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SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
[X] ANNUAL REPORT UNDER SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended : December 31, 1997
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[ ] TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from _________________to_______________
Commission File Number 0-22349
PAN WESTERN ENERGY CORPORATION
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(Exact name of small business issuer as specified in its charter)
OKLAHOMA 73-1130486
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
1850 SOUTH BOULDER AVENUE
SUITE 300
TULSA, OKLAHOMA 74119
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code: (918) 582-4957
Securities registered pursuant to Section 12(b) of the Act:
TITLE OF EACH CLASS NAME OF EACH EXCHANGE ON WHICH
TO BE SO REGISTERED EACH CLASS TO BE REGISTERED
------------------- ---------------------------
None None
Securities registered pursuant to Section 12(g) of the Act:
COMMON STOCK, $0.01 PAR VALUE
Check whether the issuer (1) filed all reports required to be filed by Section
13 or 15(d) of the Securities Exchange Act of 1934 during the past 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 No X (1)
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(1) The Registrant became subject to the filing requirements by virtue of filing
a Form 10SB which became effective on June 26, 1997.
Check if there is no disclosure of delinquent filers in response to Item 405 of
Regulation S-B is not contained in this form, and no disclosure will be
contained, to the best of registrant's knowledge, in definitive proxy or
information statements incorporated by reference in Part III of this Form 10KSB
or any amendment to this Form 10KSB. [ ]
As of December 31, 1997, 3,367,405 shares of the Registrants Common Stock, $0.01
par value, were outstanding.
DOCUMENTS INCORPORATED BY REFERENCE
None
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Certain statements in this Registration Statement under the captions "Item
1. Description of Business", "Item 6. Management's Discussion and Analysis or
Plan of Operation" and "Item 2. Description of Property", and else where in this
Form 10KSB constitute "forward-looking statements" within the meaning of the
Private Securities Litigation Reform Act of 1995 (the "Reform Act"). Such
forward-looking statements involve known and unknown risks, uncertainties and
other factors which may cause the actual results, performance or achievements of
the Company, or industry trends and results, to be materially different from any
future results, trends, performance, or achievements expressed or implied by
such forward-looking statements. Such risks, uncertainties and other factors
include, among others, the following: general economic and business conditions;
oil and gas and other industry conditions and trends, including supply and
demand; fluctuations in the prices for oil, gas and refined products;
competition; import protection and regulation (including the implementation of
the World Trade Organization and North American Free Trade Agreement); the loss
of any significant customers; changes in business strategy or development plans;
availability, terms and deployment of debt and equity capital; quality of
management; business abilities and judgment of personnel; availability of
qualified personnel; changes in or the failure to comply with government
regulations (including environmental regulation); and other factors referenced
in this Form 10KSB. See "Item 1. Description of Business - Cautionary Statement
and Risk Factors."
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PART I
ITEM 1. DESCRIPTION OF BUSINESS.
Pan Western Energy Corporation (the "Company") is an independent oil and
gas company engaged in the acquisition, development and production of oil and
gas in the United States. The Company was incorporated in 1981 under the laws
of the State of Oklahoma with the objective of exploring for, developing,
producing and managing oil and gas reserves. Early efforts of the Company
focused on exploratory drilling in Oklahoma, Colorado, Kansas, Nebraska and
Texas. Since 1989, the Company has focused primarily on the acquisition of
producing oil and gas properties in Oklahoma and Texas. During 1995 and 1996,
the Company acquired the producing oil and gas properties of six limited
partnerships in which the Company was the general partner. These producing
properties, along with producing properties acquired from others during the same
period, significantly increased the Company's asset base.
The Company currently owns and operates producing oil and gas properties
located in the states of Texas and Oklahoma and owns royalty interests in 14
non-operated wells located in the state of Ohio. Daily gross production from 89
wells operated by the Company in these states currently averages approximately
163 Bbls of oil and 1,160 Mcf of gas. Total daily production from both operated
and non-operated wells, net to the Company's interest, averaged approximately
123 Bbls of oil and 686 Mcf of gas from a total of 61 net wells during the year
ended December 31, 1997.
In seeking to acquire additional oil and gas properties, the Company
focuses primarily on properties with producing oil and gas reserves which it
believes have potential for additional exploitation through additional
development and enhanced recovery via lateral completions and improved operating
techniques rather than highly speculative exploration efforts. The Company
intends to focus its acquisition program on producing properties in which the
Company will become the operator following acquisition, allowing the Company to
maintain a low cost operating structure. The Company will also seek properties
that are underdeveloped, overly burdened with expenses or owned by financially
troubled companies. Management intends to focus on oil and gas properties
located in the mid-continent region of the United States where Company personnel
are best able to draw on their prior oil and gas experience. The Company
intends to acquire properties using internally generated cash flow, bank
borrowings and, when appropriate, common stock of the Company.
The Company is currently reviewing several potential drilling prospects.
These prospects are considered to be developmental in nature and management
currently believes that the Company will participate in a developmental drilling
project during 1998. It is management's opinion that the Company will need to
participate in some amount of development drilling in the future to bolster its
reserve base and future cash flow.
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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS
Cautionary Statement Regarding Forward-Looking Statements. In the interest
of providing the Company's shareholders with certain information regarding the
Company, including management's assessment of the Company's future plans and
operations, certain statements set forth in this Form 10KSB contain or are based
on the Company's projections or estimates of revenue, income, earnings per share
and other financial items or relate to management's future plans and objectives
or to the Company's future economic and financial performance. All such
statements, other than statements of historical fact, contained in this Form
10KSB statements in "Item 1. Description of Business, Item 6. Management's
Discussion and Analysis or Plan of Operation and Item 2. Description of
Property" generally are accompanied by words such as "anticipate," "believe,"
"intend," "estimate," "project" or "expect" or similar statements. Such
statements are "forward- looking statements" within the meaning of Section 27A
of the Securities Act of 1933, as amended, and Section 21E of the Securities
Exchange Act of 1934, as amended, and are made pursuant to and in reliance on
the safe harbor provisions of such sections.
Although any forward-looking statements contained in this Form 10KSB or
otherwise expressed by or on behalf of the Company are, to the knowledge and in
the judgment of the officers and directors of the Company, reasonable and
expected to prove true, management is not able to predict the future with
certainty and no assurance can be given that such statements will prove correct.
Forward-looking statements involve known and unknown risks and uncertainties
which may cause the Company's actual performance and financial results in future
periods to differ materially from any projection, estimate or forecasted result.
These risks and uncertainties include, among other things: general economic and
business conditions; oil and gas industry conditions and trends; volatility of
oil and gas prices; product supply and demand; market competition; risks
inherent in the Company's oil and gas operations; imprecision of reserve
estimates; the Company's ability to replace and expand oil and gas reserves; the
Company's ability to generate sufficient cash flow from operations to meet its
current and future obligations; the Company's ability to access and terms of
external sources of debt and equity capital; and such other risks and
uncertainties described from time to time in the Company's periodic reports and
filings with the Securities and Exchange Commission. These and other risks are
described elsewhere in this Form 10KSB and will be described from time to time
in the Company's future filings with the Securities and Exchange Commission.
Accordingly, shareholders and potential investors are cautioned that certain
events or circumstances could cause actual results to differ materially from
those projected, estimated or predicted. In addition, forward- looking
statements are based on management's knowledge and judgment as of the date of
this Form 10KSB, and the Company does not intend to update any forward-looking
statements to reflect events occurring or circumstances existing hereafter.
DISPOSITIONS
The Company closed the sale of all of its oil and gas properties located in
the state of Kansas effective February 1, 1997. This sale included 7 gross (5.6
net) wells which had daily gross production of 20.5 (12.9 net) barrels of oil
per day. Total proved developed oil reserves for
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these properties at December 31, 1996 were 33,010 barrels of oil. The sales
price received by the Company was $120,000 which resulted in a gain on sale of
approximately $44,000.
In November, 1997, the Company sold three wells and plugged two wells on
its Stillwater, Oklahoma properties. The Company received cash consideration of
$25,367 from these transactions and recorded a loss on the sale of properties in
the approximate amount of $214,400.
BUSINESS STRATEGY
The Company's business strategy has been and will continue to be the
acquisition of producing oil and gas properties and exploitation of those
properties to maximize production and ultimate reserve recovery. The Company's
present business strategy is to concentrate on expanding its asset base and cash
flow primarily through emphasis on the following activities:
. Acquiring additional producing oil and gas properties, including
properties with poten tial for developmental drilling to maintain a
significant inventory of undeveloped prospects and to enhance the
Company's foundation for future growth;
. Increasing production cash flow and asset value by developing the
Company's proven undeveloped reserves;
. Building on the Company's existing base of operations by concentrating
its development activities in its primary operating areas of Texas and
Oklahoma;
. Serving as operator of its wells to ensure technical performance and
reduce costs;
. Expanding its relationships with major and large independent oil and
gas companies to access their producing as well as undeveloped
properties, seismic data and financial resources;
. Managing financial risk and mitigating technical risk by:
. drilling in known productive trends with multi-horizon geologic
potential;
. diversifying investment over a large number of wells in the
Company's primary operating areas;
. developing properties that provide a balance between short and
long reserve lives;
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. Using, where appropriate, the horizontal drilling technology licensed
by the Company from Amoco Corporation to enhance recovery of oil and
gas from producing properties;
. Maintaining low general and administrative expenses and increasing
economies of scale to reduce per unit Operating Costs and reserve
addition costs.
ACQUISITION AND EXPLOITATION ACTIVITIES
Acquisitions. Historically, the Company has allocated a substantial
portion of its capital expenditures to the acquisition of producing oil and gas
properties. During 1997, the Company acquired a .5% overriding royalty interest
in a well which the Company operates. This interest was acquired from an
individual's estate and the Company paid $500 for the interest. During 1997, the
Company made several bids on oil and gas properties however, the Company was
unsuccessful in acquiring any of these properties as higher bids than the
Company's were accepted. During the fiscal years 1996 and 1995, the Company
acquired 706,949 and 1,843,970 Mcf of natural gas and 428,519 and 1,258,830 Bbls
of oil for total costs of approximately $222,000 and $2,246,000 respectively.
These acquisitions represent a cost of $0.41 per Boe in 1996 and $1.43 per Boe
in 1995. The Company has financed its acquisitions primarily through cash flow,
bank borrowings and issuance of Common Stock.
During 1996, the Company purchased from unaffiliated third parties four
small working interests in producing wells which the Company operates. The total
purchase price paid for these interests was $10,855. In addition, effective May
31, 1996, the Company acquired the remaining interests in two partnerships which
had not been acquired in a 1995 transaction described below. The Company
acquired these partnership interests in exchange for 46,320 shares of the
Company's Common Stock. This acquisition was negotiated on behalf of the Company
by its President, Sid Anderson, and the partnership interests acquired were
valued at approximately $59,000 based upon the estimated value of the
partnerships' oil and gas reserves as determined by an independent petroleum
reservoir engineer. Also in 1996, the Company acquired the Northwest Antelope
Mississippi Chat Unit located in Noble and Garfield Counties, Oklahoma from four
unaffiliated sellers for a total purchase price of $152,500. This acquisition
was negotiated on behalf of the Company by its President, Sid Anderson, and the
purchase price was based on a review of the property by an independent petroleum
reservoir engineer. One of the sel lers in this transaction was Kato Operating
Company. Approximately six months after this acquisition, the president of Kato
Operating Company, Mr. B. E. (Bud) Livingston, was elected to the Board of
Directors of the Company.
During 1995, the Company acquired all of the limited partners' interests in
four oil and gas limited partnerships in which it was the general partner and
liquidated the partnerships. In addition, the Company acquired approximately 96%
and 74% of the limited partners' interest in two other partnerships in which the
Company was the general partner. The consideration paid by the Company for these
limited partnership interests consisted of 1,349,900 shares of the Company's
Common Stock which was valued at approximately $1,267,000 based upon the
estimated value of the partnerships' oil and gas reserves as determined by an
independent
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petroleum reservoir engineer. The consideration paid also included $8,392 in
cash and the assumption by the Company of approximately $611,000 in partnership
debt. This acquisition was negotiated on behalf of the Company by its President,
Sid Anderson. In addition, during 1995 the Company purchased working interests
in two producing oil and gas properties from Kato Operating Company, Livingston
Oil and other unaffiliated third parties for a total purchase price of $975,000.
The properties purchased consisted of a unit containing 10 producing wells and
several shut-in wells located in Stonewall County, Texas and also included a
group of five producing leases with a total of nine producing wells located in
Lipscomb County, Texas. This acquisition was negotiated on behalf of the Company
by its President, Sid Anderson. The purchase price paid by the Company was based
on a review of the properties by independent petroleum reservoir engineers.
Approximately seven months after this acquisition, Mr. B. E. (Bud) Livingston,
President of both Kato Operating Company and Livingston Oil, was elected to the
Board of Directors of the Company. Also during 1995, the Company purchased small
working interests in wells which the Company operated from three unaffiliated
individuals for a total purchase price of approximately $4,000.
To the extent that it has the capital resources to do so, the Company
intends to continue to pursue a business strategy that emphasizes reserve
additions through acquisitions. The Company intends to focus its acquisition
program on producing properties which it believes have potential for additional
exploitation through additional development and enhanced recovery via lateral
completions and improved operating techniques. The Company will seek properties
that are underdeveloped, overly burdened with expenses or owned by financially
troubled companies. Management intends to focus on properties located in the
mid-continent region of the United States, primarily in the states of Texas and
Oklahoma, where Company personnel are best able to draw on their prior oil and
gas experience. It is anticipated that a majority of the potential acquisition
opportunities will be internally generated by Company personnel, although some
opportunities may be brought to the Company by non-employee Directors or
stockholders of the Company. The Company does not currently have any plans to
engage professional firms or consultants that specialize in acquisitions but may
do so in the future. The Company may utilize any one or a combination of lines
of credit with banks, public and private sales of debt and equity securities,
joint oil and gas development arrangements and internally-generated cash flow to
finance its acquisition efforts. No assurance can be given that sufficient
external or internal funds will be available to fund the Company's desired
acquisitions.
The Company maintains its own land, geological, petroleum engineering and
accounting staff which participate in evaluating prospective acquisitions. The
Company utilizes an acquisitions screening approach using applicable engineering
and geological criteria in the review and evaluation process. This evaluation
process helps to form the basis of the purchase price for a potential
acquisition. The Company generally considers the following in its decision-
making process: discounted future net revenues, payout, dollars per proven
barrels of oil and/or Mcf of gas and other potential behind pipe zones or
drilling opportunities. The Company will continue to weigh the comparative
value of various methods of reserve acquisitions and employ the method it
believes is most advantageous in any given transaction. After the acquisition
of oil and gas properties, management generally develops a reservoir depletion
plan to maximize production rates, ultimate reserve recovery and cash flow
generation. Such plans consider field operating
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procedures, workovers, recompletions, secondary recovery implementation,
additional drilling and such other procedures as the situation dictates.
The Company does not have a specific budget for the acquisition of oil and
gas properties since the timing and size of acquisitions are difficult to
forecast. However, the Company is constantly reviewing acquisition
possibilities.
