economic conditions many allow the Company to do so, the carrying value
of the Holmgreen mineral property was reduced in 1994 by recording an
impairment expense of $171,000. No oil and gas properties were impaired by the
Company during 1994.
ExproFuels Division
Due to the fact that the ExproFuels division commenced its operations during
the final part of the fiscal year ended August 1993, a direct comparison of
1994 operating results to 1993 would not be meaningful. Following are the
significant operating results of the ExproFuels division for its year ending
August 31, 1994.
Two new conversion facilities were opened during 1994, one in New Orleans,
Louisiana and one in Dallas, Texas. The New Orleans facility was opened
primarily as a result of the Company being selected as a subcontractor for
Ecogas, Inc., who was awarded a contract to convert up to 25% of the state's
vehicles to CNG. Under ExproFuels' contract with Ecogas, ExproFuels was to
convert at least 100 vehicles per month. Accordingly, in February the Company
opened a state-of-the-art conversion facility and hired and trained nine
mechanics plus two support staff in anticipation of generating revenues of
approximately $250,000 per month. Ecogas and the State of Louisiana have been
unable to deliver vehicles to convert near the rates established in the
contract. Therefore, the Company laid off six of its mechanics as of August
31, 1994. Revenue from this location was approximately $182,000 for fiscal
year 1994, which is not sufficient for the Company to operate profitably at
this location. The Company has taken steps to attempt to rectify the number of
vehicles made available to convert, but generally has been unsuccessful.
The Dallas, Texas, conversion facility was opened during May of 1994 primarily
to convert a private fleet of approximately thirty vehicles to LPG. Under the
terms of this contract, the Company is financing the cost of the
conversion for the customer in exchange for lease fees and a five-year fuel
sales contract. The customer is refueling its vehicle fleet at the Company's
LPG refueling station constructed during the year near Love Field Airport in
Dallas. The Company anticipates that the refueling facility, which is
available for private fleet use, will act as an additional incentive for other
private fleets to convert their vehicles. In addition, the Company has hired
an outside consultant to help generate additional conversion sales in the
Dallas area.
The San Antonio, Texas conversion facility, which was the first conversion
facility opened during 1993, continued to grow during fiscal 1994 as conversion
sales from this facility grew to approximately $400,000 for the year. In
addition, two refueling construction contracts totaling $162,603 were completed
by the San Antonio conversion personnel.
During the second half of 1994, the Company became increasingly dissatisfied
with the progress made by Greenway Environmental Research related to the
development and technology rights to convert diesel engines acquired by the
Company during 1993. Management finally determined it could no longer work
with Greenway in an effective manner and, accordingly, its Development and
Licensing Agreement with Greenway was terminated effective August 31, 1994.
The carrying value of the technological rights and its related obligation were
written off, resulting in a charge to current years operations of $144,000.
The ExproFuels division continued to invest heavily in sales and promotional
activities during the 1994 fiscal year. These activities, as well as the
increased overhead expenses associated with its new conversion facilities
opened during the year, resulted in total general and administrative expenses
within the division to increase to approximately $700,000 for the year. Major
components of general and administrative expenses include $117,000 for
promotional related expenses, $108,000 for occupancy related expenses, and
$357,000 for salaries, wages and consulting services. The overall loss from
operations for the ExproFuels division was $835,543 for the year ended August
31, 1994.
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1993 Compared to 1992
Oil and Gas Division
During 1993, oil and gas revenues increased to $61,000 from $44,000 in 1992.
This increase was primarily attributable to the Company's successful
participation with a 12.5% carried working interest in Prime Operating's Paloma
#1-84. Other revenues in 1993 amounted to only $11,000 compared to $101,000 in
1992. This decrease was due to the Company not selling any oil and gas
properties in 1993 as opposed to 1992 when it recognized a gain on the sale of
properties of $55,000 and other operating income was $45,000. The Company also
had a small overriding royalty interest in two successful wells that commenced
production in late 1993. This helped increase the Company's present value of
future net revenues by over 250% to $694,000 at August 31, 1993.
Operating costs and expenses remained fairly stable as compared to 1992, except
that the Company recognized a non-cash increase in abandoned leases in 1993 to
$1,305,000 from $688,000 in 1992. This was the result of the Company releasing
all but 5,330 acres it held under lease in Canada. This acreage was released
because the Company could not find an equity partner willing to participate in
the Canadian leasehold acreage. The Company also dropped certain of its leases
in Zavala and Maverick Counties in Texas due to the oil and gas industry's
reduced interest in drilling in certain of the leased areas.
ExproFuels Division
During fiscal year 1993, the Company commenced operations in the alternative
fuels industry through its ExproFuels division. The Company acquired the
worldwide rights to technology to convert diesel engines to alternative fuels
from Greenway Environmental Research at a cost of approximately $400,000 under
a three-year Development and Licensing Agreement. In May of 1993, the division
opened its first conversion facility in San Antonio, Texas and was awarded its
first contract with the Judson Independent School District which generated
$41,000 in sales prior to year end.
The increase in general and administrative expenses during 1993 of $155,000 was
primarily attributable to the increased overhead and start-up expenses of the
ExproFuels division.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The Consolidated Financial Statements and Notes thereto are set out in this
Form 10-K commencing on page F-1.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURES
None
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PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
The following table sets forth certain information regarding the directors and
executive officers of the Company, as of November 8, 1995:
Name Position Age
-------- ------------ -------
Stephen M. Gose, Jr. Chairman of the Board of Directors 65
Thomas H. Gose Director and Secretary 40
James E. Sigmon President and Director 47
Stephen M. Gose, Jr., has served as Chairman of the Board of Directors of the
Company since July, 1984. He has been active for more than five years in
exploration and development of oil and gas properties, in real estate
development, and in ranching through the operations of Cibolo Properties, Inc.,
its predecessors and affiliates. Inc.
Thomas H. Gose is the sole Director, CEO and President of Cibolo Properties,
Inc. He formerly served as President of Spectrum Resources, Inc. (a majority
shareholder of the Company) since 1987. Since February, 1989, he has also
served as Director of the Company and as Secretary of the Company since January
2, 1992. He has been the President of the Company's alternative fuels
division, ExproFuels, since its inception. Thomas H. Gose is the son of
Stephen M. Gose, Jr.
James E. Sigmon has served as the Company's President since February 1985. He
has been a Director of the Company since July 27, 1984.
Each of the aforementioned Executive Officers and/or Directors have been
elected to serve for one year or until his successor is duly elected.
ITEM 11. EXECUTIVE COMPENSATION
Summary Compensation Information: The following table contains certain
information for each of the fiscal years indicated with respect to the chief
executive officer and those executive officers of the Company as to whom the
total annual salary and bonuses exceed $100,000:
SUMMARY COMPENSATION TABLE
Name and Other Annual Long-term All other
Principal Position Year Salary Bonuses Compensation Compensation Compensation
- ------------------ ---- ------ ------- ------------ ------------ ------------
James E. Sigmon 1995 $ 72,000 $ 0 $ - (1) $ 0 $ 0
President & CEO 1994 88,958 0 0 0 0
1993 109,000 0 0 0 0
(1) Other compensation is less than 10% of salary and bonuses.
