<PAGE> 1
AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON AUGUST 31, 1998
REGISTRATION NO. 333-
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SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
-----------------------
FORM S-1
REGISTRATION STATEMENT UNDER THE SECURITIES ACT OF 1933
-----------------------
GULFPORT ENERGY CORPORATION
(Exact name of registrant as specified in its charter)
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<S> <C> <C>
DELAWARE 1311 73-1521290
(State or other jurisdiction of (Primary Standard Industrial (I.R.S. Employer
incorporation or organization) Classification Code Number) Identification No.)
</TABLE>
6307 WATERFORD BLVD., SUITE 100
OKLAHOMA CITY, OKLAHOMA 73118
(405) 848-8807
(ADDRESS, INCLUDING ZIP CODE, AND TELEPHONE NUMBER,
INCLUDING AREA CODE, OF REGISTRANT'S PRINCIPAL EXECUTIVE OFFICES)
MARK LIDDELL
PRESIDENT
6307 WATERFORD BLVD., SUITE 100
OKLAHOMA CITY, OKLAHOMA 73118
(405) 848-8807
(NAME, ADDRESS, INCLUDING ZIP CODE, AND TELEPHONE NUMBER,
INCLUDING AREA CODE, OF AGENT FOR SERVICE)
WITH A COPY TO:
SETH R. MOLAY, P.C.
AKIN, GUMP, STRAUSS, HAUER & FELD, L.L.P.
1700 PACIFIC AVENUE
SUITE 4100
DALLAS, TEXAS 75201
(214) 969-2800
Approximate date of commencement of proposed sale to the public: As
soon as practicable after the effective date of this Registration Statement.
If any of the securities being registered on this Form are to be
offered on a delayed or continuous basis pursuant to Rule 415 under the
Securities Act of 1933, check the following box. [X]
If this Form is filed to register additional securities for an offering
pursuant to Rule 462(b) under the Securities Act, please check the following box
and list the Securities Act registration statement number of the earlier
effective registration statement for the same offering. [ ]
If this Form is a post-effective amendment filed pursuant to Rule
462(c) under the Securities Act, check the following box and list the Securities
Act registration statement number of the earlier effective registration
statement for the same offering. [ ]
If delivery of the prospectus is expected to be made pursuant to Rule
434, please check the following box: [ ]
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CALCULATION OF REGISTRATION FEE
========================================================================================================================
PROPOSED PROPOSED
MAXIMUM MAXIMUM AMOUNT OF
TITLE OF EACH CLASS AMOUNT TO BE OFFERING PRICE AGGREGATE REGISTRATION
OF SECURITIES TO BE REGISTERED REGISTERED(1) PER SHARE(2) OFFERING PRICE(2) FEE
- ------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
Common Stock, $.01 par value per share 100,000,000 Shares $0.10 $10,000,000 $2,950
- ------------------------------------------------------------------------------------------------------------------------
Rights(3) -- -- -- --(4)
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(1) Pursuant to Rule 416(a) of the Securities Act of 1933, as amended, this
Registration Statement also relates to any and all Rights issued hereby
due to the rounding up of Rights distributed hereby to the nearest whole
number for each recipient thereof, and the Common Stock issuable upon
exercise thereof.
(2) Estimated solely for the purpose of calculating the registration fee in
accordance with Rule 457.
(3) Evidencing the rights to subscribe for the shares of Common Stock
described above.
(4) Since both the Rights and the Common Stock underlying the Rights are being
registered for distribution under this Registration Statement, for
purposes of Rule 457 there is no separate registration fee for the Rights.
THE REGISTRANT HEREBY AMENDS THIS REGISTRATION STATEMENT ON SUCH DATE
OR DATES AS MAY BE NECESSARY TO DELAY ITS EFFECTIVE DATE UNTIL THE REGISTRANT
SHALL FILE A FURTHER AMENDMENT WHICH SPECIFICALLY STATES THAT THIS REGISTRATION
STATEMENT SHALL THEREAFTER BECOME EFFECTIVE IN ACCORDANCE WITH SECTION 8(a) OF
THE SECURITIES ACT OF 1933 OR UNTIL THE REGISTRATION STATEMENT SHALL BECOME
EFFECTIVE ON SUCH DATE AS THE COMMISSION, ACTING PURSUANT TO SECTION 8(a), MAY
DETERMINE.
<PAGE> 3
INFORMATION CONTAINED HEREIN IS SUBJECT TO COMPLETION OR AMENDMENT. A
REGISTRATION STATEMENT RELATING TO THESE SECURITIES HAS BEEN FILED WITH THE
SECURITIES AND EXCHANGE COMMISSION. THESE SECURITIES MAY NOT BE SOLD NOR MAY
OFFERS TO BUY BE ACCEPTED PRIOR TO THE TIME THE REGISTRATION STATEMENT BECOMES
EFFECTIVE. THIS PROSPECTUS SHALL NOT CONSTITUTE AN OFFER TO SELL OR THE
SOLICITATION OF ANY OFFER TO BUY NOR SHALL THERE BE ANY SALE OF THESE SECURITIES
IN ANY STATE IN WHICH SUCH OFFER, SOLICITATION OR SALE WOULD BE UNLAWFUL PRIOR
TO REGISTRATION OR QUALIFICATION UNDER THE SECURITIES LAWS OF ANY SUCH STATE.
SUBJECT TO COMPLETION, DATED AUGUST 31, 1998
PROSPECTUS
GULFPORT ENERGY CORPORATION
100,000,000 SHARES OF COMMON STOCK
---------------------
Gulfport Energy Corporation, a Delaware corporation formerly known as
WRT Energy Corporation (the "Company"), is distributing to the holders of its
Common Stock, par value $.01 per share (the "Common Stock"), non-transferable
rights (the "Rights") to subscribe for and purchase an aggregate of
approximately 100,000,000 shares (the "Shares") of Common Stock. Holders of
Common Stock of record as of __________, 1998 ("Eligible Stockholders") are
entitled to receive one Right for each 0.22076 share of Common Stock held as of
such date. Each Right entitles the holder to subscribe to purchase one share of
Common Stock for $0.10 (the "Subscription Price"). Holders of Rights who
exercise all of their Rights will have the right to oversubscribe for Shares at
the Subscription Price, subject to pro rata allocation based on the number of
Shares oversubscribed by each holder of Rights. No fractional rights or cash in
lieu thereof will be distributed by the Company, and the number of Rights
distributed to each Eligible Stockholder will be rounded up to the nearest whole
number. The distribution of the Rights and sale of shares of Common Stock are
referred to herein as the "Rights Offering."
The Rights will expire at 5:00 p.m., Kansas City time, on
_______________, 1998, unless extended by the Company (such date and time, the
"Expiration Date"), and thereafter will be void and of no effect. Holders who do
not exercise their Rights prior to the Expiration Date will relinquish the value
inherent in the Rights. Once a holder has exercised any Rights, such exercise
may not be revoked. There is no minimum number of Shares that must be subscribed
for in the Rights Offering for it to be completed. The Board of Directors of the
Company may, in its sole discretion, amend the terms and conditions of the
Rights Offering or terminate the Rights Offering and revoke the Rights at any
time prior to the Expiration Date.
The Common Stock is traded in the over-the-counter market under the
symbol "GPOR." On August 27, 1998, the closing bid price of the Common Stock, as
reported on the over-the-counter ("OTC") Bulletin Board, was $0.47 See "Price
Range of Common Stock."
SEE "RISK FACTORS" BEGINNING ON PAGE 5 FOR A DISCUSSION OF CERTAIN
FACTORS THAT SHOULD BE CONSIDERED IN CONNECTION WITH AN INVESTMENT IN THE COMMON
STOCK OFFERED HEREBY.
---------------------
THESE SECURITIES HAVE NOT BEEN APPROVED OR DISAPPROVED BY THE SECURITIES AND
EXCHANGE COMMISSION OR ANY STATE SECURITIES COMMISSION, NOR HAS THE
SECURITIES AND EXCHANGE COMMISSION OR ANY STATE SECURITIES COMMISSION
PASSED UPON THE ACCURACY OR ADEQUACY OF THIS PROSPECTUS. ANY
REPRESENTATION TO THE CONTRARY IS A CRIMINAL OFFENSE.
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SUBSCRIPTION PROCEEDS TO
PRICE COMPANY(1)
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<S> <C> <C>
Per share of Common Stock......... $ 0.10 $10,000,000
Total ............................ $10,000,000 $10,000,000
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</TABLE>
(1) Before deducting expenses payable by the Company with respect to the
Rights Offering, estimated at approximately $________. The Shares are
being offered and sold directly by the Company, and no commission or
other remuneration will be paid to any person for soliciting purchases of
Shares in the Rights Offering. See "The Rights Offering."
---------------------
THE DATE OF THIS PROSPECTUS IS _____________, 1998
<PAGE> 4
PROSPECTUS SUMMARY
The following summary is qualified in its entirety by the more detailed
information and financial statements (including the notes thereto) appearing
elsewhere in this Prospectus. Unless the context otherwise requires, (i) the
term the "Company" means Gulfport Energy Corporation, formerly known as WRT
Energy Corporation, and its subsidiaries taken as a whole, either prior to or
after the Effective Date (as defined herein), as the context requires, (ii) the
term "Gulfport" means Gulfport Energy Corporation and its subsidiaries taken as
a whole after the Effective Date, and (iii) the term "Old WRT" means WRT Energy
Corporation and its subsidiaries taken as a whole prior to the Effective Date.
Certain terms relating to the oil and gas business are defined in the "Glossary
of Certain Oil and Gas Terms" section of this Prospectus. The Company intends to
amend its Certificate of Incorporation to increase the number of authorized
shares of Common Stock. The closing of the Rights Offering on the terms
described herein is subject to effectiveness of such amendment.
THE COMPANY
The Company owns and operates mature oil and gas properties in the
Louisiana Gulf Coast area. The Company seeks to achieve reserve growth and
increase its cash flow by entering into strategic alliances with companies
possessing Gulf Coast exploration experience and by undertaking lower risk
development projects. The Company was organized in July 1997 and merged with WRT
Energy Corporation, a Texas corporation ("Old WRT"), on July 11, 1997 upon the
consummation of Old WRT's bankruptcy reorganization.
On February 14, 1996 (the "Petition Date"), Old WRT filed a petition with
the United States Bankruptcy Court for the Western District of Louisiana (the
"Bankruptcy Court") for protection under Chapter 11 of the United States
Bankruptcy Code (the "Bankruptcy Code"). Such case is referred to herein as the
"Reorganization Case." By order dated May 5, 1997, the Bankruptcy Court
confirmed the Joint Plan of Reorganization (the "Plan") of Old WRT and
co-proponents DLB Oil and Gas, Inc. ("DLB") and Wexford Management, LLC
("Wexford Management" and, together with DLB, "DLBW"). The Plan was consummated
and became effective on July 11, 1997 (the "Effective Date"). On the Effective
Date, Old WRT was merged with and into Gulfport, which was a newly formed
Delaware corporation named "WRT Energy Corporation." Effective March 30, 1998,
the Company changed its name to "Gulfport Energy Corporation."
The Company's principal executive offices are located at 6307 Waterford
Blvd., Suite 100, Oklahoma City, Oklahoma 73118, and its telephone number is
(405) 848-8807.
THE RIGHTS OFFERING
Rights.......................... Each Eligible Stockholder will receive one
non-transferable Right for each 0.22076
shares of Common Stock held of record by
such holder at the close of business on
___________, 1998 (the "Record Date"). No
fractional rights or cash in lieu thereof
will be distributed by the Company; instead
the number of Rights distributed by the
Company to each holder of Common Stock will
be rounded up to the nearest whole number.
An aggregate of approximately 100,000,000
Rights will be distributed pursuant to the
Rights Offering. Each Right will entitle the
holder thereof to subscribe to purchase one
Share for the Subscription Price. An
aggregate of approximately 100,000,000
shares of Common Stock will be sold upon
exercise of all the Rights. See "The Rights
Offering--The Rights."
Basic Subscription Privilege.... Each Right will entitle the Eligible
Stockholder to receive, upon payment of the
Subscription Price, one Share (the "Basic
Subscription Privilege"). See "The Rights
Offering--Subscription Privileges--Basic
Subscription Privilege."
Oversubscription Privilege...... Each Eligible Stockholder who exercises in
full such holder's Basic Subscription
Privilege may also subscribe for Excess
Shares (as
<PAGE> 5
defined herein), if any, at the
Subscription Price (the "Oversubscription
Privilege"). If an insufficient number of
Excess Shares is available to satisfy all
exercises of the Oversubscription
Privilege, the available Excess Shares will
be prorated among Eligible Stockholders who
exercise their Oversubscription Privilege
in proportion to the respective number of
Rights exercised by the holder pursuant to
the Basic Subscription Privilege. See "The
Rights Offering--Subscription
Privileges--Oversubscription Privilege."
Excess Shares .................... All of the Shares not initially subscribed
for through the exercise of the Basic
Subscription Privilege by the Eligible
Stockholders (the "Excess Shares").
Subscription Price................ $0.10 per Share.
Expiration Date................... 5:00 p.m., Kansas City time, on __________,
1998 (subject to extension by the Company).
Rights not exercised prior to the
Expiration Date will be void and will no
longer be exercisable by the holder.
Procedure for Exercising Rights... The Basic Subscription Privilege and the
Oversubscription Privilege may be exercised
by properly completing and signing the
Subscription Certificate evidencing the
Rights (each, a "Subscription Certificate")
and forwarding such Subscription
Certificate by mail, hand or
overnight/express mail carrier (or
following the guaranteed delivery
procedures), together with payment of the
Subscription Price for each Share
subscribed for pursuant to the Basic
Subscription Privilege and the
Oversubscription Privilege, to UMB Bank,
NA, as subscription agent (the
"Subscription Agent"), on or prior to the
Expiration Date to the following address:
UMB Bank, NA
Securities Transfer Division
928 Grand Avenue
13th Floor
Kansas City, MO 64106
If forwarding Subscription Certificates by
mail, it is recommended that insured,
registered mail be used. No interest will
be paid on funds delivered in payment of
the Subscription Price. The "Instructions
as to Use of Gulfport Energy Corporation
Subscription Certificates" (the
"Instructions") accompanying the
Subscription Certificates should be read
carefully and followed in detail. See "The
Rights Offering--Exercise of Rights."
2
<PAGE> 6
NO REVOCATION.................... Once a holder of Rights has exercised the
Basic Subscription Privilege or the
Oversubscription Privilege, such exercise
may not be revoked. See "The Rights
Offering--No Revocation."
Transferability of Rights........ The Rights are non-transferable and will
not be traded during the period they are
outstanding.
Certain Federal Income Tax
Considerations................. For United States federal income tax
purposes, Rights holders generally will not
recognize taxable income in connection with
the issuance to them or exercise by them of
Rights. Rights holders may incur gain or
loss upon the sale of the shares of Common
Stock upon the exercise of the Rights or
upon the receipt of dividends. See "Certain
Federal Income Tax Considerations."
Use of Proceeds.................. Net cash proceeds, if any, from the Rights
Offering will be used by the Company for
general corporate purposes, including its
short-term operating needs and capital
expenditures. See "Use of Proceeds."
Amendment and Termination........ The Board of Directors of the Company may,
in its sole discretion, amend the terms
and conditions of the Rights Offering or
terminate the Rights Offering and revoke
the Rights at any time prior to the
Expiration Date.
Subscription Agent............... UMB Bank, NA.
Dilution......................... To the extent an Eligible Stockholder does
not exercise its Rights in full, such
Eligible Stockholder's voting power and
percentage equity interest in the Company,
including its percentage interest in any
future earnings, would suffer substantial
dilution.
Common Stock Outstanding as of
the Record Date................ 22,076,315 shares
Common Stock Outstanding after
the Rights Offering............ 122,076,315 shares (assuming all the Rights
are exercised)(1).
RISK FACTORS
See "Risk Factors" for a discussion of certain factors that should be
considered in connection with an investment in the Common Stock offered hereby,
including certain risks associated with the Rights Offering.
- ----------
(1) Excludes options to purchase 60,000 shares of Common Stock issued to an
employee of the Company and warrants to purchase 221,000 shares of Common Stock
issued pursuant to the Plan. See "Management" and Note 11 to the Company's
Consolidated Financial Statements.
3
<PAGE> 7
SUMMARY HISTORICAL FINANCIAL DATA
The following summary historical financial data as of and for the years
ended December 31, 1996 and 1995, as of and for the six months and ten days
ended July 10, 1997, and for the six months ended June 30, 1997 for Old WRT and
as of and for the five months and 21 days ended December 31, 1997 and the six
months ended June 30, 1998 for Gulfport are derived from the consolidated
financial statements of the Company included elsewhere in this Prospectus. The
selected financial data at December 31, 1994 and 1993 and for the years then
ended have been derived from historical consolidated financial statements of Old
WRT. The financial data set forth below should be read in conjunction with
"Management's Discussion and Analysis of Financial Condition and Results of
Operations" and the consolidated financial statements of the Company and the
notes thereto included elsewhere in this Prospectus. The historical financial
data as of December 31, 1996 and 1997 and for the six months and ten days ended
July 10, 1997 and the five months and 21 days ended December 31, 1997 have been
derived from the Company's audited consolidated financial statements. All other
historical financial data have been derived from unaudited consolidated
financial statements of the Company.
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GULFPORT OLD WRT
---------------------------- ----------------------------
SIX SIX
MONTHS JULY 11, SIX MONTHS MONTHS
ENDED 1997 TO TEN DAYS ENDED ENDED
JUNE 30, DECEMBER 31, JULY 10, JUNE 30,
1998 1997 1997 1997
---------- ------------ -------------- ----------
(UNAUDITED)
STATEMENT OF OPERATIONS DATA (IN THOUSANDS, EXCEPT PER
SHARE AMOUNTS)
<S> <C> <C> <C> <C>
Oil and gas sales .................... $ 6,722 $ 9,756 $ 10,138 $ 5,381
---------- ---------- ---------- ----------
Operating expenses ................... 26,590(3) 11,478 11,002 4,605
---------- ---------- ---------- ----------
Net income(loss) from operations ..... (19,868) (1,713) (864) 776
---------- ---------- ---------- ----------
Interest expense ..................... 758 727 1,106 615
Reorganization costs ................. -- -- 7,771 1,026
Net income (loss) before income
taxes and extraordinary item ...... (20,280) (1,713) (9,615) (815)
Extraordinary item ................... -- -- 88,723 --
Net income (loss) before
dividends on preferred stock ...... (20,280) (1,713) 79,108 (815)
Dividends on preferred stock(4) ...... -- -- (1,510) (712)
Net income (loss) attributable to
common stock ...................... (20,280) (1,713) 77,598 (1,527)
Earnings (loss) per common
and common equivalent share(5) .... (0.92) (0.08) N/A N/A
Average common and common
equivalent shares outstanding ..... 22,076 22,076 9,539 9,539
Capital expenditures ................. $ 805 $ 5,644 $ 2,562 $ 250
<CAPTION>
OLD WRT
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YEAR ENDED DECEMBER 31,
-----------------------------------------------------------
1996 1995 1994 1993
---------- ---------- ---------- ----------
(UNAUDITED) (UNAUDITED) (UNAUDITED)
<S> <C> <C> <C> <C>
Oil and gas sales .................... $ 24,019 $ 24,655 $ 11,034 $ 4,657
---------- ---------- ---------- ----------
Operating expenses ................... 40,855(2) 139,497(1) 10,126 5,841
---------- ---------- ---------- ----------
Net income(loss) from operations ..... (16,836) (114,842) 908 (1,184)
---------- ---------- ---------- ----------
Interest expense ..................... 5,562 13,759 19 447
Reorganization costs ................. 7,345 -- -- --
Net income (loss) before income
taxes and extraordinary item ...... (29,387) (128,175) 4,266 (1,322)
Extraordinary item ................... -- -- -- --
Net income (loss) before
dividends on preferred stock ...... (29,387) (128,175) 4,230 (1,322)
Dividends on preferred stock(4) ...... (2,846) (2,846) (2,846) (591)
Net income (loss) attributable to
common stock ...................... (32,233) (131,021) 1,384 (1,913)
Earnings (loss) per common
and common equivalent share(5) .... N/A N/A N/A N/A
Average common and common
equivalent shares outstanding ..... 9,539 9,466 7,792 4,154
Capital expenditures ................. $ 4,823 $ 116,730 $ 40,087 $ 14,325
</TABLE>
<TABLE>
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GULFPORT OLD WRT
-------------------------- ----------
JUNE 30, DECEMBER 31, JULY 10,
1998 1997 1997
---------- ------------ ----------
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BALANCE SHEET DATA
Working capital (deficit) .............. $ (4,949) $ (719) $ (148,231)
Property, plant and
equipment, net ...................... 62,341 81,501 55,698
Total assets ........................... 72,191 92,346 67,706
Total long-term debt ................... 10,660 13,528 --
Shareholders' equity (deficit) ......... 50,000 70,280 (91,366)
<CAPTION>
OLD WRT
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DECEMBER 31,
------------------------------------------------------
1996 1995 1994 1993
---------- ---------- ---------- ----------
(IN THOUSANDS)
<S> <C> <C> <C> <C>
BALANCE SHEET DATA
Working capital (deficit) .............. $ (148,932) $ (131,601) $ 6,301 $ 24,270
Property, plant and
equipment, net ...................... 56,899 63,913 59,042 18,586
Total assets ........................... 68,076 79,247 81,857 48,233
Total long-term debt ................... -- -- 6,260 205
Shareholders' equity (deficit) ......... (90,551) (61,869) 63,538 43,394
</TABLE>
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(1) Operating expenses for 1995 include a non-cash charge of $103,000,000
related to impairment of long-lived assets pursuant to SFAS No. 121,
non-cash charges of $3,600,000 related to a minimum production guarantee
obligation, a $2,000,000 provision for doubtful accounts, and a $1,400,000
charge related to restructuring costs incurred. See "Management's
Discussion and Analysis of Financial Condition and Results of Operations."
(2) Operating expenses for 1996 include a non-cash charge of $3,900,000
related to impairment of long-lived assets pursuant to SFAS No. 121,
non-cash charges of $5,600,000 related to a minimum production guarantee
obligation, and a $5,200,000 provision for doubtful accounts. See
"Management's Discussion and Analysis of Financial Condition and Results
of Operations."
(3) Operating expense for the six months ended June 30, 1998 include a
non-cash charge of $16,200,000 related to a ceiling test write-down. See
"Management's Discussion and Analysis of Financial Condition and Results
of Operations."
(4) Reflects accrued but undeclared dividends during 1996 and during the six
months and ten days ended July 10, 1997.
(5) Earnings per share data not comparable to the Reorganization case.
4
<PAGE> 8
RISK FACTORS
In addition to the other information contained in this Prospectus and
the documents incorporated herein by reference, the following factors should be
considered carefully in evaluating an investment in the Common Stock offered
hereby.
