Filed pursuant to Rule 424(b)(3)
Registration No. 333-116048
P R O S P E C T U S
GULFWEST ENERGY INC.
19,179,192 Shares of GulfWest Energy Inc. Class A Common Stock
(the "Shares")
This prospectus relates to the resale of up to 19,179,192 Shares issuable
to certain selling shareholders assuming the exercise of warrants or conversion
and exchange of certain preferred stock by those shareholders. This offering is
not being underwritten. The selling shareholders have advised us that they will
sell the shares from time to time in the open market, in privately negotiated
transactions or a combination of these methods at market prices prevailing at
the time of sale, at prices related to the prevailing market prices, at
negotiated prices, or otherwise as described under "Plan of Distribution." We
will pay all expenses of registration incurred in connection with this offering,
but the selling shareholders will pay all of their selling commission, brokerage
fees and related expenses.
Our common stock is traded over-the-counter under the symbol "GULF". On
December 7, 2004, the average of the high and low bid and asked prices of our
common stock as traded over-the-counter was $.68 per share.
Investing in our stock involves a high degree of risk. Please see "Risk
Factors" beginning on page 5 for a discussion of certain factors that you should
consider before investing.
Neither the Securities and Exchange Commission nor any state securities
commission has approved or disapproved of these securities or passed upon the
accuracy or adequacy of this prospectus. Any representation to the contrary is a
criminal offense.
The information in this prospectus is not complete and may be changed. The
selling shareholders may not sell or offer those securities until this
registration statement filed with the Securities and Exchange Commission is
effective. This prospectus is not an offer to sell these securities and it is
not soliciting an offer to buy these securities in any state where the offer or
sale is not permitted.
The date of this prospectus is December 7, 2004
TABLE OF CONTENTS
PROSPECTUS SUMMARY................................................................................................2
WHERE YOU CAN FIND ADDITIONAL INFORMATION.........................................................................4
RISK FACTORS......................................................................................................5
CAPITALIZATION...................................................................................................11
DIVIDEND POLICY..................................................................................................11
FORWARD-LOOKING STATEMENTS.......................................................................................12
MARKET PRICE OF COMMON STOCK.....................................................................................13
SELLING SHAREHOLDERS.............................................................................................14
PLAN OF DISTRIBUTION.............................................................................................17
SELECTED HISTORICAL FINANCIAL DATA...............................................................................19
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS............................20
BUSINESS AND PROPERTIES..........................................................................................28
MANAGEMENT.......................................................................................................35
EXECUTIVE COMPENSATION...........................................................................................37
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT...................................................39
CERTAIN TRANSACTIONS.............................................................................................40
DESCRIPTION OF SECURITIES........................................................................................41
GLOSSARY OF INDUSTRY TERMS AND ABBREVIATIONS.....................................................................45
LEGAL MATTERS....................................................................................................47
EXPERTS..........................................................................................................47
INDEX TO FINANCIAL STATEMENTS...................................................................................F-1
PROSPECTUS SUMMARY
This summary highlights selected information contained elsewhere in this
prospectus. The following summary does not contain all of the information that
may be important. You should read the detailed information appearing elsewhere
in this prospectus before making an investment decision. Certain terms that we
use in our industry are italicized and defined in the "Glossary of Industry
Terms and Abbreviations". Unless otherwise indicated, all references to
"GulfWest", the "Company", "we", "us" and "our" refer to GulfWest Energy Inc.
and our subsidiaries.
Our Business
We are primarily engaged in the acquisition, development, exploitation and
production of crude oil and natural gas. Our focus is on increasing production
from our existing properties through further exploitation, development and
exploration, and on acquiring additional interests in crude oil and natural gas
properties in the United States of America.
Since we made our first significant acquisition in 1993, we have
substantially increased the value of our crude oil and natural gas reserves
through a combination of acquisitions and the further exploitation and
development of our properties. At December 31, 2003, our estimated proved
reserves were approximately 5.0 million barrels (MBbl) of oil and 32.7 billion
cubic feet (Bcf) of natural gas with a Present Value discounted at 10% (PV-10)
of $114.4 million. Due to the limited available capital over the last three
years, we have not spent enough capital to maintain or increase our reserves.
This has led to a decrease in our proved reserves in each of the years. All of
our properties are located on land in Texas, Colorado, Louisiana, Oklahoma and
Mississippi, with the exception of Grand Lake in Louisiana. In the future, we
plan to expand by continued exploitation of our existing properties and through
the acquisition of additional properties.
Our operations are considered to fall within a single industry segment,
which is the acquisition, development, production and servicing of crude oil and
natural gas properties. See "Management's Discussion and Analysis of Financial
Condition and Results of Operations."
Our Company
We were formed as a corporation under the laws of the State of Utah in 1987
as Gallup Acquisitions, Inc., and subsequently changed our name to First
Preference Fund, Inc. and then to GulfWest Energy, Inc. We became a Texas
corporation by a merger effected in July 1992, in which our name became GulfWest
Oil Company. On May 21, 2001, we changed our name to GulfWest Energy Inc. Our
common stock is traded over-the-counter (OTC) under the symbol "GULF".
Our principal office is located at 480 North Sam Houston Parkway East,
Suite 300, Houston, Texas 77060 and our telephone number is (281) 820-1919.
Recent Transactions
On April 27, 2004, we completed an $18,000,000 financing package with new
energy lenders. We used $15,700,000 to retire existing debt of $27,584,145,
resulting in forgiveness of debt of $11,884,145, the elimination of a hedging
liability and the return to the Company of Series F Preferred Stock with an
aggregate liquidation preference of $1,000,000 (this preferred stock, at the
request of the Company, was transferred to a financial advisor to the Company
and to two companies affiliated with two directors of the Company. See "Certain
Relationships and Related Transactions.") This taxable gain
2
resulting from these transactions will be completely offset by available
net operating loss carryforwards. The term of the note is eighteen months and it
bears interest at the prime rate plus 11%. This rate increases by .75% per month
beginning in month ten. We paid the new lenders $1,180,000 in cash fees and also
issued them warrants to purchase 2,035,621 shares of our common stock at an
exercise price of $.01 per share, expiring in five years. The warrants are
subject to anti-dilution provisions. We are required by the terms of the
warrants to register the resale of the common stock underlying the warrants, and
those shares are offered by this prospectus. See "Management's Discussion and
Analysis of Financial Condition and Results of Operations."
Simultaneously, our wholly-owned subsidiary, GulfWest Oil & Gas Company,
completed the initial phase of a private offering of its Series A Preferred
Stock for $4,000,000. The Series A Preferred Stock is exchangeable into our
common stock based on a liquidation value of $500 per share of Series A
Preferred Stock divided by $.35 per share of our common stock, or 11,428,571
shares. As part of an advisory fee, we issued $500,000 of the Series A Preferred
Stock to a financial advisor. One of our directors acquired $1,500,000 of the
Series A Preferred Stock. The resale of the shares of common stock to be issued
upon the exchange of the Series A Preferred Stock is offered by this prospectus.
The Series A Preferred Stock is entitled to receive dividends at the rate
of $45.00 per share per annum, payable quarterly, as declared by the Board of
Directors. The Series A Preferred Stock is redeemable in whole or in part at any
time, at the option of the issuer, at a price of $500 per share, plus all
accrued and undeclared unpaid dividends. The exchange price of the Series A
Preferred Stock is based upon $0.35 per share of common stock. At December 7,
2004, 50 shares of the Series A Preferred Stock had been exchanged for 71,428
shares of our common stock.
Pursuant to an agreement with the financial advisor, who provided access to
the lenders and raised $1,900,000 of the Series A Preferred Stock, we paid the
following: a cash fee of $400,000, at closing of the transaction; $250,000 in
cash, payable $10,000 per month for 25 months; and $500,000 issued in Series A
Preferred Stock (as mentioned above). In addition, the financial advisor
received 400 shares of our Series F Preferred Stock from a former lender.
Of the $21,500,000 total cash raised, we used $15,700,000 to pay existing
debt and $1,580,000 to pay fees and commissions, leaving $4,220,000 available
for capital expenditures and working capital.
Other Securities Being Offered
In addition to the transactions described above, this prospectus also
covers the resale of our common stock to be acquired upon conversion and
exchange of our preferred stock and upon exercise of certain other warrants we
have issued.
As of December 7, 2004, there was a total of 18,940 shares of preferred
stock issued and outstanding in three series, including 8,000 shares of Series D
Preferred Stock, 9,000 shares of Series E Preferred Stock and 1,940 shares of
Series F Preferred Stock (collectively, "Preferred Stock"). The 8,000 shares of
Series D Preferred Stock are held by a former director, the 9,000 shares of
Series E Preferred Stock are held by a current director and the 1,940 shares of
Series F are held by a financial advisor to the Company, two private investors,
an officer and two companies affiliated with two directors. See "Certain
Relationships and Related Transactions." On a fully converted basis, the 8,000
shares of Series D Preferred Stock would convert to 500,000 shares of common
stock. On a fully converted basis, the 9,000 shares of Series E Preferred Stock
would convert to 2,250,000 shares of common stock. On a fully converted basis,
the 1,940 shares of Series F Preferred Stock would convert to 970,000 shares of
common stock.
3
Since 1996 we have occasionally issued warrants to employees, consultants
and directors as additional compensation. These warrants have exercise prices
ranging from $0.75 to $1.20 per share and entitle the warrant holders to
purchase up to 890,000 shares of common stock. The warrants contain certain
anti-dilution provisions and have expiration dates from January 6, 2005 to
December 7, 2006.
Additionally, warrants have occasionally been issued to lenders or
guarantors on loans to the Company as additional consideration for entering into
the loans or guaranties. These warrants have an exercise price of $.75 per
warrant and entitle the warrant holders to purchase up to 1,075,000 shares of
common stock. A director of the Company has 625,000 of these warrants. The
warrants contain certain anti-dilution provisions and have expiration dates
ranging from February 12, 2005 to April 1, 2008.
Summary of the Offering
This prospectus relates to the resale of an aggregate of up to 19,179,192
shares of our common stock (the "Shares") issuable or issued to certain selling
shareholders, assuming the conversion and exchange of the preferred stock
described above and the exercise of the warrants described above. The selling
shareholders may offer to sell the Shares at fixed prices, at prevailing market
prices at the time of sale, or at varying negotiated prices. We will not receive
any proceeds from the resale of Shares by the holders thereof.
As of December 7, 2004 the total number of shares of our common stock
outstanding was 18,593,969, not including the shares reserved for issuance upon
the conversion and exchange of the preferred stock and the exercise of the
warrants described above.
On December 7, 2004, the average of the high and low bid and asked prices
of our common stock as traded over-the-counter was $.68 per share.
WHERE YOU CAN FIND ADDITIONAL INFORMATION
We have filed a registration statement on Form S-1, as amended, to register
the shares of common stock being offered by this prospectus. In addition, we
file annual, quarterly and special reports, proxy statements and other
information with the Securities and Exchange Commission. Prospective purchasers
may read and copy any reports, statements or other information we file at the
Securities and Exchange Commission's public reference facilities in Washington,
D.C., New York and Chicago, Illinois. Please call the Securities and Exchange
Commission at 1-800-SEC-0330 for further information on the public reference
facilities. Our Securities and Exchange Commission filings are also available to
the public from commercial document retrieval services, and at the web site
maintained by the Securities and Exchange Commission at http://www.sec.gov. As
allowed by Securities and Exchange Commission rules, this prospectus does not
contain all the information contained in the registration statement or in
exhibits to the registration statement.
4
RISK FACTORS
Investing in our stock involves a high degree of risk. You should carefully
consider the following risk factors in addition to the other information in this
prospectus before making an investment in our stock. Any of the following risks
could cause the trading price of the Shares to decline.
Our success depends heavily upon our ability to market our crude oil and
natural gas production at favorable prices.
In recent decades, there have been both periods of worldwide overproduction
and underproduction of crude oil and natural gas, and periods of increased and
relaxed energy conservation efforts. Such conditions have resulted in excess
supply of, and reduced demand for, crude oil on a worldwide basis and for
natural gas on a domestic basis. At other times, there has been short supply of,
and increased demand for, crude oil and, to a lesser extent, natural gas. These
changes have resulted in dramatic price fluctuations.
The degree to which we are leveraged could possibly have important
consequences to our shareholders, including the following:
(i) Our indebtedness, acquisitions, working capital, capital expenditures
or other purposes may be impaired;
(ii) Funds available for our operations and general corporate purposes or
for capital expenditures will be reduced as a result of the dedication of a
substantial portion of our consolidated cash flow from operations to the payment
of the principal and interest on our indebtedness;
(iii) We may be more highly leveraged than certain of our competitors,
which may place us at a competitive disadvantage;
(iv) The agreements governing our long-term indebtedness and bank loans may
contain restrictive financial and operating covenants;
(v) An event of default (not cured or waived) under financial and operating
covenants contained in our debt instruments could occur and have a material
adverse effect;
(vi) Certain of the borrowings under our debt agreements have floating
rates of interest, which causes us to be vulnerable to increases in interest
rates; and
(vii) Our substantial degree of leverage could make us more vulnerable to a
downturn in general economic conditions.
Our ability to make principal and interest payments under long-term
indebtedness and bank loans will be dependent upon our future performance, which
is subject to financial, economic and other factors, some of which are beyond
our control.
We cannot assure you that our current level of operating results will
continue or improve. We believe that we will need to access capital markets in
the future in order to provide the funds necessary to repay a significant
portion of our indebtedness. We cannot assure you that any such refinancing will
be possible or that we can obtain any additional financing, particularly in view
of our anticipated high levels of debt. If no such refinancing or additional
financing were available, we could default on our debt obligations.
5
We have incurred net losses in the past and there can be no assurance that
we will be profitable in the future.
We have incurred net losses in three of the last five fiscal years. Our
accountants have included a "going concern" notation in their letter
accompanying our audited financial statements. See "Financial Statements." If we
continue to sustain net losses in future years, it will be difficult to continue
as an operating entity.
Our future operating results may fluctuate significantly depending upon a
number of factors, including industry conditions, prices of crude oil and
natural gas, rates of production, timing of capital expenditures and drilling
success. These variables could have a material adverse effect on our business,
financial condition, results of operations and the market price of our common
stock.
Estimates of crude oil and natural gas reserves depend on many assumptions
that may turn out to be inaccurate.
Estimates of our proved reserves for crude oil and natural gas and the
estimated future net revenues from the production of such reserves rely upon
various assumptions, including assumptions as to crude oil and natural gas
prices, drilling and operating expenses, capital expenditures, taxes and
availability of funds. The process of estimating crude oil and natural gas
reserves is complex and imprecise.
Actual future production, crude oil and natural gas prices, revenues,
taxes, development expenditures, operating expenses and quantities of
recoverable crude oil and natural gas reserves may vary substantially from the
estimates we obtain from reserve engineers. Any significant variance in these
assumptions could materially affect the estimated quantities and present value
of reserves we have set forth. In addition, our proved reserves may be subject
to downward or upward revision due to factors that are beyond our control, such
as production history, results of future exploration and development, prevailing
crude oil and natural gas prices and other factors.
Approximately 25% of our total estimated proved reserves at December 31,
2003 were proved undeveloped reserves, which are by their nature less certain.
Recovery of such reserves requires significant capital expenditures and
successful drilling operations. The reserve data set forth in the reserve
engineer reports assumes that substantial capital expenditures are required to
develop such reserves. Although cost and reserve estimates attributable to our
crude oil and natural gas reserves have been prepared in accordance with
industry standards, we cannot be sure that the estimated costs are accurate,
that development will occur as scheduled or that the results of such development
will be as estimated.
You should not interpret the present value referred to in this prospectus
as the current market value of our estimated crude oil and natural gas reserves.
In accordance with Securities and Exchange Commission requirements, the
estimated discounted future net cash flows from proved reserves are generally
based on prices and costs as of the date of the estimate. Actual future prices
and costs may be materially higher or lower.
The estimates of our proved reserves and the future net revenues from which
the present value of our properties is derived were calculated based on the
actual prices of our various properties on a property-by-property basis at
December 31, 2003. The average prices of all properties were $29.51 per barrel
of oil and $5.82 per thousand cubic feet (Mcf) of natural gas at that date.
6
Actual future net cash flows will also be affected by increases or
decreases in consumption by crude oil and natural gas purchasers and changes in
governmental regulations or taxation. The timing of both the production and the
incurring of expenses in connection with the development and production of crude
oil and natural gas properties affect the timing of actual future net cash flows
from proved reserves. In addition, the 10% discount factor, which is required by
the Securities and Exchange Commission to be used in calculating discounted
future net cash flows for reporting purposes, is not necessarily the most
appropriate discount factor. The effective interest rate at various times and
the risks associated with our business or the oil and gas industry in general
will affect the accuracy of the 10% discount factor.
Except to the extent that we acquire properties containing proved reserves
or conduct successful development or exploitation activities, our proved
reserves will decline as they are produced.
In general, the volume of production from crude oil and natural gas
properties declines as reserves are depleted. Our future crude oil and natural
gas production is highly dependent upon our success in finding or acquiring
additional reserves.
The business of acquiring, enhancing or developing reserves requires
considerable capital.
Our ability to make the necessary capital investment to maintain or expand
our asset base of crude oil and natural gas reserves could be impaired to the
extent that cash flow from operations is reduced and external sources of capital
become limited or unavailable. In addition, we cannot be sure that our future
acquisition and development activities will result in additional proved reserves
or that we will be able to drill productive wells at acceptable costs.
Crude oil and natural gas drilling and production activities are subject to
numerous risks, many of which are beyond our control.
These risks include (i) the possibility that no commercially productive oil
or gas reservoirs will be encountered; and, (ii) that operations may be
curtailed, delayed or canceled due to title problems, weather conditions,
governmental requirements, mechanical difficulties, or delays in the delivery of
drilling rigs and other equipment that may limit our ability to develop, produce
and market our reserves. We cannot assure you that new wells we drill will be
productive or that we will recover all or any portion of our investment in such
new wells.
Drilling for crude oil and natural gas may not be profitable.
Any wells that we drill may be dry wells or wells that are not sufficiently
productive to be profitable after drilling. Such wells will have a negative
impact on our profitability. In addition, our properties may be susceptible to
drainage from production by other operators on adjacent properties.
Our industry experiences numerous operating risks that could cause us to
suffer substantial losses.
Such risks include fire, explosions, blowouts, pipe failure and
environmental hazards, such as oil spills, natural gas leaks, ruptures or
discharges of toxic gases. We could also suffer losses due to personnel injury
or loss of life; severe damage to or destruction of property; or environmental
damage that could result in clean-up responsibilities, regulatory investigation,
penalties or suspension of our operations. In accordance with customary industry
practice, we maintain insurance policies against some, but not all, of the risks
described above. Our insurance policies may not adequately protect us against
loss or liability. There is no guarantee that insurance policies that protect us
against the many risks we face will continue to be available at justifiable
premium levels.
7
As owners and operators of crude oil and natural gas properties, we may be
liable under federal, state and local environmental regulations for activities
involving water pollution, hazardous waste transport, storage, disposal or other
activities.
Our past growth has been attributable to acquisitions of producing crude
oil and natural gas properties with proved reserves. There are risks involved
with such acquisitions.
The successful acquisition of properties requires an assessment of
recoverable reserves, future crude oil and natural gas prices, operating costs,
potential environmental and other liabilities, and other factors beyond our
control. Such assessments are necessarily inexact and their accuracy uncertain.
In connection with such an assessment, we perform a review of the subject
properties that we believe to be generally consistent with industry practices.
Such a review, however, will not reveal all existing or potential problems, nor
will it permit us, as the buyer, to become sufficiently familiar with the
properties to fully assess their capabilities or deficiencies. We may not
inspect every well and, even when an inspection is undertaken, structural and
environmental problems may not necessarily be observable.
When we acquire properties, in most cases, we are not entitled to
contractual indemnification for pre-closing liabilities, including environmental
liabilities.
We generally acquire interests in properties on an "as is" basis with
limited remedies for breaches of representations and warranties. In those
circumstances in which we have contractual indemnification rights for
pre-closing liabilities, we cannot assure you that the seller will be able to
fulfill its contractual obligations. In addition, the competition to acquire
producing crude oil and natural gas properties is intense and many of our larger
competitors have financial and other resources substantially greater than ours.
We cannot assure you that we will be able to acquire producing crude oil and
natural gas properties that have economically recoverable reserves for
acceptable prices.
We may acquire royalty, overriding royalty or working interests in
properties that are less than the controlling interest.
In such cases, it is likely that we will not operate, nor control the
decisions affecting the operations, of such properties. We intend to limit such
acquisitions to properties operated by competent parties with whom we have
discussed their plans for operation of the properties.
We will need additional financing in the future to continue to fund our
development and exploitation activities.
We have made and will continue to make substantial capital expenditures in
our exploitation and development projects. We intend to finance these capital
expenditures with cash flow from operations, existing financing arrangements or
new financing. We cannot assure you that such additional financing will be
available. If it is not available, our development and exploitation activities
may have to be curtailed, which could adversely affect our business, financial
condition and results of operations, as was the case in 2003.
8
The marketing of our natural gas production depends, in part, upon the
availability, proximity and capacity of natural gas gathering systems, pipelines
and processing facilities.
We could be adversely affected by changes in existing arrangements with
transporters of our natural gas since we do not own most of the gathering
systems and pipelines through which our natural gas is delivered to purchasers.
Our ability to produce and market our natural gas could also be adversely
affected by federal, state and local regulation of production and
transportation.
The crude oil and natural gas industry is highly competitive in all of its
phases.
Competition is particularly intense with respect to the acquisition of
desirable producing properties, the acquisition of crude oil and natural gas
prospects suitable for enhanced production efforts, and the hiring of
experienced personnel. Our competitors in crude oil and natural gas acquisition,
development, and production include the major oil companies, in addition to
numerous independent crude oil and natural gas companies, individual proprietors
and drilling programs.