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OPTIONS/SAR GRANTS IN LAST FISCAL YEAR
Potential Recognizable
Value at Assumed
% of Total Options Annual Rates
# Options Granted to Employees Exercise Price Expiration ---------------------------
Name Granted (1) in Fiscal Year per Share Date 5% 10% 20%
------------- ----------- -------------------- -------------- ----------- ---- ---- ----
James E. Sigmon 100,000 100% $ 2.75 2/10/05 $6,875 $13,750 $27,500
(1) Options to purchase common stock were granted on February 10, 1995 and
approved by Shareholders April 28, 1995.
AGGREGATED OPTION/SAR EXERCISES IN LAST FISCAL YEAR
AND FISCAL YEAR END OPTION/SAR VALUES
Number of Unexercised Value of Unexercised
# Shares Value Options/SARs Options/SARs
Name Exercised Realized August 31, 1995 August 31, 1995
------------- --------- -------- ----------------------- ---------------------
James E. Sigmon 50,000 $ 93,750 150,000 $ 20,500
Stephen M. Gose, Jr. 100,000 26,848 -0- -0-
All of Mr. Sigmon's unexercised options were exercisable as of August 31, 1995.
COMPENSATION OF DIRECTORS
Members of the Board of Directors of the Company are not compensated for any
services provided as a director except that during the year ended August 31,
1995, Mr. Stephen M. Gose, Jr. was paid $46,000 in his capacity as Chairman of
the Board of Directors.
EMPLOYMENT CONTRACTS
The Company had an employment agreement with its president, Mr. James E.
Sigmon, which sets his salary at a minimum of $72,000 annually. The agreement
is cancelable with 90 days notice by the Company.
COMPENSATION COMMITTEE INTERLOCKS AND INSIDER PARTICIPATION
The Company does not have a compensation committee. During the year ended
August 31, 1995, the following officers participated in deliberations of the
Company's Board of Directors concerning executive officer compensation: Mr.
James E. Sigmon, Mr. Thomas H. Gose and Mr. Stephen M. Gose, Jr.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The following tables set forth beneficial ownership of the Company's common
stock, its only class of equity security. The percent owned is based on
7,262,985 shares outstanding which includes 1,735,015 shares under options and
warrants as of November 8, 1995.
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SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
The following table sets forth information concerning all persons known to the
Company to beneficially own 5% or more if its common stock.
Name and Address of Number of Shares Percent
Beneficial Owner Beneficially Owned Owned
------------------ ------------------ -------
Thomas H. Gose (1) 1,165,044 16.04%
500 North Loop 1604 East
Suite 250
San Antonio, TX 78232
Western Exploration Pty. Ltd. 400,000 5.51%
11490 Westheimer
Suite 200
Houston, TX 77077-6841
Donald Q. Greenway(2) 375,000 5.16%
40104 Industrial Park Circle
Georgetown, TX 78626
(1) Includes 1,144,644 shares owned by Spectrum Resources, Inc. (SRI). SRI
is a wholly-owned subsidiary of Cibolo Properties, Inc. Thomas H. Gose, as
the sole shareholder of Cibolo, has the power to vote the shares owned by
SRI. Accordingly, he is deemed to be the beneficial owner of the SRI
shares.
(2) Represents a warrant to acquire shares that is exercisable at August 31,
1995, and expires July 31, 1996.
SECURITY OWNERSHIP OF DIRECTORS AND EXECUTIVE OFFICERS
The following table sets forth the number of shares of common stock
beneficially owned as of November 8, 1995 by each director, each executive
officer named in the Summary Compensation Table and by all directors and
executive officers as a group. Information provided is based on the Form 4's
obtained from stock records of the Company and the Company's transfer agent.
Number of Shares Percent
Name Beneficially Owned Owned
-------- ------------------ -------
Thomas H. Gose 1,165,044 16.04%
James E. Sigmon 200,000 2.75%
Stephen M. Gose, Jr. 100,000 1.38%
All Directors and Executive
Officers as a group (3 persons) 1,465,044 20.17%
Information provided is based on Form 4's, stock records of the Company and the
Company's transfer agent.
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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
In August, 1995, a company affiliated with the Company's Chairman loaned the
Company $50,000. The loan was repaid in full on August 31, 1995.
During 1995, the Company acquired unproved oil and gas leasehold acreage from
a company owned by the Chairman, with a basis of $300,000, for 186,731 shares
of its Common Stock.
During the year ended August 31, 1994, Mr. Harold D. Rogers, a former Vice
President of the Company, represented certain persons, including himself, who
have joint ventured with the Company in certain oil and gas properties. During
1994, the Company acquired an option for $200,000 from one of these joint
ventures. The option allows the Company to increase its interest in certain
oil and gas properties. A part of this option was exercised in 1995, reducing
the capitalized portion of the option to $166,667 at August 31, 1995.
In May 1994, a corporation in which Mr. Rogers owns an interest, loaned the
Company $500,000 under the terms of a convertible promissory note. The terms
of the note include interest at 10% per annum, payable quarterly, and a
conversion option at $3.00 per common share of stock. The note is callable at
the option of the Company in the event the closing bid price of the Company's
common stock averages $7.00 for a period of forty-five days.
In February 1994, the Company reached an agreement with its president, James E.
Sigmon, to restructure his employment compensation. Mr. Sigmon agreed to
reduce his annual salary from $109,000 per year to $72,000, and was granted a
one percent (1%) overriding royalty interest in the Paloma and Kincaid leases
in Maverick County, Texas, in which the Company has an interest.
In February 1994, a corporation in which Jim Holisky, a former controller of
the Company owned an interest, entered into a drilling joint venture with the
Company to drill a gas well in Maverick County, Texas. The corporation
contributed $100,000 to the joint venture in exchange for a 25% working
interest in the gas well, and options for a 5% working interest in four
additional gas wells. On May 2, 1994, the Company acquired 80% of the 25%
working interest (net 20% working interest) for 60,150 shares of common stock.
In November 1993, James E. Sigmon, the president of the Company canceled
accrued payroll in the amount of $322,492 due to him from previous years under
his employment agreement. The Company accounted for this extinguishment of
debt as an extraordinary item for the year ended August 31,1994.
As of August 31, 1993, the Company owed Spectrum Resources, Inc., an affiliated
company, $31,275 for prior services as well as a note payable in the amount of
$10,073 bearing interest at 12% per annum. In December of 1993, the note was
modified to include the remaining amount for services plus accrued interest.
The note was paid in full in 1995.
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PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
(A) The following documents are being filed as part of this annual report on
Form 10-K after the signature page, commencing on page F-1.
(1) Consolidated Financial Statements:
Independent Auditors' Reports.
Consolidated Balance Sheets, August 31, 1995 and 1994
Consolidates Statements of Operations, Years Ended August 31,
1995, 1994 and 1993.
Consolidated Statements of Stockholders' Equity, Years Ended
August 31, 1995, 1994 and 1993.