DEPENDENCE ON RIGHTS OFFERING TO MEET CAPITAL REQUIREMENTS
The ability of the Company to satisfy its capital requirements and
implement its business strategy is dependent upon the success of the Rights
Offering. The Rights are nontransferable and the Company is not a party to any
standby commitment or other agreement pursuant to which Eligible Stockholders
have agreed to exercise any minimum number of Rights. The Company believes
that it will need at least $7.5 million to meet its short-term needs. Further,
the failure of the Company to raise at least $7.5 million through the Rights
Offering or a private placement of Common Stock on or before November 30, 1998
will constitute an event of default under the Amended Credit Agreement (as
defined herein). If such funds are not raised, the Company believes that it
will be forced to seek protection from its creditors under applicable
bankruptcy laws. In such an event, the Company believes that holders of the
Common Stock would realize little, if any, of their investment in the Company.
The Company currently has no financing plan to raise such capital other than
the Rights Offering.
RISKS ARISING FROM BANKRUPTCY REORGANIZATION; RECENT OPERATING LOSSES; GOING
CONCERN QUALIFICATION
During 1995 and 1996, Old WRT operated at a loss and filed for
protection under Chapter 11 of the Bankruptcy Code on February 14, 1996. On
April 28, 1997, the Plan was approved by the Bankruptcy Court. The Plan became
effective on July 11, 1997. Since the Effective Date, the Company has been
hampered by limited financial resources to meet its operating needs and
experienced losses for both the period July 11, 1997 to December 31, 1997 and
the six months ended June 30, 1998. The Company anticipates that it will
continue to incur significant losses. Further, in the event the Company
experiences losses from continuing operations in the future, the Company
anticipates that such losses could result in a stockholders' deficit.
The independent auditor's report on the financial statements of the
Company is modified and it states that there are conditions which raise
substantial doubt about the ability of the Company to continue as a going
concern. Specifically, the auditor's report states that revenues from the
Company's producing properties will not be sufficient to finance the estimated
future capital expenditures necessary to fully develop the existing proved
reserves, nor recover the carrying value of the Company's oil and natural gas
properties. The financial statements do not include any adjustments that might
result from this uncertainty. The financial statements included in this
Prospectus have been prepared assuming the Company will continue as a going
concern. See "Management's Discussion and Analysis of Financial Condition and
Results of Operations," "Business--Events Leading to the Reorganization Case"
and Note 2 to the Consolidated Financial Statements.
IMPAIRMENT OF ASSET VALUE
The Company uses the full cost method of accounting for its investment
in oil and gas properties. Under the full cost method of accounting, all costs
of acquisition, exploration and development of oil and gas reserves are
capitalized into a "full cost pool" as incurred, and properties in the pool are
depleted and charged to operations using the units-of-production method based on
the ratio of current production to total proved oil and gas reserves. To the
extent that such capitalized costs, net of depletion and amortization, exceed
the present value of estimated future net revenues, discounted at 10%, from
proved oil and gas reserves, after income tax effects, such excess costs are
charged to operations. Once incurred, a write down of oil and gas properties is
not reversible at a later date, even if oil or gas prices increase. As the
result of a ceiling test performed at June 30, 1998, the Company was required to
write down the value of its oil and gas properties by $16.0 million.
RISKS ARISING FROM LACK OF COMPARABLE OPERATING HISTORY
As a result of Old WRT's Chapter 11 reorganization and the adoption of
fresh-start accounting, certain components of the Company's results of
operations for the year ended December 31, 1997 are not comparable to prior
periods. See "Management's Discussion and Analysis of Financial Condition and
Results of Operations."
RISKS ARISING FROM VOLATILITY OF OIL AND GAS PRICES AND MARKETABILITY OF
PRODUCTION
The Company's revenues, profitability and future rate of growth are
substantially dependent upon prevailing prices for oil and gas. Oil and gas
prices have been extremely volatile in recent years and are likely to continue
to be volatile in the future. Such prices are affected by many factors outside
the control of the Company. These external factors and the volatile nature of
the energy markets make it difficult to estimate future prices of oil and gas.
Any substantial decline in the price of oil and gas will likely have a material
adverse effect on the Company's operations, financial condition and level of
expenditures for the development of its oil and gas reserves, and may result in
additional writedowns of the Company's investments due to ceiling test
limitations. The marketability of the Company's production depends in part upon
the availability, proximity and capacity of gathering systems, pipelines and
processing facilities. Federal and state regulation of oil and gas production
and transportation, general economic conditions, tax and energy policies,
changes in supply and changes in demand all could adversely affect the Company's
ability to produce and market its oil and gas. If market factors were to change
5
<PAGE> 9
dramatically, the financial impact on the Company could be substantial. The
availability of markets and the volatility of product prices are beyond the
control of the Company and thus represent a significant risk. See
"Business--Regulation" and "Management's Discussion and Analysis of Financial
Condition and Results of Operations."
In accordance with customary industry practice, the Company relies on
independent third party service providers to provide most of the services
necessary to drill new wells, including drilling rigs and related equipment and
services, horizontal drilling equipment and services, trucking services,
tubulars, fracing and completion services and production equipment. The industry
has experienced significant price increases for these services during the last
year and this trend is expected to continue into the future. These cost
increases could in the future significantly increase the Company's development
costs and decrease the return possible from drilling and development activities,
and possibly render the development of certain proved undeveloped reserves
uneconomical.
DEPENDENCE ON ACQUIRING OR FUNDING ADDITIONAL RESERVES
The Company's future success depends upon its ability to find, develop
or acquire additional oil and gas reserves that are economically recoverable.
The proved reserves of the Company will generally decline as reserves are
depleted, except to the extent that the Company conducts successful exploration
or development activities or acquires properties containing proved reserves, or
both. To increase reserves and production, the Company must commence exploratory
drilling, undertake other replacement activities or utilize third parties to
accomplish these activities. There can be no assurance, however, that the
Company will have sufficient resources to undertake these actions, that the
Company's exploratory projects or other replacement activities will result in
significant additional reserves or that the Company will have success drilling
productive wells at low finding and development costs. Furthermore, although the
Company's revenues may increase if prevailing oil and gas prices increase
significantly, the Company's finding costs for additional reserves could also
increase. For a discussion of the Company's reserves, see "Business--Reserves."
UNCERTAINTY OF ESTIMATES OF OIL AND GAS RESERVES
There are numerous uncertainties inherent in estimating quantities of
proved reserves and in projecting future rates of production and timing of
expenditures, including many factors beyond the control of the Company. The
reserve information set forth in this Prospectus represents only estimates based
on reports prepared by Netherland, Sewell & Associates, Inc., as of January 1,
1998. Petroleum engineering is not an exact science. Information relating to the
Company's proved oil and gas reserves is based upon engineering estimates.
Estimates of economically recoverable oil and gas reserves and of future net
cash flows necessarily depend upon a number of variable factors and assumptions,
such as historical production from the area compared with production from other
producing areas, the assumed effects of regulations by governmental agencies and
assumptions concerning future oil and gas prices, future operating costs,
severance and excise taxes, capital expenditures and workover and remedial
costs, all of which may in fact vary considerably from actual results. For these
reasons, estimates of the economically recoverable quantities of oil and gas
attributable to any particular group of properties, classifications of such
reserves based on risk of recovery and estimates of the future net cash flows
expected therefrom prepared by different engineers or by the same engineers at
different times may vary substantially. Actual production, revenues and
expenditures with respect to the Company's reserves will likely vary from
estimates, and such variances may be material. See "Business--Reserves."
OPERATING HAZARDS AND UNINSURED RISKS
The Company's operations are subject to all of the hazards and
operating risks inherent in drilling for and production of oil and gas,
including the risk of fire, explosions, blow-outs, pipe failure, abnormally
pressured formations and environmental hazards such as oil spills, gas leaks,
ruptures or discharges of toxic gases. The occurrence of any of these events
could result in substantial losses to the Company due to injury or loss of life,
severe damage to or destruction of property, natural resources and equipment,
pollution or other environmental damage, clean-up responsibilities, regulatory
investigation and penalties and suspension of operations. In accordance with
customary industry practice, the Company maintains insurance against some, but
not all, of these risks. There can be no assurance that any insurance will be
adequate to cover any losses or liabilities. The Company cannot predict the
continued availability of insurance, or its availability at premium levels that
justify its purchase. In
6
<PAGE> 10
addition, the Company may be liable for environmental damage caused by previous
owners of properties purchased by the Company, which liabilities would not be
covered by insurance. See "Business--Operational Hazards and Insurance."
RISKS ARISING FROM GOVERNMENTAL REGULATION
The Company's oil and gas operations are subject to various federal,
state and local governmental regulations which may be changed from time to time
in response to economic and political conditions. Matters subject to regulation
include discharge permits for drilling operations, drilling bonds, reports
concerning operations, the spacing of wells, unitization and pooling of
properties and taxation. From time to time, regulatory agencies have imposed
price controls and limitations on production by restricting the rate of flow of
oil and gas wells below actual production capacity to conserve supplies of oil
and gas. In addition, the production, handling, storage, transportation and
disposal of oil and gas, by-products thereof and other substances and materials
produced or used in connection with oil and gas operations are subject to
regulation under Federal, state and local laws and regulations primarily
relating to protection of human health and the environment. These laws and
regulations have continually imposed increasingly strict requirements for water
and air pollution control and solid waste management. Significant expenditures
may be required to comply with governmental laws and regulations applicable to
the Company. The Company believes the trend of more expansive and stricter
environmental legislation and regulations will continue. See
"Business--Regulation."
COMPETITION
The Company operates in a highly competitive environment. The Company
competes with major and independent oil and gas companies, many of whom have
financial and other resources substantially in excess of those available to the
Company. These competitors may be better positioned to take advantage of
industry opportunities and to withstand changes affecting the industry, such as
fluctuations in oil and gas prices and production, the availability of
alternative energy sources and the application of government regulation. See
"Business--Competition and Markets."
RISKS ARISING FROM CONCENTRATION OF OWNERSHIP
As of the date of this Prospectus, the Company's executive officers
and directors, in the aggregate, beneficially own approximately 48% of the
outstanding Common Stock. As a result, these stockholders, acting together,
are, and after completion of the Rights Offering, depending upon the exercise of
Rights by Eligible Stockholders, will continue to be able to influence
significantly and possibly control most matters requiring approval by the
stockholders of the Company, including the election of directors. Such a
concentration of ownership may have the effect of delaying or preventing a
change in control of the Company, including transactions in which stockholders
might otherwise receive a premium for their shares over then current market
prices. See "Management," "Principal Stockholders" and "Description of
Securities."
PREFERRED STOCK; POSSIBLE ANTI-TAKEOVER EFFECTS
The Company is authorized to issue up to 1,000,000 shares of preferred
stock, par value $.01 per share (the "Preferred Stock"), of which no shares are
outstanding as of the date hereof. Shares of Preferred Stock may be issued from
time to time in one or more series as the Board of Directors, by resolution or
resolutions, may from time to time determine, each of said series to be
distinctively designated. The voting powers, preferences and relative,
participating, optional and other special rights, and the qualifications,
limitations or restrictions thereof, if any, of each such series of Preferred
Stock may differ from those of any and all other series of Preferred Stock at
any time outstanding, and, subject to certain limitations of the Company's
Certificate of Incorporation and the Delaware General Corporation Law (the
"DGCL"), the Board of Directors may fix or alter, by resolution or resolutions,
the designation, number, voting powers, preferences and relative, participating,
optional and other special rights, and qualifications, limitations and
restrictions thereof, of each such series Preferred Stock.
7
<PAGE> 11
No Preferred Stock is currently outstanding, and the Company has no
present plans for the issuance of any Preferred Stock. However, the issuance of
any such Preferred Stock could materially adversely affect the rights of holders
of Common Stock and, therefore, could reduce the value of the Common Stock. In
addition, specific rights granted to future holders of Preferred Stock could be
used to restrict the Company's ability to merge with, or sell its assets to, a
third party. The ability of the Board of Directors to issue Preferred Stock
could discourage, delay or prevent a takeover of the Company, thereby preserving
control of the Company by the current stockholders. See "Description of
Securities."
LACK OF LIQUIDITY FOR COMMON STOCK
The common stock of Old WRT was delisted from the Nasdaq National
Market effective February 29, 1996 due to Old WRT's failure to meet certain
criteria for continued quotation. The Common Stock is quoted in the "pink
sheets" published by the National Quotation Bureau and is traded in the
over-the-counter market on the OTC Bulletin Board. See "Price Range of Common
Stock and Dividend Policy." The Rights are non-transferable.
DETERMINATION OF SUBSCRIPTION PRICE
The Subscription Price for a Share to be issued pursuant to the Rights
will be $0.10. The Subscription Price was determined by the Company. In
determining the Subscription Price, consideration was given to such factors as
the current market price of the Common Stock, the availability of financing
alternatives and the level and volatility of commodity prices. The Subscription
Price should not be considered an indication of the actual value of the Company
or the Common Stock. There can be no assurance that the market price of the
Common Stock will not decline during the subscription period or that, following
the issuance of the Common Stock upon exercise of Rights, a subscribing Rights
holder will be able to sell Shares purchased in the Rights Offering at a price
equal to or greater than the Subscription Price.
NON-PARTICIPANTS IN THE OFFERING WILL SUFFER SUBSTANTIAL DILUTION
To the extent an Eligible Stockholder does not exercise its Rights in
full, such Eligible Stockholder's voting power and percentage equity interest in
the Company, including its percentage interest in any future earnings, would
suffer substantial dilution.
LACK OF DIVIDENDS
The Company has paid no cash dividends on the Common Stock, and there
is no assurance that the Company will achieve sufficient earnings to pay cash
dividends on its Common Stock in the future. The Company intends to retain any
earnings to fund its operations. Therefore, the Company does not anticipate
paying any cash dividends on the Common Stock in the foreseeable future.
Further, the Amended Credit Agreement (as defined herein) restricts the Company
from declaring or paying any dividends on any class of its capital stock so long
as the Amended Credit Agreement is outstanding. See "Price Range of Common Stock
and Dividend Policy--Dividend Policy."
IRREVOCABILITY OF SUBSCRIPTIONS
The election of exercise Rights is irrevocable. Until certificates
representing the Shares are delivered, subscribing Rights holders may not be
able to sell such Shares. Certificates representing Shares purchased in the
Rights Offering will be delivered by mail as soon as practicable following the
Expiration Date. No interest will be paid to Rights holders on funds delivered
to the Subscription Agent pursuant to the exercise of Rights pending delivery of
such certificates and return of any excess funds not applied to the purchase of
Shares.
CERTAIN FEDERAL INCOME TAX CONSIDERATIONS
Holders of Common Stock should recognize no income or gain for federal
income tax purposes upon the receipt, exercise or lapse of the Rights.
Nevertheless, the federal income tax treatment of the distribution of Rights to
holders of Common Stock and any subsequent exercise or lapse of such Rights is
subject to some uncertainty. In
8
<PAGE> 12
addition, purchasers of Common Stock should consider the federal income tax
implications arising from the payment of dividends on or the sale of shares of
Common Stock. See "Certain Federal Income Tax Considerations" for a more
detailed discussion of the federal income tax consequences resulting from the
purchase, ownership and disposition of Rights and shares of Common Stock.
AVAILABILITY OF FEDERAL INCOME TAX BENEFITS
As of the date of the Offering, the Company has accrued certain net
operating losses ("NOLs"). The Company believes that the distribution and
exercise of Rights received in the Offering will not result in an ownership
change within the meaning of Section 382 of the Internal Revenue Code of 1986.
However, transfers of the Company's stock in the future could result in such an
ownership change. In such a case, the ability of the Company to use its NOLs
accrued through the ownership change date would be limited. In general, the
amount of NOL the Company could use for any tax year after the date of the
ownership change would be limited to the value of the stock of the Company (as
of the ownership change date) multiplied by the long-term tax-exempt rate.
DEPENDENCE ON MANAGEMENT SERVICES PROVIDED BY DLB EQUITIES, LLC
The Company depends upon management services provided solely by DLB
Equities, LLC pursuant to the Administrative Services Agreement (as defined
herein) to implement the Company's business strategy and manage its operations.
Although the Administrative Services Agreement has a primary term expiring on
April 28, 1999, thereafter it may be terminated on 60 days' written notice by
either party. After the expiration of the primary term, there can be no
assurance that DLB Equities, LLC will continue to provide management services to
the Company pursuant to the Administrative Services Agreement or otherwise.
Furthermore, the Administrative Services Agreement does not guarantee the
Company access to any of the executive officers listed under "Management" or any
of the operating personnel currently responsible for conducting the Company's
operations. In addition, there will be competition between the Company, on the
one hand, and DLB Equities, LLC and its affiliates, on the other hand, for the
time and effort of employees of DLB Equities, LLC who provide services to the
Company. If the Company were deprived of access to certain key members of its
management team, or other personnel or lost access to such services altogether,
the Company's results of operations could be materially adversely affected. See
"Certain Transactions--Administrative Services Agreement."
USE OF PROCEEDS TO SATISFY OBLIGATIONS OWED TO AFFILIATES.
Certain Eligible Stockholders, which own in the aggregate 10,677,894
shares of Common Stock and will receive Rights to purchase an aggregate of
48,368,095 Shares, are affiliates of a Director of the Company and the
Company's Chief Executive Officer and President, respectfully (the "Affiliated
Eligible Stockholders"). As of August 25, 1998, the Company owed (i) the
Affiliated Eligible Stockholders an aggregate of $2.4 million as the lenders
under the Stockholder Credit Facility (as defined herein) and (ii) three of
the Affiliated Eligible Stockholders approximately $1.6 million as the holders
of a receivable arising from services provided to the Company under the
Administrative Services Agreement. The Subscription Price for the Shares and
Excess Shares, if any, purchased by these stockholders will be paid through the
forgiveness of an equal amount owed to them by the Company and any outstanding
amounts will be repaid to such stockholders in cash out of the proceeds of the
Rights Offering or other available funds. See "Use of Proceeds" and "Certain
Transactions."
YEAR 2000 COMPLIANCE
The Company has and will continue to make certain investments in
software systems and applications to ensure it is year 2000 compliant. The
financial impact to the Company to ensure year 2000 compliance has not been and
is not anticipated to be material to its financial position or results of
operations.
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<PAGE> 13
DISCLOSURE REGARDING FORWARD-LOOKING STATEMENTS
This Prospectus includes "forward-looking statements" within the
meaning of Section 27A of the Securities Act of 1933, as amended (the
"Securities Act"), and Section 21E of the Securities Exchange Act of 1934, as
amended (the "Exchange Act"). All statements, other than statements of
historical facts, included in this Prospectus that address activities, events or
developments that the Company expects or anticipates will or may occur in the
future, including such things as estimated future net revenues from oil and gas
reserves and the present value thereof, future capital expenditures (including
the amount and nature thereof), business strategy and measures to implement
strategy, competitive strengths, goals, expansion and growth of the Company's
business and operations, plans, references to future success, references to
intentions as to future matters and other such matters are forward-looking
statements. These statements are based on certain assumptions and analyses made
by the Company in light of its experience and its perception of historical
trends, current conditions and expected future developments as well as other
factors it believes are appropriate in the circumstances. However, whether
actual results and developments will conform with the Company's expectations and
predictions is subject to a number of risks and uncertainties; general economic,
market or business conditions; the opportunities (or lack thereof) that may be
presented to and pursued by the Company; competitive actions by other oil and
gas companies; changes in laws or regulations; and other factors, many of which
are beyond the control of the Company. Consequently, all of the forward-looking
statements made in this Prospectus are qualified by these cautionary statements
and there can be no assurance that the actual results or developments
anticipated by the Company will be realized, or even if realized, that they will
have the expected consequences to or effects on the Company or its business or
operations.
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<PAGE> 14
USE OF PROCEEDS
There is no minimum number of Shares that must be subscribed for in
the Rights Offering for it to be completed. Accordingly, proceeds to the
Company from the Rights Offering will range from zero, assuming that no Shares
are purchased, to approximately $10.0 million, assuming that all of the Shares
are purchased, in each case prior to deducting expenses of the Rights Offering
which are currently estimated to be $____________. The net proceeds, if any,
from the Rights Offering will be used by the Company for general corporate
purposes, including its short-term operating needs and capital expenditures,
and may include payments on obligations owed by the Company to Affiliated
Eligible Stockholders arising from the Stockholder Credit Facility and the
Administrative Services Agreement. As of August 25, 1998, the Company owed (i)
the Affiliated Eligible Stockholders an aggregate of $2.4 million as the
lenders under a $3.0 million revolving credit facility (the "Stockholder Credit
Facility") and (ii) three of the Affiliated Eligible Stockholders approximately
$1.6 million as the holders of a receivable arising from services provided to
the Company under the Administrative Services Agreement. Borrowings under the
Stockholder Credit Facility will be used to repay $2.0 million of outstanding
indebtedness under the Amended Credit Agreement and the balance will be used
for general corporate purposes. The Subscription Price for the Shares and
Excess Shares, if any, purchased by Affiliated Eligible Stockholders will be
paid through the forgiveness of an equal amount owed to them by the Company and
any outstanding amounts will be repaid to such stockholders in cash out of the
proceeds of the Rights Offering or other available funds. At a Subscription
Price of $0.10 per Share, the Affiliated Eligible Stockholders could purchase
approximately 46 million Shares through the forgiveness of all such amounts.
The ability of the Company to satisfy its capital requirements and
implement its business strategy is dependent upon the success of the Rights
Offering. The Rights are nontransferable and the Company is not a party to any
standby commitment or other agreement pursuant to which Eligible Stockholders
have agreed to exercise any minimum number of Rights. The Company believes that
it will need at least $7.5 million to meet its short-term needs. Further, the
failure of the Company to raise at least $7.5 million through the Rights
Offering or a private placement of Common Stock on or before November 30, 1998
will constitute an event of default under the Amended Credit Agreement. If such
funds are not raised, the Company believes that it will be forced to seek
protection from its creditors under applicable bankruptcy laws. In such an
event, the Company believes that holders of the Common Stock would realize
little, if any, of their investment in the Company. The Company currently has
no financing plan to raise such capital other than the Rights Offering. See
"Management's Discussion and Analysis of Financial Condition and Results of
Operations" and "Certain Transactions."
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<PAGE> 15
CAPITALIZATION
The following table sets forth the capitalization of the Company as of
June 30, 1998, and as adjusted to reflect the sale of all 100,000,000 Shares
offered by the Company in the Rights Offering and the application of the net
proceeds therefrom as described under "Use of Proceeds." This table should be
read in conjunction with the Company's Consolidated Financial Statements and
Notes thereto that appear elsewhere in this Prospectus.
<TABLE>
<CAPTION>
AS OF JUNE 30, 1998
-------------------------------
HISTORICAL AS ADJUSTED(1)
------------ --------------
(IN THOUSANDS)
<S> <C> <C>
Current maturities of long-term debt (2)..... $ 3,014 $ 1,014
============ ============
Long-term debt (3) .......................... $ 10,424 $ 10,424
Other long-term liabilities ................. 236 236
------------ ------------
Total long-term liabilities ........... 10,660 10,660
Stockholders' equity:
Preferred Stock, $.01 par value,
authorized--1,000,000 shares;
none issued ......................... -- --
Common Stock, $.01 par value,
authorized--50,000,000 shares;
22,076,315 shares issued and
outstanding $ 221 $ 721
Additional paid-in capital ............ 71,772 81,192
Accumulated deficit ................... (21,993) (21,993)
------------ ------------
Total stockholders' equity ............ 50,000 59,920
------------ ------------
Total capitalization ................ $ 63,674 $ 71,594
============ ============
</TABLE>
- ----------
(1) Assumes that an aggregate of 100,000,000 shares of Common Stock are
purchased in the Rights Offering resulting in gross proceeds to the
Company of $10.0 million.