Many of these competitors possess and employ financial and personnel
resources substantially in excess of those which are available to us and may,
therefore, be able to pay more for desirable producing properties and prospects
and to define, evaluate, bid for, and purchase a greater number of producing
properties and prospects than our financial or personnel resources will permit.
Our ability to generate reserves in the future will be dependent on our ability
to select and acquire suitable producing properties and prospects while
competing with these companies.
The domestic oil industry is extensively regulated at both the federal and
state levels. Although we believe we are presently in compliance with all laws,
rules and regulations, we cannot assure you that changes in such laws, rules or
regulations, or the interpretation thereof, will not have a material adverse
effect on our financial condition or the results of our operations.
Legislation affecting the oil and gas industry is under constant review for
amendment or expansion, frequently increasing the regulatory burden on the
industry. There are numerous federal and state agencies authorized to issue
rules and regulations affecting the oil and gas industry. These rules and
regulations are often difficult and costly to comply with and carry substantial
penalties for noncompliance.
State statutes and regulations require permits for drilling operations,
drilling bonds, and reports concerning operations. Most states also have
statutes and regulations governing conservation matters, including the
unitization or pooling of properties, and the establishment of maximum rates of
production from wells. Some states have also enacted statutes prescribing price
ceilings for natural gas sold within their states.
Our industry is also subject to numerous laws and regulations governing
plugging and abandonment of wells, discharge of materials into the environment
and other matters relating to environmental protection. The heavy regulatory
burden on the oil and gas industry increases the costs of our doing business as
an oil and gas company, consequently affecting our profitability.
9
We have "blank check" preferred stock.
Our Articles of Incorporation authorize the Board of Directors to issue
preferred stock without further shareholder action in one or more series and to
designate the dividend rate, voting rights and other rights preferences and
restrictions. The issuance of preferred stock could have an adverse impact on
holders of common stock. Preferred stock is senior to common stock.
Additionally, preferred stock could be issued with dividend rights senior to the
rights of holders of common stock. Finally, preferred stock could be issued as
part of a "poison pill", which could have the effect of determining offers to
acquire the Company See "Description of Securities"
We do not pay dividends on our common stock.
Our board of directors presently intends to retain all of our earnings for
the expansion of our business; therefore we do not anticipate distributing cash
dividends on our common stock in the foreseeable future. Any decision of our
board of directors to pay cash dividends will depend upon our earnings,
financial position, cash requirements and other factors.
The holders of our common stock do not have cumulative voting rights,
preemptive rights or rights to convert their common stock to other securities.
We are authorized to issue 80,000,000 shares of common stock, $.001 par
value per share. As of December 7, 2004, there were 18,593,969 shares of common
stock issued and outstanding. Since the holders of our common stock do not have
cumulative voting rights, the holder(s) of a majority of the shares of common
stock present, in person or by proxy, will be able to elect all of the members
of our board of directors. The holders of shares of our common stock do not have
preemptive rights or rights to convert their common stock into other securities.
Management controls the Company.
Mr. J. Virgil Waggoner, our Chairman of the Board and one of the selling
shareholders, owns 9,601,829 shares of our common stock, which represents almost
52% of the currently outstanding common stock. Additionally, Mr. Waggoner has
the right to acquire an additional 7,180,714 shares pursuant to conversion and
exchange of preferred stock and exercise of currently exercisable warrants and
options. See "Security Ownership of Certain Beneficial Owners and Management."
Additionally, all current directors and officers as a group own almost 70% of
the outstanding common stock (assuming they convert all preferred stock and
exercise all currently exercisable warrants and options held by them). For as
long as Mr. Waggoner and the other directors and officers continue to own over a
majority of the outstanding common stock, they will be able to control elections
to the board of directors and other matters submitted to shareholders. The
percentage ownership of directors and officers could be reduced by the issuance
of common stock on conversion and exchange of preferred stock and the exercise
of warrants, although it is impossible to say how many shares will be actually
issued.
The number of shares of outstanding common stock could increase
significantly as a result of our recent transactions.
If all of the common stock offered by this prospectus is issued by the
Company, the number of our outstanding shares of common stock will more than
double. It is impossible to say how many shares, if any, will be issued by the
Company and how many shares, in turn, will be resold under this prospectus.
However, it is possible that our stock price could decline significantly as a
result of an increased number of shares being offered into the market.
10
CAPITALIZATION
The following table sets forth our capitalization as of September 30, 2004
and as adjusted to give effect to the issuance of the shares offered by this
prospectus listed under "Summary - Other Securities Being Offered", assuming
conversion and exchange of all the preferred stock described in this prospectus
and exercise of all of the outstanding warrants. You should read this table in
conjunction with our financial statements, "Selected Financial Data" and
"Management's Discussion and Analysis of Results of Operations and Financial
Condition" included elsewhere in this prospectus.
September 30, 2004
Actual As Adjusted
------------ ------------
Total long-term debt, less current portion $21,377,396 $21,377,396
Total current liabilities 12,647,876 12,647,876
------------ ------------
Total debt 34,025,272 34,025,272
------------ ------------
Shareholders' equity
Series A Preferred Stock, $.01 par value, $500 liquidation value, 8,000 shares outstanding 80 -
Series D Preferred Stock, $.01 par value, $500 liquidation value, 8,000 shares outstanding 80 -
Series E Preferred Stock, $.01 par value, $500 liquidation value, 9,000 shares outstanding 90 -
Series F Preferred Stock, $.01 par value, $500 liquidation value, 2,000 shares outstanding 20 -
Class A Common Stock, $.001 par value, 18,492,541 shares outstanding actual, 37,671,733 as
adjusted 18,493 37,672
Additional paid-in equity 34,063,386 35,557,332
Accumulated deficit (19,037,073) (19,037,073)
------------ ------------
Total shareholders' equity 15,045,076 16,557,931
------------ ------------
Total capitalization $49,070,078 $50,583,203
============ ============
DIVIDEND POLICY
We have never declared or paid cash dividends on our common stock. We
currently intend to retain all available funds and any future earnings for use
in the operation of our business and to fund future growth. We do not anticipate
paying any cash dividends in the foreseeable future.
11
FORWARD-LOOKING STATEMENTS
We make forward-looking statements throughout this prospectus. Whenever you
read a statement that is not simply a statement of historical fact (such as when
we describe what we "believe," "expect" or "anticipate" will occur, and other
similar statements), you must remember that our expectations may not be correct,
even though we believe they are reasonable. We do not guarantee that the
transactions and events described in this prospectus will happen as described
(or that they will happen at all). The forward-looking information contained in
this prospectus is generally located in the material set forth under the
headings "Summary," "Risk Factors," "Management's Discussion and Analysis of
Financial Condition and Results of Operations" and "Business" but may be found
in other locations as well. These forward-looking statements generally relate to
our plans and objectives for future operations and are based upon our
management's reasonable estimates of future results and trends.
YOU SHOULD RELY ONLY ON THE INFORMATION CONTAINED IN THIS PROSPECTUS. WE
HAVE NOT AUTHORIZED ANYONE TO PROVIDE YOU WITH INFORMATION THAT IS DIFFERENT.
THIS PROSPECTUS MAY ONLY BE USED WHERE IT IS LEGAL TO SELL THESE SECURITIES. THE
INFORMATION CONTAINED IN THIS PROSPECTUS IS ACCURATE ONLY AS OF THE DATE OF THIS
PROSPECTUS, REGARDLESS OF WHEN THIS PROSPECTUS IS DELIVERED OR THE DATE OF ANY
SALE OF OUR COMMON STOCK.
12
MARKET PRICE OF COMMON STOCK
Our common stock is traded over-the-counter (OTC) under the symbol "GULF".
Fidelity Transfer Company, 1800 South West Temple, Suite 301, Box 53, Salt Lake
City, Utah 84115, (801) 484-7222 is the transfer agent for the common stock. The
high and low trading prices for the common stock for each quarter in 2004, 2003
and 2002 are set forth below. The trading prices represent prices between
dealers, without retail mark-ups, mark-downs, or commissions, and may not
necessarily represent actual transactions.
High Low
---- ---
2004
----
First Quarter $.56 $.32
Second Quarter $.56 $.33
Third Quarter $.85 $.45
2003
----
First Quarter $.45 $.42
Second Quarter .47 .35
Third Quarter .47 .43
Fourth Quarter .47 .32
2002
----
First Quarter $.66 $.55
Second Quarter .60 .46
Third Quarter .51 .20
Fourth Quarter .44 .32
We are authorized to issue 80,000,000 shares of Class A common stock, par
value $.001 per share (the "common stock"). As of December 7, 2004, there were
18,593,969 shares of common stock issued and outstanding (not including shares
issuable upon exercise of outstanding warrants or upon conversion and exchange
of preferred stock) and held by approximately 625 beneficial owners.
13
SELLING SHAREHOLDERS
The selling shareholders may offer and sell, from time to time, any or all
of the Shares. Because the selling security holders may offer all or only some
portion of the 19,179,192 Shares to be registered, no estimate can be given as
to the amount or percentage of these Shares that will be held by the selling
shareholders upon termination of the offering.
The following table sets forth the name and relationship with us, if any,
of certain of the selling shareholders and (i) the number of shares of common
stock beneficially owned by the selling shareholders as of the date of this
prospectus, (ii) the maximum number of shares of common stock which may be
offered for the account of the selling shareholders under this prospectus and
(iii) the amount and percentage of common stock that would be owned by the
selling shareholders after completion of the offering, assuming a sale of all of
the common stock which may be offered hereunder. Except as otherwise noted
below, the selling shareholders have not, within the past three years, had any
position, office or other material relationship with us.
Beneficial ownership is determined under the rules of the Securities and
Exchange Commission. The number of shares beneficially owned by a person
includes shares of common stock subject to options held by that person that are
currently exercisable or exercisable within 60 days of the date of this
prospectus. The shares issuable under these securities are treated as if
outstanding for computing the percentage ownership of the person holding these
securities but are not treated as if outstanding for the purposes of computing
the percentage ownership of any other person.
------------------------------------------------------ ------------------ ----------------- ------------------
Name and Address of Total Shares % of Ownership Total Shares
Selling Security Holder Registered Owned1
------------------------------------------------------ ------------------ ----------------- ------------------
Petrobridge Investment Management, LLC 2,035,621 9.9 2,035,621
1600 Smith Street, Suite 4250
Houston, TX 77002
------------------------------------------------------ ------------------ ----------------- ------------------
Petro Capital Advisors 1,628,571 8.1 1,628,571
1845Woodall Rodgers Frwy. ,Suite1700
Dallas, TX 75201
------------------------------------------------------ ------------------ ----------------- ------------------
Virgil Waggoner2 7,160,714 65.4 16,782,543
6605 Cypresswood Drive, Suite 250
Spring, TX 77379
------------------------------------------------------ ------------------ ----------------- ------------------
Patrick Parker 857,143 4.4 857,143
Scarbrough Building, 6th and Congress,
101 W. 6th St. Suite 610
Austin, TX 78701
------------------------------------------------------ ------------------ ----------------- ------------------
Douglas Moreland 1,428,571 7.2 1,428,571
1655 East Layton Drive
Englewood, CO 80110
------------------------------------------------------ ------------------ ----------------- ------------------
Stanley Chason 71,429 * 71,429
1230 Watervale Court,
Pasadena, MD 21122
------------------------------------------------------ ------------------ ----------------- ------------------
14
------------------------------------------------------ ------------------ ----------------- ------------------
Name and Address of Total Shares % of Ownership Total Shares
Selling Security Holder Registered Owned1
------------------------------------------------------ ------------------ ----------------- ------------------
XMen, LLC 1,714,286 8.9 1,714,286
520 Lake Cook Road, Suite105
Deerfield, IL 60015
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Bruce Goldstein 57,143 * 57,143
1934 Deercrest Lane
Northbrook, IL 60062
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Barry S. Cohn Revocable Trust 214,286 1.2 214,286
2505 Astor Court
Glenview, IL 60025
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Bargus Partnership 714,286 3.7 714,286
664 South Evergreen Ave
Woodbury Heights, NJ 08097
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Edwin J. Hagerty 371,429 2.0 371,429
5100 West Grove Dr.
Dallas, TX 75248
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Star-Tex Trading Company 285,713 * 370,381
16300 Addison Rd., Suite 300
Addison, TX 75001
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
ST Advisory Corp./John E. Loehr3 270,000 3.3 617,491
16300 Addison Rd., Suite 300
Addison, TX 75001
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Thomas R, Kaetzer4 325,000 3.9 733,852
480 N. Sam Houston Parkway, Suite 300
Houston, TX 77060
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Jim C. Bigham5 125,000 1.3 245,985
480 N. Sam Houston Parkway, Suite 300
Houston, TX 77060
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Marshall A. Smith III6 270,000 4.7 889,005
480 N. Sam Houston Parkway, Suite 300
Houston, TX 77060
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Intermarket Management LLC7 500,000 2.7 500,000
170 Broadway., Suite 1700
New York, NY 10038
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Star Investments , LTD 100,000 * 139,500
3421 Causeway Blvd., Suite 103
Metairie, LA 70002
------------------------------------------------------ ------------------ ----------------- ------------------
15
------------------------------------------------------ ------------------ ----------------- ------------------
Name and Address of Total Shares % of Ownership Total Shares
Selling Security Holder Registered Owned1
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Ray B. Nesbitt 150,000 * 393,333
1 Winston Woods
Houston, TX 77024
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
J. T. Thompson 40,000 * 40,000
1212 Woodhollow Drive, No. 15101
Houston, TX 77057
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Rick Gardner 100,000 * 100,000
1615 Poydras, 5th Floor
New Orleans, LA 70112
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Ron Zimmerman 60,000 * 60,000
1212 Woodhollow Drive, No. 15101
Houston, TX 77057
------------------------------------------------------ ------------------ ----------------- ------------------
------------------------------------------------------ ------------------ ----------------- ------------------
Steven M. Morris 500,000 * 500,000
P.O. Box 941828
Houston, TX 77094
------------------------------------------------------ ------------------ ----------------- ------------------
* Less than 1%
1 Includes shares registered hereunder.
2 Mr. Waggoner is Chairman of the Board of the Company. See "Management."
3 Mr. Loehr is Chief Executive Officer and a director of the Company. See "Management."
Reflects 270,000 shares issuable to Mr. Loehr pursuant immediately exercisable warrants and 200,000 shares
issuable upon exchange of preferred stock held by ST Advisory Corp. ST Advisory Corp. is owned by John E. Loehr.
4 Mr. Kaetzer is President, Chief Operating Officer and a director of the Company. See "Management."
5 Mr. Bigham is Vice President and Secretary of the Company. See "Management."
6 Mr. Smith is a director of the Company. See "Management."
7 Mr. M. Scott Manolis, one of our directors, is Chairman, Chief Executive Officer and an owner of this
Company. See "Management" and "Certain Relationships and Related Transactions."
16
PLAN OF DISTRIBUTION
The selling shareholders may, from time to time, sell all or a portion of
the shares of common stock on any market upon which the common stock may be
quoted (currently the OTC Bulletin Board), in privately negotiated transactions
or otherwise. Such sales may be at fixed prices prevailing at the time of sale,
at prices related to the market prices or at negotiated prices. The shares of
common stock being offered by this prospectus may be sold by the selling
shareholders using one or more of the following methods, without limitation:
(a) Block trades in which the broker or dealer so engaged will attempt to
sell the shares of common stock as agent but may position and resell a
portion of the block as principal to facilitate the transaction;
(b) purchases by broker or dealer as principal and resale by the broker or
dealer for its account pursuant to this prospectus;
(c) an exchange distribution in accordance with the rules of the
applicable exchange;
(d) ordinary brokerage transactions and transactions in which the broker
solicits purchasers;
(e) privately negotiated transactions;
(f) market sales (both long and short to the extent permitted under the
federal securities laws);
(g) at the market to or through market makers or into an existing market
for the shares;
(h) through transactions in options, swaps or other derivatives (whether
exchange listed or otherwise); and
(i) a combination of any aforementioned methods of sale.
In the event of the transfer by the selling shareholder of its shares to
any pledgee, donee or other transferee, we will amend this prospectus and the
registration statement of which this prospectus forms a part by the filing of a
post-effective amendment in order to have the pledgee, donee or other transferee
in place of the selling shareholder who has transferred his or her shares.
In effecting sales, brokers and dealers engaged by a selling shareholder
may arrange for other brokers or dealers to participate. Brokers or dealers may
receive commissions or discounts from the selling shareholder or, if any of the
broker-dealers act as an agent for the purchaser of such shares, from the
purchaser in amounts to be negotiated which are not expected to exceed those
customary in the types of transactions involved. Broker-dealers may agree with a
selling shareholder to sell a specified number of the shares of common stock at
a stipulated price per share. Such an agreement may also require the
broker-dealer to purchase as principal any unsold shares of common stock at the
price required to fulfill the broker-dealer commitment to the selling
shareholder if such broker-dealer is unable to sell the shares on behalf of the
selling shareholder. Broker-dealers who acquire shares of common stock as
principal may thereafter resell the shares of common stock from time to time in
transactions which may involve block transactions and sales to and through other
broker-dealers, including transactions of the nature described above. Such sales
by a broker-dealer could be at prices and on terms then prevailing at the time
of sale, at prices related to the then-current market price or in negotiated
transactions. In connection with such resales, the broker-dealer may pay to or
receive from the purchasers of the shares commissions as described above.
17
A selling shareholder and any broker-dealers or agents that participate
with that selling shareholder in the sale of the shares of common stock may be
deemed to be "underwriters" within the meaning of the Securities Act of 1933, as
amended, in connection with these sales. In that event, any commissions received
by the broker-dealers or agents and any profit on the resale of the shares of
common stock purchased by them may be deemed to be underwriting commissions or
discounts under the Securities Act of 1933, as amended.
From time to time, a selling shareholder may pledge its shares of common
stock pursuant to the margin provisions of its customer agreements with its
brokers. Upon a default by a selling shareholder, the broker may offer and sell
the pledged shares of common stock from time to time. Upon a sale of the shares
of common stock, the selling shareholders intend to comply with the prospectus
delivery requirements under the Securities Act of 1933 by delivering a
prospectus to each purchaser in the transaction. We intend to file any
amendments or other necessary documents in compliance with the Securities Act of
1933 which may be required in the event a selling shareholder defaults under any
customer agreement with brokers.
To the extent required under the Securities Act of 1933, a post effective
amendment to this registration statement will be filed, disclosing the name of
any broker-dealers, the number of shares of common stock involved, the price at
which the common stock is to be sold, the commissions paid or discounts or
concessions allowed to such broker-dealers, where applicable, that such
broker-dealers did not conduct any investigation to verify the information set
out or incorporated by reference in this prospectus and other facts material to
the transaction.
We and the selling shareholders will be subject to applicable provisions of
the Securities Exchange Act of 1934, as amended, and the rules and regulations
under it, including, without limitation, Rule 10b-5 and, insofar as a selling
shareholder is a distribution participant and we, under certain circumstances,
may be a distribution participant, under Regulation M. All of the foregoing may
affect the marketability of the common stock.
All expenses of the registration statement including, but not limited to,
legal, accounting, printing and mailing fees are and will be borne by us. Any
commissions, discounts or other fees payable to brokers or dealers in connection
with any sale of the shares of common stock will be borne by the selling
shareholder, the purchasers participating in such transaction, or both.
Any shares of common stock covered by this prospectus that qualify for sale
pursuant to Rule 144 under the Securities Act of 1933, as amended, may be sold
under Rule 144 rather than pursuant to this prospectus.
18
SELECTED HISTORICAL FINANCIAL DATA
The following table sets forth selected historical financial data of our
Company for the nine-month period ended September 30, 2004 and 2003, and as of
December 31, 2003, 2002, 2001, 2000 and 1999, and for each of the periods then
ended. See "Business" and "Management's Discussion and Analysis of Financial
Condition and Results of Operations." The income statement data for the years
ended December 31, 2003, 2002 and 2001 and the balance sheet data at December
31, 2003 and 2002 are derived from our audited financial statements contained
elsewhere herein. The income statement data for the years ended December 31,
2000 and 1999 and the balance sheet data at December 31, 2001, 2000 and 1999 are
derived from our Annual Report on Form 10-K for those periods. You should read
this data in conjunction with our consolidated financial statements and the
notes thereto included elsewhere herein.
(in thousands, except per share data)
Nine Month Period
Ended September 30,
(unaudited) Year Ended December 31
2004 2003 2003 2002 2001 2000 1999
------------------------------------------------------------------------------------------------------------
Income Statement
Data
-----------------
Operating
Revenues $7,876,941 $8,476,790 $11,010,723 $10,839,797 $12,990,581 $8,984,175 $2,812,639
Net income (loss)
from
operations 1,296,567 1,350,832 917,571 927,655 3,451,875 2,464,017 (1,464,094)
Net income (loss) 4,440,654 (1,510,681) (3,024,426) (4,502,313) 1,044,291 352,774 (2,269,506)
Dividends on
preferred stock (256,084) - (127,083) (112,500) (56,250) - (450,684)
Net income (loss)
available to
common
shareholders 4,184,570 (1,510,681) (3,151,509) (4,614,813) 988,401 352,774 (2,720,190)
Net income
(loss), per
share
of common
stock,
basic $.23 $(.08) $(.17) $(.25) $.05 $.02 $(.34)
Net income
(loss), per
share
of common
stock,
diluted $.14 $(.08) $(.17) $(.25) $.05 $.02 $(.34)
Weighted average
number
of shares of
common
stock
outstanding 18,492,541 18,492,541 18,492,541 18,492,541 18,464,343 17,293,848 7,953,147
Balance Sheet
Data
-----------------
Current assets $2,682,118 $1,932,956 $1,742,689 $2,353,046 $2,205,862 $2,934,804 $1,357,465
Total assets 53,163,515 51,827,422 52,428,774 53,088,941 51,379,209 32,374,128 20,009,793
Current
liabilities 12,647,876 43,750,817 44,619,652 43,998,566 12,492,365 7,594,986 4,650,691
Long-term
obligations 22,457,432 94,416 1,393,607 137,808 26,541,957 18,077,371 11,304,318
Other liabilities 3,013,131 641,796 591,467 1,128,993 - - -
Shareholders'
Equity $15,045,076 $7,338,393 $5,824,648 $7,823,574 $12,344,887 $6,701,771 $4,054,784
19
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS
You should read the following discussion in conjunction with our financial
statements and the notes thereto included elsewhere in this prospectus. This
discussion and analysis contains forward-looking statements within the meaning
of the federal securities laws. These forward-looking statements are subject to
risks and uncertainties that could cause actual results to differ materially
from historical results or our predictions. Please see "Risk Factors" and
"Forward-Looking Statements" for a discussion of the uncertainties, risks and
assumptions associated with these statements.