Consolidated Statements of Cash Flows, Years Ended August 31,
1995, 1994 and 1993.
Notes to Consolidated Financial Statements.
(2) Financial Statement Schedule for the years ended August 31, 1995,
1994 and 1993:
Schedule II - Valuation and Qualifying Reserves.
All other schedules for which provision is made in the applicable
accounting regulations of the Securities and Exchange Commission
are omitted as the required information is inapplicable or the
information is presented in the Consolidated Financial Statements
or Notes thereto.
(3) Exhibits:
** 3.1 Articles of Incorporation of the Registrant filed as
Exhibit 3(B) to the registration statement on Form
S-1; Reg. No. 2-65661.
** 3.2 Articles of Amendment to Articles of Incorporation of
The Exploration Company, dated July 27, 1984, filed
as Exhibit 3.2 to Registrant's Annual report on Form
10-K, dated February 4, 1985.
** 3.3 Articles of Amendment to the Articles of Incorporation
of the Exploration Company dated April 2, 1985.
** 3.4 By-Laws of the Registrant filed as Exhibit 5(A) to the
Registration Statement on Form S-1; Reg. 2-65661.
** 3.5 Amendment to By-Laws of registrant, dated September 1,
1985.
** 3.6 Articles of Amendment to the Articles of Incorporation
of The Exploration Company dated April 6, 1990.
**10.2 Employment Agreement between the Registrant and James E.
Sigmon, dated October 1, 1984.
**10.3 Registrant's Amended and Restated 1983 Incentive Stock
Option Plan filed as Exhibit A to registrant's
definitive Proxy Statement, dated February 20, 1985.
**10.4 Registrant's 1995 Flexible Incentive Plan, filed as
Exhibit A to registrant's definitive Proxy statement,
dated April 28, 1995
** Previously filed
(b) Reports on Form 8-K:
No reports on Form 8-K have been filed in the 4th quarter of the
registrant's fiscal year or through the date of this filing.
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SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the Registrant has duly caused this Report to be signed
on its behalf by the undersigned, thereunto duly authorized.
THE EXPLORATION COMPANY
Registrant
November 27, 1995 By: /s/ JAMES E. SIGMON,
-------------------------------------
James E. Sigmon,
President
Pursuant to the requirements of the Securities Exchange Act of 1934,
this Report has been signed below by the following persons on behalf of the
registrant and in the capacities and on the dates indicated.
SIGNATURES TITLE DATE
- ---------- ----- ----
/s/ STEPHEN M. GOSE, JR. Chairman of the Board of Directors November 27, 1995
- -----------------------------------
Stephen M. Gose, Jr.
/s/ THOMAS H. GOSE Director and Secretary November 27, 1995
- -----------------------------------
Thomas H. Gose
/s/ JAMES E. SIGMON President and Director November 27, 1995
- ----------------------------------- (Principal Executive Officer)
James E. Sigmon (Principal Financial Officer)
29
30
THE EXPLORATION COMPANY AND SUBSIDIARY
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995 AND 1994
AUDITED CONSOLIDATED FINANCIAL STATEMENTS Page
----
Independent Auditors' Report F-2
Consolidated Balance Sheets F-4
Consolidated Statements of Operations F-6
Consolidated Statements of Stockholders' Equity F-7
Consolidated Statements of Cash Flows F-8
Notes to Consolidated Financial Statements F-10
SUPPORTING SCHEDULE
Schedule II - Valuation and Qualifying Reserves F-22
F-1
31
INDEPENDENT AUDITORS' REPORT
The Board of Directors and Stockholders
The Exploration Company and Subsidiary
We have audited the consolidated balance sheets of The Exploration Company and
Subsidiary as of August 31, 1995 and 1994, and the related consolidated
statements of operations, stockholders' equity and cash flows for the years
then ended. 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 financial statements referred to above present fairly, in
all material respects, the consolidated financial position of The Exploration
Company and Subsidiary as of August 31, 1995 and 1994, and the consolidated
results of their operations and their consolidated cash flows for the years
then ended, in conformity with generally accepted accounting principles.
The consolidated financial statements have been prepared assuming that the
Company will continue as a going concern. As discussed in Note 2 to the
consolidated financial statements, the Company's recurring losses from
operations and a deficiency of quick assets to current liabilities of $433,404
at August 31, 1995 raise substantial doubt about the Company's ability to
continue as a going concern. Management's plans concerning these matters are
also discussed in Note 2. The consolidated financial statements do not include
any adjustments that might result from the outcome of this uncertainty.
We have also audited Schedule II of The Exploration Company and Subsidiary for
the years ended August 31, 1995 and 1994. In our opinion, this schedule
presents fairly, in all material respects, the information required to be set
forth therein.
Akin, Doherty, Klein & Feuge, P.C.
San Antonio, Texas
November 16, 1995
F-2
32
INDEPENDENT AUDITORS' REPORT
The Board of Directors and Stockholders
The Exploration Company and Subsidiary
We have audited the consolidated statements of operations, stockholders' equity
and cash flows of The Exploration Company and Subsidiary for the year ended
August 31, 1993. 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 audit.
We conducted our audit 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 audit provides a reasonable basis
for our opinion.
In our opinion, the financial statements referred to above present fairly, in
all material respects, the consolidated results of operations of The
Exploration Company and Subsidiary and their consolidated cash flows for the
year ended August 31, 1993, in conformity with generally accepted accounting
principles.
The accompanying 1993 financial statements have been prepared assuming that the
Company will continue as a going concern. The Company incurred a net loss of
$2,277,144 during the year ended August 31, 1993, and as of that date, the
Company's current liabilities exceeded its current assets by $1,000,184. These
factors among others, raise substantial doubt about the Company's ability to
continue as a going concern. The financial statements do not include any
adjustments that might result from the outcome of this uncertainty.
Additionally, as of August 31, 1993, the Company has significant investments in
unproved mineral properties and unproved oil and gas properties. The ability
of the Company to recover the net carrying value of these assets is dependent
upon the Company's ability to raise additional funds for exploration and
development, the ultimate determination of their economic viability and the
resolution of other uncertainties.
We have also audited Schedule II of The Exploration Company and Subsidiary for
the year ended August 31, 1993. In our opinion, this schedule presents fairly,
in all material respects the information required to be set forth therein.
Lowrey, Zaccagni & Crider, P.C.