(2) At June 30, 1998, current maturities of large-term debt included $3.0
million owed under the Credit Agreement. In connection with the
execution of the Amended Credit Agreement, the Company intends to
repay $2.0 million of this amount with borrowings made under the
Stockholder Credit Facility. See "Use of Proceeds."
(3) For a description of the long-term debt, see "Management's Discussion
and Analysis of Financial Condition and Results of Operations" and Note
9 to the Consolidated Financial Statements included elsewhere in this
Prospectus.
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<PAGE> 16
PRICE RANGE OF COMMON STOCK AND DIVIDEND POLICY
Since the Effective Date, the Common Stock has been included for
quotation on the OTC Bulletin Board under the trading symbol "WRTE" (through
March 30, 1998) and "GPOR" thereafter. The following table sets forth the high
and low sales prices for the Common Stock in each quarter commencing with the
Effective Date:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31, 1997 LOW HIGH
---------------------------- ----------- -----------
<S> <C> <C>
Third quarter (commencing July 11, 1997) No activity No activity
Fourth quarter $ 3.75 $ 5.00
YEAR ENDING DECEMBER 31, 1998
-----------------------------
First Quarter $ 3.36 $ 4.63
Second Quarter $ 1.12 $ 3.38
Third Quarter (through August 27, 1998) $ 0.50 $ 1.31
</TABLE>
Prior to February 29, 1996, Old WRT's common stock was quoted on the
Nasdaq National Market under the symbol "WRTE." During the period January 1,
1996 through February 29, 1996, the high and low sales prices reported on the
Nasdaq National Market were $1.19 and $0.25, respectively. Effective February
29, 1996, Old WRT's common stock was delisted from the Nasdaq National Market.
HOLDERS OF RECORD
At the close of business on August 1, 1998, there were 22,076,315
shares of Common Stock outstanding held by 256 stockholders of record.
DIVIDEND POLICY
The Company has never paid dividends on the Common Stock. The Company
currently intends to retain all earnings to fund its operations. Therefore, the
Company does not intend to pay any cash dividends on the Common Stock in the
foreseeable future. Further, the Amended Credit Agreement restricts the Company
from declaring or paying any dividends on any class of its capital stock so long
as the Amended Credit Agreement is outstanding.
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<PAGE> 17
THE RIGHTS OFFERING
THE RIGHTS
The Company is distributing non-transferable Rights to the record
holders of its outstanding Common Stock as of the Record Date, at no cost to
such record holders. The Company will distribute one Right for each 0.22076
shares of Common Stock held on the Record Date. Each Right will entitle an
Eligible Stockholder to subscribe to purchase one share of Common Stock at the
Subscription Price.
No fractional Rights or cash in lieu thereof will be issued or paid,
and the number of Rights distributed to each holder of Common Stock will be
rounded up to the nearest whole number of Rights. Because the number of Rights
distributed to each record holder will be rounded up to the nearest whole
number, beneficial owners of Common Stock who are also the record holders of
such shares may receive more Rights than beneficial owners of Common Stock who
are not the record holders of their shares.
SUBSCRIPTION PRIVILEGES
BASIC SUBSCRIPTION PRIVILEGE. Each Right will entitle the holder
thereof to receive, upon payment of the Subscription Price, one Share.
Certificates representing Shares purchased pursuant to the Basic Subscription
Privilege will be delivered to subscribers as soon as practicable after the
Expiration Date, irrespective of whether the Subscription Privilege is exercised
immediately prior to the Expiration Date or earlier.
OVERSUBSCRIPTION PRIVILEGE. Subject to the allocation described below,
each Right also carries the right to subscribe at the Subscription Price for
Excess Shares. Only Eligible Stockholders who exercise their Basic Subscription
Privilege in full will be entitled to exercise the Oversubscription Privilege.
If the Excess Shares are not sufficient to satisfy all subscriptions
pursuant to the Oversubscription Privilege, the Excess Shares will be allocated
pro rata (subject to the elimination of fractional shares) among those Rights
holders exercising the Oversubscription Privilege, in proportion, not to the
number of shares requested pursuant to the Oversubscription Privilege, but to
the number of shares each beneficial holder subscribed for pursuant to the Basic
Subscription Privilege; provided, however, that if such pro rata allocation
results in any Rights holder being allocated a greater number of Excess Shares
than such holder subscribed for pursuant to the exercise of such holder's
Oversubscription Privilege, then such holder will be allocated only such number
of Excess Shares as such holder subscribed for and the remaining Excess Shares
will be allocated among all other holders exercising the Oversubscription
Privilege. Certificates representing Excess Shares purchased pursuant to the
Oversubscription Privilege will be delivered to subscribers as soon as
practicable after the Expiration Date and after all prorations and adjustments
by the terms of the Rights Offering have been effected.
Banks, brokers and other nominee holders of Rights who exercise the
Basic Subscription Privilege and the Oversubscription Privilege on behalf of
beneficial owners of Rights will be required to certify to the Subscription
Agent and the Company, in connection with the exercise of the Oversubscription
Privilege, as to the aggregate number of Rights that have been exercised and the
number of shares of Common Stock that are being subscribed for pursuant to the
Oversubscription Privilege by each beneficial owner of Rights on whose behalf
such nominee holder is acting.
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<PAGE> 18
EXPIRATION DATE
The Rights will expire at 5:00 p.m., Kansas City time, on __________,
1998, unless extended by the Company. After the Expiration Date, unexercised
Rights will be void and no longer exercisable by the holder. The Company will
not be obligated to honor any purported exercise of Rights received by the
Subscription Agent after the Expiration Date, regardless of when the documents
relating to such exercise were sent, except pursuant to the Guaranteed Delivery
Procedures described below.
DETERMINATION OF SUBSCRIPTION PRICE
The Subscription Price for a Share to be issued pursuant to the Rights
will be $0.10. The Subscription Price was determined by the Company. In
determining the Subscription Price, consideration was given to such factors as
the current market price of the Common Stock, the availability of financing
alternatives and the level and volatility of commodity prices. The Subscription
Price should not be considered an indication of the actual value of the Company
or the Common Stock. There can be no assurance that the market price of the
Common Stock will not decline during the subscription period or that, following
the issuance of the Common Stock upon exercise of Rights, a subscribing Rights
holder will be able to sell Shares purchased in the Rights Offering at a price
equal to or greater than the Subscription Price.
EXERCISE OF RIGHTS
Rights may be exercised by delivery to the Subscription Agent, on or
prior to the Expiration Date, of the properly completed and duly executed
subscription forms (together with any required signature guarantees),
accompanied by payment in full of the Subscription Price for each Share
subscribed for pursuant to the Basic Subscription Privilege and the
Oversubscription Privilege (except as permitted pursuant to clause (iii) of the
next sentence). Such payment in full must be made by (i) check or bank draft
drawn upon a United States bank or postal, telegraphic or express money order
payable to "UMB Bank, NA, as Subscription Agent"; or (ii) wire transfer of funds
to the account maintained by the Subscription Agent for such purpose at UMB
Bank, NA. Payment of the Subscription Price will be deemed to have been received
by the Subscription Agent only upon (a) clearance of any uncertified check, (b)
receipt by the Subscription Agent of any (i) certified check, cashier's check or
bank draft drawn upon a U.S. bank, (ii) check made payable by a member of a
national securities exchange or a member of the NASD or (iii) any postal,
telegraphic or express money order or (c) receipt of good funds in the
Subscription Agent's account designated above. PLEASE NOTE THAT FUNDS PAID BY
UNCERTIFIED PERSONAL CHECK MAY TAKE AT LEAST FIVE BUSINESS DAYS TO CLEAR.
ACCORDINGLY, HOLDERS WHO WISH TO PAY THE SUBSCRIPTION PRICE BY MEANS OF
UNCERTIFIED PERSONAL CHECK ARE URGED TO MAKE PAYMENT SUFFICIENTLY IN ADVANCE OF
THE EXPIRATION DATE TO ENSURE THAT SUCH PAYMENT IS RECEIVED AND CLEARS BY SUCH
DATE, AND ARE URGED TO CONSIDER PAYMENT BY MEANS OF CERTIFIED OR CASHIER'S
CHECK, MONEY ORDER OR WIRE TRANSFER OF FUNDS.
Subscription forms and payment of the Subscription Price should be
delivered to one of the addresses set forth below under "--Subscription Agent."
If a Rights holder wishes to exercise Rights, but time will not permit
such holder to cause the Subscription Certificate(s) evidencing such Rights to
reach the Subscription Agent on or prior to the Expiration Date, such Rights may
nevertheless be exercised if all of the following conditions (the "Guaranteed
Delivery Procedures") are met:
(i) such holder has caused payment in full of the Subscription
Price for each Share being subscribed for pursuant to the Basic
Subscription Privilege and the Oversubscription Privilege to be
received (in the manner set forth above) by the Subscription Agent on
or prior to the Expiration Date;
(ii) the Subscription Agent receives, on or prior to the
Expiration Date, a notice of guaranteed delivery (a "Notice of
Guaranteed Delivery"), substantially in the form provided with the
Instructions distributed with the Subscription Certificates, from a
member firm of a registered national securities exchange or a member of
the National Association of Securities Dealers, Inc., or a commercial
bank or
15
<PAGE> 19
trust company having an office or correspondent in the United States
(each, an "Eligible Institution"), stating the name of the exercising
Rights holder, the number of Rights held by such exercising holder, the
number of shares of Common Stock being subscribed for pursuant to the
Basic Subscription Privilege and the number of shares, if any, being
subscribed for pursuant to the Oversubscription Privilege, and
guaranteeing the delivery to the Subscription Agent of any Subscription
Certificate(s) evidencing such Rights within three business days
following the date of the Notice of Guaranteed Delivery; and
(iii) the properly completed and duly executed Subscription
Certificate(s), including any required signature guarantees, evidencing
the Rights being exercised is received by the Subscription Agent within
three business days following the date of the Notice of Guaranteed
Delivery relating thereto. The Notice of Guaranteed Delivery may be
delivered to the Subscription Agent in the same manner as Subscription
Certificates at the address set forth below, or may be transmitted to
the Subscription Agent by facsimile transmission Facsimile No. (816)
221-0438. Additional copies of the form of Notice of Guaranteed
Delivery are available upon request from the Information Agent.
Unless a subscription form (i) provides that the Shares to be issued
pursuant to the exercise of Rights represented thereby are to be delivered to
the record holder of such Rights or (ii) is submitted for the account of an
Eligible Institution, signatures on such Subscription Certificate must be
guaranteed by an Eligible Institution, subject to the standards and procedures
adopted by the Subscription Agent.
Funds received in payment of the Subscription Price for Excess Shares
subscribed for pursuant to the Oversubscription Privilege will be held in a
segregated account pending issuance of such Excess Shares. If an Eligible
Stockholder exercising the Oversubscription Privilege is allocated less than all
of the Excess Shares that such holder wished to subscribe for pursuant to the
Oversubscription Privilege, the excess funds paid by such holder in respect of
the Subscription Price for shares not issued will be returned by mail without
interest or deduction as soon as practicable after the Expiration Date.
A holder who holds shares of Common Stock for the account of others,
such as a broker, a trustee or a depositary for securities, should notify the
respective beneficial owners of such shares as soon as possible to ascertain
such beneficial owners' intentions and to obtain instructions with respect to
the Rights beneficially owned by them. Beneficial owners of Common Stock or
Rights held through such a holder of record should contact the holder and
request the holder to effect transaction in accordance with the beneficial
owner's instructions.
If either the number of Rights being exercised is not specified on a
subscription form, or the payment delivered is not sufficient to pay the full
aggregate Subscription Price for all shares of Common Stock stated to be
subscribed for, the Rights holder will be deemed to have exercised the maximum
number of Rights that could be exercised for the amount of the payment delivered
by such Rights holder. If the payment delivered by the Rights holder exceeds the
aggregate Subscription Price for the number of Rights evidenced by the
subscription form(s) delivered by such Rights holder, the payment will be
applied, until depleted, to subscribe for Shares in the following order: (i) to
subscribe for the number of Shares, if any, indicated on the subscription
form(s) pursuant to the Basic Subscription Privilege; (ii) to subscribe for
Shares until the Basic Subscription Privilege has been fully exercised with
respect to all of the Rights represented by the subscription form(s); and (iii)
to subscribe for additional Shares pursuant to the Oversubscription Privilege
(subject to any applicable proration). Any excess payment remaining after the
foregoing allocation will be returned to the Rights holder as soon as
practicable by mail, without interest or deduction.
The Instructions accompanying the subscription forms should be read
carefully and followed in detail. DO NOT SEND SUBSCRIPTION FORMS OR PAYMENT TO
THE COMPANY.
THE METHOD OF DELIVERY OF SUBSCRIPTION FORMS AND PAYMENT OF THE
SUBSCRIPTION PRICE TO THE SUBSCRIPTION AGENT WILL BE AT THE ELECTION AND RISK OF
THE RIGHTS HOLDERS, BUT IF SENT BY MAIL IT IS RECOMMENDED THAT SUCH CERTIFICATES
AND PAYMENTS BE SENT BY REGISTERED MAIL, PROPERLY INSURED, WITH RETURN RECEIPT
REQUESTED, AND THAT A SUFFICIENT NUMBER OF DAYS BE ALLOWED TO ENSURE DELIVERY TO
THE SUBSCRIPTION AGENT AND CLEARANCE OF PAYMENT PRIOR TO THE EXPIRATION DATE.
BECAUSE UNCERTIFIED PERSONAL CHECKS MAY TAKE AT LEAST
16
<PAGE> 20
FIVE BUSINESS DAYS TO CLEAR, RIGHTS HOLDERS ARE STRONGLY URGED TO PAY, OR
ARRANGE FOR PAYMENT, BY MEANS OF CERTIFIED OR CASHIER'S CHECK, MONEY ORDER OR
WIRE TRANSFER OF FUNDS.
All questions concerning the timeliness, validity, form and eligibility
of any exercise of Rights will be determined by the Company, whose
determinations will be final and binding. The Company reserves the absolute
right to reject any and all purchases not properly submitted or the acceptance
of which would, in the opinion of its counsel, be unlawful. The Company, in its
sole discretion, may waive any defect or irregularity, or permit a defect or
irregularity to be corrected within such time as it may determine, or reject the
purported exercise of any Right by reason of any defect or irregularity in such
exercise. Subscriptions will not be deemed to have been received or accepted
until all irregularities have been waived or cured within such time as the
Company determines in its sole discretion. Neither the Company nor the
Subscription Agent will be under any duty to give notification of any defect or
irregularity in connection with the submission of Subscription Certificates or
incur any liability for failure to give such notification. Rejected exercises
and the Subscription Price paid therefor will be returned promptly by the
Subscription Agent to the appropriate holders of the Rights.
The Company further reserves the right to terminate the Rights Offering
prior to acceptance of subscriptions by the Company; however, in the absence of
a material adverse change in its business, financial condition or results of
operations, the Company expects to consummate the Rights Offering.
Any questions or requests for assistance concerning the method of
exercising Rights or requests for additional copies of this Prospectus, the
Instructions or the Notice of Guaranteed Delivery should be directed to the
Company.
NO REVOCATION
AFTER A HOLDER OF RIGHTS HAS EXERCISED THE BASIC SUBSCRIPTION PRIVILEGE
OR THE OVERSUBSCRIPTION PRIVILEGE, SUCH EXERCISE MAY NOT BE REVOKED BY SUCH
RIGHTS HOLDER.
RIGHTS ARE NON-TRANSFERABLE
Rights may not be transferred in whole or in part.
AMENDMENT AND TERMINATION
The Board of Directors of the Company, in its sole discretion, may
amend the terms and conditions of the Rights Offering or terminate the Rights
Offering and revoke the Rights at any time prior to the Expiration Date. In
the event of such termination, the Company will return to all Eligible
Stockholders who exercised Rights their subscription payments, without interest
or deductions, as soon as practicable.
DELIVERY OF STOCK CERTIFICATES
Stockholders whose shares of Common Stock are held of record by Cede &
Co. ("Cede") or by any other depository or nominee on their behalf or on behalf
of their broker-dealers will have their shares of Common Stock acquired pursuant
to the Basic Subscription Privilege or Oversubscription Privilege credited to
the account of Cede or such other depository or nominee. With respect to all
other stockholders, stock certificates for all shares of Common Stock acquired
pursuant to the Basic Subscription Privilege or Oversubscription Privilege will
be mailed as soon as practicable after the Expiration Date and after payment for
the shares of Common Stock subscribed for has cleared, which clearance may take
up to 15 days from the date of receipt of the payment.
SUBSCRIPTION AGENT
The Company has appointed UMB Bank, NA as Subscription Agent for the
Rights Offering. The Subscription Agent's address, which is the address to which
the Subscription Certificates and payment of the Subscription Price should be
delivered by mail, hand or overnight/express mail carrier, as well as the
address to which Notice of Guaranteed Delivery must be delivered, is as follows:
UMB Bank, NA
Securities Transfer Division
928 Grand Avenue
13th Floor
Kansas City, MO 64106
17
<PAGE> 21
The Subscription Agent's telephone number is (816) 860-7786 and its
facsimile number is (816) 221-0438.
The Company will pay the fees and expenses of the Subscription Agent,
and has also agreed to indemnify the Subscription Agent from any liability which
it may incur in connection with the Rights Offering.
DILUTIVE EFFECTS OF RIGHTS OFFERING
To the extent an Eligible Stockholder does not exercise its Rights in
full, such Eligible Stockholder's voting power and percentage equity interest in
the Company, including its percentage interest in any future earnings, would
suffer substantial dilution.
STATE AND FOREIGN SECURITIES LAWS
Subscription forms will not be mailed to Rights holders whose addresses
are outside the United States or who have APO or FPO addresses, but will be held
by the Subscription Agent for such holders' accounts. The Company will not
offer, sell or issue any of the Rights or the Shares in any jurisdiction where
it is unlawful to do so or whose laws, rules, regulations or orders would
require the Company, in its sole discretion, to incur costs, obligations or time
delays disproportionate to the net proceeds to be realized by the Company from
such offers, sales or issuances. The Rights may not be exercised by any person,
and neither this Prospectus nor any Subscription Certificate shall constitute an
offer to sell or a solicitation of an offer to purchase any Shares, in any
jurisdiction in which such transactions would be unlawful. No action has been
taken in any jurisdiction outside the United States to permit offers and sales
of the Rights or the Shares. Consequently, the Company may reject subscriptions
pursuant to the exercise of Rights by any holder of Rights outside the United
States, and the Company may also reject subscriptions from holders in
jurisdictions within the United States if it should later determine that it may
not lawfully issue shares to such holders, even it could by qualifying the
shares for sale or by taking other actions in such jurisdictions, or that the
costs, obligations or time delays related thereto are disproportionate to the
net proceeds to be realized therefrom.
REGISTRATION AND RESALE OF SHARES
This Prospectus will not be available for reoffers or resales of the
Shares by persons deemed to be "affiliates" of the Company within the meaning of
the Securities Act. Such "affiliates" may accomplish reoffers or resales of such
securities only pursuant to (i) another appropriate prospectus contained in an
effective registration statement under the Securities Act, (ii) an appropriate
exemption under the Securities Act, or (iii) Rule 144 of the General Rules and
Regulations promulgated under the Securities Act. Further, the directors and
officers of the Company and any beneficial owner of more than 10% of the issued
and outstanding Common Stock may be liable pursuant to Section 16(b) of the
Exchange Act to the Company for certain amounts realized upon the purchase and
sale, or sale and purchase, of any shares of Common Stock within any period of
less than six months. The persons referred to above should consult counsel for
additional information regarding impediments with respect to their purchase and
sale of shares of Common Stock.
18
<PAGE> 22
SELECTED HISTORICAL FINANCIAL DATA
The following selected historical financial data as of and for the
years ended December 31, 1996 and 1995, as of and for the six months and ten
days ended July 10, 1997, and for the six months ended June 30, 1997 for Old WRT
and as of and for the five months and 21 days ended December 31, 1997 and the
six months ended June 30, 1998 for Gulfport are derived from the consolidated
financial statements of the Company included elsewhere in this Prospectus. The
selected financial data at December 31, 1994 and 1993 and for the years then
ended have been derived from historical consolidated financial statements of Old
WRT. The financial data set forth below should be read in conjunction with
"Management's Discussion and Analysis of Financial Condition and Results of
Operations" and the consolidated financial statements of the Company and the
notes thereto included elsewhere in this Prospectus. The historical financial
data as of December 31, 1996 and 1997 and for the six months and ten days ended
July 10, 1997 and the five months and 21 days ended December 31, 1997 have been
derived from the Company's audited consolidated financial statements. All other
historical financial data have been derived from unaudited consolidated
financial statements of the Company.