Development Activities. The Company concentrates its acquisition efforts
on proved producing properties which demonstrate a potential for significant
additional development through workovers, behind-pipe recompletions, secondary
recovery operations, the drilling of development or infill wells, and other
exploitation activities which the Company may find appropriate. The Company has
pursued an active workover and recompletion program on the properties it has
acquired and intends to continue its workover and recompletion program in the
future as properties acquired warrant. In connection with oil and gas property
acquisitions, properties are reviewed and evaluated by the Company with a view
toward taking the appropriate actions to maximize production. Such actions may
include repair or replacement of equipment or more extensive efforts such as
recompletion in a different producing zone or implementation of secondary
recovery operations. The expenditures required for the Company's workover and
recompletion program have historically been financed, and it is expected that
they will continue to be financed, by borrowings and internally generated funds.
Exploratory drilling has been minimal to date. The Company reviews
exploration proposals from other companies and individuals and may from time to
time participate in certain ventures where the risk-reward ratio is sufficiently
high to warrant capital outlays. The Company does not anticipate generating
exploration projects utilizing its own staff at the present time. However, the
Company is currently reviewing several drilling ventures and expects to
participate in a drilling venture within the next twelve months.
PRODUCTION
The Company owns and operates producing oil and gas properties located in
the states of Texas and Oklahoma and owns royalty interests in 14 non-operated
wells located in the state of Ohio. The Company continuously evaluates the
profitability of its oil, gas and related activities and has a policy of
divesting itself of unprofitable oil and gas properties or areas of operation
that are not consistent with its operating philosophy.
The Company operates 89 producing wells and owns non-operated interests in
14 producing wells and units in these states. Oil and gas sales from the
Company's producing oil and gas properties accounted for substantially all of
the Company's revenues for the years ended December 31, 1997 and 1996.
The following summarizes the Company's principal areas of oil and gas
production activity.
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<TABLE>
<CAPTION>
AVERAGE AVERAGE NUMBER OF
LOCATION WORKING NET REVENUE PRODUCING
FIELD NAME (COUNTY, STATE) INTEREST INTEREST WELLS
- ---------- --------------- -------- -------- -----
<S> <C> <C> <C> <C>
Flowers Stonewall, TX 100.00% 87.50% 14
Antelope Noble and 97.98% 78.94% 14
Garfield, OK
Pegs Hills Borden, TX 100.00% 80.00% 5
Higgins West Lipscomb, TX 100.00% 82.20% 8
Kellin Lipscomb, TX 100.00% 87.50% 2
Centrahoma Coal, OK 83.02% 65.54% 12
Bowlegs Seminole, OK 100.00% 87.50% 2
Fitts Pontotoc, OK 81.97% 64.92% 13
Hardscrabble Lincoln, OK 28.16% 22.27% 5
</TABLE>
OIL AND GAS PARTNERSHIPS
The Company is the sole general partner in Pan Western 1986 Drilling
Program, Ltd. limited partnership ("1986 Program") and Pan Western 1987
Production Program, Ltd. limited partnership ("1987 Program"), whose purposes
are the acquisition, drilling, development, production, marketing and operation
of oil and gas properties. As general partner, the Company is entitled to
18.57% and 15% of the current earnings or losses for the 1986 and 1987 Programs,
respectively, and is also entitled to a "back-in" interest upon payout. For
additional information regarding these partnerships, See Note 3 to the Company's
Consolidated Financial Statements elsewhere in this Form 10KSB.
HORIZONTAL DRILLING
The Company has entered into a license agreement with Amoco Corporation for
a patented short-radius horizontal drilling and completion technology. The
technology is designed to permit enhanced recovery of oil and gas from producing
formations which have high bottom hole pressures but low permeability. This
technology has been used in several oil and gas fields at both foreign and
domestic locations. The Company currently plans to use this technology to
maximize recoverable oil and gas reserves on a number of the Company's
properties and to possibly offer the technology as a service to other oil and
gas producers in the future. The Company currently plans to offer its customers
a complete package of services needed to complete a short-radius horizontal
extension without having to rely on several different
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contractors as is the case with most of the other companies offering horizontal
drilling services. The Company plans to offer these services through its wholly-
owned subsidiary, Lateral Completion Technologies, Inc. ("LCT"). The Company
currently estimates the costs to fund the initial operations of LCT to be
approximately $1,500,000 for the purchase of drilling and associated equipment
necessary to exploit the Amoco technology and approximately $500,000 for working
capital for the first year of operation. The Company is attempting to obtain the
required funding through a joint venture arrangement with an industry partner or
through debt or equity financing however, to date the Company has been
unsuccessful in its attempts to obtain the funding on any terms and no assurance
can be given that such capital will be available on terms satisfactory to the
Company.
MARKETING
The availability of a market for oil and gas produced or marketed by the
Company is dependent upon a number of factors beyond its control which cannot be
accurately predicted. These factors include the proximity of wells to, and the
available capacity of, natural gas pipelines, the extent of competitive domestic
production and imports of oil and gas, the availability of other sources of
energy, fluctuations in seasonal supply and demand, and governmental regulation.
In addition, there is always the possibility that new legislation may be enacted
which would impose price controls or additional taxes upon crude oil or natural
gas, or both. In the event a productive gas well is completed in an area that is
distant from existing gas pipelines, the Company may allow the well to remain
shut-in until a pipeline is extended to the well or until additional wells are
drilled to establish the existence of sufficient producing reserves to justify
the cost of extending existing pipelines to the area. It appears that the United
States is emerging from a period of oversupply of natural gas which has, and may
still, cause delays, restrictions or reductions of natural gas production and
which in the past has adversely affected gas prices. Oversupplies of natural gas
can be expected to recur from time to time and may result in depressed gas
prices and in the gas producing wells of the Company being shut-in.
Since the early 1970's the supply and market price for crude oil has been
significantly affected by policies adopted by the member nations of OPEC.
Members of OPEC establish among themselves prices and production quotas for
petroleum products from time to time with the intent of manipulating the global
supply and price levels for crude oil. In addition, Canada recently revised its
laws affecting the exportation of natural gas to the United States. Mexico also
continues to fine tune its import/export policies. The oil and gas policies of
the United States, Canada and Mexico are impacted by the Canadian/U.S. Free
Trade Agreement, the General Agreement on Tariffs and Trade, and the North
American Free Trade Agreement. These factors are expected to increase
competition and may adversely affect the price of natural gas in certain areas
of the United States. The Company is unable to predict the effect, if any,
which OPEC, Canadian and Mexican policies, and emerging international trade
doctrines will have on the amount of, or the prices received for, oil and
natural gas produced and sold by the Company.
Changes in oil and natural gas prices significantly affect the revenues and
cash flow of the Company and the value of its oil and gas properties.
Significant declines in the prices of oil and natural gas could have a material
adverse effect on the business and financial condition of the
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Company. The Company is unable to predict accurately whether the price of oil
and natural gas will rise, stabilize or decline in the future.
Substantially all of the Company's crude oil and condensate production is
sold at posted prices under short term contracts, as is customary in the
industry. The most significant purchasers of the Company's oil and gas
production during the year ended December 31, 1997 were Conoco Oil Company,
Total Petroleum, Inc., Mega II, LLC., and Sun Oil Company which accounted for
approximately 18%, 17%, 14% and 11% of the Company's total oil and gas revenues,
respectively. The most significant purchasers of the Company's production during
the year ended December 31, 1996 were Conoco Oil Company, Sun Oil Company, Total
Petroleum, Inc., and Octagon Resources, Inc. which accounted for 18%, 16%, 15%
and 11% of the Company's total oil and gas revenues, respectively. No other
purchaser of crude oil or natural gas during these periods exceeded 10% of the
Company's oil and gas sales.
The Company's gas production is sold primarily on the spot market or under
market sensitive long term agreements with a variety of purchasers, including
intrastate and interstate pipelines, their marketing affiliates, independent
marketing companies and other purchasers who have the ability to move the gas
under firm transportation agreements.
COMPETITION
Competition in the acquisition of producing oil and gas properties and in
the exploration and production of oil and gas is intense. In seeking to obtain
desirable producing properties, new leases and exploration prospects, the
Company faces competition from both major and independent oil and gas companies
as well as from numerous individuals. Many of these competitors have financial
and other resources substantially in excess of those available to the Company.
Increases in worldwide energy production capability and decreases in energy
consumption as a result of conservation efforts have brought about substantial
surpluses in energy supplies in recent years. This, in turn, has resulted in
substantial competition for markets historically served by domestic natural gas
resources both with alternate sources of energy and among domestic gas
suppliers. As a result, there have been reductions in oil and gas prices,
widespread curtailment of gas production and delays in producing and marketing
gas after it is discovered. Changes in government regulations relating to the
production, transportation and marketing of natural gas have also resulted in
significant changes in the historical marketing patterns of the industry.
Generally, these changes have resulted in the abandonment by many pipelines of
long-term contracts for the purchase of natural gas, the development by gas
producers of their own marketing programs to take advantage of new regulations
requiring pipelines to transport gas for regulated fees, and the emergence of
various types of gas marketing companies and other aggregators of gas supplies.
As a consequence, gas prices, which were once effectively determined by
government regulation, are now largely established by market competition.
Competitors of the Company in this market include other producers, gas pipelines
and their affiliated marketing companies, independent marketers, and providers
of alternate energy supplies.
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REGULATION
The oil and gas industry is extensively regulated by federal, state and
local authorities. Legislation affecting the oil and gas industry is under
constant review for amendment or expansion. Numerous departments and agencies,
both federal and state, have issued rules and regulations applicable to the oil
and gas industry and its individ ual members, some of which carry substantial
penalties for the failure to comply. The regulatory burden on the oil and gas
industry increases its cost of doing business and, consequently, affects its
profitability. Inasmuch as such laws and regulations are frequently amended or
reinterpreted, the Company is unable to predict the future cost or impact of
complying with such regulations.
Exploration and Production. Exploration and production operations of the
Company are subject to various types of regulation at the federal, state and
local levels. Such regulation includes requiring permits for the drilling of
wells, maintaining bonding requirements in order to drill or operate wells, and
regulating the location of wells, the method of drilling and casing wells, the
surface use and restoration of properties upon which wells are drilling and
producing, and the plugging and abandoning of wells. The Company's operations
are also subject to various conservation matters. These include the regulation
of the size of drilling and spacing units or proration units, the density of
wells which may be drilled, and the unitization or pooling of oil and gas
properties or interests. In this regard, some states allow the forced pooling
or integration of tracts to facilitate exploration while other states rely on
voluntary pooling of lands and leases. In addition, state conservation laws
establish maximum rates of production from oil and gas wells, generally prohibit
the venting or flaring of gas, and impose certain requirements regarding the
rate of production. The effect of these regulations is to limit the amounts of
oil and gas the Company can produce from its wells, and to limit the number of
wells or the locations at which the Company can drill.
The states of Oklahoma and Texas have adopted or are considering revisions
to their production allowable rules under which they regulate the quantities of
natural gas which may be produced within their borders. The stated rationale
behind such prorationing legislation and rulemaking is the conservation of
natural resources, prevention of waste and protection of the correlative rights
of oil and gas interest owners by limiting production to the available market.
It is impossible at this time to determine the effect, if any, these
developments may have on the natural gas industry as a whole. The Company does
not believe the developments will materially affect its operations.
Certain of the Company's oil and gas leases are granted by the federal
government and administered by various federal agencies. Such leases require
compliance with detailed federal regulations and orders which regulate, among
other matters, drilling and operations on these leases and calculation of
royalty payments to the federal government. The Mineral Lands Leasing Act of
1920 places limitations on the number of acres under federal leases that may be
owned in any one state. While the Company does not have a substantial federal
lease acreage position in any state or in the aggregate, the Company does own
interests in federal oil and gas leases which produce amounts of oil and gas
material to the Company. The Mineral Lands Leasing Act of 1920 and related
regulations also may restrict a corporation from holding title to federal
onshore oil and
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gas leases if stock of such corporation is owned by citizens of foreign
countries which are not deemed reciprocal under such Act. Reciprocity depends,
in large part, on whether the laws of the foreign jurisdiction discriminate
against a United States person's ownership of rights to minerals in such
jurisdiction. The purchase of shares in the Company by citizens of foreign
countries who are not deemed to be reciprocal under such Act could have an
impact on the Company's ownership of federal leases.
The Company's operations are subject to extensive federal, state and local
laws and regulations relating to the generation, storage, handling, emission,
transportation and discharge of materials into the environment. Permits are
required for various of the Company's operations, and these permits are subject
to revocation, modification and renewal by issuing authorities. Governmental
authorities have the power to enforce compliance with their regulations, and
violations are subject to fines, injunctions or both. It is possible that
increasingly strict requirements will be imposed by environmental laws and
enforcement policies thereunder. The Company is also subject to laws and
regulations concerning occupational safety and health. It is not anticipated
that the Company will be required in the near future to expend amounts that are
material in the aggregate to the Company's overall operations by reason of
environmental or occupational safety and health laws and regulations, but
inasmuch as such laws and regulations are frequently changed, the Company is
unable to predict the ultimate cost of compliance.
Natural Gas Sales and Transportation. Federal legislation and regulatory
controls have historically affected the price of the gas produced by the
Company and the manner in which such production is marketed. The transportation
and sale for resale of gas in interstate commerce are regulated pursuant to the
Natural Gas Act of 1938 (the "NGA") and the Natural Gas Policy Act of 1978 (the
"NGPA") and Federal Energy Regulatory Commission ("FERC") and regulations
promulgated thereunder. Since 1978, maximum selling prices of certain
categories of gas, whether sold in interstate or intrastate commerce, have been
regulated pursuant to the NGPA. The NGPA established various categories of gas
and provided for graduated deregulation of price controls of several categories
of gas and the deregulation of sales of certain categories of gas. All price
deregulation contemplated under the NGPA has already taken place.
TITLE TO PROPERTIES
As is customary in the oil and gas industry, the Company performs a minimal
title investigation before acquiring oil and gas properties, which generally
consists of obtaining a title report from legal counsel covering title to the
major properties (for example, properties comprising at least 80% by value of
the acquired properties) and due diligence reviews by independent landmen of the
remaining properties. The Company believes that it has satisfactory title to
such properties in accordance with standards generally accepted in the oil and
gas industry. A title opinion is obtained prior to the commencement of any
drilling operations on such properties. The Company's properties are subject to
customary royalty interests, liens incident to operating agreements, liens for
current taxes and other burdens which the Company believes do not materially
interfere with the use of or affect the value of such properties. Substantially
all of the Company's oil and gas properties are and will continue to be
mortgaged to secure borrowings under the Company's credit facilities.
13
<PAGE>
OPERATIONAL HAZARDS AND INSURANCE
The operations of the Company are subject to all risks inherent in the
exploration for and production of oil and gas, including such natural hazards as
blowouts, cratering and fires, which could result in damage or injury to, or
destruction of, drilling rigs and equipment, formations, producing facilities or
other property, or could result in personal injury, loss of life or pollution of
the environment. Any such event could result in substantial expense to the
Company which could have a material adverse effect upon the financial condition
of the Company to the extent it is not fully insured against such risk. The
Company carries insurance against certain of these risks but, in accordance with
standard industry practice, the Company is not fully insured for all risks,
either because such insurance is unavailable or because the Company elects not
to obtain insurance coverage because of cost. Although such operational risks
and hazards may to some extent be minimized, no combination of experience,
knowledge and scientific evaluation can eliminate the risk of investment or
assure a profit to any company engaged in oil and gas operations.
EMPLOYEES
As of December 31, 1997 the Company employed a total of seven full time
employees at its offices in Tulsa, Oklahoma consisting of 2 production and land
personnel, one of whom is an executive officer, and 5 financial, accounting and
administrative personnel, three of whom are executive officers. The Company also
has one full time field employee in the state of Texas. The Company also
engages the services of 12 additional contract field personnel. The Company
believes its relations with its employees and contractors are excellent.