San Antonio, Texas
November 5, 1993
F-3
33
THE EXPLORATION COMPANY AND SUBSIDIARY
CONSOLIDATED BALANCE SHEETS
AUGUST 31, 1995 AND 1994
1995 1994
-------- --------
ASSETS
Current Assets:
Cash and equivalents $ 85,918 $ 103,756
Accounts receivable, less allowance for doubtful accounts of
$9,973 in 1995 and 1994:
Joint interest owners 5,139 35,344
Trade accounts 226,139 83,192
Oil and gas production 42,500 47,716
Affiliates 72,196 -
----------- -----------
345,974 166,252
Inventories 103,956 121,871
Note receivable 602,528 -
Prepaid expenses and other 60,714 71,729
----------- -----------
Total current assets 1,199,090 463,608
Property and Equipment:
Oil and gas properties (successful efforts),
less accumulated depreciation, depletion and
amortization of $267,503 in 1995 and $165,503 in 1994 1,902,912 1,283,431
Other property and equipment:
Mineral properties 704,967 876,472
Transportation and other equipment 193,404 160,199
Equipment under capital leases 93,326 86,510
Fuel stations 159,729 95,106
Less accumulated depreciation and amortization (145,649) (49,147)
----------- -----------
Net property and equipment 2,908,689 2,452,571
Other Assets:
Option to acquire oil and gas properties 166,667 200,000
Investment in venture 150,000 -
Other assets 168,446 36,809
----------- -----------
485,113 236,809
----------- -----------
Total Assets $ 4,592,892 $ 3,152,988
=========== ===========
See notes to Consolidated Financial Statements.
F-4
34
THE EXPLORATION COMPANY AND SUBSIDIARY
CONSOLIDATED BALANCE SHEETS
AUGUST 31, 1995 AND 1994
1995 1994
-------- --------
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities:
Accounts payable and accrued expenses $ 550,043 $ 488,201
Due to joint interest partners 69,209 248,739
Accrued payroll and taxes 40,932 40,717
Current portion of long-term debt 188,419 32,872
Current portion of capital leases 16,693 13,740
----------- -----------
Total current liabilities 865,296 824,269
Long-term Liabilities:
Long-term debt 2,300,115 612,028
Long-term debt due affiliates - 42,606
- ----------- -----------
2,300,115 654,634
Capital lease obligations 49,734 60,964
----------- -----------
Total long-term liabilities 2,349,849 715,598
Stockholders' Equity:
Common stock, par value $ .01 per share;
authorized 200,000,000 shares; issued
and outstanding 5,527,970 and 4,591,087
at August 31, 1995 and 1994, respectively 55,280 45,912
Additional paid-in capital 17,348,088 15,439,465
Accumulated deficit (16,025,621) (13,872,256)
----------- -----------
Total stockholders' equity 1,377,747 1,613,121
----------- -----------
Total Liabilities and Stockholders' Equity $ 4,592,892 $ 3,152,988
=========== ===========
See notes to Consolidated Financial Statements.
F-5
35
THE EXPLORATION COMPANY AND SUBSIDIARY
CONSOLIDATED STATEMENTS OF OPERATIONS
YEARS ENDED AUGUST 31, 1995, 1994 AND 1993
1995 1994 1993
--------- -------- --------
Revenues:
Oil and gas division:
Oil and gas sales $ 304,342 $ 209,194 $ 61,089
Other operating income 26,911 27,246 11,101
ExproFuels division:
Conversion sales 578,362 627,366 41,442
Fuel station construction sales 97,241 162,603 -
Alternative fuel sales 97,748 31,664 3,084
-------------- ------------- -------------
1,104,604 1,058,073 116,716
Costs and Expenses:
Oil and gas division:
Lease operations 21,225 27,863 34,393
Production taxes 21,312 16,900 3,361
Exploration expenses 151,142 57,927 187,282
Abandoned leases and equipment 21,000 31,245 1,305,428
Impairment of oil and gas properties - - 87,661
Impairment of mineral properties 171,505 171,505 -
Depreciation, depletion and amortization 106,200 53,594 15,623
General and administrative 813,211 524,729 506,254
ExproFuels division:
Depreciation and amortization 92,302 77,543 4,574
Abandonment of technological rights - 144,681 -
Cost of sales 1,062,022 701,198 77,197
General and administrative 587,916 733,754 146,039
-------------- ------------- -------------
Total costs and expenses 3,047,835 2,540,939 2,367,812
-------------- ------------- -------------
Loss from operations (1,943,231) (1,482,866) (2,251,096)
Other Income (Expense):
Sublease rental income 6,750 - -
Interest income 6,348 1,567 -
Interest expense (223,232) (69,654) (26,048)
-------------- ------------- -------------
(210,134) (68,087) (26,048)
-------------- ------------- -------------
Loss before extraordinary item (2,153,365) (1,550,953) (2,277,144)
Extraordinary item-gain on cancellation
of debt - 322,492 -
-------------- ------------- ------------
Net loss $ (2,153,365) $ (1,228,461) $ (2,277,144)
============== ============= ============
Amounts per common share:
Loss before extraordinary item $ (0.44) $ (0.36) $ (0.64)
Extraordinary item - 0.07 -
-------------- ------------- ------------
Net loss $ (0.44) $ (0.29) $ (0.64)
============== ============= ============
Weighted average number of common
shares outstanding 4,863,961 4,267,363 3,533,973
============== ============= ==========
See notes to Consolidated Financial Statements.
F-6
36
THE EXPLORATION COMPANY AND SUBSIDIARY
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
YEARS ENDED AUGUST 31, 1995, 1994 AND 1993
Common Stock Additional
---------------------------- Paid-in Accumulated
Shares Amount Capital Deficit Total
-------- -------- --------- ----------- ------
Balance at September 1, 1992 158,331,642 $ 1,583,317 $ 10,757,775 $ (10,366,651) $ 1,974,441
Reverse stock split 1 for 50 (155,164,892) (1,551,649) 1,551,649 - -
Issuance of common stock
for cash 446,000 4,460 887,540 - 892,000
Issuance of common stock
in exchange for oil and
gas properties 250,000 2,500 622,500 - 625,000
Net loss for the year - - - (2,277,144) (2,277,144)
---------- ------------- ------------ ------------- -----------
Balance at August 31, 1993 3,862,750 38,628 13,819,464 (12,643,795) 1,214,297
Issuance of common stock
for cash 570,687 5,707 1,142,066 - 1,147,773
Issuance of common stock
in exchange for oil and
gas properties 60,150 602 232,479 - 233,081
Issuance of common stock
warrants with convertible debt - - 2,681 - 2,681
Common stock warrants exercised 97,500 975 242,775 243,750
Net loss for the year - - - (1,228,461) (1,228,461)
---------- ------------- ------------ ------------- -----------
Balance at August 31, 1994 4,591,087 45,912 15,439,465 (13,872,256) 1,613,121
Issuance of common stock
for cash 299,056 2,990 504,937 - 507,927
Issuance of common stock
in exchange for oil and
gas properties 350,227 3,502 710,240 - 713,742
Conversion of debt to common stock 267,600 2,676 599,852 - 602,528
Issuance of common stock
warrants with convertible debt - - 33,794 - 33,794
Common stock warrants exercised 20,000 200 59,800 - 60,000
Net loss for the year - - - (2,153,365) (2,153,365)
---------- ------------- ------------ ------------- -----------
Balance at August 31, 1995 5,527,970 $ 55,280 $ 17,348,088 $ (16,025,621) $ 1,377,747
========== ============= ============ ============= ===========
See notes to Consolidated Financial Statements.