<TABLE>
<CAPTION>
GULFPORT OLD WRT
----------------------------- -------------------------
SIX SIX
MONTHS JULY 11, SIX MONTHS MONTHS
ENDED 1997 TO TEN DAYS ENDED ENDED
JUNE 30, DECEMBER 31, JULY 10, JUNE 30,
1998 1997 1997 1997
---------- ------------ -------------- ----------
(UNAUDITED)
STATEMENT OF OPERATIONS DATA (IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C>
Oil and gas sales .................... $ 6,722 $ 9,756 $ 10,138 $ 5,381
---------- ---------- ---------- ----------
Operating expenses ................... 26,590 11,478 11,002 4,605
---------- ---------- ---------- ----------
Net income(loss) from operations ..... (19,868) (1,713) (864) 776
---------- ---------- ---------- ----------
Interest expense ..................... 758 727 1,106 615
Reorganization costs ................. -- -- 7,771 1,026
Net income (loss) before income
taxes and extraordinary item ...... (20,280) (1,713) (9,615) (815)
Extraordinary item ................... -- -- 88,723 --
Net income (loss) before
dividends on preferred stock ...... (20,280) (1,713) 79,108 (815)
Dividends on preferred stock (4) ..... -- -- (1,510) (712)
Net income (loss) attributable to
common stock ...................... (20,280) (1,713) 77,598 (1,527)
Earnings (loss) per common
and common equivalent share (5) ... (0.92) (0.08) N/A N/A
Average common and common
equivalent shares outstanding ..... 22,076 22,076 9,539 9,539
Capital expenditures ................. $ 805 $ 5,644 $ 2,562 $ 250
<CAPTION>
OLD WRT
----------------------------------------------------------
YEAR ENDED DECEMBER 31,
----------------------------------------------------------
1996 1995 1994 1993
---------- ---------- ---------- ----------
(UNAUDITED) (UNAUDITED) (UNAUDITED)
<S> <C> <C> <C> <C>
Oil and gas sales .................... $ 24,019 $ 24,655 $ 11,034 $ 4,657
---------- ---------- ---------- ----------
Operating expenses ................... 40,855(2) 139,497(1) 10,126 5,841
---------- ---------- ---------- ----------
Net income(loss) from operations ..... (16,836) (114,842) 908 (1,184)
---------- ---------- ---------- ----------
Interest expense ..................... 5,562 13,759 19 447
Reorganization costs ................. 7,345 -- -- --
Net income (loss) before income
taxes and extraordinary item ...... (29,387) (128,175) 4,266 (1,322)
Extraordinary item ................... -- -- -- --
Net income (loss) before
dividends on preferred stock ...... (29,387) (128,175) 4,230 (1,322)
Dividends on preferred stock (4) ..... (2,846) (2,846) (2,846) (591)
Net income (loss) attributable to
common stock ...................... (32,233) (131,021) 1,384 (1,913)
Earnings (loss) per common
and common equivalent share (5) ... N/A N/A N/A N/A
Average common and common
equivalent shares outstanding ..... 9,539 9,466 7,792 4,154
Capital expenditures ................. $ 4,823 $ 116,730 $ 40,087 $ 14,325
</TABLE>
<TABLE>
<CAPTION>
GULFPORT OLD WRT
--------------------------- -----------
JUNE 30, DECEMBER 31, JULY 10,
1998 1997 1997
----------- ----------- -----------
<S> <C> <C> <C>
BALANCE SHEET DATA
Working capital (deficit) .............. $ (4,949) $ (719) $ (148,231)
Property, plant and
equipment, net ...................... 62,341 81,501 55,698
Total assets ........................... 72,191 92,346 67,706
Total long-term debt ................... 10,660 13,528 --
Shareholders' equity (deficit) ......... 50,000 70,280 (91,366)
<CAPTION>
OLD WRT
------------------------------------------------------
DECEMBER 31,
------------------------------------------------------
1996 1995 1994 1993
---------- ---------- ---------- ----------
(IN THOUSANDS)
<S> <C> <C> <C> <C>
Working capital (deficit) .............. $ (148,932) $ (131,601) $ 6,301 $ 24,270
Property, plant and
equipment, net ...................... 56,899 63,913 59,042 18,586
Total assets ........................... 68,076 79,247 81,857 48,233
Total long-term debt ................... -- -- 6,260 205
Shareholders' equity (deficit) ......... (90,551) (61,869) 63,538 43,394
</TABLE>
- ------------------
(1) Operating expenses for 1995 include a non-cash charge of $103,000,000
related to impairment of long-lived assets pursuant to SFAS No. 121,
non-cash charges of $3,600,000 related to a minimum production guarantee
obligation, a $2,000,000 provision for doubtful accounts, and a $1,400,000
charge related to restructuring costs incurred. See "Management's
Discussion and Analysis of Financial Condition and Results of Operations."
(2) Operating expenses for 1996 include a non-cash charge of $3,900,000
related to impairment of long-lived assets pursuant to SFAS No. 121,
non-cash charges of $5,600,000 related to a minimum production guarantee
obligation, and a $5,200,000 provision for doubtful accounts. See
"Management's Discussion and Analysis of Financial Condition and Results
of Operations."
(3) Operating expense for the six months ended June 30, 1998 include a
non-cash charge of $16,200,000 related to a ceiling test write-down. See
"Management's Discussion and Analysis of Financial Condition and Results
of Operations."
(4) Reflects accrued but undeclared dividends during 1996 and during the six
months and ten days ended July 10, 1997.
(5) Earnings per share data not comparable to the Reorganization case.
19
<PAGE> 23
MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
As a result of the Reorganization Case and Plan, which was
consummated and became effective on July 11, 1997, the Company was required to
present its financial statements pursuant to fresh start reporting standards.
Accordingly, the financial statements of Gulfport are not comparable to the
financial statements of Old WRT. However, in the case of the statement of
operations, the Company believes that comments comparing calendar years provide
a more meaningful understanding of the Company's operations.
The following discussion and analysis of the Company's financial
condition and results of operations is based in part on the consolidated
financial statements and the notes thereto included elsewhere in this Prospectus
and should be read in conjunction therewith.
OVERVIEW
The Company owns and operates mature oil and gas properties in the
Louisiana Gulf Coast. The Company seeks to achieve reserve growth and increase
its cash flow by entering into strategic alliances with companies possessing
Gulf Coast exploration experience and by undertaking lower risk development
projects. The Company was organized under the laws of Delaware in July 1997 and
merged with Old WRT on July 11, 1997 upon the consummation of Old WRT's
bankruptcy reorganization.
On February 14, 1996, Old WRT filed a petition with the Bankruptcy
Court for protection under Chapter 11 of the Bankruptcy Code. Upon filing of the
voluntary petition for relief, Old WRT, as debtor-in-possession, was authorized
to operate its business for the benefit of claim holders and interest holders,
and continued to do so, without objection or request for appointment of a
trustee. All debts of Old WRT as of the Petition Date were stayed by the
bankruptcy petition and were subject to compromise pursuant to such proceedings.
Old WRT operated its business and managed its assets in the ordinary course as
debtor-in-possession, and obtained court approval for transactions outside the
ordinary course of business. Based on these actions, all liabilities of the
Company outstanding at February 14, 1996 were reclassified to estimated
pre-petition liabilities.
By order dated May 5, 1997, the Bankruptcy Court confirmed the Plan
of Old WRT and co-proponents DLB and Wexford Management. The Plan was
consummated and became effective on July 11, 1997. On the Effective Date, Old
WRT was merged with and into Gulfport. On the Effective Date, Gulfport allocated
the actual reorganization value to the entity's assets as defined by Statement
of Position Number 90-7, "Financial Reporting by Entities in Reorganization
Under the Bankruptcy Code" ("SOP 90-7").
The markets for oil and gas have been volatile and are likely to
remain so in the future. Prices for oil and gas are subject to wide fluctuations
in response to relatively minor changes in the supply and demand for oil and
gas, market uncertainty and a variety of additional factors that are beyond the
control of the Company. In the future, lower oil and gas prices may reduce (i)
the attractiveness or viability of exploration prospects and the amount of oil
and gas reserves that may be produced economically, (ii) the Company's cash flow
from operations, (iii) the amount available for borrowing under the Company's
credit facilities and (iv) the Company's net income and capital expenditures.
The Company uses the full cost method of accounting for its
investment in oil and gas properties. Under the full cost method of accounting,
all costs of acquisition, exploration and development of oil and gas reserves
are capitalized into a "full cost pool" as incurred, and properties in the pool
are depleted and charged to operations using the units-of-production method
based on the ratio of current production to total proved oil and gas reserves.
To the extent that such capitalized costs, net of depletion and amortization,
exceed the present value of estimated future net revenues, discounted at 10%,
from proved oil and gas reserves, after income tax effects, such excess costs
are charged to operations. Once incurred, a write down of oil and gas properties
is not reversible at a later date, even if oil or gas prices increase. As a
result of a ceiling test performed at June 30, 1998, the Company was required to
write down the value of its oil and gas properties by $16.0 million.
The discussion in this section includes statements that are not
purely historical and are "forward-looking statements" within the meaning of
Section 27A of the Securities Act and Section 21E of the Exchange Act,
20
<PAGE> 24
including statements regarding the Company's expectations, hopes, beliefs,
intentions and strategies regarding the future. The Company's actual results
could differ materially from its expectations discussed herein. Certain
important factors that could cause actual results to differ materially from the
Company's expectations are disclosed elsewhere in this Prospectus. See
"Disclosure Regarding Forward-Looking Statements."
BANKRUPTCY OF OLD WRT
For a discussion of events related to Old WRT's operations and
subsequent filing for protection under Chapter 11 of the Bankruptcy Code, see
"Business--Events Leading to the Reorganization Case."
ACCOUNTING CHANGES
Before July 11, 1997, the Company used the successful efforts method
for reporting oil and gas operations. Commencing on the Effective Date, the
Company converted to the full cost pool method of accounting for its oil and gas
operations.
Due to the restating of property values to comply with fresh start
accounting and the conversion from the successful efforts method to the full
cost pool method for reporting oil and gas operations on the Effective Date,
comparison of depreciation, depletion, and amortization expense for the year
ended December 31, 1997 with prior years will not be meaningful.
RESULTS OF OPERATIONS
Set forth in the table below are the average prices received by the
Company and production volumes during the periods indicated.
<TABLE>
<CAPTION>
SIX MONTHS
YEAR ENDED DECEMBER 31, ENDED JUNE 30,
---------------------------------------- --------------------------
1997 1996 1995 1998 1997
---------- ----------- ----------- ------------ ----------
<S> <C> <C> <C> <C> <C>
Production Volumes
Oil (MBbls) 566 615 778 284 246
Gas (MMcf) 2,818 3,629 7,403 1,243 1,712
Oil equivalents (MBoe) 1,036 1,220 2,012 491 531
Average Prices
Oil (per Bbl) $ 20.93 $ 22.17 $ 16.59 $ 13.64 $ 20.98
Gas (per Mcf) $ 2.86 $ 2.86 $ 1.59 $ 2.29 $ 2.63
Oil equivalents (per MBoe) $ 19.20 $ 19.68 $ 12.27 $ 13.68 $ 18.17
Average production costs (per Boe) $ 9.05 $ 10.90 $ 4.74 $ 9.37 $ 8.67
Average production taxes (per Boe) $ 1.48 $ 1.47 $ 1.08 $ 1.15 $ 1.19
</TABLE>
COMPARISON OF SIX MONTHS ENDED JUNE 30, 1998 AND 1997
During the six months ended June 30, 1998, the Company reported a
net loss of $20.3 million, a 276% increase from net loss before undeclared
dividends on preferred stock of $5.4 million for the corresponding period in
1997. The increase in net loss was due primarily to the following factors:
Oil and Gas Revenues. During the six months ended June 30, 1998, the
Company reported oil and gas revenues of $6.7 million, a 45% decrease from oil
and gas revenues of $9.7 million for the comparable period in 1997. This
decrease was primarily attributable to a significant reduction in gas production
and the average price received for oil during 1998.
Other Income. Other income increased $0.2 million, or 200%, from
$0.1 million for the six months ended June 30, 1997 to $0.3 million for the
comparable period in 1998. This increase resulted from the Company's increased
cash holdings in accounts bearing interest and an increase in overhead income,
during the first quarter of 1998.
21
<PAGE> 25
Production Costs. Production costs, including lease operating costs
and gross production taxes, remained constant at $5.2 million for the six months
ended June 30, 1998 and the same period in 1997. Although there was consistency
for comparison purposes, there was a decrease in operating costs in the 1998
period primarily as the result of a reduction of field related services
performed by third party contractors that was offset by an increase to operating
costs in the West Cote Blanche Bay ("WCBB") field as a result of the Company's
acquisition, on the Effective Date, of an additional 50% working interest in
depths above the Rob "C" marker, of which the Company is the operator.
Depreciation, Depletion and Amortization. Depreciation, depletion
and amortization increased $17.0 million, or 548%, from $3.1 million for the six
months ended June 30, 1997 to $20.1 million for the comparable period in 1998.
As a result of fresh start accounting prescribed for companies exiting
bankruptcy, a new cost basis in assets was recognized based upon fair market
value of the assets. In addition, the Company converted from the successful
efforts method to the full cost pool method for reporting oil and gas properties
on the Effective Date. As prescribed by the full cost pool method of reporting
oil and gas properties, ceiling tests are performed to determine if the carrying
value of oil and gas assets exceeds the sum of the discounted estimated future
cash flows. As a result of a ceiling test performed at June 30, 1998, the
Company was required to write down the value of its oil and gas properties by
$16.0 million. Due to the restating of property values to comply with fresh
start accounting and the conversion from the successful efforts method to the
full cost pool method of reporting oil and gas properties, comparisons of the
1998 and 1997 periods are not meaningful.
General and Administrative Expenses. General and administrative
expenses decreased $0.7 million, or 54%, from $2.0 million for the six months
ended June 30, 1997 to $1.3 million for the comparable period in 1998. This
decrease was due primarily as a result of the Company's change in strategy
resulting in a reduction in personnel and general and administrative costs.
Provision for Doubtful Accounts. Provision for doubtful decreased
to zero for the six months ended June 30, 1998 from $0.1 million for 1997.
Interest Expense. Interest expense decreased $0.2 million, or 25%,
from $1.0 million for the six months ended June 30, 1997 to $0.8 million for the
same period in 1998. This decreased was due to (i) a reduction in outstanding
debt and (ii) an 0.8125% reduction in interest rate set forth in the Credit
Agreement.
Reorganization Costs. Reorganization costs decreased $2.7 million,
or 100%, from $2.7 million for the six months ended June 30, 1997 to zero for
the comparable period in 1998. On the Effective Date, the Company recorded a
$1.0 million accrual for estimated future costs to be incurred in connection
with the reorganization. As a result, any reorganization costs incurred since
the Effective Date have no effect on the income statement of the Company.
COMPARISON OF YEARS ENDED DECEMBER 31, 1997 AND 1996
The Company reported net income attributable to Common Stock of
$75,885,000 for the year ended December 31, 1997, as compared with net loss
attributable to Common Stock of $32,233,000, for the year ended December 31,
1996. The change in earnings attributable to Common Stock of $109,628,000 was
due primarily to the following factors:
Oil and Gas Revenues. During 1997, the Company reported oil and gas
revenues of $19.9 million, a 17% decrease from revenues of $24.0 million for
1996. The decreased revenues are attributable to a decrease in production
volumes of 184 MBoe along with a decrease of $0.48 per Boe in average sales
price for the year. The production declines were due primarily to normal
production declines and the loss of production from two large oil wells on the
Deer Island lease during 1997, offset in part by the acquisition of the
remaining 50% interest in the WCBB properties on the Effective Date.
Production Costs. Production costs decreased $3,918,000, or 29%, to
$9.4 million in 1997 from $13.3 million in 1996. Production costs per Boe
decreased 14% from $10.92 in 1996 to $9.41 per Boe in 1997. This decrease in
production costs per Boe was due primarily to the inclusion in 1996 of the
following as additional production costs: (i) disputed claims adjustments
totaling approximately $3,986,000; and (ii) the Lac Blanc
22
<PAGE> 26
purchase price adjustment in the amount of $479,000. Production costs per Boe
excluding the previously mentioned items increased by $0.81 in 1997 as compared
with 1996, due primarily to increased workover activities.
Gross Production Taxes. Production taxes decreased by $258,000, or
14%, from $1,791,000 in 1996 to $1,533,000 in 1997. This decrease was partially
attributable to the fact that in Louisiana gross production taxes on gas sales
are computed on a volumetric basis rather than on the sales price, and gas
volumes decreased by 811 Mmcf, and partially due to a decrease of $1,792,000 in
oil sales in 1997 as compared with 1996.
Depreciation, Depletion and Amortization. Depreciation, depletion
and amortization expense was $7,856,000 in 1997. Due to the restating of
property values to comply with fresh start accounting and the conversion from
the successful efforts method to the full cost pool method for reporting oil and
gas operations on the Effective Date, comparisons of 1997 depreciation,
depletion, and amortization expense with prior years are not meaningful.
General and Administrative Expense. General and administrative
expenses increased by 13% from $3,210,000 in 1996 to $3,642,000 in 1997 due
primarily to a $616,000 reduction in the amount of administrative costs charged
to operations. Also contributing to this increase was a substantial increase in
audit fees and contract labor incurred in connection with implementing the Plan.
These increases were partially offset by lower salary expense and other cost
savings implemented by management.
Provision for Doubtful Accounts. Provision for doubtful accounts
decreased $5,087,000 from $5,158,000 in 1996 to $71,000 in 1997. The provision
for doubtful accounts for 1996 consisted primarily of an allowance of a
receivable in the amount of $4,278,000 relating to the Tri-Deck (as defined
herein) legal proceeding. See "--Commitments and Contingencies" and "Business --
Legal Proceedings." On January 20, 1998, the Company's rights to its claims
against Tri-Deck were assigned to the Litigation Entity (as defined herein) in
consideration for the right to receive a percentage ranging from 50% to 80% of
the net proceeds from the settlement of these claims. In addition, during 1996
the Company charged an additional $880,000 to bad debts expense related to
receivables deemed uncollectible as a result of the Reorganization Case.
Restructuring Charges and Reorganization Costs. During 1997, the
Company incurred $7,771,000 in reorganization costs, consisting of $3,000,000
contributed to the Litigation Entity, as called for in the Plan, $1,515,000
reimbursed to DLB for restructuring costs it incurred on the Company's behalf,
professional fees totaling $2,213,000 and an accrual of $1,043,000 for estimated
future costs to be incurred in connection with the reorganization. See
"Business--Events Leading to the Reorganization Case."
During 1996, the Company incurred reorganization costs of
$7,345,000, consisting primarily of professional fees totaling $2,594,000, and
the write-off of previously capitalized debt issuance costs on the Senior Notes
(as defined herein) in the amount of $3,834,000. See "Business--Events Leading
to the Reorganization Case."
Minimum Production Guarantee Obligation. By a Joint Venture
Agreement, dated October 18, 1991 (the "Tricore Joint Venture Agreement"), the
Company entered into a joint venture (the "Tricore JV") to develop certain oil
and gas properties with Tricore Energy Venture, L.P., a Texas limited
partnership ("Tricore") and Stag Energy Corporation ("Stag"). Pursuant to the
Tricore Joint Venture Agreement, the Company provided Tricore with a limited
production guarantee based on a specified minimum production schedule. As
collateral for the Company's obligations under the production guarantee, Tricore
held a partial assignment of an interest in the WCBB field. This 4.68% working
interest (3.72% net revenue interest) assignment was made subject to the terms
and provisions of the Tricore Joint Venture Agreement. Upon satisfaction of the
production guarantee, Tricore was required to execute and deliver a release of
the partial assignment. The Company accrued $5,555,000 in 1996 and $3,591,000 in
1995 related to its anticipated minimum production guarantee obligation to
Tricore. The additional accrual in 1996 was due in part to the disallowance of
the Section 29 Energy Credit by the Federal Energy Regulatory Commission
("FERC") and the subsequent ruling in the FERC's favor by the United States
Court of Appeals, and in part due to downward revisions of the reserve estimates
associated with the properties collateralizing the production payment
obligations.
No additional liability was accrued in 1997 in connection with this
production payment guarantee. On December 9, 1997, the Tricore claim was settled
by the Bankruptcy Court as an Allowed General Unsecured Claim
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in the amount of $6,800,000 for which Tricore received 524,000 shares of Common
Stock and 524,000 Litigation Entity interests. As a part of this settlement,
Tricore transferred its interest in the Tricore JV, including the 4.68% working
interest in the WCBB field, to the Company with the stipulation that if the
Company sells any of Tricore JV's properties within one year, the Company will
pay to Tricore 100% of the net proceeds from the sale.
Impairment of Long-Lived Assets. During 1996, the Company recognized
an impairment loss related to its oil and gas properties and long-lived assets
in the amount of $3,864,000. The 1996 impairment loss was due primarily to
further declines in the Company's estimated oil and gas reserves and the write
down of certain other equipment to its appraised value.
Based primarily on an analysis of the independent engineers reserve
report, dated January 1, 1998, management has determined that there was no
impairment of long-lived assets during 1997.
Interest Expense. Interest expense decreased $3,729,000, or 67%,
from $5,562,000 in 1996 to $1,833,000 in 1997, primarily due to the termination
of the interest accrual on the $100,000,000 in Senior Notes as of February 14,
1996 (the filing date of the Chapter 11 proceedings). See "Business--Events
Leading to the Reorganization Case."
Extraordinary Gain. During 1997, the Company recognized an
extraordinary gain of $88,723,000 related to the forgiveness of debt recognized
in connection with implementing the Plan.
COMPARISON OF YEARS ENDED DECEMBER 31, 1996 AND 1995
The Company reported a net loss attributable to common stock of
$32,233,000 ($3.38) per share, for the year ended December 31, 1996, as compared
with a net loss attributable to common stock of $131,021,000 ($13.84) per share
for 1995. The reduction in net losses attributable to common stock of
$98,788,000 was due primarily to the following factors:
Oil and Gas Revenues. During 1996, the Company reported oil and gas
revenues of $24,019,000, a 3% decrease from revenues of $24,655,000 for 1995.
The decreased revenues were attributable to a decrease in production volumes of
792 MBoe offset by an increase of $5.58 per MBoe in average sales price for the
year. The production declines were due primarily to the mechanical failure of
the Exxon Fee No. 23 located in the Lac Blanc Field and normal production
declines.
Production Costs. Production costs increased $3,770,000, or 40%,
from $9,534,000 in 1995 to $13,304,000 in 1996. Production costs per MBoe
increased 130% from $4.74 in 1995 to $10.92 in 1996. This increase in production
costs per MBoe was due primarily to the inclusion in 1996 of the following as
additional production costs: (i) disputed claims adjustments totaling
approximately $3,986,000; and (ii) the Lac Blanc purchase price adjustment in
the amount of $479,000. Production costs on the properties excluding the
previously mentioned items decreased by 7% while the oil sales volume decreased
by 21% and the gas sales volume decreased by 51%, resulting in significantly
increased production costs per MBoe.
Gross Production Taxes. Production taxes decreased $348,000, or 16%,
from $2,139,000 in 1995 to $1,791,000 in 1996. This decrease was attributable to
the fact that in Louisiana gross production taxes on gas sales are computed on a
volumetric basis rather than on the sales price, and gas volumes decreased by
51% in 1996. This decrease in production taxes was partially offset by a $5.58
per barrel increase in the average price received for oil in 1996, which
increased gross production taxes attributable to oil production.
Depreciation, Depletion and Amortization. Depreciation, depletion
and amortization expense decreased 37% from $12,645,000 in 1995 to $7,973,000 in
1996. This decrease was due primarily to a 21% decrease in oil production
combined with a 51% decrease in gas production. On an MBoe basis, depreciation,
depletion and amortization expense increased 4% from $6.30 per MBoe in 1995 to
$6.54 per MBoe in 1996.
General and Administrative Expense. General and administrative
expenses decreased by 34% from $4,882,000 in 1995 to $3,210,000 in 1996 as a
result of the Company's change in strategy resulting in a substantial reduction
in personnel and third-party geological and engineering costs.
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<PAGE> 28
Provision for Doubtful Accounts. Provision for doubtful accounts
increased $3,151,000 from $2,007,000 at December 31, 1995 to $5,158,000 at
December 31, 1996. The provision for doubtful accounts for 1996 consisted
primarily of an allowance of a receivable in the amount of $4,278,000 relating
to the Tri-Deck legal proceeding. See "--Commitments and Contingencies" and
"Business--Legal Proceedings." In addition, during 1996 the Company charged an
additional $880,000 to bad debts expense related to receivables deemed
uncollectible as a result of the Reorganization Case.
Restructuring Charges and Reorganization Costs. During 1996, the
Company incurred reorganization costs of $7,345,000, consisting primarily of
professional fees totaling $2,594,000 and the write-off of previously
capitalized debt issuance costs on the Senior Notes in the amount of $3,834,000.
See "Business--Events Leading to the Reorganization Case."
During 1995, the Company incurred $1,433,000 in restructuring
charges consisting primarily of the write-off of approximately $1,000,000 in
leasehold improvements related to the relocation of the Company's operations
from The Woodlands, Texas, approximately $305,000 in severance costs related to
staff reductions and changes in senior management, and $145,000 in legal and
other costs directly related to the Reorganization Case.