ITEM 2. DESCRIPTION OF PROPERTY
OIL AND GAS PROPERTIES
All of the Company's oil and gas properties, reserves and activities are
located onshore in the continental United States in the states of Texas and
Oklahoma. There are no quantities of oil or gas produced by the Company which
are subject to long-term supply or similar agreements with foreign governmental
authorities.
Oil and Gas Reserves. Williamson Petroleum Consultants, Inc., an
independent petroleum engineering consulting firm, has made estimates of the
Company's oil and gas reserves as of January 1, 1998 and Sycamore Resou rces,
LLC ("Sycamore Resources)", an independent petroleum engineering consulting
firm, has made estimates of the Company's oil and gas reserves as of January 1,
1997. Both of these reports cover the estimated present value of future net cash
flows before income taxes (discounted at 10%) attributable to the Company's
proved developed reserves, as well as its proved undeveloped reserves and
estimated future net cash flows from such reserves. The Sycamore Resources
report includes the Company's oil and gas properties located in the state of
Kansas which have subsequently been sold, and neither report includes the
Company's royalty interests in 14 wells located in the state of Ohio which are
not material to the Company's total oil and gas reserves.
14
<PAGE>
The quantities of the Company's proved reserves of oil and natural gas
presented below include only those amounts which the Company reasonably expects
to recover in the future from known oil and gas reservoirs under existing
economic and operating conditions. Proved developed reserves are limited to
those quantities which are recoverable commercially at current prices and costs,
under existing regulatory practices and with existing technology. Accordingly,
any changes in prices, operating and development costs, regulations, technology
or other factors could significantly increase or decrease estimates of the
Company's proved developed reserves. The Company's proved undeveloped reserves
include only those quantities which the Company reasonably expects to recover
from the drilling of new wells based on geological evidence from offsetting
wells. The risks of recovering these reserves are higher from both geological
and mechanical perspectives than the risks of recovering proved developed
reserves.
Set forth below are estimates of the Company's net proved reserves and
proved developed reserves and the estimated future net revenues from such
reserves and the present value thereof based upon the standardized measure of
discounted future net cash flows relating to proved oil and gas reserves in
accordance with the provisions of Statement of Financial Accounting Standards
No. 69. "Disclosures about Oil and Gas Producing Activities." Estimated future
net cash flows from proved reserves are determined by using estimated quantities
of proved reserves and the periods in which they are expected to be developed
and produced based on economic conditions at the date of the report. The
estimated future production is priced at current prices at the date of the
report. The resulting estimated future cash inflows are then reduced by
estimated future costs to develop and produce reserves based on cost levels at
the date of the report. No deduction has been made for depletion, depreciation
or income taxes or for indirect costs, such as general corporate overhead.
Present values were computed by discounting future net revenues at 10% per
annum.
The following tables set forth estimates of the proved oil and natural gas
reserves of the Company as of January 1, 1998, as evaluated by Williamson
Petroleum Consultants, Inc.
<TABLE>
<CAPTION>
OIL (BBLS) GAS (MCF)
---------- ----------------------
DEVELOPED UNDEVELOPED TOTAL DEVELOPED UNDEVELOPED TOTAL
---------- ----------- --------- --------- ----------- ---------
<S> <C> <C> <C> <C> <C> <C>
Oklahoma 172,300 299,173 471,473 2,716,986 1,713,190 4,430,176
Texas 646,344 231,806 878,150 1,384,279 437,342 1,821,621
------- ------- --------- --------- --------- ---------
Total 818,644 530,979 1,349,623 4,101,265 2,150,532 6,251,797
======= ======= ========= ========= ========= =========
</TABLE>
The following table sets forth amounts as of December 31, 1997 determined
in accordance with the requirements of the applicable accounting standards, of
the estimated future net cash flows from production and sale of the proved
reserves attributable to the Company's oil and gas properties before income
taxes and the present value thereof. Benchmark prices used in determining the
future net cash flow estimates as of January 1, 1998 were $16.80 per barrel for
oil and $1.80 per Mcf for gas.
15
<PAGE>
<TABLE>
<CAPTION>
AT DECEMBER 31, 1997
- -------------------------------------------------------------------------------------
(IN THOUSANDS)
PROVED PROVED TOTAL
DEVELOPED UNDEVELOPED PROVED
RESERVES RESERVES RESERVES
--------- ----------- --------
<S> <C> <C> <C>
Estimated future net cash flows from
proved reserves before income taxes $12,475 $7,797 $20,272
Present value of estimated future net cash
flows from proved reserves before income
taxes (discounted at 10%) $ 5,584 $2,991 $ 8,575
</TABLE>
The estimation of oil and gas reserves is a complex and subjective process
which is subject to continued revisions as additional information becomes
available. Reserve estimates prepared by different engineers from the same data
can vary widely. Therefore, the reserve data presented herein should not be
construed as being exact. Any reserve estimate depends in part on the quality
of available data, engineering and geologic interpretation, and thus represents
only an informed professional judgment. Subsequent reservoir performance may
justify upward or downward revision of such estimate.
Estimates of the Company's proved reserves have been filed or included in
reports to the Securities and Exchange Commission but not to any other federal
authority or agency.
For further information on reserves, costs relating to oil and gas
activities, and results of operations from producing activities, see Note 13 to
the Company's Consolidated Financial Statements - Supplementary Financial
Information About Oil and Gas Producing Activities (unaudited).
Productive Wells and Acreage. The following table sets forth the Company's
producing wells and Developed Acreage assignable thereto at December 31, 1997.
<TABLE>
<CAPTION>
PRODUCTIVE WELLS
- --------------------------------------------------------------------
DEVELOPED ACREAGE OIL GAS TOTAL
------------------- ----------- ----------- -----------
GROSS NET GROSS NET GROSS NET GROSS NET
------- ------- ----- ---- ----- ---- ----- -----
<S> <C> <C> <C> <C> <C> <C> <C>
15,301 13,367 63 48.31 26 13.10 89 61.41
</TABLE>
At December 31, 1997, the Company held no undeveloped acres.
Production, Unit Prices and Costs. The following table set forth
information with respect to production and average unit prices and costs for the
periods indicated.
16
<PAGE>
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31
----------------------
1997 1996
---------- ----------
<S> <C> <C>
PRODUCTION:
Gas (Mcf) 250,409 263,123
Oil (Bbls) 45,136 56,871
AVERAGE SALES
PRICES:
Gas (per Mcf) $ 1.88 $ 1.86
Oil (per Bbl) 19.85 20.85
AVERAGE LEASE
OPERATING
COSTS PER BOE (1) 6.86 7.20
</TABLE>
(1) The components of production costs may vary substantially among wells
depending on the methods of recovery employed and other factors, but
generally include production taxes, lease overhead, maintenance and repair,
labor and utilities.
Sale of Kansas Oil and Gas Properties. Effective February 1, 1997, the Company
sold all of its producing oil and gas properties in the state of Kansas. This
sale included 7 gross (5.6 net) wells which had average daily gross production
of 20.5 (12.9 net) barrels of oil per day. Total proved developed oil reserves
at December 31, 1996 amounted to 33,010 barrels of oil. There were no proved
undeveloped oil reserves associated with these properties. The sale price
received by the Company was $120,000 which resulted in a gain on sale of assets
of approximately $44,000.
ITEM 3. LEGAL PROCEEDINGS
The Company is not a party to any material pending legal proceedings.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matter was submitted during the fourth quarter of the year ended
December 31, 1997 to a vote of the security holders.
17
<PAGE>
PART II
ITEM 5. MARKET FOR COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
The Company became eligible to trade publicly by virtue of filing a Form
10SB with the Securities and Exchange Commission. The registration became
effective June 26, 1997. Since that time, the Company has been unable to
establish a public market for it's common stock. And there is currently no
public market for the Company's common stock. There have been no dividends
declared or paid to the owners of the common stock. It is the Company's present
policy to retain any earnings for working capital purposes, and accordingly the
Company does not expect to pay dividends in the foreseeable future.
ITEM 6. MANAGEMENT'S DISCUSSION AND ANALYSIS OR PLAN OF OPERATION.
The selected financial information set forth below for each of the
Company's fiscal years ended December 31, 1997 and 1996 is derived from the
audited consolidated financial statements of the Company appearing elsewhere in
this Form 10KSB. The selected financial information set forth below should be
read together with management's discussion and analysis set forth below and the
Company's audited consolidated financial statements, including the notes
thereto, appearing elsewhere in this Form 10KSB.
18
<PAGE>
SELECTED FINANCIAL INFORMATION
<TABLE>
<CAPTION>
YEAR ENDED
DECEMBER 31
-----------------------
1997 1996
-----------------------
<S> <C> <C>
STATEMENT OF OPERATIONS DATA:
Oil and gas sales.............................................. $1,361,212 $ 1,675,193
Operating income............................................... 82,333 122,524
---------- -----------
Total revenue.................................................. 1,443,545 1,797,717
Lease operating costs.......................................... 596,247 725,432
Depreciation, depletion, and
amortization.................................................. 264,266 318,556
Interest expense............................................... 211,390 233,411
Salaries and wages............................................. 373,768 375,482
General and administrative..................................... 482,398 378,535
Other expense, net............................................. 174,641 18,745
---------- -----------
Net loss....................................................... $ (659,165) $ (252,444)
========== ===========
Net loss per common share, basic and diluted................... $(0.20) $(0.08)
========== ===========
Weighted average common shares outstanding, basic and diluted.. 3,312,500 3,141,035
BALANCE SHEET DATA:
Working capital (deficit)...................................... (631,662) (1,361,893)
Property and equipment, net.................................... 2,359,434 2,930,856
Total assets................................................... 2,987,281 3,626,212
Current portion of long-term
debt and notes payable........................................ 769,564 1,338,665
Long-term debt................................................. 1,669,628 1,072,469
Stockholders' equity........................................... 123,056 554,330
</TABLE>
RESULTS OF OPERATIONS
The Company follows the "successful efforts" method of accounting for its
oil and gas properties whereby costs of productive wells and productive leases
are capitalized and depleted on a unit-of-production basis over the life of the
remaining proved reserves. Depletion of capitalized costs is provided on a
well-by-well basis. Exploratory expenses, including geological and geophysical
expenses and annual delay rentals, are charged to expense as incurred.
Exploratory drilling costs, including the cost of stratigraphic test wells, are
initially capitalized, but charged to expense if and when the well is determined
to be unsuccessful.
The factors which most significantly affect the Company's results of
operations are (i) the sale prices of crude oil and natural gas, (ii) the level
of oil and gas sales, (iii) the level of lease operating expenses, (iv) the
level of exploratory activities, and (v) the level of and interest rates on
borrowings. Total sales volumes and the level of borrowings are significantly
impacted by the degree of success the Company experiences in its efforts to
acquire oil and gas properties and its ability to maintain or increase
production from existing oil and gas properties through its development and
production enhancement activities. The following table reflects certain
historical operating data for the periods presented.
19
<PAGE>
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31
----------------------
1997 1996
---------- ----------
<S> <C> <C>
NET SALES VOLUMES:
Oil (Bbls) 45,136 56,871
Natural gas (Mcf) 250,409 263,123
Oil equivalent (Boe) 86,871 100,725
AVERAGE SALES PRICES:
Oil (per Bbl) $ 19.85 $ 20.85
Natural gas (per Mcf) 1.88 1.86
OPERATING EXPENSES PER BOE
OF NET SALES:
Lease operating $ 6.86 $ 7.20
General, administrative and other 12.37 9.99
Depreciation, depletion and amortization 3.04 3.16
</TABLE>
Relatively modest changes in either oil or gas prices significantly impact
the Company's results of operations and cash flow and could significantly impact
the Company's borrowing capacity. Prices received by the Company for sales of
oil and natural gas have fluctuated significantly from period to period. The
Company's ability to maintain current borrowing capacity and to obtain
additional capital on attractive terms is substantially dependent on oil and gas
prices. Domestic spot oil prices have ranged from a low of approximately $11 per
barrel in July 1986 to a high of approximately $40 per barrel in October 1991,
with a price as of March 30, 1998 of approximately $14.50 per barrel. The
fluctuations in oil prices during these periods reflect market uncertainty
regarding OPEC's ability to control the production of its member countries, as
well as concerns related to the global supply and demand for crude oil. Since
the end of the Gulf War in early 1991, crude oil prices have experienced
continued weakness, primarily as a result of OPEC's inability to maintain
disciplined production quotas by member countries and the uncertainty associated
with Iraq's return to the crude oil export market. These factors continue to
overhang the market and will create significant price volatility for the
foreseeable future.
Natural gas prices received by the Company fluctuate generally with changes
in the spot market price for gas. Spot market gas prices have generally
declined in recent years because of lower worldwide energy prices as well as
excess deliverability of natural gas in the United States. However, natural gas
prices have rebounded recently and appear to be poised for further
strengthening. Domestic spot natural gas prices have ranged from a low of
approximately $0.90 per Mcf in January 1992 to a high of approximately $4.44 per
Mcf in December 1996, with a price as of March 30, 1997 of approximately $1.60
per Mcf. Environmental concerns coupled with recent increases in the use of
natural gas to produce electricity have combined to improve prices. As part of
continued deregulation of natural gas, U.S. pipelines have been made more
accessible to both buyers and sellers of natural gas and, as a result, natural
gas will be able to more effectively compete for market share with other end-use
energy forms.
20
<PAGE>
The Company's principal source of cash flow is the production and sale of
its crude oil and natural gas reserves, which are depleting assets. Cash flow
from oil and gas sales depends upon the quantity of production and the price
obtained for such production. An increase in prices permits the Company to
finance its operations to a greater extent with internally generated funds. A
decline in oil and gas prices reduces the cash flow generated by the Company's
operations, which in turn reduces the funds available for servicing debt,
acquiring additional oil and gas properties and exploring for an developing new
oil and gas reserves.
In addition to the foregoing, the results of the Company's operations vary
due to seasonal fluctuations in the sales prices and volumes of natural gas. In
recent years, natural gas prices have been generally higher in the fall and
winter. Due to these seasonal fluctuations, results of operations for
individual annual and quarterly periods may not be indicative of results which
may be realized on an annual basis.
Year ended December 31, 1997 compared to year ended December 31, 1996.
Total revenues for the year ended December 31, 1997 decreased 19.70% to
$1,443,545 from $1,797,717 for the year ended December 31, 1996. Oil and gas
revenues decreased from $1,675,193 for the year ended December 31, 1996 to
$1,361,212 for the year ended December 31, 1997. These decreases were
attributable to both declines in production of oil and gas and a decline in the
average oil price received during the year ended December 31, 1997 as compared
to the year ended December 31, 1996. Average prices received by the Company
were $19.85 per Bbl of oil and $1.88 per Mcf of gas during fiscal 1997 compared
to $20.85 per Bbl of oil and $1.86 per Mcf of gas received during fiscal 1996.
Oil and gas production for the year ended December 31, 1997 was 11,735 Bbls
and 12,714 Mcf lower than production volumes experienced during the prior year
ended December 31, 1996. These production declines were primarily attributable
to the sale of the Company's Kansas properties which produced approximately
4,700 barrels of oil during the year ended December 31, 1996 and the normal
decline in production over time. In addition, the Company experienced severe
problems with one of its oil wells during the year ended December 31, 1997. This
well produced approximately 3,700 bbls of oil during the year ended December 31,
1996 as compared to approximately 1,400 during the year ended December 31, 1997.