Overview
We are engaged primarily in the acquisition, development, exploitation,
exploration and production of crude oil and natural gas. Our focus is on
increasing production from our existing crude oil and natural gas properties
through the further exploitation, development and exploration of those
properties, and on acquiring additional interests in crude oil and natural gas
properties. Our gross revenues are derived from the following sources:
1. Oil and gas sales that are proceeds from the sale of crude oil and
natural gas production to midstream purchasers;
2. Operating overhead and other income that consists of earnings from
operating crude oil and natural gas properties for other working interest
owners, and marketing and transporting natural gas. This also includes earnings
from other miscellaneous activities.
3. Well servicing revenues that are earnings from the operation of well
servicing equipment under contract to other operators. During 2003, we worked
only for our own account.
The following is a discussion of our consolidated financial condition,
results of operations, financial condition and capital resources. You should
read this discussion in conjunction with our Consolidated Financial Statements
and the Notes thereto contained elsewhere herein. See "Financial Statements."
Results of Operations
The factors which most significantly affect our results of operations are
(1) the sales price of crude oil and natural gas, (2) the level of total sales
volumes of crude oil and natural gas, (3) the cost and efficiency of operating
our properties, (4) depletion and depreciation of oil and gas property costs and
related equipment, (5) the level of and interest rates on borrowings, (6) the
level and success of new acquisitions and development of existing properties,
and (7) the adoption of changes in accounting rules.
We consider depletion and depreciation of oil and gas properties and
related support equipment to be critical accounting estimates, based upon
estimates of oil and gas reserves.
The estimates of oil and gas reserves utilized in the calculation of
depletion and depreciation are estimated in accordance with guidelines
established by the Securities and Exchange Commission and the Financial
Accounting Standards Board, which require that reserve estimates be prepared
under existing economic and operating conditions with no provision for price and
cost escalations over prices and costs existing at year end, except by
contractual arrangements.
We emphasize that reserve estimates are inherently imprecise. Accordingly,
the estimates are expected to change as more current information becomes
available. Our policy is to amortize capitalized oil and gas costs on the unit
of production method, based upon these reserve estimates. It is reasonably
possible the estimates of future cash inflows, future gross revenues, the amount
of oil and gas reserves, the remaining estimated lives of the oil and gas
properties, or any combination of the above may be increased or reduced in the
near term. If reduced, the carrying amount of capitalized oil and gas properties
may be reduced materially in the near term.
20
Comparative results of operations for the periods indicated are discussed below.
Three-Month Period Ended September 30, 2004 compared to Three Month Period
Ended September 30, 2003.
Revenues
Oil and Gas Sales. Revenues from the sale of crude oil and natural gas for
the quarter increased 17% from $2,401,000 in 2003 to $2,816,400 in 2004 due to
higher commodity prices offset by lower production volumes and the sale of two
properties in West Texas and one property in Oklahoma. The lower production
volumes were due to the natural decline in production from our Gulf Coast
fields. We have implemented a development plan which should result in increased
production in future quarters.
Operating Overhead and Other Income. Revenues from these activities
decreased from $35,100 in 2003 to $(13,400) in 2004. This was due to
fluctuations in prices of natural gas in our imbalance accounts.
Costs and Expenses
Lease Operating Expenses. Lease operating expenses decreased 20% from
$1,434,000 in 2003 to $1,149,800 in 2004 due to lower production volumes and the
sale of two properties in West Texas and one property in Oklahoma.
Depreciation, Depletion and Amortization (DD&A). DD&A decreased 3% from
$540,300 in 2003 to $526,300 in 2004, due to lower commodity sales volumes.
General and Administrative (G&A) Expenses. G&A expenses increased 31% for
the period from $380,200 in 2003 to $498,200 in 2004, due to increased costs
related to our financing activities.
Interest Expense. Interest expense increased 37% from $756,200 in 2003 to
$1,036,600 in 2004, primarily due to a significant increase in our interest rate
following our refinancing.
Nine-Month Period Ended September 30, 2004 compared to Nine-Month Period
Ended September 30, 2003.
Revenues
Oil and Gas Sales. Revenues from the sale of crude oil and natural gas for
the period decreased 7% from $8,376,000 in 2003 to $7,811,400 in 2004 due to
lower production volumes and the sale of two properties in West Texas and one
property in Oklahoma. Our development plan to increase production did not start
until May 2004.
Operating Overhead and Other Income. Revenues from these activities
decreased 35% from $100,800 in 2003 to $65,600 in 2004. This was due to
fluctuations in prices of natural gas in our imbalance accounts.
21
Costs and Expenses
Lease Operating Expenses. Lease operating expenses decreased 11% from
$4,196,400 in 2003 to $3,749,000 in 2004 due to lower production volumes and the
sale of two properties in West Texas and one property in Oklahoma.
Depreciation, Depletion and Amortization (DD&A). DD&A decreased 18% from
$1,714,900 in 2003 to $1,402,500 in 2004, due to lower commodity sales volumes.
General and Administrative (G&A) Expenses. G&A expenses increased 13% for
the period from $1,214,700 in 2003 to $1,371,800 in 2004, due to increased costs
related to our financing activities.
Interest Expense. Interest expense increased 28% from $2,328,900 in 2003 to
$2,971,400 in 2004, due to a significant increase in our interest rate following
our refinancing.
Year Ended December 31, 2003 Compared to Year Ended December 31, 2002
Revenues
Oil and Gas Sales. Our operating revenues from the sale of crude oil and
natural gas increased by 4% from $10,447,000 in 2002 to $10,844,000 in 2003.
This increase was due to higher sales prices but offset by normal oil and gas
production declines. We were unable to offset the production declines through
development efforts because of limited development capital.
Well Servicing Revenues. There were no revenues from our well servicing
operations in 2003 compared to $39,000 in 2002 since we ceased performing work
for other operators and concentrated on our own properties.
Operating Overhead and Other Income. Revenues from these activities
decreased 53% from $354,000 in 2002 to $166,000 in 2003, primarily due to (1)
the loss of an oil and gas marketing contract and (2) lower pipeline volumes
resulting in less transportation revenue.
Costs and Expenses
Lease Operating Expenses. Lease operating expenses increased 2% from
$5,430,000 in 2002 to $5,528,000 in 2003 due to increased vendor prices and
increased production taxes.
Cost of Well Servicing Operations. There were no well servicing expenses in
2003 compared to $56,000 in 2002 since we did not work for other operators.
Depreciation, Depletion and Amortization (DD and A). DD and A decreased 17%
from $2,698,000 in 2002 to $2,226,000 in 2003, principally due to lower
production volumes. We also recorded income of $262,000 related to the
cumulative effect of adopting SFAS 143.
Accretion Expense. We recorded accretion expense of $77,000 as a result of
adopting SFAS 143 "Asset Retirement Obligation", effective January 1, 2003.
General and Administrative (G and A) Expenses. G and A expenses increased
31% from $1,728,000 in 2002 to $2,262,000 in 2003 due to expenses associated
with financing efforts that were not culminated.
Interest Income and Expense. Interest expense increased 6% from $3,159,000
in 2002 to $3,363,000 in 2003 due to penalty interest paid to our largest
lender.
22
Other Financing Costs. In 2003, we recorded an expense of $1,000,000 to
account for the issuance of 2,000 shares of our preferred stock to our largest
lender under a financial agreement.
Unrealized Gain (Loss) on Derivative Instruments. The estimated future fair
value of derivative instruments at December 31, 2003 resulted in an unrealized
gain of $537,000 in 2003 compared to an unrealized loss of $1,597,000 in 2002.
Dry Holes, Abandoned Property and Impaired Assets. The cost of abandoned
property in 2003 was $359,000 because the lack of capital to complete projects
resulted in the loss of leases. This compared to combined costs of dry holes,
abandoned property and impaired assets of $617,000 in 2002.
Dividends on Preferred Stock. In 2003, accrued and unpaid dividends on
preferred stock due were $127,000. In 2002, dividends on preferred stock due and
paid were $112,000.]
Depreciation, Depletion and Amortization (DD&A). DD&A decreased 3% from
$540,300 in 2003 to $526,300 in 2004, due to lower commodity sales volumes.
General and Administrative (G&A) Expenses. G&A expenses increased 31% for
the period from $380,200 in 2003 to $498,200 in 2004, due to increased costs
related to our financing activities.
Interest Expense. Interest expense increased 37% from $756,200 in 2003 to
$1,036,600 in 2004, primarily due to a significant increase in our interest rate
following our refinancing.
Year Ended December 31, 2002 Compared to Year Ended December 31, 2001
Revenues
Oil and Gas Sales. Our operating revenues from the sale of crude oil and
natural gas decreased by 16% from $12,426,000 in 2001 to $10,447,000 in 2002.
This decrease was due to normal oil and gas production declines of 6% and oil
and gas price declines of 10%.
Well Servicing Revenues. Revenues from our well servicing operations
decreased by 77% from $169,000 in 2001 to $39,000 in 2002. This decrease was due
to performing less work for third parties and the sale of one of our workover
rigs.
Operating Overhead and Other Income. Revenues from these activities
decreased 10% from $395,000 in 2001 to $354,000 in 2002, primarily as a result
of the termination of a gas transportation sales contract with a local utility.
Costs and Expenses
Lease Operating Expenses. Lease operating expenses increased 5% from
$5,155,000 in 2001 to $5,430,000 in 2002 due to increased vendor prices which
more than offset a decrease in production taxes.
Cost of Well Servicing Operations. Well servicing expenses decreased 69%
from $182,000 in 2001 to $56,000 in 2002 due to less work under contract to
third parties and the sale of one workover rig.
Depreciation, Depletion and Amortization (DD and A). DD and A increased 8%
from $2,491,000 in 2001 to $2,698,000 in 2002, due to a reduction in proved
reserves at year end 2002.
General and Administrative (G and A) Expenses. G and A expenses were
essentially unchanged from $1,710,000 in 2001 to $1,728,000 in 2002.
23
Interest Income and Expense. Interest expense increased 15% from $2,757,000
in 2001 to $3,159,000 in 2002 due to increased debt associated with the funding
of acquisitions in August, 2001, capital used in our development program and
issuance of warrants associated with working capital loans.
Unrealized Gain (Loss) on Derivative Instruments. The estimated future fair
value of derivative instruments at December 31, 2002 resulted in an unrealized
loss of $1,597,000 in 2002 compared to an unrealized gain of $4,215,000 in 2001.
Also in 2001, an unrealized loss of $3,747,000, resulting from the cumulative
effect of adopting SFAS No. 133 "Accounting for Derivative Instruments and Other
Hedging Activities," was recorded.
Dry Holes, Abandoned Property, Impaired Assets. The costs of a dry hole in
Louisiana of $339,000, abandoned property in Oklahoma of $222,000 and impaired
assets in Mississippi of $55,000 totaled $617,000 in 2002 compared to none in
2001.
Dividends on Preferred Stock. In 2002, dividends on Preferred Stock due and
paid were $112,000. Dividends on Preferred Stock due were $56,000 and paid were
$28,000 in 2001.
Financial Condition and Capital Resources
At September 30, 2004, our current liabilities exceeded our current assets
by $9,965,758. We had a loss of $4,835,708 for the quarter compared to a loss of
$399,457 for the period in 2003. The loss for 2004 included a non-cash loss of
approximately $1.9 million associated with the change in our estimate of the
fair value of our hedge, approximately $1.9 million loss on the sale of assets
and approximately $500,000 of amortization of expenses associated with our
refinancing.
During the third quarter of 2004, our sales volumes were 40,733 barrels of
crude oil and 272,611 Mcf of natural gas compared to 49,330 barrels of crude oil
and 263,561 Mcf of natural gas in the third quarter of 2003. Revenue for crude
oil sales for the period was $1,332,744 in 2004 compared to $1,176,604 in 2003
and for natural gas sales was $1,483,642 in 2004 compared to $1,224,363 in 2003.
During the nine-month period ended September 30, 2004 our sales volumes
were 127,530 barrels of oil and 756,614 Mcf of natural gas compared to 169,953
barrels of oil and 908,346 Mcf of natural gas for the period in 2003. Revenue
for crude oil sales for the period was $3,861,893 in 2004 compared to $4,076,097
in 2003 and for natural gas sales was $3,949,480 in 2004 compared to $4,299,889
in 2003.
On April 27, 2004, in our wholly-owned subsidiary, GulfWest Oil and Gas
Company, we completed an $18,000,000 financing package with a new energy lender.
We used $15,700,000 to retire existing debt of $27,584,145, resulting in
forgiveness of debt of $11,884,145. This taxable gain will be completely offset
by available net operating loss carryforwards. The term of the note is eighteen
months and it bears interest at the prime rate plus 11%. This rate increases by
.75% per month beginning in month ten. We paid the new lender $1,180,000 in cash
fees and also issued the new lender warrants to purchase 2,035,621 shares of our
common stock at an exercise price of $.01 per share, expiring in five years. The
warrants are subject to demand registration and anti-dilution provisions.
Simultaneously, our wholly-owned subsidiary, GulfWest Oil & Gas Company,
completed the initial phase of a private offering of its Series A Preferred
Stock for $4,000,000. The Series A Preferred Stock is exchangeable for our
Common Stock based on a liquidation value of $500 per share of Series A
Preferred Stock divided by $.35 per share of our Common Stock. As part of a fee
and commission, we issued $500,000 of the Series A Preferred Stock to a
financial advisor. One of our directors acquired $1,500,000 of the Series A
Preferred Stock.
24
Of the $21,500,000 total cash raised, we used $15,700,000 to pay existing
debt and $1,580,000 to pay fees and commissions, leaving $4,220,000 available
for capital expenditures and working capital.
As of September 30, 2004 we have incurred $2,983,787 in loan fees. This
includes lender fees of $1,540,000 ($1,180,000 paid in cash and a $360,000 fee
due at the termination of the loan), financial advisor fees of $1,150,000, which
includes the $500,000 of Series A Preferred Stock, and $293,787 for other
professional fees. Also, the lender charges a quarterly administrative fee of
$25,000. These costs are being amortized over the term of the loan and are
included in other financing costs.
In addition we issued the lender warrants valued at $916,029. The value of
the warrants is recorded as a note discount and is being expensed over the term
of the loan and included in interest expense.
Inflation and Changes in Prices
While the general level of inflation affects certain costs associated with
the petroleum industry, factors unique to the industry result in independent
price fluctuations. Such price changes have had, and will continue to have a
material effect on our operations; however, we cannot predict these
fluctuations.
The following table indicates the average crude oil and natural gas prices
received over the last three years by quarter. Average prices per barrel of oil
equivalent, computed by converting natural gas production to crude oil
equivalents at the rate of 6 Mcf per barrel, indicate the composite impact of
changes in crude oil and natural gas prices.
Average Prices
------------------------------------------------------------
Crude Oil Per
And Natural Equivalent
Liquids Gas Barrel
----------------- ---------------- ----------------
(per Bbl) (per Mcf)
2003
----
First $24.53 $5.36 $28.08
Second 23.53 4.47 25.04
Third 23.85 4.32 24.86
Fourth 24.99 4.56 25.02
2002
----
First $19.40 $2.81 $18.31
Second 20.75 3.16 19.83
Third 22.04 2.87 19.67
Fourth 22.38 3.56 22.11
2001
----
First $24.15 $5.27 $27.87
Second 24.14 3.88 23.71
Third 23.25 3.08 21.08
Fourth 19.94 2.62 17.96
25
Controls and Procedures
As of September 30, 2003, an evaluation was performed under the supervision
and with the participation of our management, including the CEO and Vice
President of Finance, of the effectiveness of the design and operation of our
disclosure controls and procedures. Based on that evaluation, our management,
including the CEO and Vice President of Finance, concluded that our disclosure
controls and procedures were effective as of September 30, 2004. There have been
no significant changes in our internal controls or in other factors that could
significantly affect internal controls subsequent to September 30, 2004.
Quantitative and Qualitative Disclosures About Market Risk
The following market rate disclosures should be read in conjunction with
the quantitative disclosures about market risk contained in the Company's 2003
annual report on Form 10-K, as well as with the consolidated financial
statements and notes thereto included in this Prospectus.
All of our financial instruments are for purposes other than trading. We
only enter derivative financial instruments in conjunction with its oil and gas
hedging activities.
Hypothetical changes in interest rates and prices chosen for the following
stimulated sensitivity effects are considered to be reasonably possible
near-term changes generally based on consideration of past fluctuations for each
risk category. It is not possible to accurately predict future changes in
interest rates and product prices. Accordingly, these hypothetical changes may
not be an indicator of probable future fluctuations.
Interest Rate Risk
We are exposed to interest rate risk on debt with variable interest rates.
At September 30, 2004, we carried variable rate debt of $28,885,455. Assuming a
one percentage point change at September 30, 2004 on our Company's variable rate
debt, the annual pretax income would change by $288,855.
Commodity Price Risk
In the past we have entered into and may in the future enter into certain
derivative arrangements with respect to portions of our oil and natural gas
production to reduce our sensitivity to volatile commodity prices. During 2003,
2002, and 2001, we entered into price swaps and put agreements. We believe that
these derivative arrangements, although not free of risk, allow us to achieve a
more predictable cash flow and to reduce exposure to price fluctuations.
However, derivative arrangements limit the benefit to us of increases in the
prices of crude oil and natural gas sales. Moreover, our derivative arrangements
apply only to a portion of our production and provide only partial price
protection against declines in price. Such arrangements may expose us to risk of
financial loss in certain circumstances. We expect that the daily volume of
derivative arrangements will vary from time to time. We continuously reevaluate
our derivative program in light of market conditions, commodity price forecasts,
capital spending and debt service requirements. For 2004, we have hedged
approximately 70% of our projected oil production and gas production.
Crude Oil Daily Volume Price per Bbl
--------- ------------ -------------
May 1, 2004 to October 31, 2005 329 Bbls $32.00
November 1, 2005 to April 30, 2006 (1) 231 Bbls $25.75 put
May 1, 2006 to October 31, 2006 (1) 198 Bbls $25.75 put
November 1, 2006 to April 30, 2007 (1) 165 Bbls $25.75 put
26
Natural Gas Daily Volume Price per MMBTU
----------- ------------ ---------------
May 1, 2004 to October 31, 2005 1,865 MMBTU $5.15
November 1, 2005 to April 30, 2006 (1) 1,698 MMBTU $4.50 put
May 1, 2006 to October 31, 2006 (1) 1,319 MMBTU $4.50 put
November 1, 2006 to April 30, 2007 (1) 989 MMBTU $4.50 put
(1) These are "put" derivative instruments we purchased and we will receive
the difference between the actual market price and the put price only if the
actual market price is below the put price. If the actual market price is equal
to or above the put price, we do not pay or receive any settlement amount.
Effective January 1, 2001, we adopted SFAS No. 133 "Accounting for
Derivative Instruments and Other Hedging Activities", as amended by SFAS No. 137
and No. 138. As a result of a financing agreement with an energy lender, we were
required to enter into an oil and gas hedging agreement with the lender. It has
been determined this agreement meets the definition of SFAS 133 "Accounting for
Derivative Instruments and Hedging Activities" and is accounted for as a
derivative instrument.
The estimated change in fair value of the derivatives is reported in Other
Income and Expense as unrealized (gain) loss on derivative instruments. The
estimated fair value of the derivatives is reported in Other Assets (or Other
Liabilities) as derivative instruments.
Oil and gas sales are adjusted for gains or losses related to the effective
portion of hedging transactions as the underlying hedged production is sold.
Changes in fair value of the ineffective portion of designated hedges or for
derivative arrangements that do not qualify as hedges are recognized in the
consolidated statement of income as derivative gain or loss. Adjustments to oil
and gas sales from our hedging activities resulted in a reduction in revenues of
$1,496,303, $368,776 and $762,480 in 2003, 2002 and 2001, respectively. In
addition, we recognized a gain/(loss) on derivatives of $537,526, ($1,596,575)
and $4,215,017 in 2003, 2002 and 2001, respectively. See Note 1 to our
Consolidated Financial Statements included in this Prospectus for additional
discussion on derivative instruments.
All hedges which were in existence at March 31, 2004 were canceled as part
of our debt restructuring on April 27, 2004. As of September 30, 2004, these
derivative instruments' liabilities had a fair value of $3,013,131. A
hypothetical change in oil and gas prices could have an effect on oil and gas
futures prices, which are used to estimate the fair value of our derivative
instrument. However, it is not practicable to estimate the resultant change, in
any, in the fair value of our derivative instrument.