Minimum Production Guarantee Obligation. Pursuant to the Tricore
Joint Venture Agreement, the Company provided Tricore with a limited production
guarantee based on the minimum production schedule attached thereto. The Company
accrued $5,555,000 in 1996 and $3,591,000 in 1995 related to its anticipated
minimum production guarantee obligation to Tricore. The additional accrual in
1996 was due in part to the disallowance of the Section 29 Energy Credit by FERC
and the subsequent ruling in FERC's favor by the United States Court of Appeals,
and in part due to downward revisions of the reserve estimates associated with
the properties collateralizing the production payment obligations.
Impairment of Long-Lived Assets. Effective December 31, 1995, the
Company adopted SFAS No. 121 resulting in the recognition of an impairment loss
related to the Company's oil and gas properties and other long-lived assets in
the amount of $103,266,000. During 1996, the Company recognized an additional
impairment loss related to its oil and gas properties and long-lived assets in
the amount of $3,864,000. The 1996 impairment loss was due primarily to further
declines in the Company's estimated oil and gas reserves and the write down of
certain other equipment to its appraised value.
Interest Expense. Interest expense decreased $8,197,000 from
$13,759,000 in 1995 to $5,562,000 in 1996, primarily due to the termination of
the interest accrual on the $100,000,000 in Senior Notes as of February 14, 1996
(the filing date of the Chapter 11 proceedings).
LIQUIDITY AND CAPITAL RESOURCES
Net cash flow provided by operating activities for the six months
ended June 30, 1998 was $1.9 million, as compared to net cash flow provided by
operating activities of $0.5 million for the comparable period in 1997. This
increase is due primarily to a $1.5 million reduction in accounts payable and
accrued liabilities during the six months ended June 30, 1998 as compared to the
same period in 1997.
Net cash flow used by operating activities for the year ended
December 31, 1997 was $1,446,000 as compared to net cash flow used by operating
activities of $20,610,000 for the year ended December 31, 1996. The reduction in
the cash flow was due primarily to an increase in payables in 1996 of
approximately $16,920,000. The increase in payables in 1996 was due to the stay
provided by the Bankruptcy Court from the payment of any pre-petition payables
and interest on the Company's then existing credit facility.
On the Effective Date, the Company received gross proceeds from the
1997 Rights Offering (as defined herein) of $13,300,000 of which $3,248,000 was
used to pay the interest and loan fees in connection with the loan from INCC (as
defined herein), $3,000,000 was used to fund the Litigation Entity called for in
the Plan, $2,963,000 was used to pay pre-petition claims, and $2,492,000 was
used to pay administrative claims. The balance of $1,597,000 was used for
additional working capital for the Company. In addition, on the Effective Date,
the Company exchanged $123,845,000 in unsecured debt for 10,000,000 shares of
Common Stock and DLBW and
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Dublin Acquisitions, a related party to DLBW, exchanged $9,293,000 of secured
debt for 2,655,000 shares of Common Stock.
Also on the Effective Date, the Company entered into a $15,000,000
credit agreement (the "Credit Agreement") with ING (U.S.) Capital Corporation
("ING") that was secured by substantially all of the Company's assets. The terms
of the Credit Agreement required the payoff of a portion of the $18,081,590 in
principal and interest outstanding under the Company's prior credit facility
(the "Prior Credit Facility") with International Nederlanden (U.S.) Capital
Corporation, a predecessor to ING ("INCC"), with proceeds under the Credit
Agreement. As of June 30, 1998, the outstanding principal balance under the
Credit Agreement was approximately $13,229,000. Pursuant to the terms of the
Credit Agreement, the Company may elect to be charged at the bank's fluctuating
reference rate plus 1.25% or the rate plus 3.0% at which Eurodollar deposits for
one, two, three or six months are offered to the bank in the Interbank
Eurodollar. Principal payments of $1,000,000 each are due in September 1998,
December 1998, and March 1999, with the remaining principal balance due at
maturity on July 10, 1999.
The Credit Agreement contains restrictive covenants which impose
limitations on the Company with respect to, among other things: (i) the
maintenance of current assets equal to at least 110% of current liabilities
(excluding any current portion of the Credit Agreement); (ii) the incurrence of
debt outside the ordinary course of business; (iii) dividends and similar
payments; (iv) the creation of additional liens on, or the sale of, the
Company's oil and gas properties and other assets; (v) the Company's ability to
enter into forward, future, swap or hedging contracts; (vi) mergers or
consolidations; (vii) the issuance of securities other than Common Stock and
options or warrants granting the right to purchase Common Stock; (viii) the
sale, transfer, lease, exchange, alienation or disposal of Company properties or
assets; (ix) investments outside the ordinary course of business; (x)
transactions with affiliates; (xi) general and administrative expenditures in
excess of $1 million during any fiscal quarter or in excess of $3 million during
each fiscal year; and (xii) the maintenance of a 1.2 to 1 coverage ratio.
On August 18, 1998, the Company amended the Credit Agreement (as so
amended, the "Amended Credit Agreement") to, among other things: (i) delete the
coverage ratio set forth in the Credit Agreement; and (ii) require interest
payments to be made by the Company on a monthly basis. The interest rate set
forth in the Credit Agreement remains unchanged in the Amended Credit Agreement.
In connection with the execution and delivery of the Amended Credit Agreement,
ING waived certain provisions of the Credit Agreement to permit (i) the Rights
Offering and the use of proceeds as specified herein, (ii) the Company to enter
into the contractual agreements discussed below under "--Recent Developments and
Plans" and (iii) the Company to undertake certain other actions. In
consideration for ING entering into the Amended Credit Agreement and granting
the waivers, the Company (a) prepaid $2.0 million of principal otherwise due in
September and December 1998 with borrowings made under the Stockholder Credit
Facility, (b) agreed to pay a $250,000 amendment fee to ING on July 11, 1999,
provided that such amendment fee will be waived if the amounts owed to ING under
the Amended Credit Agreement have been paid in full by July 10, 1999; and (c)
issued warrants to ING, which warrants will permit ING to purchase 2% of the
outstanding shares of Common Stock on a fully diluted basis after giving effect
to the Rights Offering, subject to a reduction to 1.5% if certain farmout
agreements proposed by the Company are not approved by ING. Pursuant to the
Amended Credit Agreement, an Event of Default (as defined therein) shall be
deemed to have occurred if the Registration Statement of which this Prospectus
is a part has not been declared effective on or before October 31, 1998 and the
Rights Offering is not completed with 30 days of such effective date; provided,
however, that if the Registration Statement is not declared effective on or
before October 31, 1998, but the Company completes a $7.5 million private
placement of Common Stock on or before November 30, 1998, no Event of Default
shall be deemed to have occurred.
On August 18, 1998, the Company entered into the Stockholder Credit
Facility, a $3.0 million revolving credit facility with the Affiliated Eligible
Stockholders. Borrowings under the Stockholder Credit Facility are due on
August 17, 1999 and bear interest at LIBOR plus 3%. Pursuant to the Stockholder
Credit Facility, the Affiliated Eligible Stockholders have the right to convert
any borrowings made under such facility into shares of Common Stock at a
conversion price of $0.20 per share only if the Rights Offering is not
completed. As of August 25, 1998, $2.4 million was outstanding under the
Stockholder Credit Facility. The Company intends to repay $2.0 million of
principal under the Amended Credit Facility with borrowings under the
Stockholder Credit Facility. The remaining $0.4 million will be used for
working capital and general corporate purposes. Each Affiliated Eligible
Stockholders will pay the Subscription Price for Shares and Excess Shares if
any, purchased in the Rights Offering through the forgiveness of an equal
amount owed to such Affiliated Eligible Stockholder under the Stockholder
Credit Facility and the Administrative Services Agreement receivable. Any
amounts that remain outstanding after such application will be repaid by the
Company with a portion of the cash proceeds from the Rights Offering or other
available funds. See "Use of Proceeds" and "Certain Transactions--Stockholder
Credit Facility."
During 1997, the Company invested $21,931,000 in property acquisition
and development, as compared to $4,282,000 during 1996. Included in such 1997
property additions was the acquisition of the 50% interest in certain
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WCBB properties not owned by the Company in exchange for 5,616,000 shares of
Common Stock, 616,000 shares of which were issued for additional capital
expenditures on these properties paid by DLB. See "Business--Events Leading to
the Reorganization Case." This 50% interest in such WCBB properties was valued
at $15,144,000 for financial reporting purposes. During 1997, the Company
received approximately $2,100,000 from the sale of substantially all of its well
servicing equipment.
Net cash provided in financing activities for 1997 was $5,137,000 as
compared to $29,611,000 during 1996. The 1996 cash flows from financing
activities occurred as a result of the deferral of pre-petition claims in
connection with the Company's bankruptcy filing in February 1996.
On the Effective Date, the Company commenced a program to increase
production rates, lengthen the productive life of wells and increase total
proved reserves primarily through sidetracks out of and recompletions of shut-in
wells and installation of hydrocyclones on gas wells producing large volumes of
formation water. In addition, certain sidetrack and development drilling
locations have been identified that are expected to improve reservoir drainage
and increase the ultimate recovery of reserves. Pursuant to this strategy, the
Company plans to utilize farmout type arrangements in which investors pay the
development costs in exchange for a working interest in the developed properties
as well as undertake internally financed low risk development projects. The
current status of this program is summarized below.
The ability of the Company to satisfy its capital requirements and
implement its business strategy is dependent upon the success of the Rights
Offering. The Rights are nontransferable and the Company is not a party to any
standby commitment or other agreement pursuant to which Eligible Stockholders
have agreed to exercise any minimum number of Rights. The Company believes that
it will need at least $7.5 million to meet its short-term needs. Further, the
failure of the Company to raise at least $7.5 million through the Rights
Offering or a private placement of Common Stock on or before November 30, 1998
will constitute an event of default under the Amended Credit Agreement. If
such funds are not raised, the Company believes that it will be forced to seek
protection from its creditors under applicable bankruptcy laws. In such an
event, the Company believes that holders of the Common Stock would realize
little, if any, of their investment in the Company. The Company currently has
no financing plan to raise such capital other than the Rights Offering.
The independent auditor's report on the financial statements of the
Company is modified and it states that there are conditions which raise
substantial doubt about the ability of the Company to continue as a going
concern. Specifically, the auditor's report states that revenues from the
Company's producing properties will not be sufficient to finance the estimated
future capital expenditures necessary to fully develop the existing proved
reserves, nor recover the carrying value of the Company's oil and natural gas
properties. The financial statements do not include any adjustments that might
result from this uncertainty. The financial statements included in this
Prospectus have been prepared assuming the Company will continue as a going
concern.
RECENT DEVELOPMENTS AND PLANS
WEST COTE BLANCHE BAY
The Company has developed a threefold plan to convert undeveloped
and non-producing reserves in the WCBB field into cash flow by (i) farming out
new drilling opportunities, (ii) farming out recompletion and reworking
opportunities and (iii) undertaking its own development program.
Farmout of New Drilling Opportunities. On March 27, 1998, the
Company and Tri-C Resources, Inc. ("Tri-C") executed an agreement to farmout
drilling rights at WCBB. During the course of the three phase program
contemplated by the agreement, Tri-C has agreed either to drill 22 wells to an
average drilling depth of 6,500 feet or drill 12 wells to the same depth and
shoot 3-D seismic surveys covering the field. The Company will be carried to the
tanks for a 30% to 50% working interest in each well. If Tri-C successfully
completes all three phases of the program, it will earn a 50% interest in the
WCBB field.
Farmout of Recompletion and Rework Opportunities. The Company is in
the process of negotiating an agreement to farmout a number of wellbores in
WCBB. Specifically, the Company intends to farmout a minimum of 15 wells a year
in exchange for a carried working interest or a reversionary interest. Once the
farmee has completed a negotiated number of wellbores or spent a specified
capital amount, the farmee will have the option to continue the relationship for
an extended period of time. There can be no assurance, however, that such an
agreement can be reached on these or other terms. Any such agreement is subject
to the approval of ING pursuant to the Amended Credit Agreement. See
"--Liquidity and Capital Resources."
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Capital Expenditures. During the next 12 months, the Company plans
to spend approximately $1,000,000 in the WCBB field on a shallow drilling
program and/or recompletions. The program consists of three new drills with
objective depths lying between approximately 2,000 and 4,000 feet. The Company
is also in the process of examining recompletion projects.
EAST HACKBERRY
Within the Hackberry field, the Company has proven non-producing and
undeveloped net reserves of 1.53 MMBO and 2.0 Bcf of gas. The Company intends to
acquire 3-D seismic surveys covering its leasehold position at Hackberry to
enable the Company to explore the field more effectively and at a lower risk.
The Company is in discussions with seismic acquisition companies concerning the
cost for a non-proprietary shoot over the Hackberry field.
With respect to this field, the Company currently intends to (i)
begin seismic data acquisition by the fourth quarter of 1998, (ii) begin the
processing of such data by the first quarter of 1999 and (iii) begin the
interpretation of this data by the second quarter of 1999 at an estimated cost
of $1,820,000. Beginning in the third quarter of 1999 and continuing through the
second quarter of 2000, the Company intends to (a) recomplete or rework five
existing wells for a net expenditure of approximately $600,000, (b) drill three
to five development wells in the 4,000 to 6,000 foot range at a net cost of
between $750,000 and $1,500,000 and (c) drill two to five development and/or
exploratory wells in the 9,000 to 13,000 foot range for a net cost of between
$1,000,000 and $3,500,000.
NAPOLEONVILLE
Pursuant to a Purchase and Sale Agreement (the "Napoleonville
Agreement") with Plymouth Resource Group 1998, L.L.C. ("Plymouth"), the Company
sold, effective as of July 1, 1998, its interest in the Napoleonville field for
$1.1 million and a 2.5% overriding royalty interest in such field. In connection
with the sale, Plymouth agreed to establish a plugging and abandoning escrow
account in accordance with and pursuant to the provisions of LSA-R.S. 30:88, et.
seq. The establishment of this escrow account is intended to protect the Company
from future liability associated with the plugging and abandoning of the field
and associated environmental liabilities.
OTHER AGREEMENTS
On August 12, 1998, the Company entered into a Contract Operating
Agreement (the "Castex Agreement") with Castex Energy, Inc. ("Castex"), pursuant
to which the Company designated Castex as the contract operator on the Bayou
Penchant field, the Bayou Pigeon field, the Deer Island field, the Golden Meadow
field and the Lac Blanc field (collectively, the "Castex Operated Properties").
As a contract operator for the Castex Operator Properties, Castex is authorized
to conduct all management, administration and operations for such properties as
if Castex were named as the operator thereof. The Castex Agreement continues, on
a month-to-month basis, until either party terminates upon 30 days notice or
until the Company conveys any portion or all of the Castex Operated Properties
to Castex or a third party. In exchange for its services, the Company will pay
Castex $10,000 per month plus all compensation that is due to the operator of
the respective Castex Operated Properties.
The Company is currently negotiating with various companies for the
sale of the non-strategic assets of the Company. The sale of these properties
would likely be to companies with existing properties in these same areas that
would have operational efficiencies and synergies that Gulfport would not be
able to realize. Several of these properties are high risk exploratory prospects
or involve high risk operation that do not fit the risk profile of Gulfport at
this time. The proceeds from any such sales will be used to repay amounts
outstanding under the Amended Credit Agreement.
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COMMITMENTS AND CONTINGENCIES
LAC BLANC ESCROW ACCOUNT
In connection with its purchase of a 91% working interest in the Lac
Blanc Field, the Company deposited $170,000 in a segregated trust account and
agreed to make additional deposits of $20,000 per month until the accumulated
balance of the trust account reaches $1,700,000. These funds are held in a
segregated account for the benefit of the State of Louisiana to insure that the
wells in the Lac Blanc Field are properly plugged upon cessation of production.
In return for this financial commitment, the State of Louisiana has granted the
sellers an unconditional release from their contingent liability to the state to
plug and abandon the wells. When all existing wells in the Lac Blanc Field have
been properly plugged and abandoned, the funds in the trust account, should any
remain, will revert to the Company. Due to the filing of the Reorganization Case
in February 1996, the Company ceased making contributions to the segregated
account. Under the Plan, commencing July 1997, the Company was obligated to fund
the unfunded portion of the trust account and maintain future funding
requirements. To date, the Company has not made any additional contributions to
such trust account. At March 31, 1998, the balance in this trust account was
$871,000.
PLUGGING AND ABANDONMENT FUNDS
In connection with the purchase of the Initial LLOG Property and the
Remaining LLOG Properties (each, as defined herein) in 1994, the Company agreed
to establish plugging and abandonment funds as allowed by Louisiana's Orphaned
Well Act. Upon completion of an independent study to be commissioned by the
Company, the State of Louisiana will establish the amount of and terms of
payment into each fund. As of August 1, 1998, the independent study had not been
completed. Accordingly, the Company is unable to determine the amount and
payment towards the future obligation related to these commitments.
In connection with the acquisition of the remaining 50% interest in
certain WCBB properties, Gulfport assumed the obligation to contribute
approximately $18,000 per month through March of 2004 to a plugging and
abandonment trust and the obligation to plug a minimum of 20 wells per year for
20 years commencing March 11, 1997. Texaco Exploration and Production, Inc.
("TEPI") retained a security interest in production from these properties and
the plugging and abandonment trust until such time the Company's plugging and
abandonment obligations to TEPI have been fulfilled. Once the plugging and
abandonment trust is fully funded, the Company can access it for use in plugging
and abandonment charges associated with the property. The Company satisfied its
plugging and abandonment obligations for the one year period ended March 10,
1998.
TEXACO GLOBAL SETTLEMENT
Pursuant to the terms of the Global Settlement Agreement, dated
February 22, 1994, between Texaco, Inc. ("Texaco") and the State of Louisiana
(the "Global Settlement Agreement"), which agreement includes the State Lease
No. 50 portion of the Company's East Hackberry Field, the Company was obligated
to commence a well or other qualifying development operation on certain
non-producing acreage in the field prior to March 1998. On January 8, 1998, the
Company applied for and was granted a permit to conduct seismic operations on
the East Hackberry Field as well as other Company properties. Because the
Company had financial constraints during this time period, the Company believes
it was commercially impracticable to shoot seismic and commence drilling
operations on such property. As a result, the Company surrendered approximately
440 non-producing acres in this field.
On May 13, 1998, under the terms of the Global Settlement Agreement,
the Louisiana State Mineral Board re-classified approximately 1,500 acres of
State Lease 340 (West Cote Blanche Bay Field) as non-producing acreage. To
extend the term of the acreage, the Company has proposed the drilling of the
Gulfport Energy Corporation S.L. 340 Well No. 847. In light of this fact, the
Company has agreed to drill with a 1,900 foot test well bottom hole objective at
some time prior to December 1998 under the recently re-classified acreage. The
drilling of such well will allow the Company an additional six months to submit
a plan to the Louisiana State Mineral Board for additional development of
non-producing acreage.
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REIMBURSEMENT OF EMPLOYEE EXPENSES & CONTRIBUTIONS TO 401(k) PLAN
The Company sponsors a 401(k) savings plan under which eligible
employees may choose to save up to 15% of salary income on a pre-tax basis,
subject to certain Internal Revenue Service ("IRS") limits. The Company
currently matches up to 6% of each employee's contributions with 25% cash
contributions. During the period commencing July 11, 1997 and ending on December
31, 1997, the period commencing January 1, 1997 and ending on July 10, 1997, and
the years ended December 31, 1996 and 1995, the Company incurred $13,000,
$23,000, $32,000, and $22,000, respectively, in matching contributions expense
associated with this plan.
TRI-DECK/PERRY GAS LITIGATION
During 1995, the Company entered into a marketing agreement with
Tri-Deck Oil and Gas Company ("Tri-Deck") pursuant to which Tri-Deck would
market all of the Company's oil and gas production. Subsequent to the agreement,
Tri-Deck's principal, and the Company's Director of Marketing, James Florence,
assigned to Plains Marketing and Transportation ("Plains Marketing") Tri-Deck's
right to market the Company's oil production and assigned to Perry Oil & Gas
("Perry Gas") its right to market the Company's gas production. During early
1996, Tri-Deck failed to make payments to the Company attributable to several
months of its gas production.
On January 20, 1998, the Company and the Litigation Entity entered
into a Clarification Agreement whereby the rights to pursue the Tri-Deck claim
were assigned to the Litigation Entity. In connection with this agreement, the
Litigation Entity agreed to reimburse the Company $100,000 for legal fees the
Company had incurred in connection this and other related claims. As additional
consideration for the contribution of this claim to the Litigation Entity, the
Company is entitled to a percentage ranging from 50% to 85% of the net proceeds
from this claim.
TITLE TO OIL AND GAS PROPERTIES
During 1996, Old WRT received notice from Wildwing Investments, Inc.
("Wildwing") claiming that the Company's title had failed as to approximately 43
acres in the Bayou Pigeon Field. Some or all of the acreage in dispute is
considered to be productive in three separate production units. The Company's
working interests in the three units were reduced to approximately 7% (5% Net
Revenue Interest ("NRI")), 75% (63% NRI), and 95% (72% NRI), respectively. The
Company's financial statements as of and for all periods ended on and after
December 31, 1995 reflect operating results and proved reserves discounted for
this title failure. As the title failure predates its ownership of the field,
the Company sought recourse against the predecessors-in-title relative to this
issue. On February 28, 1998, the Company entered into a settlement agreement
with Wildwing, which settlement provides that Plains Resource & Transportation,
Inc. and Wickford Energy Marketing, Inc. ("Stakeholders"), who are currently
holding funds in suspense attributable to mineral production from the leases
made the subject of the lawsuit, will be instructed by the Company and Wildwing
to distribute $269,500 to Wildwing in full and final compromise of such
litigation. Additional sums held by the Stakeholders are to be distributed to
the lessors of the leases made the subject of the litigation an amount for
payment of royalties due and owing up to the date of the filing of such lawsuit.
The balance held by the Stakeholders, currently estimated to be approximately
$370,000, will thereafter be distributed to the Company.
On July 20, 1998, Sanchez Oil & Gas Corporation ("Sanchez")
initiated litigation against the Company in the Fifteenth Judicial District
Court, Parish of Lafayette, State of Louisiana. In its petition, Sanchez
alleges, among other things, that the Company was obligated, by virtue of the
terms of a letter dated June 26, 1997, between Sanchez and the Company (the
"Sanchez Letter"), to grant a sublease to Sanchez for an undivided 50% interest
in two of the Company's oil, gas and mineral leases covering lands located in
the North Bayou Penchant area of Terrebonne Parish, Louisiana. Pursuant to this
lawsuit, Sanchez is seeking specific performance by the Company of the
contractual obligation that Sanchez alleges to be present in the Sanchez Letter
and monetary damages. The litigation is in its earliest stages and discovery has
not yet begun. In addition, the Company is currently reviewing the claims set
forth in the lawsuit to determine the appropriate response thereto.
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<PAGE> 34
YEAR 2000 COMPLIANCE
The Company has and will continue to make certain investments in
software systems and applications to ensure it is year 2000 compliant. The
financial impact to the Company to ensure year 2000 compliance has not been and
is not anticipated to be material to its financial position or results of
operations.