Operating income declined from $122,524 during the year ended December 31,
1996 to $82,333 during the year ended December 31, 1997. The decline is
attributable to a reduction in the number of wells on which the administrative
overhead and field supervision charges made to third party working interest
owners is being charged. The Company continues to charge third party working
interest owners these overhead fees on a monthly basis on wells that the Company
operates.
Lease operating expenses decreased from $725,432 during 1996 to $596,247
during the year ended December 31, 1997. Lease operating expense is comprised
of the normal and recurring expenses incurred in the operation of oil and gas
wells, production taxes, compression
21
<PAGE>
and dehydration fees and transportation costs. Normal and recurring lease
operating expense decreased from $624,074 in fiscal 1996 to $503,125 during
fiscal 1997. The $120,949 decline in normal lease operating expenses during the
year ended December 31, 1997 as compared to the previous year is due primarily
to the Company spending less on ongoing maintenance programs which was due to
the limited cash resources available to the Company during 1997. Production
taxes during 1997 amounted to $92,692 compared to $96,939 in the prior year. The
decrease in taxes is a direct result of decreased revenue from oil and gas sales
experienced during the year ended December 31, 1997. Compression and dehydration
fees decreased from $3,304 during fiscal 1996 to $430 experienced during fiscal
1997 and there were no transportation costs paid by the Company during fiscal
1997 as compared to $1,114 in transportation costs paid by the Company during
fiscal 1996.
Compensation expense decreased from $375,482 during fiscal 1996 to $373,768
during fiscal 1997. This decrease is attributable to the Company not replacing a
clerical employee who resigned during the third quarter of 1997.
Depreciation, depletion and amortization expense for the year ended
December 31, 1997 was $264,266 compared to $318,556 for the prior year.
Depletion of oil and gas assets is based on a unit of production method and
support equipment is depreciated over its estimated useful life. The decrease
is attributable to decreased production of oil and gas during 1997 on
approximately the same amount of proved producing reserves and the exclusion of
the Company's Kansas properties and Stillwater properties from the depletion
base. These properties were disposed of during the year ended December 31, 1997.
General and administrative expenses for the year ended December 31, 1997
increased to $482,398 from $378,535 for the prior year reflecting primarily
increases in accounting and auditing fees, legal fees, loan fees, printing and
copying expenses, professional fees, insurance costs, and travel expenses. As
compared against fiscal 1996, accounting and auditing fees increased by $2,515,
legal fees increased by $27,097, printing and copying fees increased by $15,086,
professional fees increased by $17,641, and travel expenses increased by $9,202.
The increase in these expenses was due primarily to the inclusion of expenses
related to the filing of a Form 10SB by the Company which became effective on
June 26, 1997. The increase in insurance costs was $5,181 and was due primarily
to the purchase of increased liability coverage by the Company. The increase in
loan fees of $ 59,750 was attributable to a transaction whereby the Company
borrowed $300,000 from an individual. As additional consideration for executing
a promissory note with the Company, the Company issued the individual 33,000
shares of its common stock and recorded the fair value of the stock issued,
($66,000), as a loan fee.
Interest expense decreased from $233,411 during fiscal 1996 to $211,390
during fiscal 1997. The decrease is attributable to a restructuring of the
Company's debt during the year ended December 31, 1997 which extended the term
of the debt at a lower rate of interest.
Other expense increased from $18,745 in 1996 to $174,641 in 1997. This
increase is comprised primarily of a net loss on the sale of oil and gas assets
during 1997. During 1997, the Company experienced a gain on sale of it's Kansas
properties in the amount of approximately
22
<PAGE>
$44,000 however, this gain was offset by a loss on the sale of the Company's
Stillwater properties in the approximate amount of $214,400.
CAPITAL RESOURCES AND LIQUIDITY
The Company's capital requirements relate primarily to the acquisition of
developed oil and gas properties and undeveloped leasehold acreage and
exploration and development activities. In general, because the Company's oil
and gas reserves are depleted by production, the success of its business
strategy is dependent upon a continuous acquisition and exploration and
development program.
The domestic spot price for crude oil has ranged from $11.00 to $40.00 per
barrel over the past ten years. To the extent that crude oil prices continue
fluctuating in this manner, the Company expects material fluctuations in
revenues from quarter to quarter which, in turn, could adversely affect the
Company's ability to timely service its debt to its principal banks and fund its
ongoing operations and could, under certain circumstances, require a write-down
of the book value of the Company's oil and gas reserves.
Since the Company is engaged in the business of acquiring producing oil and
gas properties, from time to time it acquires certain non-strategic and marginal
properties in some of its purchases. A portion of the Company's on-going
profitability is related to the disposition of these non-strategic properties on
a regular basis. The Company expects to continue to pursue sales of these
types of properties in the future. In most cases the revenue from these
properties is insignificant and in many cases does not exceed the lease
operating expense. As a result, a portion of the Company's capital resources
are generated by the sale of assets from continuing operations. Sales of non-
strategic and minor interests oil and gas properties accounted for a net loss of
$168,628 during fiscal 1997 and $7,326 in losses during fiscal 1996. The loss
experienced during 1997 was comprised of a gain on sale of it's Kansas
properties in the amount of approximately $44,000 and a loss on the sale of the
Company's Stillwater properties in the approximate amount of $214,400.
Capital Expenditures. The timing of most of the Company's capital
expenditures is discretionary. Currently there are no material long-term
commitments associated with the Company's capital expenditure plans.
Consequently, the Company has a significant degree of flexibility to adjust the
level of such expenditures as circumstances warrant. The Company primarily uses
internally generated cash flow and proceeds from the sale of oil and gas
properties to fund capital expenditures, other than significant acquisitions,
and to fund its working capital needs. If the Company's internally generated
cash flows should be insufficient to meet its debt service or other obligations,
the Company may reduce the level of discretionary capital expenditures or
increase the sale of non-strategic oil and gas properties in order to meet such
obligations. The level of the Company's capital expenditures will vary in
future periods depending on energy market conditions and other related economic
factors. The Company anticipates that its cash flow will be sufficient to fund
its operations and debt service at their current levels for the next year.
23
<PAGE>
Substantially all of the Company's capital expenditures have been made to
acquire oil and gas properties. During the year ended December 31, 1997, the
Company acquired a .5% overriding royalty interest from an estate in a well
which the Company operates. This interest was acquired for $500. During the year
ended December 31, 1996, the Company completed three acquisitions of oil and gas
properties for a cost of approximately $222,000, including the value of the
remaining limited partners' interest in the two limited partnerships which were
no t 100% acquired in fiscal 1995. These remaining limited partnership
interests were acquired for 46,320 shares of the Company's common stock. The
Company's strategy is to continue to expand its reserve base principally through
acquisitions of producing oil and gas properties. It is likely that capital
expenditures will exceed cash provided by operating activities in years where
significant growth occurs in the Company's oil and gas reserve base. In such
cases, additional external financing will be required.
The Company intends to continue its practice of reserve replacement and
growth through the acquisition of producing oil and gas properties, although at
this time it is unable to predict the number and size of such acquisitions, if
any, which will be completed. In addition, it is anticipated that the Company
may participate in one or more developmental drilling ventures during fiscal
1998. The Company's ability to finance its oil and gas acquisitions is
determined by its cash flow from operations and available sources of debt and
equity financing.
As of December 31, 1997, the Company had a working capital deficit of $
631,662 compared to a working capital deficit of $1,361,893, as of December 31,
1996. During the year ended December 31, 1997 the Company experienced a decrease
in unrestricted cash of $218,013 primarily as a result of the net loss of
$659,165 coupled with reductions in accounts payable and an increase in
restricted cash and partially offset by a decrease in accounts receivable, the
proceeds from the sale of oil and gas properties and the proceeds from the sale
of common stock.
Financing Arrangements. To date, the Company has financed its acquisitions
of oil and gas properties primarily through bank borrowings and issuance of
Common Stock. At December 31, 1997, the Company had a total indebtedness to
three principal lenders in the aggregate amount of $2,439,192. At December 31,
1996, the Company was indebted to three principal lenders in the aggregate
amount of $2,411,134. On January 2, 1998, the Company refinanced its
outstanding debt with two of its lenders with the third lender. This refinancing
resulted in a reduction of the aggregate monthly payments on the Company's
indebtedness from approximately $63,000 to approximately $36,542, an extension
of maturities from one to three years to December 30, 2002, and an interest rate
of 10%. The Company anticipates that at maturity it will be able to refinance
this indebtedness as necessary on satisfactory terms. All of the Company's oil
and gas properties are subject to mortgages granted to secure this debt.
The Company owns the office building in Tulsa, Oklahoma in which its
executive offices are located. The Company financed the acquisition of this
building through borrowing from a bank. At December 31, 1997, the Company was
indebted to this bank in the principal amount of $204,288. This loan bears
interest at the rate of 9.5% per year, and requires monthly payments of $2,261,
with approximately $175,000 due at maturity in March 2001. The Company has
granted a mortgage on the building to secure this debt.
24
<PAGE>
For additional information regarding the indebtedness of the Company at
December 31, 1997, see Note 5 to the Company's audited consolidated financial
statements elsewhere in this Form 10KSB.
SEASONALITY
The results of operations of the Company are somewhat seasonal due to
seasonal fluctuations in the price for crude oil and natural gas. Recently,
crude oil prices have been generally higher in the third calendar quarter and
natural gas prices have been generally higher in the first calendar quarter. Due
to these seasonal fluctuations, results of operations for individual quarterly
periods may not be indicative of results which may be realized on an annual
basis.
INFLATION AND PRICES
In recent years, inflation has not had a significant impact on the
Company's operations or financial condition. The generally downward pressure on
oil and gas prices during most of such periods has been accompanied by a
corresponding downward pressure on costs incurred to acquire, develop and
operate oil and gas properties as well as the costs of drilling and completing
wells on properties.
OFFICE FACILITIES
The Company owns the office building in Tulsa, Oklahoma in which its
executive offices are located. The Company occupies approximately 2,862 square
feet of space in this building with the remaining 5,724 square feet available
for rental to third parties. At present, approximately 1,430 square feet are
unoccupied. The building is subject to a mortgage in the current principal
amount of $204,288 payable in monthly installments of $2,261 until March 2001 at
which time the balance of approximately $175,000 will be due. The Company
believes this facility is adequate for its present requirements. Except for
this office building, the Company owns no material properties other than its oil
and gas properties.
ITEM 7. FINANCIAL STATEMENTS AND SUPPLEMENTAL DATA
The financial statements required to be filed in this Report begin at Page
F-1 of this Report.
ITEM 8. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
During the two fiscal years ended December 31, 1997, the Company has not
filed any Current Report on Form 8-K reporting any change in which there was a
reported disagreement on any matter of accounting principles or practices,
financial statement disclosure or auditing scope or procedure.
25
<PAGE>
PART III
ITEM 9. DIRECTORS, EXECUTIVE OFFICERS, PROMOTERS AND CONTROL PERSONS
The following table sets forth the executive officers and directors of the
Company.
<TABLE>
<CAPTION>
NAME AGE POSITION
---- --- --------
<S> <C> <C>
Sid L. Anderson 50 Chairman of the Board, President and Chief
Executive Officer
Clayton E. Woodrum 57 Executive Vice President, Secretary and
Director
Buddie E. Livingston, II 43 Vice President - Operations
Vincent R. Kemendo 43 Vice President and Chief Financial Officer
C. Dennis McKittrick 47 Director
B. E. (Bud) Livingston 70 Director
Anthony I. Ciciola 50 Director
</TABLE>
The Company's Directors will serve until the next annual meeting of
shareholders and until their successors are elected and qualified. Officers are
elected at the annual meeting of the Board of Directors following the annual
meeting of shareholders and serve at the discretion of the Board. Directors of
the Company do not receive any compensation for serving in their capacity as
directors, but are reimbursed for out-of-pocket expenses incurred in attending
meetings.
Sid L. Anderson. Mr. Anderson has served as Chairman of the Board of
Directors and President of the Company since its organization in 1981. From 1977
to 1981, Mr. Anderson was engaged in the private practice of law, specializing
in taxation. From 1972 to 1977 Mr. Anderson was employed as a tax manager with
Peat, Marwick, Mitchell & Co. in Tulsa, Oklahoma. Mr. Anderson received his
Bachelor of Business Administration in Accounting and his Juris Doctor degrees
from the University of Oklahoma in 1969 and 1972, respectively. Mr. And erson
was admitted to the Oklahoma Bar Association in 1972 and became a Certified
Public Accountant in Oklahoma in 1974. Mr. Anderson is currently a member of the
Natural Gas Committee and is a former Director of the Oklahoma Independent
Petroleum Association. He is also a member of the Executive Advisory Board for
the College of Business Administration at the University of Tulsa and a Regent
of Rogers University. Mr. Anderson is a Trustee and former Chairman of the Tulsa
Industrial Authority.
Clayton E. Woodrum. Mr. Woodrum has been a principal in the financial
consulting firm of Woodrum, Wilson, Kemendo & Cuite, P.C. and its predecessors,
located in Tulsa, Oklahoma
26
<PAGE>
since 1986. Mr. Woodrum received his Bachelor of Science degree in Accounting in
1963 from Kansas State University and became a Certified Public Accountant in
Oklahoma in 1965.
Buddie E. Livingston, II. Mr. Livingston joined the Company on September 1,
1995. From 1981 through August, 1995 Mr. Livingston was production
superintendent for KATO Operating Company located in Bristow, Oklahoma. From
1975 to 1981 Mr. Livingston was employed by Sun Oil Company, USA as a senior
engineer and production specialist and worked in sun's domestic and
international operations. Mr. Livingston attended the University of South
Louisiana. Mr. Livingston is the son of Mr. B. E. (Bud) Livingston, a Director
of the Company.
Vincent R. Kemendo. Mr. Kemendo joined the Company on December 26, 1995.
Prior to that, since 1991, Mr. Kemendo was a consultant with the consulting firm
of Woodrum, Shoulders, Kemendo & Evanson in Tulsa, Oklahoma. From 1988 to 1991,
Mr. Kemendo was employed as Controller for Mathews Auto Electric, Inc., an auto
parts warehousing operation. From 1983 to 1988, Mr. Kemendo was Vice President-
Budgeting and Administration for Fitzgerald, DeArman & Roberts, Inc., a regional
brokerage firm with corporate headquarters in Tulsa, Oklahoma. Prior to that
time Mr. Kemendo was employed by Cotton Petroleum Corporation as Coordinator of
Financial Analysis. Mr. Kemendo received his Bachelor of Science in Business
Administration degree from Drake University in 1977 and received his Masters of
Business Administration from Oklahoma State University in 1978.
C. Dennis McKittrick. Mr. McKittrick was elected a Director of the Company
in July 1993. Mr. McKittrick is Executive Vice President of Southern Financial
Group, Inc., an investment banking firm headquartered in Columbia, South
Carolina. From 1988 to 1992, Mr. McKittrick was Executive Vice President of
McCarley and Associates, an investment banking firm headquartered in Greenville,
South Carolina. Prior to 1988, Mr. McKittrick was First Vice President and
Partner of Johnson, Lane, Space, Smith and Co., Inc., an investment banking firm
headquartered in Savannah, Georgia.