More generally, dramatic price volatility in the natural gas and oil
markets has existed the past several years. In fact, the average quoted prices
for natural gas hovered around the low levels of $2.10 per MCf in January 2002,
with the expectation of further decreases. However, the market price
dramatically reversed in the summer months of 2002 and have continued to
improve, which lead natural gas to trade at an average NYMEX price of $5.44 per
MMBTU for 2003.
Financial Statements and Supplementary Data
Information with respect to this our financial statements and supplementary
data is contained in our financial statements beginning on Page F-1 of the
financial section of this Prospectus.
27
BUSINESS AND PROPERTIES
Our Business
This summary highlights selected information contained elsewhere in this
prospectus. The following summary does not contain all of the information that
may be important. You should read the detailed information appearing elsewhere
in this prospectus before making an investment decision. Certain terms that we
use in our industry are italicized and defined in the "Glossary of Industry
Terms and Abbreviations.". Unless otherwise indicated, all references to
"GulfWest", the "Company", "we", "us" and "our" refer to GulfWest Energy Inc.
and our subsidiaries.
We are primarily engaged in the acquisition, development, exploitation and
production of crude oil and natural gas. Our focus is on increasing production
from our existing properties through further exploitation, development and
exploration, and on acquiring additional interests in crude oil and natural gas
properties.
Since we made our first significant acquisition in 1993, we have
substantially increased our ownership in producing properties and the value of
our crude oil and natural gas reserves through a combination of acquisitions and
the further exploitation and development of our properties. At December 31,
2003, our part of the estimated proved reserves these properties contain was
approximately 5.0 million barrels (MBbl) of oil and 32.7 billion cubic feet
(Bcf) of natural gas with a Present Value discounted 10% (PV-10) of $114.4
million. At present, all of our properties are located on land in Texas,
Colorado, Louisiana and Oklahoma, except for the property on Grand Lake,
Louisiana. In the future, we plan to expand by acquiring additional properties
in those areas, and in similar properties located in other areas of the United
States.
Our operations are considered to fall within a single industry segment,
which is the acquisition, development, production and servicing of crude oil and
natural gas properties. See "Management's Discussion and Analysis of Financial
Condition and Results of Operations."
Our Company
We were formed as a corporation under the laws of the State of Utah in 1987
as Gallup Acquisitions, Inc., and subsequently changed our name to First
Preference Fund, Inc. and then to GulfWest Energy, Inc. We became a Texas
corporation by a merger effected in July 1992, in which our name became GulfWest
Oil Company. On May 21, 2001, we changed our name to GulfWest Energy Inc.
Our principal office is located at 480 North Sam Houston Parkway East,
Suite 300, Houston, Texas 77060 and our telephone number is (281) 820-1919.
GulfWest Energy Inc. has six active and three inactive, direct or indirect,
wholly owned subsidiaries: The active subsidiaries are:
1. GulfWest Oil and Gas Company, a Texas corporation, was organized
February 18, 1999 and is the owner of record of interests in certain crude oil
and natural gas properties located in Colorado, Texas, and Louisiana. It has one
wholly owned subsidiary, GulfWest Oil and Gas Company (Louisiana) LLC, a
Louisiana company, that was formed July 31, 2001 and is the owner of record of
interests in certain crude oil and natural gas properties in Louisiana.
2. SETEX Oil and Gas Company, a Texas corporation, was organized August 11,
1998 and is the operator of crude oil and natural gas properties in which we own
the majority working interest.
28
3. RigWest Well Service, Inc., a Texas corporation, was organized September
5, 1996 and operates well servicing equipment for our own account.
4. DutchWest Oil Company, a Texas corporation, was organized July 28, 1997
and is the owner of record of interests in certain crude oil and natural gas
properties located along the Gulf Coast of Texas.
5. GulfWest Development Company, a Texas corporation, was organized
November 9, 2000 and is the owner of record of interests in certain crude oil
and natural gas properties located in Texas and Mississippi.
Our Business Strategy
We have pursued a business strategy of acquiring interests in crude oil and
natural gas producing properties where production and reserves can be increased
through exploitation activities. Such activities include workovers, development
drilling, recompletions, replacement or addition of equipment and waterflood or
other secondary recovery techniques. We have expanded our business plan to
include an increased but controlled emphasis on development drilling for
additional crude oil and natural gas reserves. Key elements of our business
strategy include:
Continued Acquisition Program. We acquired properties in four crude oil and
natural gas fields in Texas and Louisiana in the year 2001. We intend to
continue to pursue interests in crude oil and natural gas properties (i) held by
small, under-capitalized operators and (ii) being divested by larger independent
and major oil and gas companies.
Development and Exploitation of Existing Properties. Our intent is to
increase crude oil and natural gas production and reserves of our existing
assets through relatively low-risk development activities, such as workovers,
recompletions, horizontal drilling from existing wellbores and infield drilling,
as well as the more efficient use of production facilities and the expansion of
existing waterflood operations.
Significant Operating Control. Currently, we are the operator of all the
wells, except two, in which we own working interests. This operating control
enables us to better manage the nature, timing and costs of development of such
wells, and marketing of the resulting production.
Ownership of Workover Rigs. We currently own three workover service rigs
and one swabbing unit that we operate for our own account. By owning and
operating this equipment, we are better able to control costs, quality of
operations and availability of equipment and services.
Greater Natural Gas Ownership. At December 31, 2003, our reserves were
comprised of 48% crude oil and 52% natural gas. We will continue to expand our
role in the domestic natural gas industry by (i) acquiring additional interests
in natural gas properties, (ii) increasing the production and reserve base of
our existing natural gas properties, and (iii) acquiring ownership of more
natural gas gathering systems and pipelines. We are presently focusing our
workover and development efforts on both crude oil and natural gas reserves to
take advantage of the higher prices of both commodities. We are also seeking to
expand our ownership of gas gathering systems and pipelines located in our main
field areas. Our goal is to have greater control of our natural gas
transportation and marketing, and an expanded role in the transportation of
natural gas produced by other parties in our area of operations.
Expanded Exploration and Exploitation Role. Historically, we have not
drilled exploratory wells due to the cost and risk associated with drilling
prospective locations. However, since the end of 1998, we have acquired
producing properties that have included significant acreage for prospective oil
and gas exploration. These include producing wells and acreage in Grimes,
Hardin, Jim Wells, Kimble, Madison, Palo Pinto, Refugio, Wharton and Zavala,
Counties, Texas; Adams, Arapaho, Elbert and Weld Counties, Colorado; Cameron
Parish, Louisiana; and Jones County, Mississippi. These acquisitions have added
existing natural gas and crude oil production to our asset base and, as
importantly, have provided us with immediate geological databases for drilling
opportunities. We have expanded our evaluation efforts in these fields and
intend to increase our development of reserves, not only through workovers of
existing wells, but by drilling additional wells.
29
Our Employees
At December 31, 2003, we had 34 full time employees, of whom 22 were field
personnel.
Our Properties
At December 31, 2003, we owned a total of 684 gross wells, of which 266
were producing, 351 were shut-in or temporarily abandoned and 67 were injection
or saltwater wells. We owned an average 94% working interest in the 266 gross
(249.90 net) producing wells. Gross wells are the total wells in which we own a
working interest. Net wells are the sum of the fractional working interests we
own in gross wells. Our part of the estimated proved reserves these properties
contain was approximately 5.0 million barrels (MBbl) of oil and 32.7 billion
cubic feet (Bcf) of natural gas. Substantially all of our properties are located
in Texas, Colorado, Louisiana and Oklahoma.
Proved Reserves
The following table reflects our estimated proved reserves at December 31
for each of the preceding three years.
2003 2002 2001
Crude Oil (MBbl)
Developed
Undeveloped 3,773 4,026 3,940
1,265 1,496 1,932
------------- ------------- -------------
Total
5,038 5,522 5,872
============= ============= =============
Natural Gas (MMcf)
Developed
Undeveloped 24,642 25,374 21,204
8,018 8,785 18,054
------------- ------------- -------------
Total 32,660 34,159 39,258
============= ============= =============
Total (MBOE) 10,481 11,215 12,415
============= ============= =============
(a) Approximately 75% of our total proved reserves were classified as
proved developed at December 31, 2003.
(b) Barrel of Oil Equivalent (BOE) is based on a ratio of 6,000 cubic feet
of natural gas for each barrel of oil.
30
Standardized Measure of Discounted Future Net Cash Flows
The following table sets forth as of December 31 for each of the preceding
three years, the estimated future net cash flow from and standardized measure of
discounted future net cash flows of our proved reserves, which were prepared in
accordance with the rules and regulations of the Securities and Exchange
Commission. Future net cash flow represents future gross cash flow from the
production and sale of proved reserves, net of crude oil and natural gas
production costs (including production taxes, ad valorem taxes and operating
expenses) and future development costs. The calculations used to produce the
figures in this table are based on current cost and price factors at December 31
for each year. We cannot assure you that the proved reserves will all be
developed within the periods used in the calculations or that prices and costs
will remain constant.
2003 2002 2001
-------------------- -------------------- -------------------
Future cash inflows $ 336,795,385 $ 308,381,837 $ 199,162,921
Future production and development costs-
Production 109,468,727 105,629,872 77,526,278
Development 21,460,459 23,350,811 23,610,596
-------------------- -------------------- -------------------
Future net cash flows before income taxes 205,866,199 179,401,154 98,026,047
Future income taxes (46,885,360) (38,611,577) (13,281,358)
-------------------- -------------------- -------------------
Future net cash flows after income taxes 158,980,839 140,789,577 84,744,689
10% annual discount for estimated timing
of cash flows (70,653,419) (63,165,742) (35,895,306)
Standardized measure of discounted
Future net cash flows(1) $ 88,327,420 $ 77,623,835 $ 48,849,383
==================== ==================== ===================
(1) The average prices of our proved reserves were $29.51 per Bbl and $5.82 per
Mcf, $28.72 per Bbl and $4.43 per Mcf, and $17.67 and $2.43 per Mcf at
December 31, 2003, 2002 and 2001 respectively.
Significant Properties
Summary information on our properties with proved reserves is set forth
below as of December 31, 2003.
Productive Wells Proved Reserves Present
--------------------------------------------------------------------------------------- ----------------
Gross Net Value (1)
Productive Wells Productive Crude Natural
Wells Oil Gas Total Amount
-------------- ------------- -------------------- -------------- ---------------- ---------------
(MBbl) (MMcf) (MBOE) ($M)
Texas 185 181.03 2,969 18,717 6,088 $ 67,235
Colorado 35 23.62 355 6,090 1,370 11,303
Oklahoma 28 28.00 150 - 150 1,301
Louisiana 17 16.88 1,558 7,853 2,867 34,484
Mississippi 1 .37 6 - 6 73
--------------- -------------- ----------------- -------------- --------------- ------------
Total 266 249.90 5,038 32,660 10,481 $ 114,396
================ ============= ================= ============== =============== ============
(1) The average prices of our proved reserves were $29.51 per Bbl and $5.82 per
Mcf at December 31, 2003.
31
All information set forth herein relating to our proved reserves, estimated
future net cash flows and present values is taken from reports prepared by
Pressler Petroleum Consultants, independent petroleum engineers. The estimates
of these engineers were based upon their review of production histories and
other geological, economic, ownership and engineering data provided by and
relating to us. No reports on our reserves have been filed with any federal
agency. In accordance with the Securities and Exchange Commission's guidelines,
our estimates of proved reserves and the future net revenues from which present
values are derived are made using year end crude oil and natural gas sales
prices held constant throughout the life of the properties (except to the extent
a contract specifically provides otherwise). Operating costs, development costs
and certain production-related taxes were deducted in arriving at estimated
future net revenues, but such costs do not include debt service, general and
administrative expenses and income taxes.
There are numerous uncertainties inherent in estimating crude oil and
natural gas reserves and their values, including many factors beyond our
control. The reserve data set forth in this report are based upon estimates.
Reservoir engineering is a subjective process, which involves estimating the
sizes of underground accumulations of crude oil and natural gas that cannot be
measured in an exact manner. The accuracy of any reserve estimate is a function
of the quality of available data, engineering and geological interpretation of
that data, and judgment. As a result, estimates of different engineers,
including those used by us, may vary. In addition, estimates of reserves are
subject to revision based upon actual production, results of future development,
exploitation and exploration activities, prevailing crude oil and natural gas
prices, operating costs and other factors. Such revisions may be material.
Accordingly, reserve estimates are often different from the quantities of crude
oil and natural gas that are ultimately recovered and are highly dependent upon
the accuracy of the assumptions upon which they are based. We cannot assure you
that the estimates contained in this report are accurate predictions of our
crude oil and natural gas reserves or their values. Estimates with respect to
proved reserves that may be developed and produced in the future are often based
upon volumetric calculations and upon analogy to similar types of reserves
rather than upon actual production history. Estimates based on these methods are
generally less reliable than those based on actual production history.
Subsequent evaluation of the same reserves based upon production history will
result in potentially substantial variations in the estimated reserves.
32
Production, Revenue and Price History
The following table sets forth information (associated with our proved
reserves) regarding production volumes of crude oil and natural gas, revenues
and expenses attributable to such production (all net to our interests) and
certain price and cost information for the years ended December 31, 2003, 2002
and 2001.
2003 2002 2001
---------------- ---------------- ----------------
Production
Oil (Bbl) 221,433 278,374 294,276
Natural gas (Mcf) 1,191,350 1,487,048 1,594,899
---------------- ---------------- ----------------
Total (BOE) 419,991 526,215 560,092
Revenue
Oil production $5,362,657 $5,859,568 $6,690,338
Natural gas production 5,481,803 4,587,601 5,735,765
---------------- ---------------- ----------------
Total $10,844,460 $10,447,169 $12,426,103
Operating Expenses $5,527,841 $5,430,205 $5,155,500
Production Data
Average sales price
Per barrel of oil $ 24.22 $ 21.05 $ 22.73
Per Mcf of natural gas 4.60 3.09 3.60
Per BOE 25.82 19.85 22.19
Average expenses per BOE
Lease operating 13.16 10.32 9.20
Depreciation, depletion and
amortization 5.30 5.13 4.45
General and administrative $ 5.39 $ 3.28 $ 3.05
Productive Wells at December 31, 2003
The following table shows the number of productive wells we own by
location:
Gross Net Gross Net
Oil Wells Oil Wells Gas Wells Gas Wells
------------ ------------ ------------- -----------
Texas 109 108.81 76 72.22
Colorado 22 14.37 13 9.25
Oklahoma 28 28.00 - -
Louisiana 13 12.88 4 4.00
Mississippi 1 .37 - -
------------ ------------ ------------- -----------
Total 173 164.43 93 85.47
============ ============ ============= ===========
33
Developed Acreage at December 31, 2003
The following table shows the developed acreage that we own, by location,
which is acreage spaced or assigned to productive wells. Gross acres are the
total acres in which we own a working interest. Net acres are the sum of the
fractional working interests we own in gross acres.
Gross Acres Net Acres
Texas 18,380 14,255
Colorado 5,000 2,700
Louisiana 1,695 1,256
Oklahoma 900 684
Total 25,975 18,895
Undeveloped Acreage at December 31, 2003
The following table shows the undeveloped acreage that we own, by location.
Undeveloped acreage is acreage on which wells have not been drilled or completed
to a point that would permit the production of commercial quantities of crude
oil and natural gas.
Gross Acres Net Acres
Texas 18,070 14,749
Colorado 10,000 6,000
Louisiana 80 55
Oklahoma 900 684
Total 29,050 21,488
Drilling Results
We did not drill any wells in 2003. In 2002, we drilled one exploratory
well, in which we own 18% working interest, that resulted in a dry hole and one
development well, in which we own 100% working interest, that is productive. We
drilled three wells in 2001, all of which were development wells and are
currently productive. These development wells included two horizontal wells, in
which we own 96% and 89% working interest, drilled by sidetracking from existing
wellbores in the Madisonville Field, Texas, and one well, in which we own 100%
working interest that was deepened in our Leona River Field, Texas.
Legal Proceedings
From time to time, we are involved in litigation relating to claims arising
out of our operations or from disputes with vendors in the normal course of
business. As of December 7, 2004, we were not engaged in any legal proceedings
that are expected, individually or in the aggregate, to have a material adverse
effect on us.
34
MANAGEMENT
The following table sets forth information on our directors and executive
officers:
Name Age Position Year First Elected
Director or Officer
J. Virgil Waggoner(1)(2) 77 Chairman of the Board 1997
John E. Loehr 59 Chief Executive Officer and 1992
Director
Thomas R. Kaetzer 46 President, Chief Operating 1998
Officer and Director
Marshall A. Smith III 57 Director 1989
M. Scott Manolis(1)(2) 50 Director 2003
Richard L. Creel 55 Vice President of Finance and 1998
Controller
Jim C. Bigham 69 Vice President and Secretary 1991
(1) Member of the Audit Committee.
(2) Member of the Compensation Committee.
J. Virgil Waggoner has served as a director of GulfWest since December 1,
1997 and was elected Chairman of the Board in May, 2002. Mr. Waggoner's career
in the petrochemical industry began in 1950 and included senior management
positions with Monsanto Company and El Paso Products Company, the petrochemical
and plastics unit of El Paso Company. He served as president and chief executive
officer of Sterling Chemicals, Inc. from the firm's inception in 1986 until its
sale and his retirement in 1996. He is currently chief executive officer of JVW
Investments, Ltd., a private company.
John E. Loehr was appointed Chief Executive Officer on May 12, 2004 and has
served as a director of GulfWest since 1992, was chairman of the board from
September 1, 1993 to July 8, 1998 and was chief financial officer from November
22, 1996 to May 28, 1998. He is also currently president and sole shareholder of
ST Advisory Corporation, an investment company, and vice-president of Star-Tex
Trading Company, also an investment company. He was formerly president of
Star-Tex Asset Management, a commodity-trading advisor, and a position he held
from 1988 until 1992 when he sold his ownership interest. Mr. Loehr is a CPA and
a member of the American Institute of Certified Public Accountants.
Thomas R. Kaetzer was appointed senior vice president and chief operating
officer of GulfWest on September 15, 1998 and on December 21, 1998 became
president and a director. He was Chief Executive Officer from March 20, 2001
until May12, 2004. Prior to joining GulfWest, Mr. Kaetzer had 17 years
experience in the oil and gas industry, including 14 years with Texaco Inc.,
which involved the evaluation, exploitation and management of oil and gas
assets. He has both onshore and offshore experience in operations and production
management, asset acquisition, development, drilling and workovers in the
continental U.S., Gulf of Mexico, North Sea, Colombia, Saudi Arabia, China and
West Africa. Mr. Kaetzer has a Masters Degree in Petroleum Engineering from
Tulane University and a Bachelor of Science Degree in Civil Engineering from the
University of Illinois.
35
Marshall A. Smith III founded GulfWest and served as an officer in various
capacities, including president, chief executive officer and chairman of the
board, from July 1989 until his resignation in May 2002. He is currently a paid
consultant and remains a director.
M. Scott Manolis is the chairman and chief executive officer of Intermarket
Management, LLC and Intermarket Brokerage, LLC. He has over twenty years
experience in commodity risk management, commodity finance and commodity-based
investments. Prior to founding Intermarket, Mr. Manolis concurrently served as
managing director of Commodity Strategies for Refco Group, LTD. and Managing
Director of Global Derivatives Strategies for Forstmann-Leff International (an
asset management firm wholly owned by Refco Group, LTD), where he directed
commodity-based investments. Prior to that, he served as a vice president and
director of the Commodity Portfolio Management Group at Jefferies & Company. He
received a B. S. in Economics from the University of South Dakota in 1979.
Richard L. Creel has served as controller of GulfWest since May 1, 1997 and
was elected vice president of finance on May 28, 1998. Prior to joining
GulfWest, Mr. Creel served as Branch Manager of the Nashville, Tennessee office
of Management Reports and Services, Inc. He has also served as controller of TLO
Energy Corp. He has extensive experience in general accounting, petroleum
accounting and financial consulting and income tax preparation.
Jim Bigham has served as secretary since 1991 and as executive vice
president of GulfWest since 1996. Prior to joining GulfWest, he held management
and sales positions in the real estate and printing industries. Mr. Bigham is
also a retired United States Air Force Major. During his military career, he
served in both command and staff officer positions in the operational,
intelligence and planning areas.
Directors are elected annually and hold office until the next annual
meeting or until their successors are duly elected and qualified.
Code of Ethical Conduct
The Board recently adopted a Code of Ethical Conduct (the "Code of
Conduct"), which requires that all employees, directors and officers, including
our Chief Executive Officer and Chief Financial Officer, adhere to the Code of
Conduct in addressing legal and ethical issues encountered in conducting their
work. The Code of Conduct requires that these individuals avoid conflict of
interests, comply with all laws and other legal requirements, conduct business
in an honest and ethical manner and otherwise act with integrity and in our best
interest. The Code of Conduct contains additional provisions that apply
specifically to our Chief Financial Officer and other financial officers with
respect to full and accurate reporting.
Board Meetings and Committees
Our board of directors has established an audit committee and a
compensation committee. The functions of these committees, their members and the
number of meetings held during 2003 are described below.
The audit committee was established to review and appraise the audit
efforts of our independent auditors, and monitor our accounts, procedures and
internal controls. The committee was comprised of Mr. John E. Loehr (Chairman),
Mr. J. Virgil Waggoner, and Mr. M. Scott Manolis. The committee met twice in
2003. The Board of Directors had made a determination that Mr. Loehr was an
independent financial expert. When Mr. Loehr was elected Chief Executive Officer
on May 12, 2004, he resigned from the audit committee. Mr. Manolis was elected
Chair of the audit committee and Mr. Marshall A. Smith III has been appointed to
that committee. The Board of Directors has not had an opportunity to conclude
whether the newly constituted audit committee has an independent financial
expert.
36
The function of the compensation committee is to fix the annual salaries
and other compensation for our officers and key employees. The committee was
comprised of Mr. J. Virgil Waggoner (Chairman), Mr. John E. Loehr and Mr. M.