31
<PAGE> 35
BUSINESS
The Company owns and operates mature oil and gas properties in the
Louisiana Gulf Coast area. The Company has a number of Louisiana assets and is
seeking to diversify its asset base through mergers, acquisitions or trades. The
Company's business strategy is to increase its reserves, production and cash
flow through exploration and development activities as well as opportunistic
acquisitions. The Company plans to implement this strategy by: (i) creating
strategic alliances with Gulf Coast explorationists with excess capital and who
specialize in utilizing advanced technology to explore and develop new oil and
gas reserves; and (ii) selectively employing the Company's capital in low risk
development activities.
STRATEGIC ALLIANCES
The Company is actively pursuing strategic alliances with companies
possessing Gulf Coast expertise and advanced technology to fully develop the
existing properties through exploration and production. In selecting potential
partners, the Company seeks partners who, through experience, have proven their
ability to negotiate the geological complexities found in South Louisiana
structures, possess adequate capital to conduct aggressive exploration programs
on the properties and maintain a reputation in the oil and gas sector as
successful performers. Through the use of multiple alliances, the Company
expects to expedite the rate of exploration and development on the existing
properties.
CONTROLLED DRILLING OPPORTUNITIES
The Company plans to conduct a controlled drilling program on
certain of its properties. Currently, the Company is planning a series of behind
pipe and sidetracking operations. By completing these projects without third
party participation, the Company will be able to retain all the profits that may
be derived from these relatively low risk plays.
BACKGROUND
On February 14, 1996, Gulfport's predecessor, Old WRT, filed a
petition with the Bankruptcy Court for protection under Chapter 11 of the
Bankruptcy Code. Upon filing of the voluntary petition for relief, Old WRT, as
debtor-in-possession, was authorized to operate its business for the benefit of
claim holders and interest holders, and continued to do so, without objection or
request for appointment of a trustee. All debts of Old WRT as of the Petition
Date were stayed by the bankruptcy petition and were subject to compromise
pursuant to such proceedings. Old WRT operated its business and managed its
assets in the ordinary course as debtor-in-possession, and obtained court
approval for transactions outside the ordinary course of business. Based on
these actions, all liabilities of the Company outstanding at February 14, 1996
were reclassified to estimated pre-petition liabilities.
By order dated May 5, 1997, the Bankruptcy Court confirmed the Plan.
The Plan was consummated and became effective on July 11, 1997. On the Effective
Date, Old WRT was merged with and into Gulfport.
EVENTS LEADING TO THE REORGANIZATION CASE
Entering 1995, the Company's strategic focus was the acquisition and
development of operated working interests in large, mature oil and gas fields in
south Louisiana. To help finance its acquisition and development program, the
Company utilized borrowings under the Prior Credit Facility which was secured by
substantially all of the Company's assets. In addition, in February 1995, the
Company offered 100,000 Units consisting of $100,000,000 aggregate principal
amount of 13 7/8% Senior Notes Due 2002 (the "Senior Notes") and warrants (the
"Warrants") to purchase an aggregate of 800,000 shares of the Old WRT's common
stock (the "1995 Offering"). The net proceeds from the 1995 Offering were used
to acquire working interests in certain oil and gas properties, to repay
substantially all borrowings under the Prior Credit Facility and other
indebtedness and for general corporate purposes.
During the remainder of 1995, the Company borrowed additional funds
under the Prior Credit Facility, bringing the outstanding borrowings to
$15,000,000, the maximum amount of borrowings available under the Prior
32
<PAGE> 36
Credit Facility. On December 31, 1995, the Prior Credit Facility converted to a
term loan whereby quarterly principal payments of one-sixteenth of the
outstanding indebtedness were due and payable.
Following the completion of the acquisition of working interests in
certain oil and gas properties, the Company initiated a significant capital
expenditure program to increase oil and gas production levels in each of its
fields. This program consisted of approximately 70 workover, side track and
recompletion projects and ten new development wells. Funding was provided from
operating cash flow, remaining proceeds from the 1995 Offering and borrowings
under the Prior Credit Facility. The Company's production levels increased on a
gas equivalent (Mcfe) basis from March 1995, when the oil and gas property
acquisitions were completed, to September 1995; however, the production
increases were realized at a slower pace than expected at the time of
acquisition.
The lower than expected level of production resulted from various
factors including a combination of ordinary production declines, unexpected
losses of production from several key wells, mechanical difficulties in the Lac
Blanc Field and significant production declines in the predominantly oil
producing WCBB field, which was not then operated by the Company. Contributing
significantly to the shortfall in anticipated production rates were three major
well projects which proved to be unsuccessful in September 1995, for which the
Company expended a total of approximately $3,600,000. Also, contributing to
lower than expected net revenues and operating cash flow was a significant
decline in oil and gas prices during the third and early fourth quarters of 1995
compared to the corresponding quarters of the previous year. These lower than
expected production rates, together with decreased oil and gas prices during the
third quarter of 1995, had a significant negative effect on the Company's
liquidity and cash flow from operations.
Based on operating results for the quarter ended September 30, 1995,
the Company had not yet realized the oil and gas production levels required at
then current prices and costs to support the Company's capital requirements and
fund existing debt service on the Senior Notes and pay dividends on its 9%
Convertible Preferred Stock ("Convertible Preferred Stock"). In early October
1995, the Company had fully utilized the $15,000,000 borrowing base available
under the Prior Credit Facility; and, in response to liquidity and cash flow
concerns, the Company changed its focus from acquisition and development of
non-producing reserves to conservation of cash resources and maintenance of
existing producing properties. The Company curtailed its activities to the
minimum level of maintenance necessary to operate prudently its producing oil
and gas wells. All other activities, including prospect acquisitions, new
drilling and development of the Company's proved non-producing and undeveloped
reserves, ceased.
In connection with this strategy, the Company made certain changes
to its corporate structure and organization aimed at reducing costs and
improving operations. On November 10, 1995, Steven S. McGuire resigned as a
director, Chairman of the Board and Chief Executive Officer of the Company.
Samuel C. Guy, the Company's Executive Vice President, also resigned as a
director. Mr. Guy's employment contract, which expired on February 29, 1996, was
not renewed by the Company. The Board of Directors appointed Raymond P. Landry,
previously President and Chief Operating Officer of the Company, to the position
of Chairman of the Board and Chief Executive Officer. See "Management."
The Company also implemented plans to reduce general and
administrative expenses in Houston, Texas as well as move the corporate offices
from The Woodlands, Texas, and reduce its workforce from 76 in October 1995 to
28 in June 1997. The workforce reductions, primarily from the Company's research
and development activities and wireline/logging operations, were consistent with
the Company's focus on conservation of cash and maintenance of existing
producing properties.
The Company experienced further decreases in oil and gas production
and related cash flows in late 1995 and early 1996, which further deteriorated
the Company's already weakened financial condition. At December 31, 1995, the
Company was in default under certain financial covenants of the Prior Credit
Facility. As a result of the declines in oil and gas production and related cash
flows, the Company was not generating, and did not expect to generate in the
near term, sufficient cash flow to meet its existing obligations, including: the
$6,900,000 interest payment on the Senior Notes due March 1, 1996, trade payable
obligations remaining from the Company's 1995 capital expenditure program,
quarterly principal and interest due on the Prior Credit Facility, dividends on
the Convertible Preferred Stock and ongoing field operating and general and
administrative expenses. As liquidity
33
<PAGE> 37
problems became more severe, the Company concluded that a comprehensive
financial restructuring would provide the best result to the various
stakeholders in the Company.
On February 14, 1996, the Company commenced a voluntary
reorganization case under Chapter 11 of the Bankruptcy Code by filing a
voluntary petition for bankruptcy relief with the Bankruptcy Court (Case No.
96BK-50212). Upon the filing of the voluntary petition for relief, the Company,
as debtor-in-possession, was authorized to operate its business for the benefit
of claim holders and interest holders, and continued to do so without objection
or request for appointment of a trustee. All debts of the Company as of the
Petition Date were stayed by the bankruptcy petition and were subject to
compromise pursuant to such proceedings. The Company did not make the March 1,
1996 interest payment on the Senior Notes and pursuant to an order of the
Bankruptcy Court did not make the scheduled interest payment of $381,000 to INCC
on February 28, 1996, nor did it make any interest payments from that date on
the Prior Credit Facility through July of 1997. In addition, the Company did not
make the first scheduled payment of $938,000 due on the Prior Credit Facility on
March 31, 1996, nor did it make any principal payments from that date through
July of 1997. On July 11, 1997, the Prior Credit Facility was paid in full,
pursuant to the Plan. During the pendency of the bankruptcy proceedings, the
Company was required to obtain court approval for transactions outside the
ordinary course of business.
On October 22, 1996, the Company accepted and signed the proposal
("DLBW Proposal") submitted by DLB and Wexford Management, on behalf of its
affiliated investment funds, providing the terms of a proposed capital
investment in a plan of reorganization for the Company. The Company subsequently
obtained Bankruptcy Court approval of the expense reimbursement provisions of
the DLBW Proposal.
Subsequent to the Company's execution of the DLBW Proposal, DLB
commenced negotiations with TEPI regarding, (i) the claim asserted by TEPI
against the Company and its affiliates ("Texaco Claim"), (ii) the purchase of
certain interests owned by TEPI in the WCBB field ("WCBB Assets") and (iii) the
Contract Area Operating Agreement related to the WCBB Assets and various other
agreements relating thereto. As a result of the negotiations, on March 11, 1997,
TEPI and DLB entered into, among other agreements, the Purchase, Sale and
Cooperation Agreement ("PS&C Agreement") pursuant to which DLB (i) agreed to
purchase the Texaco Claim, (ii) agreed to purchase the WCBB Assets from TEPI and
(iii) agreed to guarantee ("P&A Guarantee") the performance of all plugging and
abandonment obligations related to both the WCBB Assets and the Company's
interests in the WCBB field and, in order to implement the P&A Guarantee, the
Company paid into a trust ("P&A Trust") established for the benefit of the State
of Louisiana, $1,000,000 on the Effective Date of the Plan.
Pursuant to the PS&C Agreement, on the Effective Date of the Plan,
DLB, among other things, assigned its rights associated with the WCBB Assets to
Gulfport, and as a result, Gulfport assumed, jointly and severally with DLB, the
liabilities with respect to the WCBB Assets.
By order dated May 5, 1997, the Bankruptcy Court approved the Plan.
The Plan involved (i) the issuance to Old WRT's unsecured creditors, on account
of their allowed claims, an aggregate of 10,000,000 shares of Common Stock, (ii)
the issuance to Old WRT's unsecured creditors, on account of their allowed
claims, the right to purchase an additional 3,800,000 shares of Common Stock at
a purchase price of $3.50 per share (the "1997 Rights Offering"), (iii) the
issuance to DLBW and affiliates of the number of shares of Common Stock obtained
by dividing DLBW's Allowed Secured Claim ("Secured Claim") amount by a
conversion price of $3.50 per share, (iv) the purchase by DLBW of all shares of
Common Stock not otherwise purchased pursuant to the 1997 Rights Offering, (v)
the transfer by DLB of the WCBB Assets to Gulfport along with the associated P&A
Trust and associated funding obligation in exchange for 5,000,000 shares of
Common Stock, (vi) the funding by WRT of $3,000,000 to an entity (the
"Litigation Entity") to be controlled by an independent party for the benefit of
most of the Company's existing unsecured creditors and the transferring to the
Litigation Entity of any and all causes of action, claims, rights of actions,
suits or proceedings which have been or could be asserted by Old WRT except for
(a) the action to recover unpaid production proceeds payable to Old WRT by
Tri-Deck and (b) the foreclosure action to recover title to certain assets,
(vii) the distribution of warrants to purchase Common Stock at an exercise price
of $10.00 per share to holders of certain securities litigation claims against
Old WRT and to holders of Old WRT's common stock and preferred stock, and (viii)
the cancellation of Old WRT's common stock and preferred stock. Pursuant to the
Plan, Gulfport owns a 12% economic interest in the Litigation Entity and the
remainder of the economic interests in the Litigation Entity were allocated to
unsecured creditors based on their ownership percentage of the 13,800,000
34
<PAGE> 38
shares of Common Stock distributed and issued as described in (i) and (ii)
above. The Plan became effective on July 11, 1997.
Upon the Effective Date of the Plan, Gulfport became the owner of
one hundred percent (100%) of the working interest in the shallow contract area
at WCBB. The proceeds from the 1997 Rights Offering were utilized to provide the
cash necessary to satisfy Administrative and Priority Claims ("APC"), fund the
Litigation Entity with $3,000,000 and provide Gulfport with working capital.
PRINCIPAL OIL AND GAS PROPERTIES
Gulfport owns interests in a number of producing oil and gas
properties located along the Louisiana Gulf Coast. The Company serves as the
operator of all properties in which it holds an interest. However, effective as
of September 1, 1998, the Company retained Castex to serve as a contract
operator of the Castex Operated Properties pursuant to the Castex Agreement. See
"Management's Discussion and Analysis of Financial Conditions and Results of
Operations--Recent Developments and Plans--Other Agreements." The following
table presents certain information as of July 1, 1998, reflecting the Company's
net interest in its producing oil and gas properties, including those held
through joint ventures.
<TABLE>
<CAPTION>
PRODUCING SHUT-IN PROVED RESERVES (2)
WELLS WELLS ACREAGE ----------------------------------
------------------ ------------------ ----------------- GAS OIL TOTAL
PROPERTY(1) GROSS NET GROSS NET GROSS NET (MBOE) (MBOE) MBOE
- ----------------------- ------- ------ ------- ------ ------- ------ -------- -------- --------
<S> <C> <C> <C> <C> <C> <C> <C> <C> <C>
Abbeville Field 0 0.0 2 1.4 61 43 10 2 12
Atchafalaya Bay Field 0 0.0 2 2.0 403 403 135 426 561
Bayou Penchant Field(3) 10 10.0 4 4.0 1,360 1,360 803 23 826
Bayou Pigeon Field(3) 9 8.0 6 4.0 1,490 1,490 21 267 288
Deer Island Field(3) 2 2.0 3 3.0 412 412 423 144 567
East Hackberry Field 14 6.8 62 32.3 3,142 1,573 326 1,588 1,914
Golden Meadow Field(3) 1 1.0 0 0.0 171 171 153 23 176
Lac Blanc Field(3) 2 2.0 7 6.0 4,755 4,755 6 0 6
West Hackberry Field 5 5.0 6 6.0 592 592 0 96 96
West Cote Blanche Bay 56 54.1 336 336.0 4,590 4,590 55 23,058 23,113
Other Wells 1 0.3 8 4.3 1,559 522 0 0 0
------ ------ ------ ------ ------ ------ -------- -------- --------
Total at year end 100 89.2 436 399.0 18,535 15,911 1,932 25,627 27,559
====== ====== ====== ====== ====== ====== ======== ======== ========
</TABLE>
- ----------
(1) Substantially all properties are located in south Louisiana.
(2) Represents proved reserves attributable to properties as estimated by
independent petroleum engineers as of January 1, 1998. See "--Reserves"
and Note 20 to Notes to Consolidated Financial Statements.
(3) Operated by Castex as of September 1, 1998.
BAYOU PENCHANT
The Bayou Penchant Field, purchased in January 1995, consists of
approximately 1,360 gross acres and includes eight producing wells, four shut-in
wells and one salt water disposal well in Terrebonne Parish, Louisiana. The
Company's working interest is 100% (approximately 86% average NRI) in all but
one well, the CL&F No. 7 well in which the Company's working interest is
approximately 70% (59% NRI). The Bayou Penchant Field is located in a marshy
area with existing dredged canals and produces primarily gas from multiple
productive zones, ranging in depth from 2,400 to 10,400 feet. During 1997, there
were three successful and two unsuccessful recompletion attempts. In July 1998,
Sanchez filed a lawsuit claiming an interest in the North Bayou Penchant Field.
See "--Legal Proceedings."
BAYOU PIGEON FIELD
The Bayou Pigeon Field, purchased in March 1995, consists of
approximately 1,490 gross acres located in the marshy coastal waters on both
sides of Little Bayou Pigeon in Iberia Parish, Louisiana. The Company has a 100%
working interest in 13 wells (nine producing and four shut in wells,
approximately 80% average NRI). The
35
<PAGE> 39
Company also owns a working interest in three additional wells in the Bayou
Pigeon Field of approximately 7% (5% NRI), 75% (63% NRI) and 95% (72% NRI),
respectively. Production from the Bayou Pigeon Field is predominately oil from
multiple productive zones at depths ranging from 6,900 to 12,000 feet. During
1996, one well was successfully recompleted. During 1997, one recompletion was
marginally successful.
DEER ISLAND FIELD
The Deer Island Field, purchased in March 1995, is located in marshy
inland waters in Terrebonne Parish, Louisiana and is accessed by workboat
through dredged canals. The Company acquired a 100% working interest
(approximately 73% NRI before payout and 66% thereafter) in approximately 412
acres comprised of two non-contiguous lease blocks in the Deer Island Field.
Current production from the two active wells in the southern lease block is
primarily gas from multiple producing zones at depths ranging from 8,200 to
10,200 feet. The two wells in the northern lease block produce from an oil sand
at a depth of approximately 10,350 feet. The interests in both tracts were
originally acquired through two separate subleases from Exxon. In the southern
lease block, the interest is composed of three tracts with varying depth
limitations, with the greatest depth being approximately 10,500 feet. Exxon
retained the rights below 10,500 feet and Exxon or other producers own the
rights to the other outstanding depths. In the northern lease block, the
interest is limited to depths between the surface and 10,720 feet. During 1997,
two significant oil and gas wells sanded up and ceased production. Although
there was no recompletion activity in 1997, two workover projects are scheduled
for the third quarter of 1998 to rework the two wells sanded up in 1997.
EAST HACKBERRY FIELD
In February 1994, the Company purchased a 100% working interest
(approximately 82% average NRI) in certain producing oil and gas properties
situated in the East Hackberry Field in Cameron Parish, Louisiana. The purchase
included two separate lease blocks, the Erwin Heirs Block, originally developed
by Gulf Oil Company, and the Texaco State Lease 50 Block, originally developed
by Texaco. The East Hackberry Field is located along the western shore of Lake
Calcasieu in Cameron Parish, Louisiana approximately 80 miles west of Lafayette
and 15 miles inland from the Gulf of Mexico. The properties cover approximately
3,142 acres of oil and gas leases, together with 13 productive wells and 63
shut-in wells that were originally drilled by Gulf Oil Company and Texaco.
In September 1994, the Company sold an overriding royalty interest
in certain producing oil and gas wells situated in the East Hackberry Field to
Milam Royalty Corporation ("Milam"). On an aggregate basis, the overriding
royalty interests provide for payment to Milam of 62.5% of 80% (equal to 50% on
a 100% working interest basis) of the net profits attributable to the wells
covered by the arrangement until Milam recovers 150% of its cash investment and
46.875% of 80% thereafter (equal to 37.5% on a 100% working interest basis).
Related agreements further provide that for an additional royalty purchase price
based on the then effective percentage described in the two preceding sentences
of the Company's future cost of drilling new wells or recompleting existing
wells in new reservoirs (and subject to certain limitations stated in such
agreements), Milam may elect to retain an identical royalty interest in the new
wells. The Company retains operational control over the East Hackberry Field.
During 1997, there was one marginally successful recompletion, one unsuccessful
recompletion attempt and one well was plugged and abandoned. Because the Company
had financial constraints during this time period, the Company believes it was
commercially impractical to shoot seismic and commence drilling operations on
such property. As a result, the Company surrendered approximately 440
non-producing acres in this field.
GOLDEN MEADOW FIELD
The Golden Meadow Field, purchased in March 1995, is located in
marshy, inland waters in Lafourche Parish, Louisiana and was discovered by
Texaco in 1961. The portion of the Golden Meadow Field in which the Company owns
a 100% working interest (approximately 79% average NRI) covers approximately 171
acres. The Golden Meadow Field is presently producing from one well drilled to a
gas bearing sand at a depth of approximately 12,500 feet. Although there was no
downhole activity in 1997, modifications to the surface equipment resulted in
improved well performance and a slight increase in proved reserves.
36
<PAGE> 40
LAC BLANC FIELD
The Lac Blanc Field, purchased in July 1993, consists of 4,755 gross
acres and underlies a marsh and shoreline near the community of Pecan Island in
Vermilion Parish, Louisiana and was first discovered in 1975. The Company
purchased a 91% average working interest (55% average NRI) in acreage within the
Lac Blanc Field from an affiliate of Freeport-McMoRan, Inc. The sellers retained
a 20% back-in working interest in any new wells drilled in previously
undeveloped fault blocks. The field has produced approximately 150 Bcf of gas
and 1.1 MMBbls of oil since its discovery, but in recent years it has
experienced substantial production declines, which were accompanied by
substantial increases in water production rates. Three unsuccessful attempts
were made during 1995 to restore production to this field and compensate for the
reduced gas volumes caused by the unexpected onset of water production. Two
workover attempts were made in the Exxon Fee No. 23 well. A split in the casing
ultimately resulted in the loss of future utility in the well. In early 1997, an
Amine unit was installed and the wells were returned to production.
In connection with the purchase of the Lac Blanc Field, the Company
established a plugging and abandonment escrow arrangement. See "Management's
Discussion and Analysis of Financial Condition and Results of
Operations--Commitments and Contingencies."
WEST HACKBERRY FIELD
In November 1992, the Company purchased a 100% working interest
(approximately 80% average NRI, subsequently increased to approximately 87.5%
NRI) in 529 acres within the West Hackberry Field in Cameron Parish, Louisiana
with five producing wells. The field was discovered in 1928 and was developed by
Superior Oil Company (now Mobil Corporation) between 1938 and 1988. During 1997,
a rod pump was installed in one of the producing wells, resulting in an initial
stabilized rate of 45 bopd.
WEST COTE BLANCHE BAY FIELD
TEPI, the operator of the WCBB field prior to March 1997, discovered
the WCBB field in 1938. This field lies approximately five miles off the coast
of Louisiana primarily in St. Mary Parish in a shallow bay, with water depths
averaging seven to eight feet, and overlies one of the largest salt dome
structures on the Gulf Coast. The Company acquired from TEPI a 6.25% working
interest in the WCBB field in July 1988. In April 1995, the Company completed
the purchase of an additional 43.75% working interest in the WCBB field from an
affiliate of Benton Oil and Gas Company and two affiliates of Tenneco, Inc. The
sellers retained their interests in all depths below approximately 10,500 feet.
Pursuant to the Plan, at the Effective Date, the Company acquired the remaining
50% working interest in the WCBB field in depths above the Rob "C" marker
located at approximately 10,500 feet and became the operator of the field.
During 1995, ten successful oil and three successful gas recompletions were made
with two additional attempts being unsuccessful. Additionally, five new
development oil wells and one new development gas well were drilled. One
development well was unsuccessful. These success ratios are consistent with the
Company's past experience in the WCBB field. During 1997, there were five
successful recompletions (including two TEPI wells), three unsuccessful
recompletion attempts, five successful workovers and two successful new wells.
During the first quarter of 1998, there were two successful and one marginally
successful recompletion attempts. The Company is currently pursuing certain
strategic alliances with respect to the WCBB field. See "Management's Discussion
and Analysis of Financial Condition and Results of Operations--Recent
Developments and Plans."