F-7
37
THE EXPLORATION COMPANY AND SUBSIDIARY
CONSOLIDATED STATEMENTS OF CASH FLOWS
YEARS ENDED AUGUST 31, 1995, 1994 AND 1993
1995 1994 1993
-------- -------- --------
OPERATING ACTIVITIES:
Net loss $ (2,153,365) $ (1,228,461) $ (2,277,144)
Adjustments to reconcile net loss to net cash
used in operating activities:
Depreciation, depletion and amortization 198,502 131,137 20,197
Cancellation of debt - (322,492) -
Abandoned leases and equipment 21,000 31,245 1,305,428
Abandonment of technological rights,
net of debt - 144,681 -
Impairment of properties 171,505 171,505 87,661
Changes in operating assets and liabilities:
Receivables (179,722) (88,432) (35,496)
Inventory 17,915 (119,480) (2,391)
Prepaid expenses and other 11,015 (61,199) (7,893)
Accounts payable and accrued expenses 62,057 271,623 208,408
Due to joint interest owners (179,530) 52,558 -
------------ ------------ ------------
Net cash (used) in operating activities (2,030,623) (1,017,315) (701,230)
INVESTING ACTIVITIES:
Development of oil and gas properties (289,980) (163,376) (75,499)
Purchase of transportation and other equipment (104,644) (230,012) (49,757)
Proceeds from sale of oil and gas properties 261,242 - -
Increase in note recievable (602,528) - -
Investment in venture (150,000) - -
Purchase of option to acquire oil and gas property - (200,000) -
Other assets (98,304) (36,809) -
------------ ------------ ------------
Net cash (used) in investing activities (984,214) (630,197) (125,256)
FINANCING ACTIVITIES:
Issuance of common stock, net of expenses 1,204,249 1,394,203 892,001
Proceeds from long-term debt obligations 1,935,664 690,317 249,800
Payments on long-term obligations (142,914) (380,021) (288,637)
------------ ------------ ------------
Net cash provided by financing activities 2,996,999 1,704,499 853,164
------------ ------------ ------------
INCREASE (DECREASE) IN CASH AND EQUIVALENTS (17,838) 56,987 26,678
Cash and equivalents at beginning of year 103,756 46,769 20,091
------------ ------------ ------------
CASH AND EQUIVALENTS AT END OF YEAR $ 85,918 $ 103,756 $ 46,769
============ ============ ============
See notes to Consolidated Financial Statements.
F-8
38
THE EXPLORATION COMPANY AND SUBSIDIARY
CONSOLIDATED STATEMENTS OF CASH FLOWS - CONTINUED
YEARS ENDED AUGUST 31, 1995, 1994 AND 1993
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
1995
The Company issued 186,731 of its common stock to an affiliate in exchange for
$300,000 of oil and gas properties (valued at the historical cost basis of the
common-control affiliate).
The Company issued 163,496 of its common stock in exchange for $413,743 of oil
and gas properties (valued at the market price per share).
The Company issued 61,212 shares of its common stock to a Director for cash of
$85,731 and a receivable for $72,196. The receivable was fully collected on
November 8, 1995.
The Company paid interest on debt of $179,635.
1994
The Company issued 60,150 shares of its common stock in exchange for $233,081
in oil and gas properties (valued at the market price per share).
The Company issued warrants for the purchase of 10,725 shares of its common
stock in conjunction with issuance of certain convertible debt (valued at $.25
per warrant).
The Company paid interest on debt of $74,468.
1993
The Company issued 250,000 shares of its common stock in exchange for $625,000
of oil and gas properties (valued at the market price per share).
The Company acquired technological rights of $396,246 for debt.
The Company converted $56,410 of accounts payable into a note payable.
The Company paid interest on debt of $5,026.
See notes to Consolidated Financial Statements.
F-9
39
THE EXPLORATION COMPANY AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995, 1994 AND 1993
NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Organization and Operations
The consolidated financial statements include the accounts of The Exploration
Company and its wholly-owned subsidiary, Colorado Exploration Company. Both
companies are organized under the laws of the State of Colorado. Colorado
Exploration Company has been inactive since its formation. There are no
intercompany accounts to be eliminated in the consolidation.
The Exploration Company is engaged in the business of acquiring, exploring and
developing oil and gas properties. In 1993, the Company commenced operations
in the alternative fuels industry through its ExproFuels Division. This
division converts vehicle engines that use gasoline for combustion to propane
or natural gas, supplies alternative fuels to customers and constructs
alternative fuels refueling facilities.
Cash and Equivalents
Cash and cash equivalents consist of all demand deposits and funds invested in
short-term investments with original maturities of three months or less.
Inventories
Inventories, consisting principally of finished goods (parts), are valued at
the lower of cost or market using the first-in, first-out method of accounting.
Mineral Properties
The Company expenses costs associated with identifying prospective mining
properties, while the costs of acquiring and developing unproven mining
properties are capitalized. All costs associated with the development of an
extracting process or to determine the economic feasibility of a project are
expensed as incurred. The Company has not incurred any development or
production costs on its mining properties.
Oil and Gas Properties
The Company uses the successful efforts method of accounting for its oil and
gas activities. Costs to acquire mineral interests in oil and gas properties,
to drill and equip exploratory wells that find proved reserves, and to drill
and equip development wells are capitalized. Costs to drill exploratory wells
that do not find proved reserves, geological and geophysical costs, and costs
of carrying and retaining unproved properties are expensed as incurred.
Depreciation, depletion and amortization (DD&A) of oil and gas properties are
computed using the unit-of-production method based upon recoverable reserves as
determined by Company engineers. Oil and gas properties are periodically
assessed for impairment, and if the unamortized capitalized costs are in excess
of the discounted present value of future cash flows relating to proved
reserves, an impairment charge is recorded.
F-10
40
THE EXPLORATION COMPANY AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995, 1994 AND 1993
NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
Other Property and Equipment
Transportation and other equipment, equipment reported under capitalized leases
and fuel stations are recorded at cost. Depreciation is computed using the
straight-line method over the estimated useful lives of the assets ranging from
five to fifteen years. Major renewals and betterments are capitalized while
repairs are expensed as incurred.
Federal Income Taxes
The Company has adopted the provisions of Financial Accounting Standards Board
Statement No. 109, Accounting for Income Taxes. Under this method, deferred
tax assets and liabilities are determined based on differences between
financial reporting and tax basis of assets and liabilities, and are measured
using the enacted tax rates and laws that will be in effect when the
differences are expected to reverse. A valuation allowance is provided against
net deferred assets for which realization is doubtful.
Net Loss Per Share
Net loss per common share is computed by dividing net loss by the weighted
average number of shares of common stock outstanding during the period. Common
stock equivalents are not considered in the computation of net loss per common
share as their effect is anti-dilutive.
Financial Instruments with Off-Balance-Sheet Risk
Financial instruments that potentially subject the Company to concentrations of
credit risk consist principally of temporary cash investments and accounts
receivables. The Company places its temporary cash investments with financial
institutions and limits the amount of credit exposure to any one financial
institution. The Company's raw materials are readily available and the Company
is not dependent on a single supplier or a few suppliers.
Reclassifications
Certain amounts for 1994 and 1993 have been reclassified for comparative
purposes to 1995.