Scott Manolis. The committee met twice in 2003. Mr. Loehr resigned from the
committee on May 12, 2004 when he became Chief Executive Officer.
Compensation of Directors
The shareholders approved an amended and restated Employee Stock Option
Plan on May 28, 1998, which included a provision for the payment of reasonable
fees in cash or stock to directors. No fees were paid to directors in 2003.
EXECUTIVE COMPENSATION
Summary Compensation Table
The following table sets forth information regarding compensation paid to
our executive officers whose total annual compensation is $100,000 or more
during each of the last three fiscal years.
Long Term
Compensation
Annual Compensation Awards
--------------------- ---------------
Other All
Other Annual Restricted
Year Compen- Stock Compen-
Name and Principal Position End Salary($) Bonus($) sation($) Awards($) Options(#) sation($)
--------------------------- --- --------- -------- --------- --------- ---------- ---------
Thomas R. Kaetzer (1) 2003 150,000 - 25,000 - -
President and 2002 144,167 - 25,000 - 100,000 -
Chief 2001 131,249 - 25,000 - 135,000 -
Executive Officer
Marshall A. Smith III (2) 2001 150,000 - - - - -
(1) Mr. Kaetzer joined us as chief operating officer in September, 1998, was
elected president in December, 1998 and chief executive officer on March
20, 2001. He receives a base annual salary $150,000, plus a $25,000 annual
contribution to a life insurance savings account paid monthly. He was also
awarded 5-year options to purchase 300,000 shares of common stock to be
issued 100,000 each year over a three year period.
(2) Mr. Smith served as chief executive officer until March 20, 2001 and as
chairman of the board until his resignation on May 11, 2002. As chairman of
the board, Mr. Smith devoted full time to the business. Effective June 1,
2002, he resigned as an executive officer and became a paid consultant at
an annual fee of $150,000, plus a $25,000 annual contribution to a life
insurance savings account to be paid monthly. His consulting agreement
expires September 30, 2004.
37
Option Grants During 2003
There were no options granted during 2003.
Option Exercises During 2003 and
Year End Option Values (1)
Number of Securities Value of Unexercised
Underlying Unexercised Options In-the-Money Options
at FY-End (#) at FY-End ($)
Exercisable/ Exercisable/
Name Unexercisable Unexercisable
---- ------------- -------------
Thomas R. Kaetzer 335,000 -0-
-0- -0-
(1) No shares were acquired or value realized upon the exercise of options
since no options were exercised by Mr. Kaetzer in 2003.
Compensation Committee Interlocks and Insider Participation
During fiscal year 2003, Messrs. Waggoner, Loehr and Manolis served on the
Compensation Committee. No interlocking relationship exists between any member
of the Board or Compensation Committee and any member of the Board or
Compensation Committee of any other company, nor has any such interlocking
relationship existed in the past.
38
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The following table sets forth information as of December 7, 2004 regarding
the beneficial ownership of common stock by each person known to us to own
beneficially 5% or more of the outstanding common stock, each director, certain
named executive officers, and the directors and executive officers as a group.
The persons named in the table have sole voting and investment power with
respect to all shares of common stock owned by them, unless otherwise noted.
Beneficial ownership is determined in accordance with the rules of the
Securities and Exchange Commission. For the purpose of calculating the number of
shares beneficially owned by a shareholder and the percentage ownership of that
shareholder, shares of common stock subject to options that are currently
exercisable or exercisable within 60 days of the date of this prospectus by that
shareholder are deemed outstanding.
Name and Address of Amount and Nature of Percent %
Beneficial Owner Beneficial Ownership
J. Virgil Waggoner1,2 16,782,543 65.4
Thomas R. Kaetzer2,3 733,852 3.9
Jim C. Bigham2,4 285,985 1.5
Richard L. Creel2,5 150,000 .8
John E. Loehr2,6 617,491 3.3
Marshall A. Smith III2,7 889,005 4.7
M. Scott Manolis2,8 500,000 2.7
All current directors and officers
as a group (8 persons)9 19,958,876 73.0
1 Includes 4,285,714 shares underlying exchangeable preferred stock,625,000
shares subject to currently exercisable warrants,225,000 underlying
convertible preferred stock and 20,000 shares subject to currently
exercisable options.
2 Shareholder's address is 480 N. Sam Houston Parkway East, Suite 300,
Houston, Texas 77060.
3 Includes 196,226 shares owned directly, 2,626 shares owned by his wife and
435,000 shares subject to currently exercisable warrants and options and
100,000 shares subject to currently exchangeable preferred stock.
4 Includes 235,000 shares subject to currently exercisable warrants and
options.
5 Includes 130,000 subject to currently exercisable options.
6 Includes 62,653 shares held directly; and 64,838 shares held by ST Advisory
Corporation and 290,000 shares subject to currently exercisable warrants
and options. Mr. Loehr is president and sole shareholder of ST Advisory
Corporation. 200,000 shares held by ST Advisory Corp subject to currently
exchangeable preferred stock.
7 Includes 596,046 shares owned directly, 2,959 shares owned by his wife and
290,000 shares subject to currently exercisable warrants and options.
8 Includes 500,000 shares held by Intermarket Management LLC subject to
currently exchangeable preferred stock .
9 Includes 1,236,754 shares subject to currently exercisable warrants and
options and 6,535,714 shares underlying convertible or exchangeable
preferred stock.
39
CERTAIN RELATIONSHIPS AND
RELATED TRANSACTIONS
Transactions With Management and Others
On October 23, 1995, we sold $25,000 each of 9% promissory notes in a
private offering to two trusts, the trustee of whom is John E. Loehr, an officer
and director. The balance of the notes was $50,000, plus accrued interest at
December 7, 2004.
In June, 1999, we issued a promissory note with interest at 8.5% to Mr.
Marshall A. Smith III, an officer and director at the time and currently a
director, in the amount of $124,083 for accrued compensation. The note has a
balance of $71,354 and is being paid in monthly installments of approximately
$1,500 per month.
On November 6, 2002, Mr. J. Virgil Waggoner, a director, provided us a loan
in the initial amount of $1,200,000, which was subsequently increased to a total
of $1,500,000, which is outstanding at December 7, 2004. We issued Mr. Waggoner
a promissory note with interest at the prime rate (prime rate 4.0% at May 26,
2004), secured by common stock our of wholly-owned subsidiary, DutchWest Oil
Company. Mr. Waggoner also received warrants to purchase 625,000 shares of our
Common Stock at an exercise price of $.75 per share. Those underlying shares are
included in this prospectus.
On April 26, 2001, we obtained a line of credit of up to $2,500,000 from a
bank for which two directors, Mr. J. Virgil Waggoner and Mr. Marshall A. Smith,
were guarantors. On April 3, 2002, the balance of the line of credit was retired
and a new line of credit of up to $3,000,000 was obtained from the bank for
which Mr. Waggoner and Mr. Smith were guarantors.
On March 5, 2004, we entered into an Option Agreement for the Purchase of
Oil and Gas Leases (the "Addison Agreement") with W. L. Addison Investments
L.L.C., a private company owned by Mr. J. Virgil Waggoner and Mr. John E. Loehr,
two of our directors, (`Addison"). Under the Addison Agreement, Addison agreed
to pay Summit, on our behalf, the non-recouped and outstanding advanced funds
amounting to $1,200,000, thereby retiring the Summit Agreement. For
consideration of such payment, Addison acquired certain oil and gas leases and
wellbores from Summit but agreed to grant us a 180-day redemption option (which
may be extended by mutual consent) to purchase the same for $1,200,000, plus
interest at the prime rate plus 2%. We tendered Addison a promissory note in the
amount of $600,000, with interest at the prime rate plus 2%, to substitute for
an account payable to Summit, pursuant to the Summit Agreement, in the same
amount. The note will be considered paid in full if we exercise the redemption
option and pay the $1,200,000, plus interest. Summit retained the right to
participate up to a 25% working interest in the drilling of any wells on the
leases acquired by Addison. In the event we exercise the redemption option,
Addison may, at its sole option, retain up to a 25% working interest in the
leases.
As part of our recent refinancing, our former lender agreed to return all
2000 shares of our Series F Preferred Stock held by it. Rather than receive the
shares as treasury shares (which would have meant cancellation of the series) at
our request the former lender transferred 400 of the shares to ST Advisory
Corp., an entity owned by John Loehr, our CEO and a director, 400 of the shares
to a financial advisor to the Company, and 200 of the shares to Thomas R.
Kaetzer, our President and Director and 1000 shares to Intermarket Management
LLC, an entity partially owned by M. Scott Manolis, one of our directors. These
transfers were to compensate the financial advisor and Mr. Loehr, Kaetzer and
Manolis for service to the Company.
40
DESCRIPTION OF SECURITIES
General
The following descriptions are summaries of material terms of our common
stock, preferred stock, articles of incorporation and bylaws. This summary is
qualified by reference to our articles of incorporation, bylaws and the
designations of our preferred stock, which have been previously filed as
exhibits to our public filings with the Securities and Exchange Commission, and
by the provisions of applicable law.
On July 8, 2004, at the Annual Meeting of Shareholders, our shareholders
increased the amount of shares we are authorized to issue from 40,000,000 to
80,000,000 shares of common stock, par value $.001 per share. As of December 7,
2004, there were 18,593,969 shares of our sole class of common stock, designated
Class A, issued and outstanding, and held by approximately 625 beneficial
owners. Our common stock is traded over-the-counter (OTC) under the symbol
"GULF". Fidelity Transfer Company, 1800 South West Temple, Suite 301, Box 53,
Salt Lake City, Utah 84115, (801) 484-7222 is the transfer agent for the common
stock.
Our Common Stock
The holders of our common stock are entitled, among other things, to one
vote per share on each matter submitted to a vote of shareholders and, in the
event of liquidation, to share ratably in the distribution of assets remaining
after payment of liabilities (including preferential distribution and dividend
rights of holders of preferred stock). They have no cumulative voting rights,
and, accordingly, the holders of a majority of the outstanding shares of the
common stock have the ability to elect all of the directors.
Holders of common stock have no preemptive or other rights to subscribe for
shares. Holders of common stock are entitled to such dividends as may be
declared by the Board out of funds legally available therefore. We have never
paid cash dividends on the common stock and do not anticipate paying any cash
dividends in the foreseeable future.
Our Preferred Stock
Our board of directors is authorized, without further shareholder action,
to issue preferred stock in one or more series and to designate the dividend
rate, voting rights and other rights, preferences and restrictions of each such
series.
As of December 7, 2004, there was a total of 18,940 shares of preferred
stock issued and outstanding in three series, including 8,000 shares of Series D
Preferred Stock, 9,000 shares of Series E Preferred Stock and 1,940 shares of
Series F Preferred Stock (collectively, "Preferred Stock"). The 8,000 shares of
Series D Preferred Stock are held by a former director, the 9,000 shares of
Series E Preferred Stock are held by a current director and the 1,940 shares of
Series F are held by a financial advisor to the Company, two private investors,
an officer and two companies affiliated with two directors. See "Certain
Relationships and Related Transactions." On a fully converted basis, the 8,000
shares of Series D Preferred Stock would convert to 500,000 shares of common
stock. On a fully converted basis, the 9,000 shares of Series E Preferred Stock
would convert to 2,250,000 shares of common stock. On a fully converted basis,
the 1,940 shares of Series F Preferred Stock would convert to 970,000 shares of
common stock.
The Series D Preferred Stock is not entitled to dividends, nor is it
redeemable, however it is convertible to common stock at any time. None of the
8,000 outstanding shares of Series D Preferred Stock has been converted. On a
fully converted basis, the 8,000 shares of Series D Preferred Stock would
convert to 500,000 shares of common stock.
41
The Series E Preferred Stock is entitled to receive dividends at the rate
of $12.50 per share per annum, payable quarterly, as declared by the Board of
Directors, until June 20, 2004 when the dividend rate shall be increased to
$30.00 per share per annum. The Board of Directors did not declare payment of
dividends during 2003. The Series E Preferred Stock is redeemable in whole or in
part at any time, at the option of the issuer, at a price of $500 per share,
plus all accrued and undeclared or unpaid dividends; except that, prior to our
redemption of the remaining, the holders of record shall be given a 60-day
written notice of the issuer's intent to redeem and the opportunity to convert
the Series E Preferred Stock to common stock. The conversion price for the
Series E Preferred Stock is based on $2.00 per share of common stock. None of
the 9,000 outstanding shares of Series E Preferred Stock has been redeemed or
converted. On a fully converted basis, the 9,000 shares of Series E Preferred
Stock would convert to 2,250,000 shares of common stock.
The Series F Preferred Stock is entitled to receive dividends at the rate
of $12.50 per share per annum, payable quarterly, as declared by the Board of
Directors, until May 30, 2006 when the dividend rate shall be increased to
$30.00 per share per annum. The Series F Preferred Stock is redeemable in whole
or in part at any time, at the option of the issuer, at a price of $500 per
share, plus all accrued and undeclared or unpaid dividends; except that, after
two years from the date of the original issuance, June 1, 2003, prior to our
redemption of the remaining shares, the holders of record shall be given a
60-day written notice of the issuer's intent to redeem and the opportunity to
convert the Series F Preferred Stock to common stock. The conversion price for
the Series F Preferred Stock is based on $1.00 per share of common stock. As of
December 7, 2004, 60 shares of Series F Preferred Stock have been converted. On
a fully converted basis, the remaining 1,940 shares of Series F Preferred Stock
would convert to 970,000 shares of common stock.
Outstanding Options and Warrants
At December 7, 2004, we had outstanding warrants and options for the
purchase of 5,999,621 shares of common stock at prices ranging from $.01 to
$.875 per share, including employee stock options to purchase 1,999,000 shares
at prices ranging from $.45 to $1.81 per share. If we issue additional shares,
the existing shareholders' percentage ownership of the Company may be further
diluted.
Anti-Takeover Effects of Texas Laws and Our Charter and Bylaws Provisions
Articles of Incorporation and Bylaws. Certain provisions in our Articles of
Incorporation and Bylaws summarized below may be deemed to have an anti-takeover
effect and may delay, deter or prevent a tender offer or takeover attempt that a
shareholder might consider to be in its best interests, including attempts that
might result in a premium being paid over the market price for the shares held
by shareholders.
Our Articles of Incorporation and Bylaws contain provisions that:
o permit us to issue, without any further vote or action by the
shareholders, additional shares of preferred stock in one or more
series and, with respect to each such series, to fix the number of
shares constituting the series and the designation of the series, the
voting powers (if any) of the shares of the series, and the
preferences and relative, participating, optional and other special
rights, if any, and any qualification, limitations or restrictions, of
the shares of such series; and
42
o Require consent of shareholders owning over 50% of the outstanding
common stock to call special meetings.
The foregoing provisions of our Articles of Incorporation and Bylaws could
discourage potential acquisition proposals and could delay or prevent a change
in control. These provisions are intended to enhance the likelihood of
continuity and stability in the composition of the board of directors and in the
policies formulated by the board of directors and to discourage certain types of
transactions that may involve an actual or threatened change of control. These
provisions are designed to reduce our vulnerability to an unsolicited
acquisition proposal. The provisions also are intended to discourage certain
tactics that may be used in proxy fights. However, such provisions could have
the effect of discouraging others from making tender offers for our shares and,
as a consequence, they also may inhibit fluctuations in the market price of our
common stock that could result form actual or rumored takeover attempts. Such
provisions also may have the effect of preventing changes in our management.
Texas Takeover Statute. We are subject to Article 13.03 of the Texas
Business Corporation Act, which, subject to certain exceptions, prohibits a
Texas corporation from engaging in any "business combination" (as defined below)
with any "affiliated shareholder" (as defined below) for a period of three years
following the date that such shareholder became an affiliated shareholder,
unless: (i) prior to such date, the board of directors of the corporation
approved either the business combination or the transaction that resulted in the
shareholder becoming an affiliated shareholder; or (ii) not more than six months
subsequent to such date, the business combination is approved by the affirmative
vote of at least 66 2/3% of the outstanding voting stock that is not owned by
the affiliated shareholder.
The Texas Business Corporation Act defines "business combination" to
include: (i) any merger, share exchange or conversion involving the corporation
and the affiliated shareholder or an affiliate; (ii) any sale, transfer, pledge
or other disposition of 10% or more of the assets of the corporation involving
the affiliated shareholder or an affiliate; (iii) subject to certain exceptions,
any transaction that results in the issuance or transfer of the corporation of
any stock of the corporation to the affiliated shareholder or an affiliate; (iv)
the adoption of a plan of liquidation or dissolution proposed by or under an
agreement with, the affiliated shareholder or an affiliate; (v) any transaction
involving the corporation that has the effect of increasing the proportionate
share of the stock of any class or series of the corporation beneficially owned
by the affiliated shareholder; or (vi) the receipt by the affiliated shareholder
of the benefit of any loans, advances, guarantees, pledges or other financial
benefits provided by or through the corporation. In general, an "affiliated
shareholder" is any entity or person beneficially owning 20% or more of the
outstanding voting stock of the corporation.
Limitation on Liability of Directors
Our articles of incorporation and bylaws indemnify our directors to the
fullest extent permitted by the Texas Business Corporation Act. Article 2.01 of
the Texas Business Corporation Act provides that a corporation may indemnify a
person who was, is, or is threatened to be made a named defendant or respondent
in a proceeding because the person is or was a director only if it is determined
that the person:
(1) conducted himself in good faith;
(2) reasonably believed:
(a) in the case of conduct in his official capacity as a
director of the corporation, that his conduct was in the
corporation's best interests; and
(b) in all other cases, that his conduct was at least not
opposed to the corporation's best interests; and
43
(3) in the case of any criminal proceeding, had no reasonable cause to
believe his conduct was unlawful.
Except to a limited extent, a director may not be indemnified in respect of
a proceeding:
(1) in which the person is found liable on the basis that personal benefit
was improperly received by him, whether or not the benefit resulted from an
action taken in the person's official capacity; or
(2) in which the person is found liable to the corporation.
Additionally, our Articles of Incorporation limit a director's liability to
the company to the fullest extent permitted by the Texas Business Corporation
Act. The Texas laws permit a corporation to limit or eliminate a director's
personal liability to the corporation or the holders of its capital stock for
breach of duty. This limitation is generally unavailable to the extent the
director is found liable for: (1) a breach of the director's duty of loyalty to
the corporation or its shareholders or members; (2) an act or omission not in
good faith that constitutes a breach of duty of the director to the corporation
or an act or omission that involves intentional misconduct or a knowing
violation of the law; (3) a transaction from which the director received an
improper benefit, whether or not the benefit resulted from an action taken
within the scope of the director's office; or (4) an act or omission for which
the liability of a director is expressly provided by an applicable statute. The
Texas laws also prohibit limitations on director liability for acts or omissions
which resulted in a violation of a statute prohibiting certain dividend
declarations and certain payments after dissolution. The effect of these
provisions is to eliminate the rights of our company and our shareholders
(through shareholders' derivative suits on behalf of our company) to recover
monetary damages against a director for breach of fiduciary duty as a director
excepting the situations described above. These provisions will not limit the
liability of directors under the federal securities laws of the United States.
44
GLOSSARY OF INDUSTRY TERMS AND ABBREVIATIONS
The following are definitions of certain industry terms and abbreviations
used in this report:
Bbl. Barrel.
BOE. Barrel of oil equivalent, based on a ratio of 6,000 cubic feet of
natural gas for each barrel of oil.
Gross Acres or Gross Wells. The total acres or wells, as the case may be,
in which a working interests is owned.
Horizontal Drilling. High angle directional drilling with lateral
penetration of one or more productive reservoirs.
Mcf. One thousand cubic feet.
Net Acres or Net Wells. The sum of the fractional working interests owned
in gross acres or gross wells.
Overriding Royalty Interest. The right to receive a share of the proceeds
of production from a well, free of all costs and expenses, except transportation
and severance taxes.
Present Value. The pre-tax present value, discounted at 10%, of future net
cash flows from estimated proved reserves, calculated holding prices and costs
constant at amounts in effect on the date of the report (unless such prices or
costs are subject to change pursuant to contractual provisions) and otherwise in
accordance with the Commission's rules for inclusion of oil and gas reserve
information in financial statements filed with the Commission.
Proceeds of Production. Money received (usually monthly) from the sale of
oil and gas produced from producing properties.
Producing Properties. Properties that contain one or more productive wells.
Productive Well. A well that is producing oil or gas or that is capable of
production.
Prospect. A lease or group of leases containing possible reserves, capable
of producing crude oil, natural gas, or natural gas liquids in commercial
quantities, either at the time of acquisition, or after vertical or horizontal
drilling, completion of workovers, recompletions, or operational modifications.
Proved Reserves. Estimated quantities of crude oil, natural gas, and
natural gas liquids that geological and engineering data demonstrate with
reasonable certainty to be recoverable in future years from known reservoirs
under existing economic conditions; i.e., prices and costs as of the date the
estimate is made. Reservoirs are considered proved if either actual production
or a conclusive formation test supports economic production.
The area of a reservoir considered proved includes:
a. That portion delineated by drilling and defining by gas-oil or oil-water
contacts, if any; and
b. The immediately adjoining portions not yet drilled but which can be
reasonably judged as economically productive on the basis of available
geological and engineering data. In the absence of information on fluid
contacts, the lowest known structural occurrence of hydrocarbons controls the
lower proved limit of the reservoir.
45
Reserves which can be produced economically through application of improved
recovery techniques (such as fluid injection) are included in the "proved"
classification when successful testing by a pilot project, or the operation of
an installed program in the reservoir, provides support for the engineering
analysis on which the project or program was based.