ACREAGE
The following table sets forth the Company's developed acreage at
December 31, 1997. The Company did not own any undeveloped acreage at December
31, 1997.
<TABLE>
<CAPTION>
DEVELOPED ACREAGE(1)(2)
-----------------------
GROSS NET
------- ------
<S> <C> <C>
Louisiana Onshore and State Waters.............. 15,975 14,135
------ ------
Total........................................... 15,975 14,135
====== ======
</TABLE>
37
<PAGE> 41
- ----------
(1) Developed acreage is acreage assigned to producing wells for the spacing
unit of the producing formation. Developed acreage in certain of the
Company's properties that include multiple formations with different well
spacing requirements may be considered undeveloped for certain formations
but have only been included as developed acreage in the presentation
above. Certain acreage is subject to depth limitations.
(2) Includes 279 gross and net acres attributable to the Napoleonville field.
Effective July 1, 1998, the Company's interests in the Napoleonville field
were sold to Plymouth pursuant to the Napoleonville Agreement. See
"Management's Discussion and Analysis of Financial Condition and Results
of Operations--Recent Developments and Plans--Napoleonville."
The oil and gas leases in which the Company has an interest are for
varying primary terms and may require the payment of delay rentals to continue
the primary terms. The operator may surrender the leases at any time by notice
to the lessors, by the cessation of production or by failure to make timely
payment of delay rentals. See "Management's Discussion and Analysis of Financial
Condition and Results of Operations--Commitments and Contingencies--Texaco
Global Settlement."
DRILLING AND RECOMPLETION ACTIVITIES
The following table contains data with respect to certain of the
Company's field operations during the years ended December 31, 1997, 1996 and
1995. The Company drilled no exploratory wells during the periods presented.
<TABLE>
<CAPTION>
1997 1996 1995
----------------- ----------------- -----------------
GROSS NET GROSS NET GROSS NET
------ ------ ------ ------ ------ ------
<S> <C> <C> <C> <C> <C> <C>
Recompletions, Side-Tracks and
Deepenings
Oil 8 7.0 12 5.7 35 19.5
Gas 6 4.5 5 3.2 17 12.7
Non-Productive 8 7.5 7 4.7 18 13.2
------ ------ ------ ------ ------ ------
Total 22 19.0 24 13.6 70 45.4
====== ====== ====== ====== ====== ======
Development Wells
Oil 1 1 0 0 6 3.5
Gas 0 0 0 0 2 1.1
Non-Productive 0 0 1 0.5 2 1.1
------ ------ ------ ------ ------ ------
Total 1 1 1 0.5 10 5.7
====== ====== ====== ====== ====== ======
</TABLE>
TITLE TO OIL AND GAS PROPERTIES
It is customary in the oil and gas industry to make only a cursory
review of title to undeveloped oil and gas leases at the time they are acquired
and to obtain more extensive title examinations when acquiring producing
properties. However, with respect to future undeveloped leasehold and producing
property acquisitions, if any, the Company will conduct title examinations on
material portions of such properties in a manner generally consistent with
industry practice. Certain of the Company's oil and gas properties may be
subject to title defects, encumbrances, easements, servitude's or other
restrictions, none of which, except as noted under the caption "Management's
Discussion and Analysis of Financial Condition and Results of
Operations--Commitments and Contingencies--Title to Oil and Gas Properties,"
in management's opinion, will in the aggregate materially restrict the Company's
operations.
RESERVES
The oil and gas reserve information set forth below represents only
estimates. Reserve engineering is a subjective process of estimating volumes of
economically recoverable oil and gas that cannot be measured in an exact manner.
The accuracy of any reserve estimate is a function of the quality of available
data and of engineering and geological interpretation. As a result, the
estimates of different engineers often vary. In addition, the results of
drilling, testing and production may justify revisions of such estimates.
Accordingly, reserve estimates often differ from the quantities of oil and gas
that are ultimately recovered. Estimates of economically recoverable oil and gas
and of future net revenues are based on a number of variables and assumptions,
all of which may vary from actual results, including geologic interpretation,
prices and future production rates and costs.
38
<PAGE> 42
The following table sets forth estimates of the proved oil and gas
reserves of the Company at January 1, 1998, as estimated by the Company's
independent petroleum engineers, Netherland, Sewell & Associates, Inc. ("NSAI"),
reduced for the proved reserves attributable to the possible title failure of
approximately 43 acres in the Bayou Pigeon Field. See "Management's Discussion
and Analysis of Financial Condition and Results of Operations--Commitments and
Contingencies--Title to Oil and Gas Properties."
<TABLE>
<CAPTION>
JANUARY 1, 1998
--------------------------------------------------------------
PROVED RESERVES DEVELOPED UNDEVELOPED TOTAL
--------------- ------------- ------------- -------------
<S> <C> <C> <C>
Oil (MBbls)(1) 7,220 18,597 25,817
Gas (MMcf) 8,259 3,317 11,576
MBoe(1) 8,596 19,150 27,746
Year-end present value of
estimated future net revenues $ 16,075,000 $ 60,355,000 $ 76,430,000
</TABLE>
- ----------
(1) Includes 189 MBoe of oil attributable to the Napoleonville field. Effective
July 1, 1998, the Company's interests in the Napoleonville field were sold to
Plymouth pursuant to the Napoleonville Agreement. See "Management's Discussion
and Analysis of Financial Condition and Results of Operations--Recent
Developments and Plans--Napoleonville."
Total reserves increased to approximately 27,746,000 Boe at January
1, 1998, from approximately 16,443,000 Boe at December 31, 1996. The 1997
year-end estimates increased from amounts previously reported due to the
addition of 11,666,000 Boe associated with the acquisition of the remaining 50%
interest in certain WCBB properties and the upward revisions to the reserves
estimates of 947,000 Boe, offset in part by 1997 production of 1,036,000 Boe.
The estimated future net revenues set forth above were determined by
using reserve quantities of proved reserves and the periods in which they are
expected to be developed and produced based on economic conditions prevailing at
January 1, 1998. The estimated future production is priced at January 1, 1998,
without escalation using $17.91 per Bbl and $2.62 per Mcf. Additional
information concerning the Company's oil and gas reserves and disclosure of the
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil
and Gas Reserves (Unaudited) is set forth in Note 20 to the Company's
Consolidated Financial Statements. As a result of a ceiling test performed at
June 30, 1998, the Company was required to write down the value of its oil and
gas properties by $16.0 million. See "Management's Discussion and Analysis of
Financial Condition and Results of Operations."
In compliance with federal law, the Company files annual reports
with the Energy Information Agency of the U.S. Department of Energy with respect
to its production of oil and gas during each calendar year and its estimated oil
and gas reserves at the end of each year. The reserve values set forth above and
in the Company's Consolidated Financial Statements attached hereto may vary
within five percent from the estimates previously provided to the Department of
Energy by the Company due to the Company's practice of including in its report
to the Department of Energy all oil and gas production and reserves attributable
to wells for which the Company serves as operator.
PRODUCTION, PRICES AND COSTS
The Company sells its oil and gas at the wellhead and does not
refine petroleum products. Other than normal production facilities, the Company
does not own an interest in any bulk storage facilities or pipelines. As is
customary in the industry, the Company sells its production in any one area to
relatively few purchasers, including transmission companies that have pipelines
near the Company's producing wells. Gas purchase contracts are generally on a
short-term "spot market" basis and usually contain provisions by which the
prices and delivery quantities for future deliveries will be determined. The
majority of the Company's crude oil production is sold on 30-day "evergreen"
contracts with prices based on postings plus a premium. The following table
contains certain historical data respecting the average sales prices received
and the average production costs incurred by the Company during the years ended
December 31, 1997, 1996 and 1995.
39
<PAGE> 43
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
----------------------------------------
1997 1996 1995
---------- ---------- ----------
<S> <C> <C> <C>
Production Volumes
Oil (MBbls) 566 615 778
Gas (MMcf) 2,818 3,629 7,403
Oil equivalents (MBoe) 1,036 1,220 2,012
Average Prices
Oil (per Bbl) $ 20.93 $ 22.17 $ 16.59
Gas (per Mcf) $ 2.86 $ 2.86 $ 1.59
Oil equivalents (per MBoe) $ 19.20 $ 19.68 $ 12.27
Average production costs (per Boe) $ 9.05 $ 10.90 $ 4.74
Average production taxes (per Boe) $ 1.48 $ 1.47 $ 1.08
</TABLE>
CUSTOMERS
During 1997, sales to Prior Energy Corporation, Wickford Energy
Marketing and Gathering and Energy Marketing Co. accounted for 43%, 29% and 22%,
respectively, of the Company's oil and gas revenues. The Company had no other
purchasers that accounted for greater than 10% of its oil and gas revenues in
the year ended December 31, 1997.
FACILITIES
The Company owns an industrial building located in Lafayette,
Louisiana with approximately 12,500 square feet of office, warehouse and shop
space.
COMPETITION AND MARKETS
AVAILABILITY OF MARKETS
The availability of a ready market for any oil and/or gas produced
by the Company depends on numerous factors beyond the control of management,
including but not limited to, the extent of domestic production and imports of
oil, the proximity and capacity of gas pipelines, the availability of skilled
labor, materials and equipment, the effect of state and federal regulation of
oil and gas production and federal regulation of gas sold in interstate
commerce. Gas produced by the Company in Louisiana is sold to various purchasers
who service the areas where the Gulfport's wells are located. The Company's
wells are not subject to any agreements that would prevent it from either
selling its gas production on the spot market or committing such gas to a
long-term contract; however, there can be no assurance that the Company will
continue to have ready access to suitable markets for its future oil and gas
production.
IMPACT OF ENERGY PRICE CHANGES
Oil and gas prices can be extremely volatile and are subject to
substantial seasonal, political and other fluctuations. The prices at which oil
and gas produced by the Company may be sold is uncertain and it is possible that
under some market conditions the production and sale of oil and gas from some or
all of its properties may not be economical. The availability of a ready market
for oil and gas, and the prices obtained for such oil and gas, depend upon
numerous factors beyond the control of the Company, including competition from
other oil and gas suppliers and national and international economic and
political developments. Because of all of the factors influencing the price of
oil and gas, it is impossible to accurately predict future prices.
REGULATION
ORPHANED WELL ACT
In June 1993, the Louisiana legislature passed the Louisiana
Oilfield Site Restoration Law (the "Orphaned Well Act") which provides that if
an oil field site is transferred from one party to another, the parties to the
transfer may elect to establish a trust account for such site to provide a
source of funds for future site restoration. A primary
40
<PAGE> 44
advantage of this law is that, once the site-specific trust account has been
approved by the Secretary of the Louisiana Department of Natural Resources (the
"DNR"), the party transferring the oil field site is relieved of liability by
the state for any site restoration costs or actions associated with the site.
Management believes that this makes the Company and others who are willing to
use this law more competitive as purchasers of oil and gas properties. If the
parties to a transfer elect to be covered under the Orphaned Well Act, the
Secretary of the DNR will require that a site assessment be performed by a
contractor approved by the special state commission created under the statute
and will require the parties to the transaction to provide a proposed funding
schedule for the trust account. The site assessment must specifically identify
site restoration costs needed to restore the oil field site based on conditions
existing at the time of the transfer. Generally, some contribution to the trust
account will be required at the time of the transfer and additional funding will
be required quarterly thereafter until the account is fully funded. The trust
account is monitored by the DNR and the funds in the trust accounts remain the
property of the DNR. The purchaser of the oil field site is liable for site
restoration at the end of its useful life. If the purchaser restores the site,
the purchaser will be entitled to recover the balance of the trust account.
Compliance with such law does not, however, relieve the parties to the
transaction from liability to private parties.
In December 1994, the Company entered into a definitive agreement
with LLOG Exploration Company ("LLOG") for the purchase of LLOG's working
interest in the Bayou Penchant Field (the "Initial LLOG Property"). This sale
was completed in January 1995. In March 1995, the Company completed its
acquisition of additional oil and gas properties owned by LLOG in four South
Louisiana fields (the "Remaining LLOG Properties"). In connection with these
purchases, the Company agreed to establish plugging and abandonment escrow funds
as allowed by the Orphaned Well Act. In connection with the Reorganization Case,
LLOG filed a claim asserting that Old WRT was required, notwithstanding the
bankruptcy case, to fulfill its contractual commitment to establish plugging and
abandonment funds (the "Asserted LLOG P&A Trusts"), and that LLOG had a vendor's
lien on the Initial LLOG Property and Remaining LLOG Properties securing Old
WRT's performance of the contractual commitment. Old WRT's disputed LLOG's claim
and its asserted vendor's lien, and filed an objection seeking a disallowance of
LLOG's claim and a determination that any claim asserted by LLOG with respect to
the Asserted LLOG P&A Trusts was unsecured. On July 8, 1997, the Bankruptcy
Court ruled that LLOG's claim with respect to the Asserted LLOG P&A Trusts was
secured by a valid vendor's lien on the Initial LLOG Property and Remaining LLOG
Properties, but did not determine the amount of such claim. Old WRT filed a
motion requesting that the Bankruptcy Court reconsider its ruling. On January
15, 1998, the Bankruptcy Court denied Gulfport's motion to reconsider its
ruling. Therefore, Gulfport will be required to establish plugging and
abandonment funds. The amount of and terms of payment into each fund will be
established by the State of Louisiana upon completion of an independent study to
be commissioned by the Company. As of August 25, 1998, the independent study had
not been completed. Accordingly, Gulfport is unable to determine the amount and
payment towards the future obligation related to these commitments.
ENVIRONMENTAL REGULATION
Operations of the Company are subject to numerous federal, state,
and local laws and regulations governing the discharge of materials into the
environment or otherwise relating to environmental protection. These laws and
regulations may require the acquisition of a permit before drilling commences,
restrict or prohibit the types, quantities and concentration of substances that
can be released into the environment in connection with drilling and production
activities, prohibit drilling activities on certain lands lying within wetlands
or other protected areas and impose substantial liabilities for pollution
resulting from drilling and production operations. Moreover, state and federal
environmental laws and regulations may become more stringent. These
environmental laws and regulations may affect the Company's operations and costs
as a result of their effect on oil and gas development, exploration, and
production operations. For instance, legislation has been proposed in Congress
from time to time that would amend the federal Resource Conservation and
Recovery Act of 1976 ("RCRA") to reclassify oil and gas production wastes as
"hazardous waste." If such legislation were enacted, it could have a significant
impact on the Company's operating costs, as well as the oil and gas industry in
general. It is not anticipated that Gulfport will be required in the near future
to expend amounts that are material in relation to its total capital
expenditures program by reason of environmental laws and regulations, but
inasmuch as such laws and regulations are frequently changed, Gulfport is unable
to predict the ultimate cost of compliance. In addition, The Comprehensive
Environmental Response, Compensation and Liability Act of 1980 ("CERCLA" or
"Superfund") and certain state laws and regulations impose liability for cleanup
of waste sites and in some cases attorney's fees, exemplary damages and/or
trebling of damages.
41
<PAGE> 45
The Oil Pollution Act of 1990 (the "OPA") and regulations thereunder
impose a variety of regulations on "responsible parties" related to the
prevention of oil spills and liability for damages resulting from such spills in
United States waters. A "responsible party" includes the owner or operator of a
facility or vessel, or the lessee or permittee of the area in which an offshore
facility is located. The OPA assigns liability to each responsible party for oil
removal costs and a variety of public and private damages. While liability
limits apply in some circumstances, a party cannot take advantage of liability
limits if the spill was caused by gross negligence or willful misconduct or
resulted from violation of a federal safety, construction or operating
regulation. If the party fails to report a spill or to cooperate fully in the
cleanup, liability limits do not apply. Few defenses exist to the liability
imposed by the OPA. The OPA also imposes ongoing requirements on a responsible
party, including proof by owners and operators of offshore oil and gas
facilities of establishment of $150,000,000 in financial responsibility.
Financial responsibility could be established by various means including
insurance, guarantee, surety bond, letter of credit or qualification as a
self-insurer. There is substantial uncertainty as to whether insurance companies
or underwriters will be willing to provide coverage under the OPA. The financial
tests or other criteria that will be used to judge self-insurance are also
uncertain. The Company cannot predict the final resolution of these financial
responsibility issues but such requirements have the potential to result in the
imposition of substantial additional annual costs on it or otherwise materially
adversely affect it. The impact of the rule should not be any more adverse to
the Company than it will be to the other similarly situated or less well
capitalized owners or operators. See "--Operational Hazards and Insurance".
The Clean Water Act, together with the related National Pollution
Discharge Elimination System ("NPDES"), and similar state environmental laws are
expected to prohibit oil and gas producers from discharging produced water
overboard into waters of the U.S. shoreward of the territorial seas ("Coastal
Waters") within one year or less. The Company is currently discharging produced
water overboard at its Tigre Lagoon facility in Louisiana. In June 1995, the
Company began underground injection at its East Hackberry facility and
discontinued overboard discharge. The Company received the final permit (WP
#4831) from the Louisiana Department of Environmental Quality ("LDEQ") on
February 18, 1995 in connection with its Tigre Lagoon facility. The final permit
expired on December 31, 1996. In addition, the Company has filed and obtained a
NPDES permit with the Environmental Protection Agency ("EPA") for coverage of
the applicable Company Coastal Waters facilities under the EPA general permit
relating to discharge of produced water.
RADIOACTIVE MATERIALS LICENSING
The Company is licensed, regulated and subject to inspection by the
LDEQ with respect to the ownership and operation of its radioactive well logging
tools. Failure to comply with such licensing and regulatory requirements could
cause the Company to lose its rights to operate its well logging tools. The
Company's radioactive well logging tools required the use of radioactive
materials and explosives which may result in substantial losses or liabilities
to third parties, including claims for bodily injuries, reservoir damage, loss
of reserves, environmental damage and other damages to persons or property. In
December 1997, the Company sold all of its radioactive well logging tools. See
"--Operational Hazards and Insurance."
FEDERAL AND STATE REGULATION
Complex regulations concerning all phases of energy development at
the local, state and federal levels apply to the Company's operations and often
require interpretation by the Company's professional staff or outside advisors.
The federal government and various state governments have adopted numerous laws
and regulations respecting the production, transportation, marketing and sale of
oil and gas. Regulation by state and local governments usually covers matters
such as the spacing of wells, allowable production rates, pooling and
unitization, environmental protection, pollution control, pricing, taxation and
other related matters. In Louisiana, the Commissioner of the Office of
Conservation is empowered to create geographic or geological units for drilling
and producing wells which units contain, in the Commissioner's sole judgment,
the production acreage likely to be efficiently and economically drained by such
well. These units are created only after notice to interested parties and a
hearing at which time the Commissioner will accept geological and engineering
testimony from the interested parties. The creation of these units could have
the result of combining the Company's leasehold interest with lease acreage held
by competing producers and could have the effect of reducing the Company's
interest in a drilling or producing well below the leasehold interest to which
it would otherwise be entitled. Unitization of the Company's properties may
force the Company to share production from its wells and leases with others and
can occur after
42
<PAGE> 46
development or acquisition costs have been incurred by the Company. If the
Company's leases are subjected to unitization, the Company may ultimately be
entitled to a lesser share of production from its wells than it expected. Any
federal leases acquired by the Company will be subject to various federal
statutes and the rules and regulations of federal administrative agencies.
Moreover, future changes in local, state or federal laws and regulations could
adversely affect the operations of the Company.
Legislation affecting the oil and gas industry is under constant
review for amendment or expansion, frequently increasing the regulatory burden.
Numerous departments and agencies, both federal and state are also authorized by
statute to issue, and have issued, rules and regulations binding the oil and gas
industry that often are costly to comply with and that carry substantial
penalties for non-compliance. In addition, production operations are affected by
changing tax and other laws relating to the petroleum industry, by constantly
changing administrative regulations and possible interruption or termination by
government authorities.
The FERC regulates the transportation and sale for resale of natural
gas in interstate commerce pursuant to the Natural Gas Act of 1938 (the "NGA")
and the Natural Gas Policy Act of 1978 (the "NGPA"). In the past, the federal
government has regulated the prices at which oil and gas could be sold.
Currently, sales by producers of natural gas, and all sales of crude oil,
condensate and natural gas liquids can be made at uncontrolled market prices,
but Congress could reenact price controls at any time.
The Company's natural gas gathering operations may be or become
subject to safety and operational regulations relating to the design,
installation, testing, construction, operation, replacement, and management of
facilities. Pipeline safety issues have recently become the subject of
increasing focus in various political and administrative arenas at both the
state and federal levels. The Company cannot predict what effect, if any, the
adoption of additional pipeline safety legislation might have on its operations,
but does not believe that any adverse effect would be material.
Proposals and proceedings that might affect the oil and gas industry
are routinely pending before the Congress, the FERC, and the courts. The Company
cannot predict when or whether any such proposals may become effective. In the
past, the natural gas industry has been very heavily regulated. There is no
assurance that the current regulatory approach pursued by the FERC will continue
indefinitely into the future.
Notwithstanding the foregoing, it is not anticipated that compliance
with existing federal, state and local laws, rules and regulations will have a
material adverse effect upon the capital expenditures, earnings or competitive
position of the Company.
OPERATIONAL HAZARDS AND INSURANCE
The Company's operations are subject to all of the risks normally
incident to the production of oil and gas, including blowouts, cratering, pipe
failure, casing collapse, oil spills and fires, each of which could result in
severe damage to or destruction of oil and gas wells, production facilities or
other property, or injury to persons. The energy business is also subject to
environmental hazards, such as oil spills, gas leaks, and ruptures and discharge
of toxic substances or gases that could expose the Company to substantial
liability due to pollution and other environmental damage. Although the Company
maintains insurance coverage considered to be customary in the industry, it is
not fully insured against certain of these risks, either because such insurance
is not available or because of high premium costs. The occurrence of a
significant event that is not fully insured against could have a material
adverse effect on the Company's financial position.
EMPLOYEES
At August 1, 1998, the Company employed 18 persons exclusive of the
Company's executive officers whose services are provided pursuant to the
Administrative Services Agreement. See "Certain Transactions." None of the
Company's employees are represented by labor unions or covered by any collective
bargaining arrangement. The Company considers its relations with its employees
to be satisfactory.
43
<PAGE> 47
LEGAL PROCEEDINGS
In 1997, Wildwing initiated litigation against the Company in the
Fifteenth Judicial District Court, Parish of Lafayette, State of Louisiana. In
its petition, Wildwing alleged that Old WRT's title had failed as to
approximately 43 acres in the Bayou Pigeon Field. Some or all of the acreage in
the dispute is considered to be productive in three separate production units.
The Company's working interest in the three units were reduced from 100% of each
unit to approximately 7% (5% NRI), 75% (63% NRI), and 95% (72% NRI),
respectively. The financial statements as of and for the years ended December
31, 1997, 1996 and 1995, reflect operating results and proved reserves
discounted for this title failure. As the title failure predates its ownership
of the field, the Company sought recourse against the predecessors-in-title
relative to this issue. On February 28, 1998, the Company entered into a
settlement agreement with Wildwing, which settlement provides that the
Stakeholders, who are currently holding funds in suspense attributable to
mineral production from the leases made the subject of the lawsuit, will be
instructed by the Company and Wildwing to distribute $269,500 to Wildwing in
full and final compromise of such litigation. Additional sums held by the
Stakeholders are to be distributed to the lessors of the leases made the subject
of the litigation an amount for payment of royalties due and owing up to the
date of the filing of such lawsuit. The balance held by the Stakeholders will
thereafter be distributed to the Company.