B. E. (Bud) Livingston. Mr. Livingston was elected a Director of the
Company in June 1996. Since 1979, Mr. Livingston has been President of his own
oil and gas production companies, KATO Operating Company and Livingston Oil
Company, and has performed independent consulting services for other oil and gas
companies. From 1948 through 1978, Mr. Livingston was employed by Sunray Oil
Corporation in a number of positions the most recent of which was Manager of
Operations - Mid-Continent Region. Mr. Livingston is the father of Buddie E.
Livingston, II, the Vice President - Operations for the Company.
Anthony I. Ciciola. Mr. Ciciola is the Chairman and Chief Executive
Officer of American Glove Corporation located in Amsterdam, New York. Since
1992, Mr. Ciciola has been a principal of Hospimed Distribution, Inc., an
enterprise that manufactures and distributes disposable hospital, medical and
non-medical products. Since 1987, he has been President of Taulen Consultant,
Inc., a company specializing in the design and setup of manufacturing
facilities. From 1975 to 1993, Mr. Ciciola was President of Action Pipe
Fabrication, Inc., a major fire protection and automatic sprinkler fabrication
and contractor in the Province of Quebec, Canada. Mr. Ciciola graduated from
Ahuntsic College in 1968 with a degree in collegial studies
27
<PAGE>
in fluid dynamics, piping and gears. Mr. Ciciola is a Canadian citizen and
resides in Montreal, Canada.
DIRECTOR AND OFFICER SECURITIES REPORTS
The Federal securities laws require the Company's Directors and executive
officers, and persons who own mo re than 10% of a registered class of the
Company's equity securities to file with the Securities and Exchange Commission
initial reports of ownership and reports of changes in ownership of any equity
securities of the Company. Copies of such reports are required to be furnished
to the Company. To the Company's knowledge, based solely on review of the copies
of such reports furnished to the Company, the only persons subject to these
reporting requirements who failed to file the required reports on a timely basis
with respect to the Company's most recent fiscal year are as follows: each of
Messrs. McKittrick and Ciciola did not file one Form 3 relating to their initial
filing requirements and Pangloss International, S.A. did not file Form 3
relating to its initial filing requirements as a 10 % or greater stockholder.
ITEM 10. EXECUTIVE COMPENSATION
The table below sets forth, in summary form, (1) the compensation paid, for
the years shown, to Sid L. Anderson, the Company's President, and the two other
highest-paid executive officers of the Company serving as executive officers on
December 31, 1996 (the "Named Officers"); (2) the stock options and stock
appreciation rights granted to the Named Officers for the years shown; and (3)
long-term payouts and other compensation to the Named Officers for the years
shown.
<TABLE>
<CAPTION>
SUMMARY COMPENSATION TABLE
LONG TERM COMPENSATION
----------------------
ANNUAL COMPENSATION AWARDS PAYOUTS
------------------- ------ -------
RESTRICTED SECURITIES
OTHER ANNUAL STOCK UNDERLYING LTIP ALL OTHER
NAME AND PRINCIPAL SALARY BONUS COMPENSATION AWARDS OPTIONS/ PAYOUTS COMP
POSITION YEAR ($) ($) ($)(1) ($) SARS (#) ($) ($)
- -------------------------- ---- ------- ----- ------------ ------ ---------- ------- ---------
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Sid L. Anderson, 1997 150,000 6,250 85,130/(2)/ --- --- --- ---
Chairman 1996 150,000 6,250 94,347/(3)/ --- --- --- ---
and President
Buddie E. Livingston, II 1997 48,000 2,000 --- --- --- --- 353
Vice President of 1996 48,000 2,000 --- --- --- --- 216
Operations
Vincent R. Kemendo 1997 40,000 1,667 --- --- --- --- ---
Vice President of 1996 40,000 1,667 --- --- --- --- ---
Finance
</TABLE>
28
<PAGE>
(1) Except as noted, none of the executive officers listed received perquisites
or other personal benefits that exceeded the lesser of $50,000 or 10
percent of the salary and bonus for such officers.
(2) Includes a $63,754 guaranty fee paid to Mr. Anderson (see "Employment
Agreements") and a total of $21,376 paid by the Company to or on behalf of
Mr. Anderson for country club dues, automobile allowance and life insurance
premiums.
(3) Includes a $75,370 guaranty fee paid to Mr. Anderson (see "Employment
Agreements") and a total of $18,977 paid by the Company to or on behalf of
Mr. Anderson for country club dues, automobile allowance and lease expense
and life insurance premiums.
BONUS PLAN
The Company has an incentive compensation bonus plan in effect for certain
salaried employees other than its President. The annual bonus pool is equal to
10% of annual net income of the Company in excess of $100,000. The plan is
currently administered and allocated among the eligible employees by the
Company's Board of Directors. No distributions have been made from this plan
since its inception.
STOCK OPTIONS
Director Stock Option Plan. The Company has adopted a Directors' Stock
Option Plan pursuant to which non-employee Directors of the Company may be
granted options to purchase shares of Common Stock of the Company. The total
number of shares which may be issued pursuant to this plan is 150,000 shares of
Common Stock. The plan provides that the exercise price of options granted
pursuant to the plan shall not be less than the fair market value of the shares
of Common Stock on the date of grant and that options granted are exercisable
for the lesser of ten years and thirty days from the date of grant or 30 days
following termination as a member of the Company's Board of Directors. The plan
is administered by the Board of Directors. Through December 31, 1997, options to
purchase 65,000 shares of the Company's Common Stock at an exercise price
ranging from $1.30 to $1.40 per share had been granted under this plan.
Employee Stock Option Plan. The Company has adopted an Employee Stock
Option Plan pursuant to which employees and any other persons who perform
substantial services for or on behalf of the Company may be granted options to
purchase shares of Common Stock of the Company. Directors who are also employees
are eligible to receive options under this plan. The total number of shares
which may be issued pursuant to this plan is 100,000 shares of Common Stock. The
plan provides that the exercise price of options granted pursuant to the plan
shall not be less than the fair market value of the shares of Common Stock on
the date of grant and that options granted are exercisable for the lesser of ten
years and thirty days from the date of grant or 30 days following termination of
employment with the Company. The plan is administered by the Board of Directors.
Through December 31, 1997, no options had been granted under this plan.
29
<PAGE>
During the year ended December 31, 1997, the Company issued 50,000 stock
options exercisable at $1.40 per share to Directors of the Company. These stock
options were issued pursuant to the Director Stock Option Plan. In addition,
during the year ended December 31, 1997, the Company issued 570,000 stock
options exercisable at $1.40 per share to employees of the Company. These
options were not issued under either of the Company's stock option plans. Other
than these option grants, there were no restricted stock awards granted, no
options or stock appreciation rights were exercised, and no awards under any
long-term incentive plan were made to any officer or employee of the Company
during the year ended December 31, 1997.
During 1996, no restricted stock awards were granted, no stock options or
stock appreciation rights were granted, no options or stock appreciation rights
were exercised, and no awards under any long-term incentive plan were made to
any officer or employee of the Company.
The following table sets forth information relating to the exercises of
stock options by each of the Company's officers and directors during the year
ended December 31, 1997 and the value of unexercised stock options as of
December 31, 1997.
AGGREGATED OPTION EXERCISES IN THE FISCAL
YEAR ENDED DECEMBER 31, 1997 AND
DECEMBER 31, 1997 OPTION VALUES
<TABLE>
<CAPTION>
OPTION EXERCISES
DURING YEAR
ENDED DECEMBER 31, 1997
----------------------- NUMBER OF SECURITIES
NUMBER OF UNDERLYING UNEXERCISED VALUE OF UNEXERCISED
SHARES OPTIONS AT IN-THE-MONEY OPTIONS
ACQUIRED VALUE DECEMBER 31, 1997 AT DECEMBER 31, 1997
--------------------------- --------------------------
NAME ON EXERCISE REALIZED UNEXERCISABLE EXERCISABLE UNEXERCISABLE EXERCISABLE
- ------------------------- ----------- -------- ------------- ------------ ------------- -----------
<S> <C> <C> <C> <C> <C> <C>
Sid L. Anderson None None 198,000 139,500/(1)/ $118,800 $84,450
Clayton E. Woodrum None None 48,000 49,500/(2)/ 28,800 30,450
Buddie E. Livingston II None None 48,000 32,000/(3)/ 28,800 19,200
Vincent R. Kemendo None None 48,000 32,000/(4)/ 28,800 19,200
C. Dennis McKittrick None None --- 17,500/(5)/ --- 11,250
B. E. (Bud) Livingston None None --- 15,000/(6)/ --- 9,000
Anthony I. Ciciola None None --- 15,000/(7)/ --- 9,000
</TABLE>
(1) Reflects 7,500 options granted in July 1993 not under either of the
Company's option plans, exercisable at $1.30 per share and 330,000 options
granted in January, 1997 not under either of the Company's option plans,
exercisable at $1.40 per share.
(2) Reflects 7,500 options granted in July 1993 under the Company's Directors'
Stock Option Plan, exercisable at $1.30 per share, 10,000 options granted
in January 1997 under the Company's Directors' Stock Option Plan,
exercisable at $1.40 per share, and 80,000
30
<PAGE>
options granted in January, 1997 not under either of the Company's option
plans, exercisable at $1.40 per share.
(3) Reflects 80,000 options granted in January, 1997 not under either of the
Company's option plans, exercisable at $1.40 per share.
(4) Reflects 80,000 options granted in January, 1997 not under either of the
Company's option plans, exercisable at $1.40 per share.
(5) Reflects 7,500 options granted in July 1993 under the Company's Directors'
Stock Option Plan, exercisable at $1.30 per share and 10,000 options
granted in January, 1997 under the Company's Directors' Stock Option Plan,
exercisable at $1.40 per share
(6) Reflects 15,000 options granted in January, 1997 under the Company's
Directors' Stock Option Plan, exercisable at $1.40 per share
(7) Reflects 15,000 options granted in January, 1997 under the Company's
Directors' Stock Option Plan, exercisable at $1.40 per share
EMPLOYMENT AGREEMENTS
The Company has entered into an employment agreement with Sid L. Anderson,
President of the Company. The term of Mr. Anderson's Employment Agreement
continues until the later of October 31, 2000 or so long as Mr. Anderson is a
personal guarantor of any of the Company's debt. Under this Agreement, Mr.
Anderson receives a base salary of $150,000 per year, plus additional annual
incentive compensation in an amount equal to 10% of the Company's annual audited
pre-tax net income in excess of $150,000. In addition, Mr. Anderson is entitled
to participate in all benefit programs the Company makes available to employees.
The Agreement also provides for the payment to Mr. Anderson of an automobile
allowance of $1,000 per month, and such other benefits as may be determined from
time to time by the Board of Directors of the Company. In addition, under the
terms of a separate Guaranty Fee Agreement between Mr. Anderson and the Company,
Mr. Anderson is entitled to a semi-annual payment of an amount equal to the
greater of $15,000 or 3% of the aggregate amount of Company indebtedness
guaranteed personally by him. To secure payment of this fee, the Company has
granted Mr. Anderson a security interest in the Company's equipment, inventory,
fixtures, receivables and other assets. Mr. Anderson's Employment Agreement
provides that the Company has the right to terminate the Agreement at any time
upon written notice and, unless the Agreement has been terminated for cause, as
defined, the Company is obligated to pay Mr. Anderson the compensation payable
for the remainder of the term of the Agreement, including any incentive
compensation, vacation pay or accrued employee benefits. Mr. Anderson has the
right to terminate his employment with the Company upon 30 days written notice
in which event, the Company is only obligated to compensate him under the terms
of the Agreement up to the date of termination. The Agreement also contains
provisions restricting Mr. Anderson from engaging in business activities in
competition with the Com pany.
31
<PAGE>
The Company has also entered into employment agreements with Buddie E.
Livingston, II, and Vincent R. Kemendo pursuant to which they are employed by
the Company as Vice President - Operations and Vice President - Finance,
respectively. The agreements with Messrs. Livingston and Kemendo expire on
December 31, 2000, unless extended by the Company's Board of Directors. Under
these agreements, Messrs. Livingston and Kemendo receive base salaries of
$48,000 and $40,000 per year, respectively. In addition, Messrs. Livingston and
Kemendo are entitled to participate in all benefit programs the Company makes
available to employees. Under their agreements, Messrs. Livingston and Kemendo
are eligible to participate in the Company's incentive compensation bonus plan.
See "Bonus Plan". The Company has the right to terminate each of these
employment agreements upon written notice and, unless the agreement has been
terminated for cause, as defined, the Company is obligated to pay the terminated
individual the compensation payable for the remainder of the term of his
agreement, including any incentive compensation, vacation pay or accrued
employee benefits. Messrs. Livingston and Kemendo each have the right to
terminate their employment agreements with the Company upon 30 days written
notice to the Company in which event the Company is only obligated to compensate
the individual up to the date of termination. Each of the Employment Agreements
also contain certain provisions restricting Messrs. Livingston and Kemendo from
engaging in business activities in competition with the Company.
ITEM 11. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
On February 18, 1997, the Company declared a four-for-one stock split in
the form of a stock dividend payable to the Company's shareholders of record on
April 1, 1997. All references to outstanding shares, share ownership and per
share amounts in this Registration Statement are presented giving effect to such
stock dividend.
As of December 31, 1997, the Company had 3,367,405 issued and outstanding
shares of Common Stock, the Company's only class of equity securities issued and
outstanding. The following table sets forth, as of December 31, 1997, the number
and percentage of shares of Common Stock of the Company owned beneficially by
(i) each director of the Company, (ii) each Named Officer of the Company named
in the Summary Compensation Table, (iii) all directors and executive officers of
the Company as a group, and (iv) each person known to the Company to own of
record or beneficially more than five percent of the Company's Common Stock.
Except as otherwise indicated, the persons named in the table have sole voting
and investment power with respect to the shares indicated. As of December 31,
1997, the Company had 302 holders of Common Stock of record.
32
<PAGE>
<TABLE>
<CAPTION>
NUMBER OF SHARES
NAME OF BENEFICIAL OWNER BENEFICIALLY OWNED PERCENT OF CLASS(1)
- ------------------------------------------- ------------------ -------------------
<S> <C> <C>
Sid L. Anderson(2)(6) 1,327,000 37.8%
Clayton E. Woodrum(3) 67,350 2.0%
Buddie E. Livingston, II(2)(6) 32,000 1.0%
Vincent R. Kemendo(2)(6) 94,500 2.8%
C. Dennis McKittrick(4) 29,705 *
B. E. (Bud) Livingston(2)(7) 15,000 *
Anthony I. Ciciola(2)(8) 15,000 *
Pangloss International, S.A. (5) 481,250 13.4%
All Executive Officers and 1,580,555 43.1%
Directors as a group (7 persons)(2)(3)(4)
</TABLE>
* less than one percent
(1) Based upon 3,367,405 issued and outstanding shares of Common Stock at
December 31, 1997. Shares of Common Stock which an individual or group has
the right to acquire within 60 days pursuant to the exercise of options,
warrants, or other convertible securities are deemed to be outstanding for
the purpose of computing the percentage ownership of such individual or
group, but are not deemed to be outstanding for the purpose of computing
the percentage ownership of any other individual or group shown in the
table.
(2) Includes (a) with respect to Mr. Anderson, 139,500 shares issuable to him
upon exercise of presently exercisable options; (b) with respect to Mr.
Livingston, II 32,000 shares issuable to him upon exercise of presently
exercisable options; (c) with respect to Mr. Kemendo, 32,000 shares
issuable to him upon exercise of presently exercisable options; (d) with
respect to Mr. Livingston, 15,000 shares issuable to him upon exercise of
presently exercisable options; and (e) with respect to Mr. Ciciola, 15,000
shares issuable to him upon exercise of presently exercisable options.