Proved Reserves do not include:
a. Oil that may become available from known reservoirs but is classified
separately as "indicated additional reserves";
b. Crude oil, natural gas, and natural gas liquids, the recovery of which
is subject to reasonable doubt because of uncertainty as to geology, reservoir
characteristics, or economic factors;
c. Crude oil, natural gas, and natural gas liquids that may occur in
undrilled prospects; and
d. Crude oil, natural gas, and natural gas liquids that may be recovered
from oil shales and other sources.
Proved Developed Reserves. Reserves that can be expected to be recovered
through existing wells with existing equipment and operating methods. Additional
oil and gas expected to be obtained through the application of fluid injection
or other improved recovery techniques for supplementing the natural forces and
mechanisms of primary recovery should be included as proved developed only after
testing by a pilot project or after operation of an installed program has
confirmed through production response that increased recovery will be achieved.
Proved Undeveloped Reserves. Reserves that are expected to be recovered
from new wells on undrilled acreage or from existing wells where a relatively
major expenditure is required for recompletion. Reserves on undrilled acreage
shall be limited to those drilling units offsetting productive units that are
reasonably certain of production when drilled. Proved reserves for other units
that have not been drilled can be claimed only where it can be demonstrated with
certainty that there is continuity of production from the existing productive
formation. Under no circumstances should estimates for proved undeveloped
reserves be attributable to any acreage for which an application of fluid
injection or other improved recovery technique is contemplated, unless such
techniques have been proven effective by actual tests in the area and in the
same reservoir.
Recompletion. The completion for production of an existing wellbore in
another formation from that in which the well has previously been completed.
Reservoir. A porous and permeable underground formation containing a
natural accumulation of producible oil or gas that is confined by impermeable
rock or water barriers and is individual and separate from other reservoirs.
Royalty. The right to a share of production from a well, free of all costs
and expenses, except transportation.
Royalty Interest. An interest in an oil and gas property entitling the
owner to a share of oil and natural gas production free of costs of production.
46
Standardized Measure. The present value, discounted at 10%, of future net
cash flows from estimated proved reserves, after income taxes, calculated
holding prices and costs constant at amounts in effect on the date of the report
(unless such prices or costs are subject to change pursuant to contractual
provisions) and otherwise in accordance with the Commission's rules for
inclusion of oil and gas reserve information in financial statements filed with
the Commission.
Waterflood. An engineered, planned effort to inject water into an existing
oil reservoir with the intent of increasing oil reserve recovery and production
rates.
Working Interest. The operating interest under a lease, the owner of which
has the right to explore for and produce oil and gas covered by such lease. The
full working interest bears 100 percent of the costs of exploration,
development, production, and operation, and is entitled to the portion of gross
revenue from the proceeds of production which remains after proceeds allocable
to royalty and overriding royalty interests or other lease burdens have been
deducted.
Workover. Rig work performed to restore an existing well to production or
improve its production from the current existing reservoir.
LEGAL MATTERS
The validity of the securities offered by this prospectus will be passed
upon for us by Jackson Walker L.L.P., Dallas, Texas.
EXPERTS
The consolidated financial statements of GulfWest Energy Inc. and
subsidiaries have been included herein and in the registration statement filed
in connection with this offering in reliance upon the report of Weaver and
Tidwell, L.L.P., independent certified public accountants, appearing elsewhere
herein and upon the authority of said firm as experts in accounting and
auditing.
Our oil and gas reserves have been reviewed by our independent reserve
engineers, Pressler Petroleum Consultants. Our disclosures of our oil and gas
reserves included in this prospectus have been presented in reliance upon the
authority of such firm as experts in petroleum engineering.
47
INDEX TO FINANCIAL STATEMENTS
Page
INDEPENDENT AUDITOR'S REPORT ON THE FINANCIAL
STATEMENTS.............................................................................. F-2
FINANCIAL STATEMENTS
Consolidated balance sheets............................................................. F-3
Consolidated statements of operations................................................... F-5
Consolidated statements of shareholders' equity......................................... F-6
Consolidated statements of cash flows................................................... F-8
Notes to consolidated financial statements.............................................. F-9
INDEPENDENT AUDITOR'S REPORT ON THE FINANCIAL STATEMENT SCHEDULE........................ F-36
FINANCIAL STATEMENT SCHEDULE............................................................ F-37
Schedule II - Valuation and Qualifying Accounts
All other Financial Statement Schedules have been omitted because they are either
inapplicable or the information required is included in the financial statements or
the notes thereto.
F-1
INDEPENDENT AUDITOR'S REPORT
To the Shareholders and
Board of Directors
GULFWEST ENERGY INC.
We have audited the accompanying consolidated balance sheets of GulfWest
Energy Inc. (a Texas Corporation) and Subsidiaries as of December 31, 2003 and
2002, and the related consolidated statements of operations, shareholders'
equity and cash flows for each of the three years in the period ended December
31, 2003. These consolidated financial statements are the responsibility of the
Company's management. Our responsibility is to express an opinion on these
consolidated financial statements based on our audits.
We conducted our audits in accordance with auditing standards generally
accepted in the United States of America. Those standards require that we plan
and perform the audit to obtain reasonable assurance about whether the
consolidated financial statements are free of material misstatement. An audit
includes examining, on a test basis, evidence supporting the amounts and
disclosures in the consolidated financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above
present fairly, in all material respects, the consolidated financial position of
GulfWest Energy Inc. and Subsidiaries as of December 31, 2003 and 2002, and the
consolidated results of their operations and their cash flows for each of the
three years in the period ended December 31, 2003, in conformity with accounting
principles generally accepted in the United States of America.
The accompanying consolidated financial statements have been prepared
assuming that the Company will continue as a going concern. As shown in the
consolidated financial statements, the Company incurred a net loss of $3,151,509
during the year ended December 31, 2003, and, as of that date, had a working
capital deficiency of $42,876,963. Those conditions raise substantial doubt
about the Company's ability to continue as a going concern. Management's plans
regarding those matters described in Note 2, "Operations and Management Plans".
The consolidated financial statements do not include any adjustments that might
result from the outcome of this uncertainty.
As explained in Note 1 to the Financial Statements, effective January 1,
2003, the Company changed its accounting method for Asset Retirement
Obligations.
\s\WEAVER AND TIDWELL, L.L.P
----------------------------
WEAVER AND TIDWELL, L.L.P.
Dallas, Texas
March 19, 2004
F-2
GULFWEST ENERGY INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
DECEMBER 31, 2003 AND 2002
ASSETS
---------------- ----------------
2003 2002
---------------- ----------------
CURRENT ASSETS
Cash and cash equivalents $ 483,618 $ 687,694
Accounts receivable - trade, net of allowance
for doubtful accounts of $-0- in 2003 and 2002 1,099,802 1,361,446
Prepaid expenses 159,269 303,906
---------------- ----------------
Total current assets 1,742,689 2,353,046
---------------- ----------------
OIL AND GAS PROPERTIES,
using the successful efforts method of accounting 58,472,886 56,786,043
OTHER PROPERTY AND EQUIPMENT 2,132,220 2,121,410
Less accumulated depreciation, depletion and amortization (10,017,931) (8,498,497)
---------------- ----------------
Net oil and gas properties and other property and equipment 50,587,175 50,408,956
---------------- ----------------
OTHER ASSETS
Deposits 20,142 37,442
Debt issue cost, net 78,768 289,497
---------------- ----------------
Total other assets 98,910 326,939
---------------- ----------------
TOTAL ASSETS $ 52,428,774 $ 53,088,941
================ ================
The Notes to Consolidated Financial Statements are an integral part of these statements.
F-3
LIABILITIES AND SHAREHOLDERS' EQUITY
---------------- -----------------
2003 2002
---------------- -----------------
CURRENT LIABILITIES
Notes payable $8,182,165 $ 4,936,088
Notes payable - related parties 1,465,000 1,290,000
Current portion of long-term debt 29,396,092 33,128,447
Current portion of long-term debt - related parties 130,152 256,967
Accounts payable - trade 5,002,675 3,928,477
Accrued expenses 443,568 458,587
---------------- ----------------
Total current liabilities 44,619,652 43,998,566
---------------- ----------------
NONCURRENT LIABILITIES
Long-term debt, net of current portion 35,801 126,552
Long-term debt - related parties - 11,256
Asset retirement obligations 1,357,206 -
---------------- ----------------
Total noncurrent liabilities 1,393,007 137,808
---------------- ----------------
OTHER LIABILITIES
Derivative instruments 591,467 1,128,993
---------------- ----------------
Total Liabilities 46,604,126 45,265,367
---------------- ----------------
COMMITMENTS AND CONTINGENCIES
SHAREHOLDERS' EQUITY
Preferred stock 190 170
Common stock 18,493 18,493
Additional paid-in capital 29,283,692 28,258,212
Retained deficit (23,477,727) (20,453,301)
---------------- ----------------
Total shareholders' equity 5,824,648 7,823,574
---------------- ----------------
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY $52,428,774 $53,088,941
The Notes to Consolidated Financial Statements are an integral part of these statements.
F-4
GULFWEST ENERGY INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
FOR THE YEARS ENDED DECEMBER 31, 2003, 2002 AND 2001
2003 2002 2001
---------------- ---------------- -----------------
OPERATING REVENUES
Oil and gas sales $10,844,460 $10,447,169 $ 12,426,103
Well servicing revenues
- 39,116 169,167
Operating overhead and other income
166,263 353,512 395,311
---------------- ---------------- ----------------
Total Operating Revenues 11,010,723 10,839,797 12,990,581
---------------- ---------------- ----------------
OPERATING EXPENSES
Lease operating expenses
5,527,841 5,430,205 5,155,500
Cost of well servicing operations
- 56,295 182,180
Depreciation, depletion and amortization 2,226,123 2,697,784 2,491,385
Accretion expense 76,823 - -
General and administrative 2,262,425 1,727,858 1,709,641
---------------- ---------------- ----------------
Total Operating Expenses 10,093,212 9,912,142 9,538,706
---------------- ---------------- ----------------
INCOME FROM OPERATIONS 917,511 927,655 3,451,875
---------------- ---------------- ----------------
OTHER INCOME AND EXPENSE
Interest expense (3,363,330) (3,159,381) (2,756,912)
Gain (Loss) on sale of assets (19,848) (56,647) (118,254)
Unrealized gain (loss) on derivative instruments 537,526 (1,596,575) 4,215,017
Dry holes, abandoned property and impaired assets (358,737) (617,365) -
---------------- ---------------- ----------------
Total Other Income and (Expense) (4,204,389) (5,429,968)
---------------- ---------------- ----------------
INCOME (LOSS) BEFORE INCOME TAXES AND CUMULATIVE EFFECT
OF CHANGE IN ACCOUNTING PRINCIPLES
INCOME TAXES (3,286,878) (4,502,313) 4,791,726
---------------- ---------------- -----------------
INCOME (LOSS) BEFORE CUMULATIVE
EFFECT OF CHANGE IN ACCOUNTING
PRINCIPLES (3,286,878) (4,502,313) 4,791,726
CUMULATIVE EFFECT OF CHANGE IN
ACCOUNTING PRINCIPLES, NET OF INCOME
TAXES 262,452 ----- (3,747,435)
---------------- ---------------- -----------------
NET INCOME (LOSS) $(3,024,426) $ (4,502,313) $ 1,044,291
DIVIDENDS ON PREFERRED STOCK
(PAID 2003-$-0-; 2002-$112,500; 2001-$28,125) (127,083) (112,500) (56,250)
---------------- ---------------- -----------------
NET INCOME (LOSS) AVAILABLE TO COMMON $(3,151,509) $ (4,614,813) $ 988,041
SHAREHOLDERS ================ ================ =================
NET INCOME (LOSS) PER SHARE, BASIC $ (.18) $ (.25) $ .25
BEFORE CUMULATIVE EFFECT OF CHANGE
IN ACCOUNTING PRINCIPLES
CUMULATIVE EFFECT OF CHANGE IN
ACCOUNTING PRINCIPLES .01 - (.20)
---------------- ---------------- -----------------
NET INCOME (LOSS) PER SHARE BASIC $ (.17) $ (.25) $ .05
================ ================ =================
NET INCOME (LOSS) PER SHARE, DILUTED BEFORE CUMULATIVE EFFECT $ (.18) $ (.25) $ .23
OF CHANGE IN
ACCOUNTING PRINCIPLES
CUMULATIVE EFFECT OF CHANGE IN
ACCOUNTING PRINCIPLES .01 - (.18)
---------------- ---------------- -----------------
NET INCOME (LOSS) PER SHARE, DILUTED $ (.17) $ (.25) $ .05
================ ================ =================
The Notes to Consolidated Financial Statements are an integral part of these statements.
F-5
GULFWEST ENERGY INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY
FOR THE YEARS ENDED DECEMBER 31, 2003, 2002 AND 2001
------------------------------
Number of Shares
------------------------------
Preferred Common
Stock Stock
----------- ---------------
8,000 18,445,041
BALANCE, December 31, 2000
Issuance of 9,000 shares of Series E preferred stock for the
acquisition of assets 9,000 -
Issuance of 47,500 shares of common stock for the acquisition of
assets - 47,500
Issuance of warrants for the acquisition of assets - -
Net income - -
Dividends paid on preferred stock - -
BALANCE, December 31, 2001 17,000 18,492,541
Issuance of warrants for additional financing - -
Net loss - -
Dividends paid on preferred stock - -
BALANCE, December 31, 2002 17,000 18,492,541
Issuance of warrants for additional financing - -
Issuance of preferred stock related to current financing 2,000 -
Net loss - -
BALANCE, December 31, 2003 19,000 18,492,541
The Notes to Consolidated Financials are an integral part of these statements.
F-6
Preferred Common Additional Retained
Stock Stock Paid-In Capital Deficit
------------------------------------------ -------------------- ------------------------
$80 $18,445 $23,537,900 $(16,854,654)
90 - 4,499,910 -
- - 35,402 -
- - 91,500 -
- - - 1,044,291
- - - (28,125)
------------------------------------------ -------------------- ------------------------
$170 $18,493- $28,164,712 $(15,838,488)
========================================== ==================== ========================
- - 93,500 -
- - ----- (4,502,313)
- - ----- (112,500)
------------------------------------------ -------------------- ------------------------
$170 $18,493- $28,258,212 $(20,453,301)
========================================== ==================== ========================
- - 25,500 -
20 - 999,980 -
- - - (3,024,426)
------------------------------------------ -------------------- ------------------------
$190 $18,493- $29,283,692 $(23,477,727)
========================================== ==================== ========================
The Notes to Consolidated Financials are an integral part of these statements.
F-7
GULFWEST ENERGY INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
FOR THE YEARS ENDED DECEMBER 31, 2003, 2002 AND 2001
2003 2002 2001
--------------- ---------------- ---------------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) $ (3,024,426) $ (4,502,313) $ 1,044,291
Adjustments to reconcile net income (loss) to net cash
Provided by operating activities:
Depreciation, depletion and amortization 2,226,123 2,697,784 2,491,385
Accretion expense 76,823 - -
Common stock and warrants issued and charged to
operations 5,500 93,500 -
Other financing costs 1,000,000 - -
Loss on sale of assets 19,848 56,647 118,254
Dry holes, abandoned property, impaired assets 358,737 617,365 -
Unrealized (gain) loss on derivative instruments (537,526) 1,596,575 (4,215,017)
Cumulative effect of accounting change (262,452) - 3,747,435
Provision for bad debts 29,201 - -
(Increase) decrease in accounts receivable -
trade, net 232,443 (109,437) 765,939
(Increase) decrease in prepaid expenses 144,637 (179,825) (40,730)
Increase (decrease) in accounts payable and
accrued expenses 1,235,503 1,043,994 797,800
--------------- ---------------- ---------------
Net cash provided by operating
activities 1,524,411 1,314,290 4,709,357
--------------- ---------------- ---------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Deposits - - (9,804)
Proceeds from sale of property and equipment 38,561 675,440 394,423
Purchase of property and equipment (1,067,924) (5,861,969) (6,962,650)
--------------- ---------------- ---------------
Net cash used in investing activities (1,029,363) (5,186,529) (6,578,031)
--------------- ---------------- ---------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Payments on debt (1,672,288) (3,410,778) (6,577,928)
Proceeds from debt issuance 973,164 7,394,181 8,530,269
Debt issue cost - - (29,544)
Dividends paid - (112,500) (28,125)
--------------- ---------------- ---------------
Net cash provided by (used in) financing
activities (699,124) 3,870,903 1,894,672
--------------- ---------------- ---------------
INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS (204,076) (1,336) 25,998
CASH AND CASH EQUIVALENTS,
Beginning of year 687,694 689,030 663,032
--------------- ---------------- ---------------
CASH AND CASH EQUIVALENTS,
End of year $ 483,618 $ 687,694 $ 689,030
=============== ================ ===============
CASH PAID FOR INTEREST $ 3,216,034 $ 3,004,015 $ 2,811,677
=============== ================ ===============
The Notes to Consolidated Financial Statements are an integral part of these statements.
F-8
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1. Summary of Significant Accounting Policies
The following is a summary of the significant accounting policies
consistently applied by management in the preparation of the accompanying
consolidated financial statements.
Organization/Concentration of Credit Risk
GulfWest Energy Inc. and our subsidiaries intend to pursue the acquisition
of quality oil and gas prospects, which have proved developed and undeveloped
reserves, and the development of prospects with third party industry partners.
The accompanying consolidated financial statements include our company and
its wholly-owned subsidiaries: (1) RigWest Well Service, Inc. ("RigWest"); (2)
GulfWest Texas Company ("GWT"), both formed in 1996; (3) DutchWest Oil Company
formed in 1997; (4) SETEX Oil and Gas Company ("SETEX") formed August 11, 1998;
(5) Southeast Texas Oil and Gas Company, L.L.C. ("Setex LLC") acquired September
1, 1998; (6) GulfWest Oil and Gas Company formed February 18, 1999; (7) LTW
Pipeline Co. formed April 19, 1999; (8) GulfWest Development Company ("GWD")
formed November 9, 2000 and (9) GulfWest Oil and Gas Company (Louisiana) LLC,
formed July 31, 2001. All material intercompany transactions and balances are
eliminated upon consolidation.
We grant credit to independent and major oil and gas companies for the sale
of crude oil and natural gas. In addition, we grant credit to joint owners of
oil and gas properties, which we, through our subsidiary, SETEX, operate. Such
amounts are secured by the underlying ownership interests in the properties. We
also grant credit to various third parties through RigWest for well servicing
operations.
We maintain cash on deposit in non-interest bearing accounts, which, at
times, exceed federally insured limits. We have not experienced any losses on
such accounts and believe we are not exposed to any significant credit risk on
cash and equivalents.
Statement of Cash Flows
We consider all highly liquid investment instruments purchased with
remaining maturities of three months or less to be cash equivalents for purposes
of the consolidated statements of cash flows.
Non-Cash Investing and Financing Activities:
During the twelve month period ended December 31, 2003, we adopted
Statement of Financial Accounting Standard No. 143 "Asset Retirement
Obligations" (SFAS 143). As a result of adopting SFAS 143, effective January 1,
2003, we recorded an asset retirement obligation liability of $1,280,383, an
increase in the carrying value of our oil and gas properties of $1,058,445, a
reduction in accumulated depletion of $484,390 and an adjustment to prior income
of $262,452. This liability was increased during 2003 by recognizing $76,823 in
accretion expense. Also, we decreased the current portion of long term
debt-related parties by applying $17,300 in deposits and reclassified $176,320
from accrued expenses to current portion of long term debt.
During the twelve month period ended December 31, 2002, we acquired $74,653
in property and equipment through notes payable to financial institutions. We
also acquired $182,742 of oil producing properties in exchange of accounts
receivable from a related party. In addition, we sold property and equipment,
which included an account receivable of $42,000. This receivable was collected
in January 2003.
F-9
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1. Summary of Significant Accounting Policies (continued)
Statement of Cash Flows - Non-cash Investing and Financing Activities -
continued
During the twelve month period ended December 31, 2001, we acquired
$15,068,774 in property and equipment through $10,441,824 in notes payable to
financial institutions and related parties, by issuing 9,000 shares of preferred
stock valued at $4,500,000, by issuing 47,500 shares of common stock valued at
$35,450 and by issuing 150,000 warrants valued at $91,500. Also, debt issue
costs increased $170,000 in notes payable.
Use of Estimates in the Preparation of Financial Statements
The preparation of consolidated 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 consolidated
financial statements and the reported amounts of revenues and expenses during
the reporting period. Actual results could differ from those estimates.
Oil and Gas Properties
We use 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, and geological and geophysical costs are
expensed.
As we acquire significant oil and gas properties, any unproved property
that is considered individually significant is periodically assessed for
impairment of value, and a loss is recognized at the time of impairment by
providing an impairment allowance. Capitalized costs of producing oil and gas
properties and support equipment, after considering estimated dismantlement and
abandonment costs and estimated salvage values, are depreciated and depleted by
the unit-of-production method.
On the sale of an entire interest in an unproved property, gain or loss on
the sale is recognized, taking into consideration the amount of any recorded
impairment if the property has been assessed individually. If a partial interest
in an unproved property is sold, the amount received is treated as a reduction
of the cost of the interest retained. On the sale of an entire or partial
interest in a proved property, gain or loss is recognized, based upon the fair
values of the interests sold and retained.