NOTE 2. GOING CONCERN UNCERTAINTY
The accompanying consolidated financial statements have been prepared on a
going concern basis, which contemplates the realization of assets and the
satisfaction of liabilities in the normal course of business. As shown in the
consolidated financial statements, the Company has suffered recurring losses
and its current its liabilities exceeded its quick assets by $443,404 as of
August 31, 1995. These factors, among others, raise substantial doubt about
the Company's ability to continue as a going concern. The consolidated
financial statements do not include any adjustments relating to the
recoverability and classification of recorded asset amounts or the amounts and
classification of liabilities that might be necessary should the Company be
unable to continue as a going concern.
Management is attempting to explore all alternatives, including renegotiating
its existing debt, obtaining additional debt and/or equity financing and
disposing of a partial or total interest in certain assets. The Company's
ability to continue to operate is dependent upon its ability to successfully
accomplish some or all of these or other alternatives, and ultimately to attain
profitable operations.
F-11
41
THE EXPLORATION COMPANY AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995, 1994, AND 1993
NOTE 3. NOTE RECIEVABLE
During the year the Company exchanged certain marketable securities for a
$602,528 promissory note receivable. The promissory note is secured, bears
interest at 9% and is due in full on June 6, 1996.
NOTE 4. INVESTMENT IN VENTURE
The Company has invested $150,000 in CNG International, L.L.C., a Tennessee
limited liability company formed for the purpose of converting motor vehicles
to operate on alternative fuels, manufacturing and selling of related component
equipment and to develop the necessary infrastructure to support operation of
motor vehicles on alternative fuels primarily in Uzbekistan, a former Soviet
Republic. At August 31, 1995, the Company had acquired an equity interest of
10.8% in the venture.
During the year ended August 31, 1995, the Company sold equipment and provided
services to CNG International in the amount of $110,611, of which $77,302 was
included in accounts receivable - affiliates at year end.
NOTE 5. STOCKHOLDERS' EQUITY
At August 31, 1995, the Company has outstanding and exercisable options to
purchase 279,800 shares of its common stock at prices ranging from $2.00 to
$3.91 per share, of which 179,800 were issued pursuant to the Company's prior
incentive plan, and 100,000 were issued under the Company's new incentive plan
(see below). The Company also has outstanding warrants to purchase 1,552,715
shares of its common stock at prices ranging from $2.68 to $6.00 per share.
The options expire at various dates from July, 1999 through March, 2004. The
warrants expire on various dates through February, 2005.
During the year ended December 31, 1995, stockholders and the Board approved
the Company's 1995 Flexible Incentive Plan which provides incentive stock
options for granting to its officers, directors and management, under which
options for the purchase of 400,000 shares of common stock have been reserved.
Options for the purchase of 100,000 shares of common stock were granted under
the plan in 1995.
No options were granted during the year ended August 31, 1994.
In December 1994, the President of the Company exercised options to acquire
50,000 shares of common stock under the terms of the Company's prior incentive
plan.
On March 29, 1993, the Board of Directors authorized a 1 for 50 reverse split
of its common stock. All references in the accompanying financial statements
to the number of shares and per share amounts for the year ended August 31,
1993 have been restated to reflect the reverse common stock split.
F-12
42
THE EXPLORATION COMPANY AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995, 1994, AND 1993
NOTE 6. LONG TERM DEBT
Long-term debt consists of the following at August 31:
1995 1994
-------- --------
Convertible note payable to Trust, with interest
at 11.50%, and principal due August 1997; secured
by certain oil and gas properties. See below. $ 1,764,697 $ 75,000
Convertible note payable to partnership, with interest
at 10%, and principal due in May 1997. See below. 500,000 500,000
Notes payable to financial institutions, with interest rates
from 8.50% to 12%, and due in monthly installments of $1,950
secured by certain vehicles. 58,837 57,395
Notes payable to individual, with interest at 12%, due
currently, and secured by certain common stock of the Company. 165,000 -
Notes payable to suppliers, with interest rates at 6.97%
and due in monthly installments of $12,505. - 12,505
Note payable to affiliate with interest at 8%, unsecured,
with principal and interest due in December 1996. - 42,606
----------- ---------
Total long-term debt 2,488,534 687,506
Less current portion (188,419) (32,872)
----------- ---------
Long-term portion of debt $ 2,300,115 $ 654,634
=========== =========
Convertible $500,000 Note Payable:
On May 25, 1994, the Company issued a three year, convertible promissory note
payable to a partnership in exchange for $500,000. The terms of the note
include interest at 10% per annum, payable quarterly, and a conversion option
at $3.00 per common share of stock. The note is callable at the option of the
Company in the event the closing bid price of the Company's common stock
averages $7.00 for a period of forty-five days.
F-13
43
THE EXPLORATION COMPANY AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995, 1994, AND 1993
NOTE 6. LONG TERM DEBT (CONTINUED)
Convertible $1,764,697 Note Payable:
On August 2, 1994, the Company entered into a master note payable and indenture
of trust agreement for up to $2,000,000 principal amount. The terms of the
master note provided for partial cash advances to be made by the lender. The
terms of each advance include interest at 11.50%, payable semi-annually on
January 1 and July 1, and a conversion option at $2.50 per common share of
stock. The Company may force the conversion at the same price per share in the
event the closing bid price of the Company's common stock has closed at $6.00
per share for fifteen consecutive days. Prior to exercising this right, the
Company must register the common stock to be received by the lender under the
Securities and Exchange Act. The principal amount of each advance is due three
years from original date of the advance, and may not be prepaid by the Company
before twelve months. The indebtness under the master note payable is secured
by certain oil and gas properties with a book basis (See Note 10. for
Standardized Measure of the oil and gas properties) of approximately $313,000
at August 31, 1995.
The following is a schedule of principal maturities of long-term debt as of
August 31, 1995:
1996 $ 188,419
1997 588,333
1998 1,703,846
1999 5,839
2000 2,097
Thereafter -
-----------
$ 2,488,534
===========
NOTE 7. LEASES
Real Estate:
The Company leases its primary office space for $5,756 per month through
February 28, 1997. In addition, the Company leases its conversion facilities
and a fuel station location under noncancellable leases with terms from one to
three years. The Company also has a sublease on one of its conversion
facilities, from which it receives $4,500 per month through January, 1997.