(3) Includes 17,850 shares held by Mr. Woodrum's spouse and 49,500 shares
issuable to Mr. Woodrum upon exercise of presently exercisable options. The
address of Mr. Woodrum is Suite 605, 9 East 4th Street, Tulsa, Oklahoma
74103.
33
<PAGE>
(4) Includes 12,205 shares held by Southern Financial Group, Inc., a company of
which Mr. McKittrick is President and Chief Executive Officer, and 17,500
shares issuable to Mr. McKittrick upon exercise of presently exercisable
options. The address of Mr. McKittrick is Suite 201, 140 North Main,
Summerville, South Carolina 29483.
(5) Includes 225,000 shares issuable to Pangloss International, S.A. upon
exercise of presently exercisable Common Stock purchase warrants. The
address of Pangloss International, S.A. is New Moon House, Eastern Road,
Nassau, Bahamas. Pangloss International, S.A. is a Bahamian corporation,
all of the outstanding shares of which are owned by Robert A. Nihon who, by
reason of such ownership, may be deemed the beneficial owner of the
Company's securities held of record by Pangloss International, S.A. Mr.
Nihon's address is the same as the address of Pangloss International.
(6) The address of Messrs. Anderson, Kemendo and Livingston, II is Suite 300,
1850 South Boulder, Tulsa, Oklahoma 74119.
(7) The address of Mr. Livingston is Highway 66 North, Turnpike Gate, Bristow,
Oklahoma 74010.
(8) The address of Mr. Ciciola is 8277 Jean Nicolet, Montreal, QC H1R 2R2.
There are no arrangements known to management which may result in a change
in control of the Company.
ITEM 12. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS.
Through August 1995, the Company sold gas produced from certain wells it
operates to a gas marketing company owned by Sid L. Anderson, Chairman of the
Board, President and Chief Executive Officer of the Company. Such sales for the
year ended December 31,1995 were approximately $89,000. The gas marketing
company collected a 3% commission on the resale of such gas, which was utilized
to pay income and other taxes of the gas marketing company. Effective September
1, 1995, the Company began to sell gas produced from the well s to an
unaffiliated purchaser.
In 1995, the Company began paying a fee to Sid L. Anderson, Chairman of the
Board, President and Chief Executive Officer of the Company, pursuant to the
terms of a Guaranty Fee Agreement. Under the terms of this Agreement, Mr.
Anderson receives an annual fee for guaranteeing Company debt equal to the
greater of $15,000 or 3% of the guaranteed debt. During 1997 and 1996, fees paid
to Mr. Anderson under this Agreement were approximately $64,000 and $76,000,
respectively.
The Company incurs fees for tax and accounting services provided by a firm
in which Clayton E. Woodrum, Executive Vice President and a Director of the
Company, is a partner. Amounts paid by the Company to this firm during 1997 and
1996 were $11,359 and $39,943,
34
<PAGE>
respectively. In addition, during 1996, the Company issued a total of 35,700
shares of Common Stock to this firm in payment for services rendered. The value
assigned to this stock, $49,980, was based on billings received from the firm.
At the request of the firm, 17,850 of these shares were issued to Pat Woodrum,
spouse of Clayton E. Woodrum, and 17,850 of these shares were issued to Andrea
Kemendo, spouse of a partner in the firm. The Company also incurs fees for
business advisory services to a firm affiliated with this board member. Such
amounts incurred in 1997 were $37,424.
During October, 1995 the Company purchased two producing oil and gas
properties from KATO Operating Company ("KATO"), Livingston Oil and other third
parties for a purchase price of $975,000. Subsequent to this transaction, Mr. B.
E. Livingston, who is the President and owner of both KATO and Livingston Oil,
was elected as a Director of the Company. The producing properties purchased
consisted of a field containing 10 producing wells and several shut-in wells and
a group of five producing leases which contain a total of nine producing wells.
Additionally, in January, 1996 the Company purchased a producing oil and gas
property from several individuals and entities, including an affiliate of KATO,
for $152,000. KATO was the operator of the property purchased and the interest
acquired from the KATO affiliate amounted to a 2.03% working interest in the
property. These transactions were reviewed by the Board of Directors and were
determined, based on negotiations that occurred at the time, to be on terms no
less favorable to the Company than could have been obtained at the time and
under the same circumstances from non-affiliated persons.
Pursuant to an agreement signed in February 1996, B. E. (Bud) Livingston, a
member of the Company's Board of Directors, will provide evaluation and
reservoir engineering services to the Company with respect to oil and gas wells
in Coal County, Oklahoma and Borden and Stonewall Counties, Texas in exchange
for an amount equal to the net of a percentage of the net revenue interest and a
percentage of the lease operating expenses attributable to certain producing oil
and gas wells located in Garfield and Noble Counties, Oklahoma. During 1997 and
1996, no amounts were paid by the Company to Mr. Livingston pursuant to this
Agreement. However, a company affiliated with this director provides well
operation services to the Company. Such amounts incurred in 1997 and 1996 were
$9,237 and $22,087, respectively
Any future transactions between the Company and its directors, officers,
principal shareholders or their affiliates will be on terms no less favorable to
the Company than may be obtained in similar, arms length transactions with
unaffiliated third parties.
35
<PAGE>
SIGNATURES
In accordance with Section 12 of the Securities Exchange Act of 1934, the
Company has caused this Registration Statement to be signed by the undersigned,
thereunto duly authorized.
PAN WESTERN ENERGY CORPORATION
(Registrant)
Date: April 13, 1998
In accordance with the Exchange Act, this report has been signed below by the
following persons on behalf of the registrant and in the capacities and on the
dates indicated.
By: /s/ Sid L. Anderson
------------------------------------------- Date: April 13, 1998
Chairman of the Board, President, and
Chief Executive Officer
By: /s/ Clayton E. Woodrum
------------------------------------------- Date: April 13, 1998
Executive Vice President and Director
(Principal Financial Officer)
By: /s/ Vincent R. Kemendo
------------------------------------------- Date: April 13, 1998
Vice President - Finance and Chief
Financial Officer (Principal Accounting
Officer)
By: /s/ Bud E. Livingston
------------------------------------------- Date: April 13, 1998
Director
By: /s/ C. Dennis McKittrick
------------------------------------------- Date: April 13, 1998
Director
By: /s/ Anthony I. Ciciola
------------------------------------------- Date: April 13. 1998
Director
36
<PAGE>
INDEPENDENT AUDITORS' REPORT
To the Board of Directors
Pan Western Energy Corporation:
We have audited the accompanying consolidated balance sheets of Pan Western
Energy Corporation and subsidiaries as of December 31, 1997 and 1996 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, such financial statements present fairly, in all material
respects, the consolidated financial position of Pan Western Energy Corporation
and subsidiaries at December 31, 1997 and 1996 and the consolidated results of
their operations and their cash flows for the years then ended in conformity
with generally accepted accounting principles.
DELOITTE & TOUCHE LLP
April 8, 1998
Tulsa, Oklahoma
<PAGE>
PAN WESTERN ENERGY CORPORATION
CONSOLIDATED BALANCE SHEETS
DECEMBER 31, 1997 AND 1996
- --------------------------------------------------------------------------------
<TABLE>
<CAPTION>
1997 1996
<S> <C> <C>
ASSETS
CURRENT ASSETS:
Cash $ 14,686 $ 232,699
Restricted cash 344,147 103,995
Receivables:
Trade, net of allowance of $11,080 178,313 283,095
Due from stockholder 4,252 1,594
Due from affiliated partnerships 1,187 1,187
Income tax receivable - 14,950
Prepaid expenses 20,350 -
----------- ----------
Total current assets 562,935 637,520
----------- ----------
Property and equipment:
Oil and gas properties (successful efforts method) 2,955,683 3,474,363
Other property and equipment 378,419 374,932
----------- ----------
3,334,102 3,849,295
Less accumulated depreciation and depletion 974,668 918,439
----------- ----------
Net property and equipment 2,359,434 2,930,856
----------- ----------
Other assets, net of accumulated amortization 64,912 57,836
----------- ----------
$ 2,987,281 $3,626,212
=========== ==========
LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES:
Accounts payable $ 247,815 $ 472,412
Undistributed oil and gas revenues 153,990 149,276
Due to affiliated partnership 7,540 7,540
Accrued liabilities 15,688 31,520
Current portion of long-term debt 769,564 1,338,665
----------- ----------
Total current liabilities 1,194,597 1,999,413
Long-term debt 1,669,628 1,072,469
----------- ----------
Total liabilities 2,864,225 3,071,882
----------- ----------
COMMITMENTS AND CONTINGENCIES
STOCKHOLDERS' EQUITY:
Preferred stock ($.05 par value; authorized 25,000,000 shares; no shares issued or outstanding) - -
Common stock ($.01 par value; authorized 25,000,000 shares; issued 1997 - 4,448,655 shares;
1996 - 4,314,810 shares) 44,487 43,148
Additional paid-in capital 1,837,253 1,610,701
Accumulated deficit (1,539,702) (880,537)
Treasury stock (1,081,250 shares) (218,982) (218,982)
----------- ----------
Total stockholders' equity 123,056 554,330
----------- ----------
$ 2,987,281 $3,626,212
=========== ==========
</TABLE>
See notes to consolidated financial statements.
-2-
<PAGE>
PAN WESTERN ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS
YEARS ENDED DECEMBER 31, 1997 AND 1996
- --------------------------------------------------------------------------------
<TABLE>
<CAPTION>
1997 1996
<S> <C> <C>
REVENUE:
Oil and gas sales $1,361,212 $1,675,193
Operating income 82,333 122,524
---------- ----------
1,443,545 1,797,717
---------- ----------
OPERATING EXPENSES:
Lease operating 596,247 725,432
Salaries and wages 373,768 375,482
Depreciation, depletion and amortization 264,266 318,556
General and administrative 482,398 378,535
---------- ----------
1,716,679 1,798,005
---------- ----------
OPERATING LOSS (273,134) (288)
---------- ----------
OTHER INCOME (EXPENSE):
Loss from rental operations, net (12,868) (22,781)
Loss on sale of assets, net (168,628) (7,326)
Interest income 6,084 4,493
Interest expense (211,390) (233,411)
Miscellaneous income 771 -
Equity in income of affiliated partnerships - 6,202
Minority interest in loss of consolidated partnerships - 667
---------- ----------
(386,031) (252,156)
---------- ----------
NET LOSS $ (659,165) $ (252,444)
========== ==========
NET LOSS PER SHARE - BASIC AND DILUTED $(0.20) $(0.08)
========== ==========
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING -
BASIC AND DILUTED 3,312,500 3,141,035
========== ==========
</TABLE>
See notes to consolidated financial statements.
-3-
<PAGE>
PAN WESTERN ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
YEARS ENDED DECEMBER 31, 1997 AND 1996
- --------------------------------------------------------------------------------
<TABLE>
<CAPTION>
ADDITIOAL TOTAL
COMMON PAID-IN ACCUMULATED TREASURY STOCKHOLDERS'
STOCK CAPITAL DEFICIT STOCK EQUITY
<S> <C> <C> <C> <C> <C>
BALANCES, JANUARY 1,
1996, AS ORIGINALLY
REPORTED $ 20,187 $ 1,380,856 $ (628,093) $ (218,982) $ 553,968
Retroactive adjustment to
reflect additional shares
issued in four-for-one
stock split effected in the
form of a stock dividend in
February, 1997 20,000 (20,000) - - -
-------- ----------- ------------ ---------- -----------
BALANCES, JANUARY 1,
1996, AS ADJUSTED 40,187 1,360,856 (628,093) (218,982) 553,968
Issuance of stock 2,961 249,845 - - 252,806
Net loss - - (252,444) - (252,444)
-------- ----------- ------------ ---------- ------------
BALANCES,
DECEMBER 31, 1996 43,148 1,610,701 (880,537) (218,982) 554,330
Issuance of stock 1,339 226,552 - - 227,891
Net loss - - (659,165) - (659,165)
-------- ----------- ------------ ---------- ------------
BALANCES,
DECEMBER 31, 1997 $ 44,487 $ 1,837,253 $ (1,539,702) $ (218,982) $ 123,056
======== =========== ============ ========== ============
</TABLE>
See notes to consolidated financial statements.
-4-
<PAGE>
PAN WESTERN ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
YEARS ENDED DECEMBER 31, 1997 AND 1996
- --------------------------------------------------------------------------------
<TABLE>
<CAPTION>
1997 1996
<S> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss $ (659,165) $ (252,444)
Adjustments to reconcile net loss to net cash provided by
(used in) operating activities:
Depreciation, depletion and amortization 264,266 318,556
Loss on sale of assets, net 168,628 7,326
Equity in income of affiliated partnerships - (6,202)
Minority interest in earnings of consolidated partnerships - (667)
Bad debt expense 1,885 1,649
Stock issued for services 66,000 49,980
(Increase) decrease in receivables 115,189 (33,175)
Increase in prepaid expenses (20,350) -
Increase in other assets (14,850) (3,850)
Increase (decrease) in accounts payable (224,597) 221,118
Increase (decrease) in accrued liabilities (15,832) 7,982
Increase (decrease) in undistributed oil and gas revenues 4,714 (16,660)
----------- ----------
Net cash provided by (used in) operating activities (314,112) 293,613
----------- ----------
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures (10,163) (549,086)
Purchase of certificate of deposit - (103,995)
Purchase of technology license - (40,000)
Proceeds from the disposal of oil and gas properties 156,465 8,219
----------- ----------
Net cash provided by (used in) investing activities 146,302 (684,862)
----------- ----------
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term debt 1,989,391 1,263,893
Repayments of long-term debt (1,961,333) (937,924)
Increase in restricted cash (240,152) -
Proceeds from sale of common stock 161,891 282,296
----------- ----------
Net cash provided by (used in) financing activities (50,203) 608,265
----------- ----------
NET INCREASE (DECREASE) IN CASH (218,013) 217,016
CASH, BEGINNING OF YEAR 232,699 15,683
----------- ----------
CASH, END OF YEAR $ 14,686 $ 232,699
=========== ==========
SUPPLEMENTAL CASH FLOW INFORMATION:
Interest paid $ 217,590 $ 231,225
=========== ==========
Income taxes paid $ - $ -
=========== ==========
</TABLE>
See notes to consolidated financial statements.
-5-
<PAGE>
PAN WESTERN ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
YEARS ENDED DECEMBER 31, 1997 AND 1996
- --------------------------------------------------------------------------------
1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
ORGANIZATION - Pan Western Energy Corporation (the "Company") was organized
effective September 2, 1981 under the laws of the State of Oklahoma. The
primary purpose of the Company is the acquisition, drilling, development,
production and operation of oil and gas properties.
BUSINESS DEVELOPMENTS - During the years ended December 31, 1997 and 1996,
the Company incurred net losses of $659,165 and $252,444, respectively, and
in 1997 had an operating cash flow deficiency of $314,112. At December 31,
1997 and 1996, the Company had working capital deficits of $631,662 and
$1,361,893, respectively, and total stockholders' equity of $123,056 and
$554,330, respectively. As described in Note 5, on January 2, 1998, the
Company refinanced certain of its outstanding debt which will reduce annual
debt service requirements and extend certain debt maturities to five years.