F-10
Other Property and Equipment
The following tables set forth certain information with respect to our
other property and equipment. We provide for depreciation and amortization using
the straight-line method over the following estimated useful lives of the
respective assets:
Assets Years
--------------------------------- -------------
Automobiles 3-5
Office equipment 7
Gathering system 10
Well servicing equipment 10
F-11
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1. Summary of Significant Accounting Policies - continued
Other Property and Equipment - continued
Capitalized costs relating to other properties and equipment:
2003 2002
-------------------- --------------------
Automobiles $ 420,776 $ 420,776
Office equipment 148,172 137,362
Gathering system 529,486 529,486
Well servicing equipment 1,033,786 1,033,786
-------------------- --------------------
2,132,220 2,121,410
Less accumulated depreciation (1,268,330) (1,037,076)
-------------------- --------------------
Net capitalized cost $ 863,890 $ 1,084,334
==================== ====================
Revenue Recognition
We recognize oil and gas revenues on the sales method as oil and gas
production is sold. Differences between sales and production volumes during the
years ended December 31, 2003, 2002, and 2001 were not significant. Well
servicing revenues are recognized as the related services are performed.
Operating overhead income is recognized based upon monthly contractual amounts
for lease operations and other income is recognized as earned.
Trade Accounts Receivable
Trade accounts receivable are reported in the consolidated balance sheet at
the outstanding principal adjusted for any chargeoffs. An allocation for
doubtful accounts is recognized by management based upon a review of specific
customer balances, historical losses and general economic conditions.
Fair Value of Financial Instruments
At December 31, 2003 and 2002, our financial instruments consist of notes
payable and long-term debt. Interest rates currently available to us for notes
payable and long-term debt with similar terms and remaining maturities are used
to estimate fair value of such financial instruments. Accordingly, the carrying
amounts are a reasonable estimate of fair value.
Debt Issue Costs
Debt issue costs incurred are capitalized and subsequently amortized over
the term of the related debt on a straight-line basis.
Earnings (Loss) Per Share
Earnings (loss) per share are calculated based upon the weighted-average
number of outstanding common shares. Diluted earnings (loss) per share are
calculated based upon the weighted-average number of outstanding common shares,
plus the effect of dilutive stock options, warrants, convertible preferred stock
and convertible debentures.
F-12
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1. Summary of Significant Accounting Policies - continued
Earnings (Loss) Per Share - continued
We have adopted Statement of Financial Accounting Standards (SFAS) No. 128
"Earnings Per Share", which requires that both basic earnings (loss) per share
and diluted earnings (loss) per share be presented on the face of the statement
of operations. Basic earnings (loss) per share are based on the weighted-average
number of outstanding common shares. Diluted earnings (loss) per-share are based
on the weighted-average number of outstanding common shares and the effect of
all potentially diluted common shares.
Impairments
Impairments, measured using fair market value, are recognized whenever
events or changes in circumstances indicate that the carrying amount of
long-lived assets (other than unproved oil and gas properties discussed above)
may not be recoverable and the future undiscounted cash flows attributable to
the asset are less than its carrying value.
Stock Based Compensation
In October 1995, SFAS No. 123, "Stock Based Compensation," (SFAS 123) was
issued. This statement requires that we choose between two different methods of
accounting for stock options and warrants. The statement defines a
fair-value-based method of accounting for stock options and warrants but allows
an entity to continue to measure compensation cost for stock options and
warrants using the accounting prescribed by APB Opinion No. 25 (APB 25),
"Accounting for Stock Issued to Employees." Use of the APB 25 accounting method
results in no compensation cost being recognized if options are granted at an
exercise price at the current market value of the stock or higher. We will
continue to use the intrinsic value method under APB 25 but are required by SFAS
123 to make pro forma disclosures of net income (loss) and earnings (loss) per
share as if the fair value method had been applied in its 2003, 2002 and 2001
financial statements.
During 2003, 2002 and 2001, we issued options and warrants totaling: 2003 -
35,000 (all exercisable); 2002 - 405,000 (all exercisable); and 2001 - 184,000
(all exercisable), respectively, to employees and directors as compensation. If
we had used the fair value method required by SFAS 123, our net income (loss)
and per share information would approximate the following amounts:
2003 2002 2001
------------------------- ------------------------- -------------------
As
As Reported ProForma AsReported ProForma Reported ProForma
------------ ------------ ------------ ------------ --------- ---------
SFAS 123 $- $-
compensation cost $- $7,350 $- 38,300 $- 99,360
APB 25
compensation cost $- $- $- $- $- $-
Net income (loss) $(3,151,509) $(3,158,859) $(4,614,813) $(4,653,113) $988,041 $888,681
F-13
2003 2002 2001
------------------------- ------------------------- -------------------
Income (loss) per
common share-basic $(.17) $(.17) $(.25) $(.25) $.05 $.05
Income (loss) per
common share-diluted $(.17) $(.17) $(.25) $(.25) $.05 $.04
F-14
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1. Summary of Significant Accounting Policies - continued
Stock Based Compensation - continued
The effects of applying SFAS 123 as disclosed above are not indicative of
future amounts. We anticipate making additional stock based employee
compensation awards in the future.
We use the Black-Sholes option-pricing model to estimate the fair value of
the options and warrants (to employee and non-employees) on the grant date.
Significant assumptions include (1) risk free interest rate 2003 - 3.0%; 2002 -
3.0%; 2001 - 4.5%; (2) weighted average expected life 2003 - 3.4; 2002 - 3.6;
2001 - 5.0; (3) expected volatility of 2003 - 147.43; 2002 - 101.73%; 2001 -
103.27%; and (4) no expected dividends.
Implementation of New Financial Accounting Standards
Effective January 1, 2001, we adopted SFAS No. 133 "Accounting for
Derivative Instruments and Other Hedging Activities", as amended by SFAS No. 137
and No. 138. As a result of a financing agreement with an energy lender, we were
required to enter into an oil and gas hedging agreement with the lender. It has
been determined this agreement meets the definition of SFAS 133 "Accounting for
Derivative Instruments and Hedging Activities" and is accounted for as a
derivative instrument.
The estimated change in fair value of the derivatives is reported in Other
Income and Expense as unrealized (gain) loss on derivative instruments. The
estimated fair value of the derivatives is reported in Other Assets (or Other
Liabilities) as derivative instruments.
The estimated fair value of the derivative instruments at January 1, 2001,
the date of initial application of SFAS 133, of $3,747,435 is reported in the
Statement of Operations as the cumulative effect of a change in accounting
principle.
In June, 2001, SFAS No. 141 "Business Combinations" and SFAS No. 142
"Goodwill and Other Intangible Assets were issued. We presently have no goodwill
or intangible assets and are thus not affected by SFAS No. 142.
Effective January 1, 2002, we adopted SFAS No. 144, "Accounting for the
Impairment or Disposal of Long-Lived Assets." This statement requires the
following three-step approach for assessing and recognizing the impairment of
long-lived assets: (1) consider whether indicators of impairment of long-lived
assets are present; (2) if indicators of impairment are present, determine
whether the sum of the estimated undiscounted future cash flows attributable to
the assets in question is less than their carrying amount; and (3) if less,
recognize an impairment loss based on the excess of the carrying amount of the
assets over their respective fair values. In addition, SFAS No. 144 provides
more guidance on estimating cash flows when performing a recoverability test,
requires that a long-lived asset to be disposed of other than by sale (such as
abandoned) be classified as "held and used" until it is disposed of, and
establishes more restrictive criteria to classify an asset as "held for sale".
The adoption of SFAS No. 144 did not have a material impact on our financial
statements since it retained the fundamental provisions of SFAS No. 121,
"Accounting for the Impairment or Disposal of Long-Lived Assets and for
Long-Lived Assets to be Disposed Of," related to the recognition and measurement
of the impairment of long-lived assets to be "held and used".
F-15
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1. Summary of Significant Accounting Policies - continued
Implementation of New Financial Accounting Standards - continued
In June 2002, the FASB issued SFAS No. 146, "Accounting for Costs
Associated with Exit or Disposal Activities." SFAS No. 146 addresses financial
accounting and reporting for costs associated with exit or disposal activities
and nullifies EITF Issue No. 94-3, "Liability Recognition for Certain Employee
Termination Benefits and Other Costs to Exit an Activity (including Certain
Costs Incurred in a Restructuring)." SFAS No. 146 requires that a liability for
a cost associated with an exit or disposal activity be recognized when the
liability is incurred. Under EITF Issue No. 94-3, a liability for an exit cost
as defined was recognized at the date of an entity's commitment to an exit plan.
SFAS No. 146 also establishes that the fair value is the objective for the
initial measurement of the liability. SFAS No. 146 is effective for exit and
disposal activities that are initiated after December 31, 2002. This statement
will impact the timing of our recognition of liabilities for costs associated
with exit or disposal activities.
Beginning in 2003, Statement of Financial Accounting Standards No. 143,
"Asset Retirement Obligations" ("SFAS 143") requires us to recognize an
estimated liability for the plugging and abandonment of our oil and gas wells
and associated pipelines and equipment. Consistent with industry practice,
historically we had assumed the cost of plugging and abandonment would be offset
by salvage value received. This statement requires us to record a liability in
the period in which our asset retirement obligation ("ARO") is incurred. After
initial recognition of the liability, we must capitalize an additional asset
cost equal to the amount of the liability. In addition to any obligation that
arises after the effective date of SFAS 143, upon initial adoption we must
recognize (1) a liability for any existing ARO's, (2) capitalized cost related
to the liability, and (3) accumulated depreciation, depletion and amortization
on that capitalized cost adjusting for the salvage value of related equipment.
The estimated liability is based on historical experience in plugging and
abandoning wells, estimated remaining lives of those wells based on reserves
estimates and federal and state regulatory requirements. The liability is
discounted using an assumed credit-adjusted risk-free rate of 7.5%. Revisions to
the liability could occur due to changes in estimates of plugging and
abandonment costs, changes in the risk-free rate or remaining lives of the
wells, or if federal or state regulators enact new plugging and abandonment
requirements. At the time of abandonment, we will be required to recognize a
gain or loss on abandonment if the actual costs do not equal the estimated
costs.
The adoption of SFAS 143 resulted in a January 1, 2003 cumulative effect
adjustment to record (i) a $1,058,445 increase in the carrying value of proved
properties, (ii) a $484,390 decrease in accumulated depreciation, depletion and
amortization, (iii) a $1,280,383 increase in noncurrent liabilities, and (iv) a
$262,452 gain, net of tax.
Note 2. Operations and Management Plans
At December 31, 2003, our current liabilities exceeded our current assets
by $42,876,963. We had a loss available to common shareholders of $3,151,509
compared to a loss available to common shareholders of $4,614,813 at December
31, 2002. This loss included non-cash items of $537,526 for unrealized gain on
derivative instruments, a loss of $358,737 for abandonment of properties and a
$262,452 gain from the recording of Asset Retirement Obligations ("ARO's"), as
required by SFAS 143, at January 1, 2003.
In 2004, we will continue the recapitalization of debt and funding of our
capital development program that we began in 2003. Following are the steps we
are taking and plan to take to achieve that purpose:
F-16
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 2. Operations and Management Plans - continued
(a) The first step is to close the refinancing of our largest debt of $27.8
million held by Concert Capital Resources LP ("CCR") and loaned to our
wholly-owned subsidiary, GulfWest Oil & Gas Company. We have entered into an
agreement with a new lending source that, subject to due diligence, will fund
approximately $14 million to purchase the $27.8 million note. The new debt
financing will also provide for the payment of closing costs. CCR has agreed to
sell the note to our new financier for a $14 million cash payment and a $4
million subordinated note from us.
(b) Secondly, we are continuing to work with our financial advisor to raise
an additional $4 to $5 million through the sale of our preferred stock. Proceeds
from this equity sale will be used for working capital and fund our new
development projects. The refinancing of the CCR debt and sale of new equity are
both currently scheduled to close in April, 2004.
(c) Effective December 1, 200l and amended August 16, 2002, we entered into
an Oil and Gas Property Acquisition, Exploration and Development Agreement (the
"Summit Agreement") with Summit Investment Group-Texas, L.L.C., an unrelated
party, ("Summit"). Under the agreement, Summit provided payments in the
aggregate of $1,200,000 in advanced funds for our use in the acquisition of oil
and gas leases and other mineral and royalty interests, and production
activities, and was to recoup and recover those advanced funds.
In a subsequent event on March 5, 2004, we entered into an Option Agreement
for the Purchase of Oil and Gas Leases (the "Addison Agreement") with W. L.
Addison Investments L.L.C., a private company owned by Mr. J. Virgil Waggoner
and Mr. John E. Loehr, two of our directors, (`Addison"). Under the Addison
Agreement, Addison agreed to pay Summit, on our behalf, the non-recouped and
outstanding advanced funds amounting to $1,200,000, thereby retiring the Summit
Agreement. For consideration of such payment, Addison acquired certain oil and
gas leases and wellbores from Summit but agreed to grant us a 180-day redemption
option (which may be extended by mutual consent) to purchase the same for
$1,200,000, plus interest at the prime rate plus 2%. We tendered Addison a
promissory note in the amount of $600,000, with interest at the prime rate plus
2%, to substitute for an account payable to Summit, pursuant to the Summit
Agreement, in the same amount. The note will be considered paid in full if we
exercise the redemption option and pay the $1,200,000, plus interest. Summit
retained the right to participate up to a 25% working interest in the drilling
of any wells on the leases acquired by Addison. In the event we exercise the
redemption option, Addison may, at its sole option, retain up to a 25% working
interest in the leases.
(d) Finally, after completing the above, we will pursue the consolidation
of all of our debt, including other asset and bridge loans. Our goal is to
simplify our financial structure and provide adequate capitalization for the
development of our oil and gas assets.
F-17
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 3. Cost of Oil and Gas Properties
The following tables set forth certain information with respect to our oil
and gas producing activities for the periods presented:
Capitalized Costs Relating to Oil and Gas Producing Activities:
2003 2002
---------------- ----------------
Unproved oil and gas properties $ 261,650 $ 439,926
Proved oil and gas properties 54,669,482 52,847,625
Support equipment and facilities 3,541,754 3,498,492
---------------- ----------------
58,472,886 56,786,043
Less accumulated depreciation, depletion and
Amortization (8,749,601) (7,461,421)
---------------- ----------------
Net capitalized costs $49,723,285 $49,324,622
================ ================
Results of Operations for Oil and Gas Producing Activities:
2003 2002 2001
--------------- ---------------- ---------------
Oil and gas sales $10,844,466 $10,447,169 $ 12,426,103
Production costs (5,527,841) (5,430,205) (5,155,500)
Depreciation, depletion and amortization (1,527,727) (2,187,036) (2,018,890)
Accretion expense (76,823) - -
--------------- ---------------- ---------------
Income tax expense - - _
--------------- ---------------- ---------------
Results of operations for oil and gas
producing activities - income $ 3,712,075 $ 2,829,928 $ 5,251,713
=============== ================ ===============
Costs Incurred in Oil and Gas Producing Activities:
2003 2002 2001
--------------- ---------------- ---------------
Property Acquisitions
Proved $ - $ 562,760 $ 15,236,808
Unproved 110,119 14,401 154,076
Development Costs 2,024,663 5,141,075 6,317,527
--------------- ---------------- ---------------
$ 2,134,782 $ 5,718,236 $ 21,708,411
=============== ================ ===============
F-18
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 3. Cost of Oil and Gas Properties - continued
Effective July 1, 2001, we acquired interests in oil and gas properties
located in Texas and Louisiana from an unrelated party, Grand Goldking L.L.C.
The acquisition cost was $15,077,358, consisting of 9,000 shares of Series E
preferred stock valued at $4,500,000 and $10,000,000 in debt. In addition, we
paid $545,300 in commissions to unrelated parties. The commissions were paid by
issuing 10,000 shares of common stock valued at $8,800, 150,000 warrants valued
at $91,500 and $445,000 in cash. We incurred additional cash costs of $33,058
related to the acquisition. On the same date, we transferred its ownership
interest in these properties to our wholly owned subsidiary, GulfWest Oil and
Gas Company.
Supplemental unaudited pro forma information (under the purchase method of
accounting) presenting the results of operations for the year ended December 31,
2001, as if the Grand Goldking acquisition had occurred as of January 1, 2001:
Year Ended
December 31,
2001
----------------
Operating revenues $ 15,649,329
Operating expenses 10,652,222
----------------
Income from operations 4,997,107
Other income and expense (3,325,166)
Income taxes -
----------------
Net income 1,671,941
Preferred dividends (112,500)
----------------
Net income to common shareholders $ 1,559,441
================
Earnings per share
Basic $ 0.08
================
Diluted $ 0.07
================
Effective January 1, 2002, we acquired oil and gas properties located in
Louisiana from a related party for $182,742. The acquisition price was the
amount of accounts receivable due us.
Note 4. Accrued Expenses
Accrued expenses consisted of the following:
December 31, December 31,
2003 2002
---------------- -----------------
Payroll and payroll taxes $ 5,833 $ 1,863
Interest 395,735 414,724
Professional fees 42,000 42,000
---------------- -----------------
$ 443,568 $ 458,587
================ =================
F-19
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 5. Notes Payable and Long-Term Debt
Notes payable is as follows:
2003 2002
------------- ------------------
Non-interest bearing note payable to an unrelated party; payable out
of 50% of the net transportation revenues from a certain natural gas
pipeline; no due date. $ 40,300 $ 40,300
Promissory note payable to a former director at 8%; due May, 2001;
unsecured. 40,000 40,000
Promissory note payable to an unrelated party at 10%; payable on
demand; unsecured. 45,000 45,000
Line of credit (up to $2,500,000) to a bank; due October, 2002;
secured by guaranty of a director; interest greater of prime rate
less .25% or 5.25%, (prime rate 4.0% at December 31, 2003). Line of
credit increased to $3,000,000 and due date extended to April, 2004. 2,995,488 2,995,488
Note payable to a bank; due March, 2003; interest at prime rate plus
1% (prime rate 4.0% at December 31, 2003); secured by guaranty of
three of our directors; retired September 2003. 500,000
Promissory note payable to an unrelated party; payable on demand;
interest at 8%; interest increased to 12% on January 1, 2003; secured
by certain oil and gas properties. 300,000 300,000
Note payable to a bank; due July, 2004; secured by guaranty of a
director; interest at prime rate (prime rate 4.0% at December 31,
2003 with a floor of 4.75% and a ceiling of 8.0%. 948,400 1,000,000
Promissory note payable to unrelated party; interest at 6%; due
June, 2003. 55,300 55,300
Promissory note payable to one of our directors; interest at 8%; due
on demand; unsecured. 50,000 50,000
Promissory note payable to one of our directors; interest at prime
rate (prime rate 4.0% at December 31, 2003); due May, 2003;
secured by common stock of DutchWest Oil Company, our wholly owned
subsidiary. 1,375,000 1,200,000
Promissory note payable to an unrelated party at 8%; due June 2003;
secured by 4% of the common stock of DutchWest Oil Company, our
wholly owned subsidiary 100,000 -
Promissory note payable to an unrelated party at 8%; due May 2003;
secured by 8% of the common stock of DutchWest Oil Company, our
wholly owned subsidiary 200,000 -
F-20
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 5. Notes Payable and Long-Term Debt
Notes payable is as follows - continued:
2003 2002
-------------- -------------------
Line of credit (up to $3,500,000) to a bank; due June 2004; secured
by the guaranty of a director; interest at prime rate (prime rate
4.0% at December 31, 2003) with a floor of 4.75% and a ceiling of
8.0% 3,497,677 -
-------------- -------------------
$ 9,647,165 $ 6,226,088
============== ===================
The weighted average interest rate for notes payable at December 31, 2003
and 2002 was 5.0% and 4.7%, respectively.
Long-term debt is as follows:
2003 2002
------------- ------------------
Line of credit (up to $3,000,000) to a bank; due July, 2003;
secured by the guaranty of a director; interest at prime rate
(prime rate 4.0% at December 31, 2003); replaced by a short-term line
of credit (up to $3,500,000) from the same bank. $ - $ 2,999,515
Subordinated promissory notes to various individuals at 9.5% interest
per annum; amounts include $50,000 due to related parties; past due. 150,000 150,000
Notes payable to finance vehicles, payable in aggregate monthly
installments of approximately $4,000, including interest of.9%
to 13% per annum; secured by the related equipment; due
various dates through 2007. 69,500 116,721
Note payable to related party to finance equipment with monthly
installments of $5,200, including interest at 13.76% per annum;
final payment due October, 2003; secured by related equipment;
retired June, 2003. - 48,850
Promissory note to a director; interest at 8.5%; due December 31,
2003. 78,941 95,670
Note payable to a bank with monthly principal payments of $2,300;
interest at 9.5%; due May, 2003; secured by related equipment;
retired May, 2003. - 11,630
Note payable to an energy lender; interest at prime plus 3.5%
(prime rate 4.0% at December 31, 2003) payable monthly out of
90% net profits from certain oil and gas properties; final payment
due May, 2004; secured by related oil and gas properties. 27,574,769 27,907,509
F-21
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 5. Notes Payable and Long-Term Debt
Long-term debt is as follows - continued:
2003 2002
------------------ -----------------
Note payable to a bank with monthly principal payments of
$36,000; interest at prime plus 1% (prime rate 4.0% at December
31, 2003) with a minimum prime rate of 5.5%; final payment due
November, 2003; secured by related oil and gas properties;
Extended to March, 2004. 1,564,000 1,996,000
Note payable to unrelated party to finance saltwater disposal
well with monthly installments of $4,540, including interest at
10% per annum; final payment due January, 2005; secured by
related well. 123,624 123,624
Note payable to related party to finance equipment with
monthly installments of $5,109, including interest at 13.75%
per annum; final payment due February, 2004; secured by related
equipment; retired June, 2003. - 65,743
Note payable to related party to finance equipment with
monthly installments of $608, including interest at 11% per
annum; final payment due February, 2004; secured by related
equipment. 1,211 7,960
------------------ -----------------
29,562,045 33,523,222
Less current portion
(29,526,244) (33,385,414)
------------------ -----------------
Total long-term debt $ 35,801 $ 137,808
================== =================
Estimated annual maturities for long-term debt are as follows:
2004 $ 29,526,244
2005 27,292
2006 7,150
2007 1,359
2008 -
------------------
$ 29,562,045
==================
F-22
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 6. Shareholders' Equity
Common Stock
2003 2002
----------------- --------------
Par value $.001; 40,000,000 shares authorized; 18,492,541
shares issued and outstanding as of December 31, 2003 and 2002,
respectively $ 18,493 $ 18,493
================= ==============
Preferred Stock
Series D, par value $.01; 12,000 shares authorized; 8,000 shares
issued and outstanding at December 31, 2003 and 2002. The
Series D preferred stock does not pay dividends and is not
redeemable. The liquidation value is $500 per share. After
three years from the date of issue, and thereafter, the shares are
convertible to common stock based upon a value of $500 per Series
D share divided by $8 per share of common stock. 80 80
Series E, par value $.01; 9,000 shares authorized; 9,000 shares
issued and outstanding at December 31, 2003 and 2002. The Series
E preferred stock pays dividends, as declared, at a rate of 2.5%
per annum, has a liquidation value of $500 per share, may be
redeemed at our option and, if not redeemed after two years, is
convertible to common stock based upon a value of $500 per Series
E share divided by $2 per share of common stock. 90 90
Series F, par value $.01; 2,000 shares authorized; 2,000 shares
issued and outstanding at December 31, 2003. The Series F
preferred stock pays dividends, as declared, at a rate of 2.5%
per annum, has a liquidation value of $500 per share, may be
redeemed at our option and, if not redeemed after two years, is
convertible to common stock based upon a value of $500 per Series
E share divided by $1 per share of common stock. 20 -
----------------- --------------
$ 190 170
================= ==============
All classes of preferred shareholders have liquidation preference over
common shareholders of $500 per preferred share, plus accrued dividends.