For the years ended August 31, 1995, 1994 and 1993, the Company incurred rent
expense of $180,841, $131,918 and $60,205, respectively. As of August 31,
1995, future minimum rentals under all noncancellable real estate leases, and
its sublease rental income, are as follows:
1996 $ 163,172
1997 51,336
---------
Future minimum rentals 214,508
Less sublease income (72,000)
---------
Net future minimum rentals $ 142,508
=========
F-14
44
THE EXPLORATION COMPANY AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995, 1994, AND 1993
NOTE 7. LEASES (CONTINUED)
Capitalized Equipment Leases:
The Company leases certain equipment located at its conversion facilities under
leases accounted for as capital leases. As of August 31, 1995, future minimum
rentals under all capital leases are as follows:
1996 $ 28,650
1997 28,211
1998 24,829
1999 8,926
---------
Total minimum rentals 90,616
Less amount representing interest,
executory costs and profit (24,189)
---------
Present value of capital lease obligations $ 66,427
=========
NOTE 8. FEDERAL INCOME TAXES
The Company has incurred losses for both financial statement and income tax
purposes. A valuation allowance equal to the net deferred tax asset has been
recorded due to the uncertainty of the realization of the asset. The following
items give rise to the deferred tax assets and liabilities at August 31, 1995
and 1994:
August 31
1995 1994
-------- --------
Deferred tax assets:
Net operating loss carryforwards $ 14,725,000 $ 12,660,000
Impairment of oil and gas properties 534,000 362,000
Other temporary differences - net 3,000 3,000
------------ ------------
Gross deferred tax assets 15,262,000 13,025,000
Statutory tax rate 34% 34%
------------ ------------
5,189,080 4,428,500
Unused investment tax credits 30,000 30,000
------------ ------------
Net deferred tax assets 5,219,080 4,458,500
Less valuation allowance (5,219,080) (4,458,500)
------------ ------------
Deferred income tax asset recorded $ -0- $ -0-
============ ============
F-15
45
THE EXPLORATION COMPANY AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995, 1994, AND 1993
NOTE 8. FEDERAL INCOME TAXES (CONTINUED)
The net operating loss carryforwards available at August 31, 1995, and the
related expiration dates are as follows:
Expires
August 31 Amount
--------- ------
1996 $ 724,641
1997 1,083,297
1998 443,082
1999 130,647
2000 479,797
2001 to 2005 4,542,182
2006 to 2010 7,321,354
------------
$ 14,725,000
============
NOTE 9. RELATED PARTY TRANSACTIONS
In August, 1995, an affiliated company loaned the Company $50,000. The loan
was repaid in full on August 31, 1995.
During 1995, the Company acquired from an affiliate unproved oil and gas
leasehold acreage, with a basis of $300,000, for 186,731 shares of the
Company's common stock.
In February, 1994 a corporation in which a former employee of the Company owned
an interest entered into a drilling joint venture with the Company to drill a
gas well in Maverick County, Texas. The corporation contributed $100,000 to
the joint venture in exchange for a 25% working interest in the gas well, and
options for a 5% working interest in four additional gas wells. In May, 1994,
the Company acquired 80% of the 25% working interest (net 20% working interest)
for 60,150 shares of common stock.
In February, 1994, the Company reached an agreement with its president to
restructure his employment compensation. The president agreed to reduce his
annual salary from $109,000 per year to $72,000, and was granted a one percent
(1%) overriding royalty interest in the Paloma and Kincaid leases in Maverick
County, Texas, in which the Company has an interest.
During the years ended August 31, 1994 and 1993, an officer of the Company
represented certain persons, including himself, who have joint ventured with
the Company in certain oil and gas properties. During 1994, the Company
acquired an option for $200,000 from these joint ventures. The option, which
expires on December 31, 1995, allows the Company to increase its interest in
certain oil and gas properties for $649,923 including the $200,000
nonrefundable option price. The officer was paid $25,100 and $13,000 for legal
services in the years ended August 31, 1994 and 1993, respectively.
F-16
46
THE EXPLORATION COMPANY AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995, 1994, AND 1993
NOTE 9. RELATED PARTY TRANSACTIONS (CONTINUED)
Effective November 30, 1993, the president of the Company canceled accrued
payroll in the amount of $322,492 due to him from previous years under his
employment agreement. The Company has accounted for this extinguishment of
debt as an extraordinary item for the year ended August 31, 1994.
During the year ended August 31, 1993, certain employees of an affiliated
company provided significant services to the Company. The Company reimbursed
the affiliated company for these general and administrative expenses in the
amount of $37,500 in 1993.
NOTE 10. OIL AND GAS PRODUCING ACTIVITIES AND PROPERTIES
Capitalized Costs and Costs Incurred Relating to Oil and Gas Activities
The Company's investment in oil and gas properties is as follows at August 31:
1995 1994
----------- -----------
Proved properties $ 1,136,468 $ 881,067
Less reserve for impairment (190,847) (190,847)
----------- -----------
Net proved properties 945,621 690,220
Unproved properties 1,224,794 758,714
----------- ------------
Total oil and gas properties 2,170,415 1,448,934
Less accumulated depreciation,
depletion and amortization (267,503) (165,503)
----------- -----------
Net capitalized cost $ 1,902,912 $ 1,283,431
=========== ===========
Costs incurred, capitalized, and expensed in oil and gas producing activities
are as follows:
1995 1994 1993
--------- ----------- ----------
Property acquisition costs, unproved $ 748,321 $ - $ 625,000
Property development and exploration costs 511,944 454,384 262,781
Depreciation, depletion and amortization 102,000 51,065 20,197
Depletion per equivalent barrel of production 3.17 3.14 5.09
F-17
47
THE EXPLORATION COMPANY AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995, 1994 AND 1993
NOTE 10. OIL AND GAS PRODUCING ACTIVITIES AND PROPERTIES (CONTINUED)
Estimated Quantities of Proved Oil and Gas Reserves (Unaudited)
The following estimates of proved developed and undeveloped reserve quantities
and related standardized measure of discounted net cash flow are estimates
only, and do not purport to reflect realizable values or fair market values of
the Company's reserves. The Company emphasizes that reserve estimates are
inherently imprecise and that estimates of new discoveries are more imprecise
than those of currently producing oil and gas properties. Accordingly, these
estimates are expected to change as future information becomes available.
Proved reserves are estimates of crude oil (including condensate and natural
gas liquids) and natural gas that 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
reserves are those expected to be recovered through existing well, equipment
and operating methods. The estimates have been prepared by the Company's
in-house reserve engineer.
Oil Gas
(Barrels) (MCF)
--------- ---------
RESERVES AT AUGUST 31, 1992 46,557 64,190
Discoveries 2,468 310,965
Revisions of previous estimates 2,834 7,666
Production (561) (20,450)
--------- ----------
RESERVES AT AUGUST 31, 1993 51,298 362,371
Discoveries 4,780 477,995
Revisions of previous estimates (45,305) 211,308
Production (2,479) (82,656)
--------- ----------
RESERVES AT AUGUST 31, 1994 8,294 969,018
Discoveries - 55,709
Revisions of previous estimates 8,428 495,027
Production (2,598) (177,238)
--------- ----------
RESERVES AT AUGUST 31, 1995 14,124 1,342,516
========= ==========
All of the Company's proved reserves are developed and are located in the
continental United States.
F-18
48
THE EXPLORATION COMPANY AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995, 1994 AND 1993
NOTE 10. OIL AND GAS PRODUCING ACTIVITIES AND PROPERTIES (CONTINUED)
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil
and Gas Reserves (Unaudited)
The "Standardized Measure of Discounted Future Net Cash Flows Relating to
Proved Oil and Gas Reserves" (Standardized Measure) presented below is computed
in accordance with SFAS No. 69. The Standardized Measure does not purport to
present the fair market value of a company's proved oil and gas reserves. This
would require consideration of expected future economic and operating
conditions, which are not taken into account in calculating the Standardized
Measure.