Although operating results have negatively impacted the Company's liquidity
and capital resources, the Company anticipates that cash flows will be
sufficient to fund its operating and debt service requirements at their
current levels for the next year. The Company's business strategy is to
continue to concentrate on expending its asset base and cash flows through
acquisition and exploitation of oil and gas reserves, to the extent that it
has the capital resources to do so. The Company considers sources of such
financing to include bank lines of credit, public and private sales of debt
or equity securities, joint oil and gas development arrangements, and
internally-generated cash flows. However, no assurance can be given that
sufficient external or internal funds will be available to fund the Company's
desired acquisitions. Should the Company's internally-generated cash flows
be insufficient to meet its debt service or other obligations, the Company
will sell non-strategic oil and gas properties to meet such obligations.
In addition to its basic oil and gas producing activities, during 1996, the
Company acquired a license from Amoco Corporation to utilize their patented
short radius curve drilling technology. The patent was originally issued in
1993. The Company paid $40,000 for the license and will pay a scheduled
royalty for its use in the future. The Company plans to use the technology
to develop reserves currently owned by the Company. In addition, in the
future the Company intends to provide the technology to other operators
through a wholly owned subsidiary, Lateral Completion Technologies, Inc.
("LCT"), and develop reserves for other operators in return for working and
net revenue interests in those reserves. The Company is currently pursuing
financing alternatives to provide the funds needed to fund the capital
expenditures and initial operating costs of LCT. These alternatives include
a private placement of debt or equity or a combination thereof.
ESTIMATES - The preparation of financial statements in conformity with
generally accepted accounting principles requires management to make
estimates and assumptions that affect the reported amounts of assets and
liabilities and disclosure of contingent assets and liabilities at the date
of the financial statements and the reported amounts of revenues and expenses
during the reporting period. Actual results could differ materially from
those estimates.
-6-
<PAGE>
PRINCIPLES OF CONSOLIDATION - The consolidated financial statements include
the accounts of Company owned partnerships, Pan Western 1993-A Production
Program, Ltd. and Pan Western 1993-C Production Program, Ltd. The Company
acquired the majority interest in these partnerships effective April 1, 1995
and the remaining partnership interests were acquired effective June 1, 1996.
In 1996, the Company formed Lateral Completion Technologies, Inc. ("LCT"), a
wholly owned subsidiary. LCT did not have any activities in 1997 and 1996.
All material intercompany transactions and balances are eliminated in
consolidation.
INVESTMENTS IN AFFILIATED PARTNERSHIPS - Investments in affiliated oil and
gas partnerships in which the Company owns less than a majority interest are
accounted for using the equity method, with amounts stated at original cost,
adjusted for the Company's share of undistributed earnings or losses. The
equity method was suspended in 1989 as the Company's share of losses exceeded
the carrying value of its investments at that time.
OIL AND GAS PROPERTIES - The Company follows the successful efforts method of
accounting for oil and gas producing 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.
Capitalized costs of producing oil and gas properties are depreciated and
depleted by the unit-of-production method on a property-by-property basis.
Support equipment is depreciated over its estimated useful life.
On the sale or retirement of a complete unit of a proved property, the cost
and related accumulated depreciation, depletion, and amortization are
eliminated from the property accounts, and the resultant gain or loss is
recognized. On the retirement or sale of a partial unit of proved property,
the cost is charged to accumulated depreciation, depletion, and amortization
with a resulting gain or loss recognized in income.
OTHER PROPERTY AND EQUIPMENT - Other property and equipment is stated at cost
and is depreciated using accelerated methods over the estimated useful lives
of the respective assets which range from 5 to 27.5 years.
OTHER ASSETS - Other assets consists primarily of a license for drilling
technology and loan origination fees which are amortized over 14 and 5 years,
respectively.
OPERATING INCOME - Operating income represents income earned by the Company
as operator of oil and gas properties and as general partner for certain
limited partnerships. Operating income consists primarily of administrative
overhead fees, field supervision charges and compressor charges.
INCOME TAXES - The Company recognizes deferred tax liabilities and assets for
the tax effects of (a) temporary differences between tax bases and financial
reporting bases of assets and liabilities, and (b) operating loss and tax
credit carryforwards. The Company records a valuation allowance for the
amount of net deferred tax assets when, in management's opinion, it is more
likely than not that such assets will not be realized.
LONG-LIVED ASSET IMPAIRMENT - The Company reviews the carrying value of long-
lived assets and certain identifiable intangibles to be held and used by the
Company for impairment whenever events or
-7-
<PAGE>
changes in circumstances indicate that the carrying amount of an asset may
not be recoverable. An impairment reserve is provided if the carrying amount
cannot be recovered through future cash flows generated by the asset. Assets
to be disposed of are reported at the lower of carrying amount or fair value
less cost to sell.
STOCK-BASED COMPENSATION - In October 1995, the Financial Accounting
Standards Board issued Statement of Financial Accounting Standards No. 123
("SFAS 123"), "Accounting for Stock-Based Compensation." SFAS 123
establishes a fair value method and disclosure standards for stock-based
employee compensation arrangements, such as stock purchase plans and stock
options. It also applies to transactions in which an entity issues its
equity instruments to acquire goods or services from non-employees, requiring
that such transactions be accounted for based on fair value. As allowed by
SFAS 123, the Company will continue to follow the provisions of Accounting
Principles Board Opinion No. 25 for its stock-based employee compensation
arrangements.
FAIR VALUE OF FINANCIAL INSTRUMENTS - Statement of Financial Accounting
Standards No. 107 "Disclosures about Fair Value of Financial Instruments"
requires disclosure regarding the fair value of financial instruments for
which it is practical to estimate that value. For accounts receivable and
accounts payable, the carrying amount approximates fair value because of the
short maturity of those instruments. The fair value of the Company's long-
term debt is estimated to approximate carrying value based on the borrowing
rates currently available to the Company for bank loans with similar terms
and maturities.
EARNINGS (LOSS) PER SHARE - The Company has adopted Statement of Financial
Accounting Standards No. 128, "Earnings Per Share," in 1997 and has restated
earnings per share for all periods presented in accordance with that
Statement.
Basic earnings per common share are computed by dividing net income
applicable to common stockholders by the weighted average number of shares of
common stock outstanding during the year.
Diluted earnings per common share are computed by dividing net income
applicable to common stockholders by the weighted average number of shares of
common stock and common stock equivalents outstanding during the year. The
weighted average number of common shares is increased by the number of shares
issuable on the exercise of warrants and options less the number of common
shares assumed to have been purchased with the proceeds from the exercise of
the options and warrants pursuant to the treasury stock method; those
purchases are assumed to have been made at the average price of the common
stock during the respective period. Outstanding stock options and warrants
have not been included in the 1997 and 1996 computations since their effect
on diluted loss per share is antidilutive.
Weighted average common shares outstanding have been retroactively adjusted
for the four-for-one stock split effected in the form of a stock dividend
declared by the Company on February 18, 1997 (see Note 10).
RESTRICTED CASH - Restricted cash consists of a certificate of deposit that
serves as collateral on a line of credit with a bank and cash in an escrow
account that was used to pay off certain loans on January 2, 1998 (see Note
5).
RECLASSIFICATION - Certain 1996 amounts have been reclassified to conform
with 1997 presentations.
-8-
<PAGE>
ACCOUNTING STANDARDS TO BE ADOPTED - Statement of Financial Accounting
Standards No. 130, "Reporting Comprehensive Income," ("SFAS 130") was issued
in June 1997. This Statement establishes standards for reporting and display
of comprehensive income and its components in a full set of general-purpose
financial statements. This Statement requires that all items that are
required to be recognized under accounting standards as components of
comprehensive income be reported in a financial statement that is displayed
with the same prominence as other financial statements. SFAS 130, effective
for fiscal years beginning after December 15, 1997, requires reclassification
of financial statements for earlier periods provided for comparative
purposes. The Company currently does not expect adoption of this Statement to
have a material effect on financial statement presentation.
Statement of Financial Accounting Standards No. 131, "Disclosures about
Segments of an Enterprise and Related Information," ("SFAS 131") was issued
in June 1997. This Statement establishes standards for the way that public
business enterprises report information about operating segments in annual
financial statements and requires that those enterprises report selected
information about operating segments in interim financial reports issued to
shareholders. It also establishes standards for related disclosures about
products and services, geographic areas, and major customers. SFAS 131,
effective for fiscal years beginning after December 15, 1997, requires
comparative information for previous years to be restated to comply with SFAS
131's reporting requirements. The Company currently does not expect adoption
of this Statement to have a material effect on financial statement
presentation or related footnote disclosures.
2. PARTNERSHIP AND OIL AND GAS PROPERTY ACQUISITIONS
In 1995, the Company acquired majority interest in several entities, and in
1996, acquired the remaining interests. These acquisitions were accounted
for using the purchase method and the purchase price was allocated to assets
acquired, primarily oil and gas properties, and liabilities assumed based on
their estimated fair values. The results of operations of the interests
acquired have been included in the Company's consolidated financial
statements subsequent to the dates of acquisition and were not material to
1996 operating results.
3. INVESTMENTS IN AFFILIATED PARTNERSHIPS
The Company is general partner in Pan Western 1986 Drilling Program, Ltd.
("1986 Program") and Pan Western 1987 Production Program, Ltd. ("1987
Program"), whose purpose is the acquisition, drilling, development,
production, marketing, and operation of oil and gas leases. As general
partner, the Company is entitled to 18.57% and 15% of the current earnings or
losses for the 1986 and 1987 Programs, respectively, and is also entitled to
a "back-in" interest upon payout.
-9-
<PAGE>
Summary financial information for these partnerships as of and for the years
ended December 31, 1997 and 1996 follows:
<TABLE>
<CAPTION>
1997 1996
<S> <C> <C>
Total assets $66,111 $54,045
======= =======
Total liabilities $ 9,409 $ 7,920
Partners' capital 56,702 46,125
------- -------
Total liabilities and partners' capital $66,111 $54,045
======= =======
Revenue $19,082 $28,126
======= =======
Net income (loss) $13,373 $(2,603)
======= =======
</TABLE>
During 1989, the Company's share of losses exceeded the carrying value of its
investment in the 1986 and 1987 Programs, and the equity method of accounting
was discontinued with no additional losses recorded by the Company. However,
during 1995, the total partners' capital of the 1986 Program became a
deficit. Accordingly, as general partner, the Company recorded additional
losses under the equity method to the extent of the 1986 Programs' capital
deficit. During 1996, the total partners' capital of the 1986 Program became
positive, and the additional losses previously recorded by the Company were
reversed. The Company's share of unrecorded losses for the 1986 and 1987
Programs was approximately $29,414 and $31,255 at December 31, 1997 and 1996,
respectively.
4. PROPERTY AND EQUIPMENT
Property and equipment consists of the following:
<TABLE>
<CAPTION>
1997 1996
<S> <C> <C>
Proved oil and gas properties:
Leasehold costs $1,977,688 $2,371,625
Intangible drilling costs 12,554 19,769
Lease and well equipment 965,441 1,082,969
---------- ----------
2,955,683 3,474,363
---------- ----------
Other property and equipment:
Land and building 269,425 269,025
Office furniture, fixtures and equipment 87,695 84,608
Automobiles 21,299 21,299
---------- ----------
378,419 374,932
---------- ----------
3,334,102 3,849,295
Less: accumulated depreciation, depletion and amortization 974,668 918,439
---------- ----------
Net capitalized costs $2,359,434 $2,930,856
========== ==========
</TABLE>
-10-
<PAGE>
Costs incurred in oil and gas property acquisitions and development
activities are as follows:
<TABLE>
<CAPTION>
1997 1996
<S> <C> <C>
Property acquisitions $ 500 $ 222,000
Development costs 5,900 393,000
-------- ----------
Total costs incurred $ 6,400 $ 615,000
======== ==========
</TABLE>
Property acquisition costs in 1996 include approximately $59,000 representing
amounts assigned to properties acquired through the partnership transactions
described in Note 2.
5. LONG-TERM OBLIGATIONS
On December 31, 1997, the Company negotiated a $1,587,928 loan with
SpiritBank, N.A. ("Spirit") for the purpose of consolidating debt owed to
Spirit and various other banks. The majority of the proceeds, $1,344,381,
were used on December 31, 1997, to refinance existing loans with Spirit. The
remaining proceeds of $234,547 were held in escrow and on January 2, 1998,
were used to pay the remaining principal and accrued interest on loans with
various other banks. This amount is included in restricted cash at December
31, 1997. The note agreement prohibits the Company from incurring additional
debt without Spirit's approval.
-11-
<PAGE>
Long-term debt consists of the following:
<TABLE>
<CAPTION>
1997 1996
<S> <C> <C>
10% note payable to bank due in monthly installments of interest only through
July 1998, monthly installments of $33,842, including interest during the
period August 1998 through December 2002, with the balance of approximately
$224,000 due at maturity, secured by oil and gas properties $1,587,928 $ -
10% unsecured note payable to individual with principal due in
April 1998, with interest paid monthly 300,000 -
9.50% note payable to bank due in monthly installments of $2,261,
including interest, through March 2001, with the balance of approx-
imately $175,000 due at maturity, secured by real estate mortgage 204,288 210,969
8.28% note payable to bank with principal and interest due on
October 28, 1998, secured by a certificate of deposit 101,100 -
10.25% at December 31, 1997 and 10.00% at December 31, 1996 note
payable to bank due in monthly installments of $2,083 plus interest
through June 2000, secured by oil and gas properties, prepaid
January 1998 64,589 87,502
9.75% note payable to bank due in monthly installments of $4,397,
including interest, through December 1998, with the balance of
approximately $9,000 due at maturity, secured by oil and gas
properties, prepaid January 1998 52,847 99,252
9.75% note payable to bank due in monthly installments of $3,302,
including interest, through December 1998, with a balance of
approximately $17,000 due at maturity, secured by oil and gas
properties, prepaid January 1998 48,161 83,535
9.50% note payable to bank due in monthly installments of $3,288, including
interest, through December 1998, with the balance of approx-imately $6,000 due
at maturity, secured by oil and gas properties, prepaid January 1998 38,073 74,302
10% unsecured note payable to bank with principal due in June 2001,
with interest paid monthly, prepaid in January 1998 22,396 25,000
8.60% note payable to bank due in monthly installments of $439,
including interest, through December 2000, secured by equipment 13,895 18,067
10% note payable to bank due in monthly installments of $21,447, including
interest, through December 1997, with the balance of approx-imately $682,000
due at maturity, secured by oil and gas properties, refinanced December 1997 - 843,914
</TABLE>
-12-
<PAGE>
<TABLE>
<CAPTION>
1997 1996
<S> <C> <C>
10% $500,000 line-of-credit payable to bank due in monthly
installments of interest only through March 1997, at which
time the outstanding principal will convert to a five-year
term loan, secured by oil and gas leases and certificate of
deposit held at bank, refinanced December 1997 - 349,713
10% note payable to bank due in monthly installments of $9,702,
including interest, through December 1999, with the balance of
principal and remaining accrued interest due at maturity, secured
by oil and gas properties, refinanced December 1997 - 300,000
10% note payable to bank due in monthly installments of $3,233,
including interest, through January 2001, with any remaining
principal due at maturity, secured by oil and gas properties - 129,774
10% note payable to bank due in monthly installments of $9,201,
including interest, through November 1997, secured by oil and
gas properties - 101,237
10% note payable to bank due in monthly installments of $2,297,
including interest, through November 1998, with any remaining
principal due at maturity, secured by oil and gas property
mortgages, prepaid in January 1997 - 51,445
10% note payable to bank due in monthly installments of $1,229,
including interest, through October 1997, with any remaining
principal due at maturity, secured by equipment - 12,862
Capital lease obligations 5,915 23,562
---------- ----------
Total obligations 2,439,192 2,411,134
Less current portion 769,564 1,338,665
---------- ----------
$1,669,628 $1,072,469
========== ==========
</TABLE>
Substantially all of the Company's debt is guaranteed by the Company's
president and major stockholder. The aggregate maturities of long-term debt
as of December 31, 1997 are as follows: 1998 - $769,564, 1999 - $287,027,
2000 - $315,072, 2001 - $508,489, and 2002 - $559,040.