Dividends in arrears at December 31, 2003 we $127,083 (Series E $112,500; Series
F $14,583).
Stock Options
We maintain a Non-Qualified Stock Option Plan (as amended and restated, the
"Plan"), which authorizes the grant of options of up to 2,000,000 shares of
common stock. Under the Plan, options may be granted to any of our key employees
(including officers), employee and nonemployee directors, and advisors. A
committee appointed by the Board administers the Plan. Prior to 1999, options
granted under the Plan had been granted at an option price of $3.13 and $1.81
per share. In July 1999, the Board authorized that all then current employee and
director options under the plan be reduced to a price of $.75 per share.
Following is a schedule by year of the activity related to stock options,
including weighted-average ("WTD AVG") exercise prices of options in each
category.
F-23
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 6. Shareholders' Equity - continued
2003 2002 2001
----------------- ----------------- -----------------
Wtd Wtd Wtd
Avg Avg Avg
Prices Number Prices Number Prices Number
------ ---------- ------ ---------- ------ ----------
Balance, January 1 $.90 1,067,000 $1.03 1,097,000 $.09 923,000
Options issued $.75 35,000 $.75 35,000 $.83 184,000
Options expired $- - $3.00 (65,000) $3.00 (10,000)
---------- ---------- ----------
Balance, December 31 $.90 1,102,000 $.90 1,067,000 $1.03 1,097,000
========== ========== ==========
All options were exercisable at December 31, 2003. Following is a schedule
by year and by exercise price of the expiration of our stock options issued as
of December 31, 2003:
2004 2005 2006 2007 Thereafter Total
---------- ----------- ---------- ---------- ------------ -----------
$ .75 432,000 35,000 185,000 652,000
$ .83 184,000 184,000
$1.13 100,000 100,000
$1.20 106,000 106,000
$1.81 60,000 60,000
---------- ----------- ---------- ---------- ------------ -----------
432,000 206,000 184,000 35,000 210,000 1,102,000
========== =========== ========== ========== ============ ===========
Stock Warrants
We have issued a significant number of stock warrants for a variety of
reasons, including compensation to employees, additional inducements to purchase
our common or preferred stock, inducements related to the issuance of debt and
for payment of goods and services. Following is a schedule by year of the
activity related to stock warrants, including weighted-average exercise prices
of warrants in each category:
2003 2002 2001
-------------------------- -------------------------- ---------------------------
Wtd Avg Wtd Avg Wtd Avg
Prices Number Prices Number Prices Number
--------- ------------- --------- ------------- --------- --------------
Balance, January 1 $ 1.24 2,181,754 $2.15 1,306,754 $ 2.31 1,392,254
Warrants issued $ .75 150,000 $ .75 1,145,000 $ .75 150,000
Warrants exercised
or expired $(3.61) (366,754) $3.57 (270,000) $ 2.22 (235,500)
------------- ------------- --------------
Balance, December 31 $ .76 1,965,000 $1.24 2,181,754 $ 2.15 1,306,754
============= ============= ==============
Included in the "warrants issued" and "warrants exercised/expired" columns
in 2002 were 270,000 warrants whose price was reduced in 2002 to $.75.
F-24
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 6. Shareholders' Equity - continued
Following is a schedule by year and by exercise price of the expiration of
our stock warrants issued as of December 31, 2003:
2004 2005 2006 2007 2008 Total
-------- --------- ---------- ---------- --------- ----------
$.75 225,000 1,590,000 1,815,000
.875 150,000 150,000
-------- --------- ---------- ---------- --------- ----------
- 375,000 1,590,000 - - 1,965,000
======== ========= ========== ========== ========= ==========
Warrants outstanding to our officers, directors and employees at December
31, 2003 and 2002 were approximately 1,515,000 and 1,682,000, respectively. The
exercise prices on these warrants range from $.75 to $.88 and expire various
dates through 2006.
Note 7. Income (Loss) Per Common Share
The following is a reconciliation of the numerators and denominators used
in computing income (loss) per share:
2003 2002 2001
--------------- -------------- --------------
Net income (loss) $(3,024,426) $(4,502,313) $1,044,291
Preferred stock dividends (127,083) (112,500) (56,250)
--------------- -------------- --------------
Income (loss) available to
common shareholders
(numerator) $(3,151,509) $(4,614,813) $988,041
=============== ============== ==============
Weighted-average number of
shares
of common stock - basic
(denominator) 18,492,541 18,492,541 18,464,343
--------------- -------------- --------------
Income (loss) per share -
basic $(.17) $(.25) $.05
=============== ============== ==============
Potential dilutive securities (stock options, stock warrants and
convertible preferred stock) in 2003 and 2002 have not been considered since we
reported a net loss and, accordingly, their effects would be antidilutive.
Potential dilutive securities (stock options, stock warrants and convertible
preferred stock) totaling 2,780,520 weighted average shares in 2001 have been
considered but there is no effect on income per common share.
Note 8. Related Party Transactions
On December 1, 1992, Ray Holifield and Associates, Inc. executed an
unsecured promissory note to us for $118,645 with interest at 10% per annum, due
on October 1, 1993. At December 31, 1993, the note was still outstanding. During
1994, we entered into an agreement with the Holifield Trust in which Holifield
will make payments on the past due note from future oil and gas revenue. During
1995, $10,995 of interest payments were received. At December 31, 2001 the
unsecured promissory note had been fully reserved. At December 31, 2002, the
unsecured promissory note had been fully written off.
On December 1, 1992, Parkway Petroleum Company, a Ray Holifield related
company, executed an unsecured promissory note to us for $54,616 with interest
at 10% per annum, due on October 1, 1993. The note was issued for amounts due
from contract drilling services we provided Parkway Petroleum
F-26
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 8. Related Party Transactions - continued
Company. At December 31, 1993, the note was still outstanding. During 1994,
we entered into an agreement with the Holifield Trust in which Holifield will
make payments on the past due note from future oil and gas revenue.
During 1995, $6,250 of interest payments were received. At December 31,
2001, the unsecured promissory note had been fully reserved. At December 31,
2002, the unsecured promissory note had been fully written off.
On January 10, 1994, we entered into a consulting agreement with Williams
Southwest Drilling Company, Inc. ("Williams") whereby we would provide
management and accounting services for $25,000 per month for a period of one
year. We accrued the consulting fees with an offset to deferred income until
payment of the fees is actually received. During 1994, $172,140 was recorded as
consulting fee income. Beginning in the second quarter 1994, we began
recognizing consulting income only as cash payments were received. Prior to the
second quarter, $75,000 in consulting fee revenue was accrued. We received
$97,140 in consulting fee payments. As of December 31, 1994, the receivable from
Williams of $202,860 for consulting fees has been offset by deferred income of
$127,860 and a provision for doubtful accounts of $75,000. Effective January 1,
1995, we received a promissory note from Williams in the amount of $202,860,
bearing interest at the rate of 10% per annum, and payable in quarterly
installments of principal and interest of $15,538.87. At December 31, 2001, the
unsecured promissory note had been fully reserved. At December 31, 2002, the
unsecured promissory note had been fully written off.
From July 22 to August 13, 1998, we advanced sums totaling $102,000 to Gulf
Coast Exploration, Inc. At December 31, 2001, the debt had been fully reserved.
At December 31, 2002, the debt had been fully written off.
On October 1, 1998, Toro Oil Company executed an unsecured promissory note
to us for the purchase of 100% of WestCo for $150,000, with interest at the
prime rate per annum and due September 30, 1999. To date, no principal payments
have been received. At December 31, 2001, the promissory note had been fully
reserved. At December 31, 2002, the debt had been fully written off.
In a subsequent event on March 5, 2004, we entered into an Option Agreement
for the Purchase of Oil and Gas Leases (the "Addison Agreement") with W. L.
Addison Investments L.L.C., a private company owned by Mr. J. Virgil Waggoner
and Mr. John E. Loehr, two of our directors, (`Addison"). Effective December 1,
200l and amended August 16, 2002, we had entered into an Oil and Gas Property
Acquisition, Exploration and Development Agreement (the "Summit Agreement") with
Summit Investment Group-Texas, L.L.C., an unrelated party, ("Summit"). Under the
agreement, Summit provided payments in the aggregate of $1,200,000 in advanced
funds for our use in the acquisition of oil and gas leases and other mineral and
royalty interests, and production activities, and was to recoup and recover
those advanced funds. Under the Addison Agreement, Addison agreed to pay Summit,
on our behalf, the non-recouped and outstanding advanced funds amounting to
$1,200,000, thereby retiring the Summit Agreement. For consideration of such
payment, Addison acquired certain oil and gas leases and wellbores from Summit
but agreed to grant us a 180-day redemption option (which may be extended by
mutual consent) to purchase the same for $1,200,000, plus interest at the prime
rate plus 2%. We tendered Addison a promissory note in the amount of $600,000,
with interest at the prime rate plus 2%, to substitute for an account payable
due to Summit, pursuant to the Summit Agreement, in the same amount. The note
will be considered paid in full if we exercise the redemption option and pay the
$1,200,000, plus interest. Summit retained the right to participate up to a 25%
working interest in the drilling of any wells on the leases acquired by Addison.
In the event we exercise the redemption option, Addison may, at its sole option,
retain up to a 25% working interest in the leases.
F-26
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 8. Related Party Transactions - continued
Interest expensed on related party notes totaled approximately $76,000,
$53,000 and $128,000 for the years ended December 31, 2003, 2002 and 2001
respectively.
Note 9. Income Taxes
The components of the net deferred federal income tax assets (liabilities)
recognized in our consolidated balance sheets were as follows:
F-27
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 9. Income Taxes - continued
December 31, December 31,
2003 2002
-------------- ---------------
Deferred tax assets
Net operating loss carryforwards $6,352,507 $5,236,485
Oil and gas properties 610,381 542,131
Capital loss carryforwards - 93,211
Derivative instruments 201,099 383,858
Accretion 26,120 -
-------------- ---------------
Net deferred tax assets before
valuation allowance 7,190,107 6,255,685
Valuation allowance (7,190,107) (6,255,685)
-------------- ---------------
Net deferred tax assets (liabilities) $- $-
============== ===============
As of December 31, 2003 and 2002, we did not believe it was more likely
than not that the net operating loss carryforwards would be realizable through
generation of future taxable income; therefore, they were fully reserved.
The following table summarizes the difference between the actual tax
provision and the amounts obtained by applying the statutory tax rate of 34% to
the income (loss) before income taxes for the years ended December 31, 2003,
2002 and 2001.
2003 2002 2001
-------------- -------------- --------------
Tax (benefit) calculated at statutory
rate $(1,028,305) $(1,530,786) $355,059
Increase (reductions) in taxes due to:
Effect on non-deductible expenses 362,910 65,174 18,157
Change in valuation allowance 934,422 1,586,988 (345,754)
Other (269,027) (121,376) (27,462)
-------------- -------------- --------------
Current federal income tax provision $- $- $-
============== ============== ==============
As of December 31, 2003 we had net operating loss carryforwards of
approximately $18,700,000, which are available to reduce future taxable income
and capital gains, respectively, and the related income tax liability. The net
operating loss carryforward expires at various dates through 2023.
Note 10. Commitments and Contingencies
Oil and Gas Hedging Activities
We entered into an agreement with an energy lender commencing in May, 2000,
to hedge a portion of our oil and gas sales for the period of May, 2000 through
April, 2004. The agreement called for initial volumes of 7,900 barrels of oil
and 52,400 Mmbtu of gas per month, declining monthly thereafter. We entered into
a second agreement with the energy lender, commencing September, 2001, to hedge
an additional portion of our oil and gas sales for the periods of September,
2001 through July, 2004 and September, 2001 through December 2002, respectively.
The agreement called for initial volumes of 15,000 barrels of oil and 50,000
Mmbtu of gas per month, declining monthly thereafter. Volumes at December 31,
2003 had declined to 6,400 barrels of oil and 21,200 Mmbtu of gas. As a result
of these agreements, we realized a reduction in revenues of $1,496,303, $368,776
and $762,480 for the twelve-month periods ended December 31, 2003, 2002 and
2001, respectively, which is included in oil and gas sales.
F-28
Lease Obligations
We lease office space at one location under a sixty-four (64) month lease,
which commenced December 1, 2001 and was amended May 30, 2002 after expansion.
Annual commitments under the lease are: 2004 - $130,050, 2005 - $132,979, 2006 -
$135,323 and 2007 - $33,977. Total rent expense for the years ended December 31,
2003, 2002 and 2001 were approximately $134,500, $91,000 and $60,000,
respectively.
F-29
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 10. Commitments and Contingencies - continued
Litigation
From time to time, we are involved in litigation arising out of our
operations or from disputes with vendors in the normal course of business. As of
March 29, 2004, we were not engaged in any legal proceedings that are expected,
individually or in the aggregate, to have a material effect on our consolidated
financial statements.
The estimates of proved oil and gas reserves utilized in the preparation of
the financial statements are estimated in accordance with guidelines established
by the Securities and Exchange Commission and the Financial Accounting Standards
Board, which require that reserve estimates be prepared under existing economic
and operating conditions with no provision for price and cost escalations over
prices and costs existing at year end except by contractual arrangements.
We emphasize that reserve estimates are inherently imprecise. Accordingly,
the estimates are expected to change as more current information becomes
available. Our policy is to amortize capitalized oil and gas costs on the unit
of production method, based upon these reserve estimates. It is reasonably
possible that, because of changes in market conditions or the inherent
imprecision of these reserve estimates, that the estimates of future cash
inflows, future gross revenues, the amount of oil and gas reserves, the
remaining estimated lives of the oil and gas properties, or any combination of
the above may be increased or reduced in the near term. If reduced, the carrying
amount of capitalized oil and gas properties may be reduced materially in the
near term.
F-30
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 11. Oil and Gas Reserves Information (Unaudited) - continued
The following unaudited table sets forth proved oil and gas reserves, all
within the United States, at December 31, 2003, 2002, and 2001, together with
the changes therein.
Crude Oil Natural Gas
(BBls) (Mcf)
--------------- ----------------
QUANTITIES OF PROVED RESERVES:
Balance December 31, 2000 4,575,179 24,811,919
Revisions (386,078) 238,595
Extensions, discoveries and additions 5,676 895,333
Purchase 2,078,561 14,905,837
Sales (107,225) 1,122
Production (294,276) (1,594,899)
--------------- ----------------
Balance December 31, 2001 5,871,837 39,257,907
Revisions (125,468) (4,959,229)
Extensions, discoveries and additions 22,129 1,090,024
Purchase 52,480 1,090,025
Sales (20,698) (837,856)
Production (278,374) (1,487,048)
--------------- ----------------
Balance December 31, 2002 5,521,906 34,158,823
Revisions (262,608) (308,080)
Extensions, discoveries and additions - -
Purchase - -
Sales - -
Production (221,335) (1,190,624)
--------------- ----------------
Balance December 31, 2003 5,037,963 32,660,119
=============== ================
PROVED DEVELOPED RESERVES:
December 31, 2001 3,939,593 21,203,989
=============== ================
December 31, 2002 4,025,552 25,374,113
=============== ================
December 31, 2003 3,772,926 24,642,407
=============== ================
F-31
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 11. Oil and Gas Reserves Information (Unaudited) - continued
STANDARDIZED MEASURE:
Standardized measure of discounted future net cash flows relating to proved
reserves:
2003 2002 2001
---- ---- ----
Future cash inflows $336,795,385 $308,381,837 $199,162,921
Future production and development
costs
Production 109,468,727 105,629,872 77,526,278
Development 21,460,459 23,350,811 23,610,596
--------------- -------------- --------------
Future cash flows before income
taxes 205,866,199 179,401,154 98,026,047
Future income taxes (46,885,360) (38,611,577) (13,281,358)
--------------- -------------- --------------
Future net cash flows after income
taxes 158,980,839 140,789,577 84,744,689
10% annual discount for estimated
timing of cash flows (70,653,419) (63,165,742) (35,895,306)
--------------- -------------- --------------
Standardized measure of discounted
future net cash flows $88,327,420 $77,623,835 $48,849,383
=============== ============== ==============
The following reconciles the change in the standardized measure of
discounted future net cash flows:
Beginning of year $77,623,835 $48,849,383 $90,381,127
Changes from:
Purchases - 3,054,793 27,032,359
Sales - (953,159) (443,324)
Extensions, discoveries and
improved
recovery, less related costs - 2,002,176 427,192
Sales of oil and gas produced net
of
production costs (5,316,619) (5,016,964) (7,270,603)
Revision of quantity estimates (3,751,921) (9,974,557) (1,783,276)
Accretion of discount 9,889,881 5,649,945 12,414,073
Change in income taxes (4,793,281) (13,624,917) 26,109,535
Changes in estimated future
development costs 2,003,801 (5,254,561) (6,360,990)
Development costs incurred that
reduced future development
costs 2,024,663 5,569,881 5,945,369
Change in sales and transfer
prices,
net of production costs 16,470,113 46,903,282 (89,573,528)
Changes in production rates
(timing)
and other (5,823,052) 418,533 (8,028,551)
--------------- -------------- --------------
End of year $88,327,420 $77,623,835 $48,849,383
=============== ============== ==============
F-32
GULFWEST ENERGY INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 12. Quarterly Results (Unaudited)
Summary data relating to the results of operations for each quarter for the
years ended December 31, 2003 and 2002 follows:
Three Months Ended
----------------------------------------------------------
March 31 June 30 September 30 December 31
------------- ------------- ------------ --------------
2003
Net sales $3,250,603 $2,790,124 $2,436,063 $2,533,933
Gross profit 862,683 406,576 81,573 (433,321)
Net income (loss) 120,659 (1,231,883) (399,457) (1,640,828)
Income (loss) per
common
share - basic
and diluted $.01 $(.07) $(.02) $(.09)
2002
Net sales $2,648,873 $2,951,798 $2,641,626 $2,597,500
Gross profit 239,912 450,255 100,527 136,961
Net income (loss) (1,964,010) (305,060) (924,750) (1,420,993)
Income (loss) per
common
share - basic
and diluted $(0.11) $(0.02) $(0.05) $(0.07)
F-33
INDEPENDENT AUDITOR'S REPORT
Shareholders and Board of Directors
GULFWEST ENERGY INC.
Our report on the consolidated financial statements of GulfWest Energy Inc.
and Subsidiaries as of December 31, 2003 and 2002 and for each of the three
years in the period ended December 31, 2003, is included on page F-2. In
connection with our audit of such consolidated financial statements, we have
also audited the related financial statement schedule for the years ended
December 31, 2003, 2002 and 2001 on page F-31.
In our opinion, the financial statement schedule referred to above, when
considered in relation to the basic consolidated financial statements taken as a
whole, presents fairly, in all material respects, the information required to be
included therein.
\s\ WEAVER AND TIDWELL, L.L.P.
-----------------------------
WEAVER AND TIDWELL, L.L.P.
Dallas, Texas
March 19, 2004
F-34
GULFWEST ENERGY INC. AND SUBSIDIARIES
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
FOR THE YEARS ENDED DECEMBER 31, 2003, 2002 AND 2001
BALANCE BALANCE
DESCRIPTION AT PROVISIONS/ RECOVERIES/ AT
BEGINNING ADDITIONS DEDUCTIONS END
OF PERIOD OF PERIOD
------------------------- ------------ -------------- -------------- --------------
For the year ended
December 31, 2001
Accounts and
notes
receivable
related
parties $740,478 $- $- $740,478
============ ============== ============== ==============
Valuation
allowance for
deferred
tax
assets $5,014,451 $(345,754) $- $4,668,697
============ ============== ============== ==============
For the year ended
December 31, 2002
Accounts and
notes
Receivable
related
parties $740,478 $- $(740,478) $-
============ ============== ============== ==============
Valuation
allowance for
deferred
tax
assets $4,668,697 $1,586,988 $- $6,255,685
============ ============== ============== ==============
For the year ended
December 31, 2003
Valuation
allowance for
deferred
tax
assets $6,255,685 $934,422 $- $7,190,107
============ ============== ============== ==============
F-35
GULFWEST ENERGY, INC.
19,179,192 Shares
Class A Common Stock
December 7, 2004
II-36