Under the Standardized Measure, future cash inflows were estimated by applying
year-end prices, adjusted for fixed determinable escalations, to the estimated
future production and development costs based on year-end costs to determine
pre-tax cash inflows. Future income taxes were computed by applying the
statutory tax rate to the excess of pre-tax cash inflows over the company's
basis in the associated proved oil and gas properties. Tax credits, permanent
differences and net operating loss carryforwards were also considered in the
future income tax calculations, thereby reducing the expected tax expense to
zero.
Set forth below is the Standardized Measure relating to proved oil and gas
reserves at August 31:
1995 1994 1993
----------- ----------- -----------
Future cash inflows $ 2,144,655 $ 2,040,727 $ 1,553,106
Future production and development costs (250,943) (390,629) (135,529)
----------- ----------- -----------
Future net cash inflows before income tax 1,893,712 1,650,098 1,417,577
Future income tax expense - - -
----------- ----------- -----------
Future net cash flows 1,893,712 1,650,098 1,417,577
10% annual discount to reflect
timing of net cash flows (671,672) (600,640) (724,241)
----------- ----------- -----------
Standardized Measure of discounted future
net cash flows relating to proved reserves $ 1,222,040 $ 1,049,458 $ 693,336
=========== =========== ==========
Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to
Proved Oil and Gas Reserves (Unaudited)
The following is an analysis of the changes in the Standardized Measure:
1995 1994 1993
----------- ----------- ---------
Standardized Measure, beginning of year $ 1,049,458 $ 693,366 $ 267,656
Discoveries 36,106 600,004 370,258
Sales and transfers, net of production costs (261,805) (164,431) (26,695)
Revisions in quantity and price estimates 503,227 (148,818) 55,381
Accretion of discount (104,946) 69,337 26,736
----------- ----------- ---------
Standardized Measure, end of period $ 1,222,040 $ 1,049,458 $ 693,336
=========== =========== =========
F-19
49
THE EXPLORATION COMPANY AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995, 1994 AND 1993
NOTE 11. SEGMENT INFORMATION AND MAJOR CUSTOMERS
The Company operates in two principal industries: oil and gas exploration and
the alternative fuels industry. Operations in the oil and gas industry consist
of acquiring, exploring and developing oil and gas properties. Operations in
the alternative fuels industry are conducted through the Company's ExproFuels
division. This division converts internal combustion engines to propane or
natural gas, supplies alternative fuels to customers and constructs alternative
fuels refueling facilities.
Loss from operations is total revenue less operating expenses. Identifiable
assets include assets identified with those operations. General and
administrative expenses of a corporate nature as well as corporate assets such
as cash and unamortized financing fees are included with those of the oil and
gas industry.
Segment information is presented below:
Oil and
Gas ExproFuels Total
------- ---------- -----
AUGUST 31, 1995:
Sales $ 331,253 $ 773,351 $ 1,104,604
Loss from operations (974,342) (968,889) (1,943,231)
Identifiable assets 3,829,679 613,213 4,442,892
Capital expenditures 853,722 104,644 958,366
AUGUST 31, 1994:
Sales $ 236,440 $ 821,633 $ 1,058,073
Loss from operations (647,323) (835,543) (1,482,866)
Identifiable assets 2,599,255 553,733 3,152,988
Capital expenditures 414,623 211,846 626,469
AUGUST 31, 1993:
Sales $ 72,190 $ 44,526 $ 116,716
Loss from operations (2,067,812) (183,284) (2,251,096)
Identifiable assets 2,102,576 527,165 2,629,741
Capital and technological expenditures 625,000 481,572 1,106,572
The Company's oil and gas sales include amounts sold to three major purchasers
in the three years ended August 31, as follows:
Purchaser 1995 1994 1993
------------- --------- ---------- ----------
A $ 191,962 $ - $ -
B 30,119 96,258 10,151
C 27,486 10,893 8,352
F-20
50
THE EXPLORATION COMPANY AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
AUGUST 31, 1995, 1994 AND 1993
NOTE 11. SEGMENT INFORMATION AND MAJOR CUSTOMERS (CONTINUED)
Sales in the ExproFuels division include amounts sold to major customers as
follows:
Customer 1995 1994 1993
------------ -------- -------- --------
A $ 117,860 $ - $ -
B 110,612 - -
C 91,078 - -
D - 92,626 -
E 60,820 231,184 -
F 26,104 71,921 44,526
G 62,227 183,941 -
NOTE 12. LEGAL PROCEEDINGS
In 1992, the Company was named as a defendant in a lawsuit involving its
ownership interest in its Holmgreen Ranch mineral property. The plaintiff
alleges a claim to a portion of the mineral interest now retained by the
Company. The Company is vigorously contesting this litigation, which is
currently set for trial in 1996. The Company believes the allegations are
without merit and no provision for loss has been made in the accompanying
financial statements.
F-21
51
THE EXPLORATION COMPANY AND SUBSIDIARY
SCHEDULE II - VALUATION AND QUALIFYING RESERVES
FOR THE THREE YEARS ENDED AUGUST 31, 1995
Balance Charges to Balance
Beginning Costs and End of
of Period Expense Write-offs Period
----------- ---------- ----------- -------
YEAR ENDED AUGUST 31, 1995
Allowance for doubtable accounts -
trade accounts $ 9,973 $ - $ - $ 9,973
======== ========= ======== ========
YEAR ENDED AUGUST 31, 1994
Allowance for doubtable accounts -
trade accounts $ 50,860 $ - $ 40,887 $ 9,973
======== ========= ======== ========
YEAR ENDED AUGUST 31, 1993
Allowance for doubtful accounts -
trade accounts $ 50,543 $ 317 $ - $ 50,860
======== ========= ======== ========
F-22
52
EXHIBIT INDEX
** 3.1 Articles of Incorporation of the Registrant filed as
Exhibit 3(B) to the registration statement on Form
S-1; Reg. No. 2-65661.
** 3.2 Articles of Amendment to Articles of Incorporation of
The Exploration Company, dated July 27, 1984, filed
as Exhibit 3.2 to Registrant's Annual report on Form
10-K, dated February 4, 1985.
** 3.3 Articles of Amendment to the Articles of Incorporation
of the Exploration Company dated April 2, 1985.
** 3.4 By-Laws of the Registrant filed as Exhibit 5(A) to the
Registration Statement on Form S-1; Reg. 2-65661.
** 3.5 Amendment to By-Laws of registrant, dated September 1,
1985.
** 3.6 Articles of Amendment to the Articles of Incorporation
of The Exploration Company dated April 6, 1990.
**10.2 Employment Agreement between the Registrant and James E.
Sigmon, dated October 1, 1984.
**10.3 Registrant's Amended and Restated 1983 Incentive Stock
Option Plan filed as Exhibit A to registrant's
definitive Proxy Statement, dated February 20, 1985.
**10.4 Registrant's 1995 Flexible Incentive Plan, filed as
Exhibit A to registrant's definitive Proxy statement,
dated April 28, 1995
EX-27 Financial Data Schedule
** Previously filed