-13-
<PAGE>
6. INCOME TAXES
Deferred tax assets and liabilities at December 31, 1997 and 1996 are
composed of the following:
1997 1996
Deferred tax asset -
Net operating loss caryforward $ 512,830 $ 242,277
Less: Valuation allowance (500,536) (229,247)
--------- ---------
12,294 13,030
--------- ---------
Deferred tax liability -
Partnersip investments basis differences 12,294 13,030
--------- ---------
Net deferred taxes $ - $ -
========= =========
At December 31, 1997, the Company had net operating loss carryforwards of
approximately $1,282,000 which will expire during the years 2009 through
2012.
The Company's income tax provision for the years ended December 31, 1997 and
1996 differs from the amount computed by applying the statutory federal
income tax rate for the following reasons:
1997 1996
Tax provision at the federal statutory rate $(224,116) $ (85,831)
State income tax benefit (39,550) (15,147)
Change in valuation allowance 271,289 63,531
Nondeductible expenses 6,004 10,297
Graduated federal income tax rates - 4,128
Other (13,627) 23,022
--------- ---------
$ - $ -
========= =========
7. RELATED PARTIES
In 1995, the Company began paying a fee to the Company president based on the
terms of a "Guaranty Fee Agreement". Under the agreement he receives an
annual fee for guaranteeing the Company debt equal to the greater of $15,000
or 3% of the guaranteed debt. During 1997 and 1996, this fee was
approximately $64,000 and $76,000, respectively.
The Company incurs fees for accounting and consulting services provided by a
firm in which a board member of the Company is a partner. Such amounts
incurred during 1997 and 1996 were $11,359 and $39,943, respectively. During
1996, the Company issued 35,700 shares of its common stock to this firm for
services rendered. The value assigned to this stock, $49,980, was based on
billings received from the firm. The Company also incurs fees for business
advisory services to a firm affiliated with this board member. Such amounts
incurred were $37,424 in 1997.
Pursuant to an agreement signed in February 1996, a director of the Company
will provide evaluation and reservoir engineering services to the Company in
exchange for an amount equal to a percentage of the net revenue interest of a
certain well less a percentage of the lease operating expenses attributable
to the same well. The Company did not utilize the engineering services
during 1996 or 1997 and no
-14-
<PAGE>
amounts were expensed under this agreement. However, a company affiliated
with this director provides well operation services to the Company. Such
amounts incurred in 1997 and 1996 were $9,237 and $22,087, respectively.
8. STOCK OPTION PLANS
The Company established the Pan Western Energy Corporation 1992 Directors
Stock Option Plan (the "Directors Plan") under which non-employee directors
of the Company may be granted options to purchase shares of common stock.
The plan provides that the option price shall be the fair value of the common
stock at the date granted and that options are exercisable for 10 years and
30 days from date granted. At December 31, 1997 and 1996, options covering
85,000 and 135,000 shares were available for grant and options covering
65,000 and 15,000 shares were exercisable, respectively. Of the outstanding
options, 15,000 were granted in July 1993 at $1.30 per share and 50,000 were
granted in January 1997 at $1.40 per share.
The 1992 Employee Stock Option Plan (the "Employee Plan") has also been
adopted by the Company's board of directors and approved by the shareholders.
There are 100,000 options available for grant under this Plan and no options
have been granted under the Plan.
Outstanding options granted under both the Directors and Employee Stock
Option Plans are terminated if the option holder ceases to be an employee or
director of the Company.
In July 1993, the board of directors approved the grant of options to the
Company's president to acquire 7,500 shares of common stock at $1.30 per
share (the estimated fair value at the date granted). These options are
exercisable at any time up to ten years from date of grant. On January 21,
1997, the board of directors approved the grant of options to certain
executive officers to acquire 570,000 shares of the Company's common stock at
$1.40 per share (the estimated fair value at the date granted). These
options vest at 40% on date of grant; 30% one year from date of grant; and
the remaining 30% two years from date of grant. These options were not
granted pursuant to the existing Employee Plan.
A summary of the status of the Company's stock option plans as well as the
options granted outside the existing plans as of December 31, 1997 and
December 31, 1996 and changes during the years then ended is presented below:
<TABLE>
<CAPTION>
1997 1996
-------------------- ---------------------
WEIGHTED WEIGHTED
AVERAGE AVERAGE
EXERCISE EXERCISE
SHARES PRICE SHARES PRICE
<S> <C> <C> <C> <C>
Outstanding at Beginning of Year 22,500 $ 1.30 37,500 $ 1.30
Granted 620,000 1.40 - -
Exercised/Canceled - - (15,000) 1.30
-------- -------- -------- --------
Outstanding at End of Year 642,500 $ 1.40 22,500 $ 1.30
======== ======== ======== ========
</TABLE>
-15-
<PAGE>
The following table summarizes information about stock options outstanding at
December 31, 1997:
<TABLE>
<CAPTION>
NUMBER
RANGE OF OUTSTANDING WEIGHTED
EXERCISE AT DECEMBER 31, AVERAGE REMAINING WEIGHTED AVERAGE
PRICES 1997 CONTRACTUAL LIFE (YEARS) EXERCISE PRICE
------ --------------- ----------------------- ----------------
<S> <C> <C> <C>
$ 1.30 22,500 5 $ 1.30
$ 1.40 620,000 9 $ 1.40
</TABLE>
At December 31, 1997, 300,500 of the options outstanding are exercisable.
The Company applies Accounting Principles Board Opinion No. 25 in accounting
for the stock options. Accordingly, no compensation cost has been
recognized. Had compensation cost been determined based on the fair value at
the grant dates for awards consistent with the method described in SFAS No.
123, the Company's net loss and loss per share for the year ended December
31, 1997 would have been increased to the pro forma amounts indicated below:
Net loss - as reported $ (659,165)
==========
Net loss - pro forma $ (779,331)
==========
Loss per share - as reported $ (0.20)
==========
Loss per share - pro forma $ (0.24)
==========
The fair value of options granted during the year ended December 31, 1997 was
estimated on the date of grant using the Black-Scholes option-pricing model
with the following weighted average assumptions used: no dividend yield,
expected lives of six years, and risk free interest rate of 6.25%.
Volatility was not considered since the Company's common stock has been
publicly traded for only a short period of time during which time the Company
has been unsuccessful in developing a market for the stock and trading
volumes are minimal. The estimated fair value of options granted during 1997
was $0.43 per share.
9. STOCK PURCHASE WARRANTS
In March 1996, Pangloss International, S.A. ("Pangloss") acquired 87,500
shares of the Company's common stock for $1.20 per share, and concurrently
was granted warrants to purchase 125,000 shares at $1.60 per share. Pangloss
was granted additional warrants in July 1996 to purchase 100,000 shares of
the Company's common stock at $1.20 per share. These warrants were issued in
connection with a $105,000 loan from Pangloss that was repaid in December
1996.
All of the warrants issued to Pangloss are exercisable at any time prior to
April 15, 2001.
10. STOCKHOLDERS' EQUITY
On June 20, 1996, the Company's stockholders approved amendments to the
Certificate of Incorporation to increase the Company's authorized common
stock to 25,000,000 shares, and to establish a class of preferred stock. The
board of directors was authorized to fix the rights and terms applicable to
the preferred stock prior to issuance.
-16-
<PAGE>
On February 18, 1997, the board of directors approved a four-for-one stock
split effected in the form of a stock dividend. The record date for the
dividend was April 1, 1997. Common shares, per share data, and stockholders'
equity amounts in the accompanying consolidated financial statements and
footnotes (unless otherwise indicated) have been retroactively adjusted to
reflect this stock split.
During 1997 the Company sold 75,000 shares of common stock at $2 per share
through an offering pursuant to Regulation D and Rule 504 of the Securities
Act of 1933. Purchases of common stock under this offering were limited to
100 shares per individual. The Company's sole purpose for this offering was
to increase the shareholder base to at least 300 in order to meet one of the
requirements imposed by NASDAQ to qualify for trading on the NASDAQ Small
Cap Market. The Company has not yet met all of such requirements.
In addition, 25,845 shares of the Company's common stock were issued during
1997 in connection with preemptive rights of existing shareholders for
shares sold by the Company under the offering described above prior to March
21, 1997. The shares were issued at a price per share ranging from $0.33 to
$1.40. The Certificate of Incorporation of the Company was amended and
restated on March 21, 1997 and provisions providing for shareholder
preemptive rights were eliminated.
During 1997 the Company issued 33,000 shares, of its common stock to an
individual in connection with a $300,000 loan from that individual. The
shares were valued at $2 per share which was the estimated fair value at the
date of issuance and $66,000 was expensed as a loan fee.
11. COMMITMENTS AND CONTINGENCIES
The Company has executed employment agreements with certain executive
officers which expire on the later of specified dates in the year 2000 or
the date to which the agreement has been extended; or, in the case of the
Company's president, as long as the president guarantees the Company's debt.
Under the terms of these agreements, the executives will receive annual
salaries aggregating $238,000. In addition, the Company's president will
receive incentive compensation equal to 10% of the Company's annual pre-tax
income in excess of $150,000. The other executive officers will share in a
bonus pool equal to 10% of the Company's net income in excess of $100,000.
In the event of the executives' termination without just cause, as defined
in the agreements, the Company must pay them these amounts for the remaining
term of the agreements.
12. SIGNIFICANT CUSTOMERS
There were four purchasers in 1997 which represented approximately 18%, 17%,
14% and 11% of the Company's total revenues. There were four purchasers in
1996 which represented approximately 18%, 16%, 15% and 11% of the Company's
total revenues.
13. SUPPLEMENTAL INFORMATION ABOUT OIL AND GAS PRODUCING ACTIVITIES (UNAUDITED)
The following information summarizes the Company's net proved reserves of
oil and gas and the present values thereof for the years ended December 31,
1997 and 1996. The information presented for 1997 and 1996 is based upon
estimates prepared by Williamson Petroleum Consultants, Inc. and Sycamore
Resources, LLC, respectively, who were engaged to perform evaluations of the
present value of estimated future net cash flows before income tax
(discounted at 10%). The information was prepared in accordance with
Statement of Financial Accounting Standards No. 69.
-17-
<PAGE>
Prices of crude oil, condensate, and gas were those prices in effect at
December 31, 1997 and 1996. Estimated future production costs, which include
lease operating costs and severance taxes (estimated assuming existing
economic conditions will continue over the lives of the individual leases,
with no adjustment for inflation), have been deducted in arriving at the
estimated future net revenues. The present value amounts should not
necessarily be equated with fair market value of the Company's oil and gas
reserves. All reserves are located in the United States.
The reliability of any reserve estimate is a function of the quality of
available information and of engineering interpretation and judgment. These
reserves should be accepted with the understanding that subsequent drilling
activities or additional information might require their revision.
The following schedules present certain data pertaining to the Company's
proved reserves at December 31, 1997 and 1996:
Estimated quantities of proved reserves:
<TABLE>
<CAPTION>
1997 1996
------------------------ -------------------------
OIL GAS OIL GAS
BBLS MCF BBLS MCF
<S> <C> <C> <C> <C>
Proved reserves:
Beginning of year 2,278,684 7,310,081 1,326,175 5,275,379
Sales and transfers of minerals
in place (81,388) (19,773) -- --
Revisions of previous estimates (803,041) (790,636) 580,861 1,590,876
Purchases of minerals in place 504 2,534 428,519 706,949
Production (45,136) (250,409) (56,871) (263,123)
---------- ---------- ---------- ----------
End of year 1,349,623 6,251,797 2,278,684 7,310,081
========== ========== ========== ==========
Proved developed reserves,
end of year 818,644 4,101,265 1,254,903 3,914,395
========== ========== ========== ==========
</TABLE>
Standardized measure of estimated discounted future net cash flows relating
to proved oil and gas reserves:
<TABLE>
<CAPTION>
1997 1996
<S> <C> <C>
Future cash inflows $ 31,807,602 $ 73,051,172
Future development costs (1,984,575) (3,958,105)
Future production costs (9,551,242) (12,031,762)
------------ ------------
Future net cash flows, before income taxes 20,271,785 57,061,305
Future income taxes (6,822,827) (21,144,475)
------------ ------------
Future net cash flows, after income taxes 13,448,958 35,916,830
10% annual discount for estimated timing of cash flows (7,760,176) (13,064,500)
------------ ------------
Standardized measure of estimated discounted future
net cash flows $ 5,688,782 $ 22,852,330
============ ============
Estimated discounted future net cash flows before income taxes $ 8,574,733 $ 36,305,648
============ ============
</TABLE>
-18-
<PAGE>
Changes in the standardized measure of estimated discounted future net cash
flows from proved oil and gas reserves:
<TABLE>
<CAPTION>
1997 1996
<S> <C> <C>
Standardized measure, beginning of period $ 22,852,330 $ 8,610,996
Sales of production, net of production costs (764,965) (949,762)
Net changes in prices and production costs (17,652,950) 9,162,113
Purchases and sales of minerals in place, net (543,434) 5,119,345
Changes in estimated future development costs 1,973,530 (2,268,685)
Revisions of previous quantity estimates (5,044,789) 8,870,097
Accretion of discount 3,630,565 1,308,203
Net changes in income taxes 10,567,326 (8,982,284)
Timing and other (9,328,831) 1,982,307
------------ ------------
$ 5,688,782 $ 22,852,330
============ ============
</TABLE>
* * * * * *
-19-
<TABLE> <S> <C>
<PAGE>
<ARTICLE> 5
<LEGEND>
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM FORM 10KSB
FOR THE PERIOD ENDED DECEMBER 31, 1997 AND IS QUALIFIED IN ITS ENTIRETY BY
REFERENCE TO SUCH FINANCIAL STATEMENTS.
</LEGEND>
<S> <C>
<PERIOD-TYPE> 12-MOS
<FISCAL-YEAR-END> DEC-31-1997
<PERIOD-START> JAN-01-1997
<PERIOD-END> DEC-31-1997
<CASH> 358,833
<SECURITIES> 0
<RECEIVABLES> 183,752
<ALLOWANCES> 11,080
<INVENTORY> 0
<CURRENT-ASSETS> 562,935
<PP&E> 3,334,102
<DEPRECIATION> 974,668
<TOTAL-ASSETS> 2,987,281
<CURRENT-LIABILITIES> 1,194,597
<BONDS> 1,669,628
0
0
<COMMON> 44,487
<OTHER-SE> 78,569
<TOTAL-LIABILITY-AND-EQUITY> 2,987,281
<SALES> 1,361,212
<TOTAL-REVENUES> 1,443,545
<CGS> 860,513
<TOTAL-COSTS> 1,716,679
<OTHER-EXPENSES> 174,641
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 211,390
<INCOME-PRETAX> (659,165)
<INCOME-TAX> 0
<INCOME-CONTINUING> (659,165)
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> (659,165)
<EPS-PRIMARY> (0.20)
<EPS-DILUTED> (0.20)
</TABLE>