During 1995, the Company entered into a marketing agreement with
Tri-Deck pursuant to which Tri-Deck would market all of the Company's oil and
gas production. Subsequent to the agreement, James Florence, who served as both
Tri-Deck's principal and WRT's Director of Marketing, assigned Tri-Deck's right
to market the Company's oil production to Plains Marketing and assigned
Tri-Deck's right to market the Company's gas production to Perry Gas. During
early 1996, Tri-Deck failed to make payments to the Company attributable to
several months of the Company's gas production. Consequently, on May 20, 1996,
the Company filed with the Bankruptcy Court a Motion to Reject the Tri-Deck
Marketing Agreement, and on May 29, 1996, the Company initiated an adversarial
proceeding against Tri-Deck and Perry Gas. Perry Gas was the party which
ultimately purchased the Company's gas production for the months in question.
On January 20, 1998, Gulfport and the Litigation Entity entered into
a Clarification Agreement to clarify provisions of the Plan that might be
ambiguous as to whether the Company or the Litigation Entity should prosecute
causes of action so as to avoid duplicative litigation efforts, as well as
possible res judicata and collateral estoppel effect as to claims, which could
reduce the pool of potential recoveries otherwise made available to each party's
respective beneficiaries. As a part of the Clarification Agreement, the
Litigation Entity will intervene or be substituted as the actual party in
interest in the Tri-Deck case and will reimburse the Company $100,000 for legal
fees incurred by the Company. As additional consideration for the contribution
of this claim to the Litigation Entity, the Company is entitled to a percentage
ranging from 50% to 85% of the net proceeds from this claim.
On July 20, 1998, Sanchez initiated litigation against the Company
in the Fifteenth Judicial District Court, Parish of Lafayette, State of
Louisiana. In its petition, Sanchez alleged, among other things, that the
Company was obligated, by virtue of the terms of the Sanchez Letter, to grant a
sublease to Sanchez for an undivided 50% interest in two of the Company's oil,
gas and mineral leases covering lands located in the North Bayou Penchant area
of Terrebonne Parish, Louisiana. Pursuant to this lawsuit, Sanchez is seeking
specific performance by the Company of the contractual obligation that Sanchez
alleges to be present in the Sanchez Letter and monetary damages. The litigation
is in its earliest stages and discovery has not yet begun. In addition, the
Company is currently reviewing the claims set forth in the lawsuit to determine
the appropriate response thereto.
On June 30, 1998, Production Management Corporation ("PMC")
initiated litigation against the Company in the United States District Court of
the Western District of Louisiana, Lafayette-Opelousas Division, alleging breach
of contract and the failure of the Company to pay certain invoices related to
services allegedly provided to the Company. The complaint seeks monetary damages
in the amount of $388,131.76 plus interest, certain legal costs and 10% in
attorney's fees. The litigation is in its earliest stages and discovery has not
yet begun. The Company is currently reviewing the claims set forth in the
lawsuit to determine the appropriate response thereto.
44
<PAGE> 48
MANAGEMENT
DIRECTORS AND EXECUTIVE OFFICERS
The officers and directors of the Company are as follows:
<TABLE>
<CAPTION>
NAME AGE POSITION
---- --- --------
<S> <C> <C>
Mark Liddell 43 President and Director
Mike Liddell 44 Chairman of the Board, Chief
Executive Officer and Director
Ronald D. Youtsey 41 Chief Financial Officer, Secretary and
Treasurer
Charles E. Davidson 44 Director
Robert E. Brooks 50 Director
David L. Houston 45 Director
</TABLE> Director
Mark Liddell has served as a director of Gulfport since July 11,
1997 and as its President since April 28, 1998. Until April 28, 1998, Mr.
Liddell held the position of President of DLB, a position he held since October
1994. Mr. Liddell was Vice President of DLB from 1991 to 1994. From 1985 to
1991, he was Vice President of DLB Energy. Since November 1997, Mr. Liddell has
served as a director of Bayard Drilling Technologies, Inc., a publicly held
drilling company, from 1991 to May 1995, Mr. Liddell served as a director of TGX
Corporation, a publicly held oil and gas company, and from 1989 to 1990, he
served as a director of Kaneb Services, Inc., a publicly held industrial
services and pipeline transportation company. He received a B.S. degree in
education and a J.D. degree from the University of Oklahoma.
Mike Liddell has served as a director of Gulfport since July 11,
1997, as Chief Executive Officer since April 28, 1998 and as Chairman of the
Board since July 28, 1998. In addition, Mr. Liddell has served as Chief
Executive Officer of DLB since October 1994, and as a director of DLB since
1991. From 1991 to 1994, Mr. Liddell was President of DLB. From 1979 to 1991, he
was President and Chief Executive Officer of DLB Energy. He received a B.S.
degree in education from Oklahoma State University. He is the brother of Mark
Liddell.
Ronald D. Youtsey has served as Secretary and Treasurer of Gulfport
since July 11, 1997 and Chief Financial Officer since July 10, 1998. From July
15, 1995 until April 28, 1998, Mr. Youtsey also held the position of Senior Vice
President and Chief Financial Officer of DLB. Mr. Youtsey joined DLB as
Controller in 1991. From 1979 to 1991, he was employed by French Petroleum
Corporation, an oil and gas exploration and production company, last serving as
Vice President of Finance. Mr. Youtsey is a Certified Public Accountant and a
member of the American Institute of Certified Public Accountants. He received a
B.S. degree in accounting from the University of Central Oklahoma.
Charles E. Davidson has served as a director of Gulfport since July
11, 1997. From July 15, 1995 until April 28, 1998, Mr. Davidson also held the
position of Chairman of the Board of Directors of DLB. Since 1994, he has also
served as managing partner of Wexford Capital Corporation, a private investment
firm. From 1984 to 1994, he was a partner in Steinhardt Partners, L.P., a
private investment firm. From 1977 to 1984, Mr. Davidson was employed by
Goldman, Sachs & Co., last serving as Vice President of corporate bond trading.
Mr. Davidson is Chairman of the Board of Resurgence Properties, Inc. and is also
a director of Presido Capital, Inc., both of which are publicly held real estate
companies. He holds a B.A. degree and a M.B.A. degree from the University of
California at Los Angeles.
Robert E. Brooks has served as a director of Gulfport since July 11,
1997. Mr. Brooks is currently a partner with Brooks Greenblatt, a commercial
finance company located in Baton Rouge, Louisiana that was formed by Mr. Brooks
in July 1997. Mr. Brooks is a Certified Public Accountant and was Senior Vice
President in charge of Asset Finance and Managed Assets for Bank One, Louisiana
between 1993 and July 1997. He received his B.S. degree from Purdue University
in mechanical engineering in 1969. He obtained graduate degrees in finance and
accounting from the Graduate School of Business at the University of Chicago in
1974.
45
<PAGE> 49
David Houston has served as a director of Gulfport since July 1998.
Since 1991, Mr. Houston has been the principal of Houston & Associates, a firm
that offers life and disability insurance, compensation and benefits plans and
estate planning. Prior to 1991, he was President and Chief Executive Officer of
Equity Bank for Savings, F.A., a $600 million, Oklahoma-based savings bank. He
currently serves on the board of directors and executive committee of Deaconess
Hospital, Oklahoma City, Oklahoma, and is the former chair of the Oklahoma State
Ethics Commission and the Oklahoma League of Savings Institutions. He received a
BS degree in business from Oklahoma State University and a graduate degree in
banking from Louisiana State University.
EXECUTIVE COMPENSATION
The following table provides certain summary information concerning
compensation paid or accrued during the three fiscal years December 31, 1997,
1996, and 1995 to the Company's Chief Executive Officer and each of the four
most highly compensated executive officers of the Company, determined as of the
end of the last fiscal year, whose annual compensation exceeded $100,000.
<TABLE>
<CAPTION>
LONG TERM
COMPENSATION
ANNUAL COMPENSATION (1)(2) AWARDS ALL OTHER
NAME AND ------------------------------------------- COMPENSATION
PRINCIPAL POSITION YEAR SALARY ($) BONUS ($) OPTIONS (#) ($) (2)
- ---------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
Gary C. Hanna, 1997 31,250 -- -- --
President (3)
Raymond P. Landry, 1997 156,000 78,000 60,000 --
Executive Vice President (4)
1996 161,962 25,000 -- --
1995 90,558 -- -- --
Wayne A. Beninger (5) 1997 95,506 65,500 --
Vice President - Strategic Planning
1996 116,804 -- --
1995 59,154 -- --
Thomas C. Stewart (6) 1997 83,359 53,000 --
Vice President of Operations
1996 108,808 -- --
1995 27,500 -- --
</TABLE>
- --------------
(1) Amounts shown include cash and non-cash compensation earned and received
by the named executives as well as amounts earned but deferred at their
election.
(2) The Company provides various perquisites to certain employees, including
the named executives. In each case, the aggregate value of the perquisites
provided to the named executives did not exceed 10% of such named
executives' annual salary and bonus.
(3) Mr. Hanna became President of the Company on July 11, 1997 and resigned on
April 28, 1998. During such period, Mr. Hanna was not paid a salary or
other compensation by Gulfport. His services were provided pursuant to the
Administrative Service Agreement and the compensation amount reflects the
portion of his compensation from DLB that was allocated to the Company
under such agreement. Effective as of April 28, 1998, Mr. Mark Liddell was
named President of the Company. Effective July 28, 1998, Mr. Mike Liddell
was named Chief Executive Officer of the Company. Messrs. Liddell will not
be paid a salary or other compensation by Gulfport. Their services will be
provided pursuant to the Administrative Services Agreement. See "Certain
Transactions."
(4) Mr. Landry received a $25,000 sign-on bonus, per the terms of his
employment contract, payment of which was deferred to 1996. Mr. Landry
received $78,000 in compensation during 1997 as a participant of the
employee stay bonus program. Mr. Landry ceased to be an Executive Vice
President on May 5, 1998, but continues to serve as an employee of the
Company.
(5) Mr. Beninger resigned as Vice President of Strategic Planning on
August 31, 1997. During 1997, Mr. Beninger received $65,500 in
compensation as a participant of the employee stay bonus program.
(6) Mr. Stewart resigned as Vice President of Operations on July 11, 1997.
During 1997, Mr. Stewart received $53,000 in compensation as a participant
of the employee stay bonus program.
46
<PAGE> 50
STOCK OPTIONS GRANTED IN 1997
The following table sets forth information concerning the grant of
stock options during 1997 to the named executives.
<TABLE>
<CAPTION>
INDIVIDUAL GRANTS
- ---------------------------------------------------------------------------- POTENTIAL REALIZABLE VALUE
NAME NUMBER OF # OF TOTAL ASSUMED ANNUAL RATES AT
SECURITIES OPTIONS OF STOCK PRICE APPRECIATION
UNDERLYING GRANTED FOR OPTION TERMS(1)
OPTIONS EMPLOYERS EXERCISE PRICE EXPIRATION ---------------------------
GRANTED (#) IN 1997 PRICE ($/SH) DATE (2) 5%($) 10%($)
- -----------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
Raymond P. Landry 60,000 100% $3.50 - $132,068 $334,686
</TABLE>
- ----------
(1) The assumed annual rates of increase are based on an annually compounded
increase of the exercise price of $3.50 per share through a presumed ten
year option term.
(2) Mr. Landry's options were granted under an employment agreement that was
part of the Plan, which was confirmed on July 11, 1997. No expiration term
was specified under the agreement.
STOCK OPTION HOLDINGS
The following table sets forth the number of unexercised options
held by named executives as of December 31, 1997. No options were exercised in
1997 and no options were in-the-money as of December 31, 1997.
<TABLE>
<CAPTION>
NUMBER OF UNEXERCISED
OPTIONS AT FY-END(1)
----------------------------------------------
NAME EXERCISABLE UNEXERCISABLE
- ---------------------------------------------------------- -------------------
<S> <C> <C>
Raymond P. Landry -- 60,000
</TABLE>
- ----------
(1) These options are exercisable at $3.50 per share.
DIRECTOR COMPENSATION
Up to the Effective Date, each director who was not a salaried
employee of the Company received $500 for his attendance at each meeting of the
Board of Directors and was reimbursed for expenses incurred in connection with
attending each such meeting. Currently, each outside director receives
compensation in the amount of $1,000 per month, $500 for attendance at each
meeting of the Board of Directors and reimbursement for expenses incurred in
connection with attending such meetings.
EMPLOYMENT AGREEMENTS
Pursuant to the Plan, Mr. Landry entered into a two-year employment
agreement with Gulfport commencing on the Effective Date. This employment
agreement provides for a salary of $156,000 per year and stock options to
purchase 60,000 shares of Common Stock at $3.50 per share pursuant to a stock
option agreement to be established by Gulfport. In addition, Gulfport assumed
the rights and obligations of existing employment contracts with Wayne A.
Beninger and Thomas C. Stewart, both of which expired on August 31, 1997, and
called for annual salaries of $125,000 and $100,000, respectively.
COMPENSATION COMMITTEE INTERLOCKS AND INSIDER TRADING
No member of the Committee is a former or current officer or
employee of the Company and no employee of the Company serves or has served on
the compensation committee (or board of directors of a corporation lacking a
compensation committee) of a corporation employing a member of this Committee.
47
<PAGE> 51
PRINCIPAL STOCKHOLDERS
The following table sets forth certain information concerning the
beneficial ownership of the Common Stock as of August 25, 1998, by (1) each
director, (2) the named executive officers, (3) each stockholder known by the
Company to own beneficially five percent or more of the outstanding shares of
the Common Stock and (4) all executive officers and directors of the Company as
a group.
<TABLE>
<CAPTION>
BENEFICIARY OWNERSHIP
------------------------------------
NAME AND ADDRESS OF BENEFICIARY OWNER(1) SHARES PERCENTAGE(2)
- ---------------------------------------- --------- -------------
<S> <C> <C>
Charles E. Davidson (3) 8,538,629 38.7%
411 West Putnam Avenue
Greenwich, Connecticut 06830
CD Holding Company LLC (4) 6,226,937 28.2%
411 West Putnam Avenue
Greenwich, Connecticut 06830
Wexford Management, LLC (5) 2,311,692 10.5%
411 West Putnam Avenue
Greenwich, Connecticut 06830
Mark Liddell(6) 1,062,618 4.8%
6307 Waterford Blvd., Suite 100
Oklahoma City, Oklahoma 73112
Mike Liddell(7) 1,076,647 4.9%
6307 Waterford Blvd., Suite 100
Oklahoma City, Oklahoma 73112
The Equitable Companies Incorporated 2,212,077 9.8%
1290 Avenue of the Americas
New York, New York 10104
Ronald D. Youtsey 208 *
Robert E. Brooks * *
David L. Houston * *
All directors and executive officers
as a group (6 individuals) 10,678,102 48.4%
</TABLE>
- ----------
* Less than one percent.
(1) Unless otherwise indicated, each person or group has sole voting and
investment power with respect to all listed shares.
(2) Each listed person's percentage ownership is determined by assuming that
options, warrants and other convertible securities that one held for such
person and that are exercisable or convertible within 60 days have been
exercised.
(3) Includes 2,311,692 shares of Common Stock held of record by the Wexford
Entities (as defined below) and 6,226,937 shares of Common Stock of record
by CD Holding Company LLC ("CD Holding"). Mr. Davidson is the Chairman
and controlling member of Wexford Management, LLC ("Wexford Management")
and the President and sole shareholder of CD Holding. Mr. Davidson
disclaims beneficial ownership of the 2,311,692 Shares owned by the
Wexford Entities.
(4) Charles E. Davidson is the President and sole stockholder of CD Holding.
(5) Includes shares of Common Stock held of record by the following seven
investment funds (the "Wexford Entities") that are affiliated with Wexford
Management: Wexford Special Situations 1996, L.P.; Wexford Special
Situations 1996 Institutional, L.P.; Wexford Special Situations 1996,
Limited; Wexford-Euris Special Situations 1996, L.P.; Wexford Spectrum
Investors LLC; Wexford Capital Partners II, L.P.; and Wexford Overseas
Partners I, L.P. Mr. Davidson is the managing partner of Wexford Capital
Corporation, which manages Wexford Management.
(6) Comprised of the shares of Common Stock held of record by Liddell
Holdings, LLC. Mr. Liddell is the sole member of Liddell Holdings, LLC.
(7) Comprised of the shares of Common Stock held of record by Liddell
Investments, LLC. Mr. Liddell is the sole member of Liddell Investments,
LLC.
48
<PAGE> 52
CERTAIN TRANSACTIONS
REORGANIZATION OF THE COMPANY
By order dated May 2, 1997, the Bankruptcy Court confirmed the Plan
of Old WRT and co-proponents DLB and Wexford Management. On July 11, 1997, DLB
and Wexford Management received, pursuant to the Plan, an aggregate of 13.2
million shares of Common Stock for various claims, assets and cash as detailed
below:
<TABLE>
<S> <C>
Unsecured debt of $34.3 million 2.88 million shares
Contribution of DLB's interest in certain WCBB properties 5.62 million shares
Cash of $5.0 million 1.43 million shares
Contribution of $11.5 million of secured and
asserted secured claims 3.27 million shares
--------------------
Total shares issued to DLB and Wexford Management 13.20 million shares
</TABLE>
For additional information concerning the Company's bankruptcy
reorganization, see "Business--Events Leading to the Reorganization Case."
ADMINISTRATIVE SERVICES AGREEMENT
Pursuant to the terms and conditions of an Administrative Services
Agreement, dated as of July 10, 1997, by and between the Company and DLB (the
"Administrative Services Agreement"), DLB agreed to make available to the
Company personnel, services, facilities, supplies, and equipment as the Company
may need, including executive and managerial, accounting, auditing and tax,
engineering, geological and geophysical, legal, land, and administrative and
clerical services. The initial term was one year beginning on the date of the
Administrative Services Agreement. The Administrative Services Agreement
continues for successive one-year periods unless terminated by either party by
written notice no less than 60 days prior to the anniversary date of the
Administrative Services Agreement. During the year ended December 31, 1997, the
services of Gary C. Hanna and Ronald D. Youtsey, the Company's then-President
and Secretary, respectively, were provided under this agreement. On April 28,
1998, in connection with the acquisition of DLB by Chesapeake Energy
Corporation, the obligations of DLB under the Administrative Services Agreement
were assigned to DLB Equities, LLC. Currently, the services of Mike Liddell,
Chief Executive Officer, Mark Liddell, President, and Ron Youtsey, Chief
Financial Officer, Secretary and Treasurer, are provided under the
Administrative Services Agreement.
In return for the services rendered under the Administrative
Services Agreement, the Company pays a monthly service charge based on the pro
rata proportion of the Company's use of services, personnel, facilities,
supplies and equipment provided by DLB Equities, LLC as determined by DLB
Equities, LLC in a good-faith, reasonable manner. The service charge was
calculated as the sum of (i) DLB Equities, LLC's fully allocated internal costs
of providing personnel and/or performing services, (ii) the actual costs to DLB
Equities, LLC of any third-party services required, (iii) the equipment,
occupancy, rental, usage, or depreciation and interest charges, and (iv) the
actual cost to DLB Equities, LLC of supplies.
At December 31, 1997, Gulfport owed DLB approximately $1.6 million
for services rendered pursuant to the Administrative Services Agreement. In
March 1998, in order to facilitate the acquisition of DLB by Chesapeake Energy
Corp., Mike Liddell, Mark Liddell and Charles Davidson purchased the receivable
from DLB for its then outstanding amount of approximately $1.6 million. Each of
Messrs. Mike and Mark Liddell and Mr. Davidson subsequently transferred his
portion of the receivable to Liddell Investments, LLC, Liddell Holdings, LLC and
CD Holding, respectively. The receivable accrues interest at the rate of LIBOR
plus 3% per annum. To the extent that Liddell Investments, LLC, Liddell
Holdings, LLC and CD Holding purchase Shares and Excess Shares they will do so
through the forgiveness of an equal amount owed to them by the Company under the
Stockholder Credit Facility and the Administrative Services Agreement. To the
extent all such amounts are not forgiven through the purchase of Shares and
Excess Shares, the Company will pay the outstanding amount in cash with a
portion of the proceeds from the Rights Offering or other available funds. See
"Use of Proceeds."
STOCKHOLDER CREDIT FACILITY
On August 18, 1998, the Company entered into the Stockholder Credit
Facility, a $3.0 million revolving credit facility with the Affiliated Eligible
Stockholders. Borrowings under the Stockholder Credit Facility are due on
49
<PAGE> 53
August 17, 1999 and bear interest at LIBOR plus 3%. Pursuant to the Stockholder
Credit Facility, the Affiliated Eligible Stockholders have the right to convert
any borrowings made under such facility into shares of Common Stock at a
conversion price of $0.20 per share only if the Rights Offering is not
completed. As of August 25, 1998, $2.4 million was outstanding under the
Stockholder Credit Facility. Pursuant to the Stockholder Credit Facility, the
Company agreed to pay to the Affiliated Eligible Stockholders an aggregate
commitment fee equal to $60,000. The Company intends to repay $2.0 million of
principal under the Amended Credit Facility with borrowings under the
Stockholder Credit Facility. The remaining $0.4 million will be used for working
capital and general corporate purposes. The Affiliated Eligible Stockholders
will pay the Subscription Price for Shares and Excess Shares, if any, purchased
in the Rights Offering through the forgiveness of an equal amount owed to them
under the Stockholder Credit Facility and the Administrative Services Agreement.
Any amounts that remain outstanding after such application will be repaid with a
portion of the cash proceeds from the Rights Offering or other available funds.
See "Use of Proceeds."
DESCRIPTION OF SECURITIES
The following summary description of the Company's capital stock is
qualified in its entirety by reference to the Company's Certificate of
Incorporation and Bylaws, each of which is filed as an exhibit to the
Registration Statement.
COMMON STOCK
The Company is currently authorized to issue up to 50,000,000 shares
of Common Stock, par value $.01 per share, of which there were 22,076,315 shares
outstanding held by 256 stockholders of record as of August 1, 1998. The Company
intends to amend its Certificate of Incorporation to increase the number of
authorized shares of Common Stock. The closing of the Rights Offering on the
terms described herein is subject to the effectiveness of such amendment.
Holders of Common Stock are entitled to cast one vote for each share held of
record on each matter submitted to a vote of stockholders. There is no
cumulative voting for election of directors. Subject to the prior rights of any
series of preferred stock which may from time to time be outstanding, if any,
holders of Common Stock are entitled to receive ratably dividends when, as, and
if declared by the Board of Directors out of funds legally available therefor
and, upon the liquidation, dissolution or winding up of the Company, are
entitled to share ratably in all assets remaining after payment of liabilities
and payment of accrued dividends and liquidation preferences on the preferred
stock, if any. There are no redemption or sinking fund provisions that are
applicable to the Common Stock. Subject only to the requirements of the DGCL,
the Board of Directors may issue shares of Common Stock without stockholder
approval, at any time and from time to time, to such persons and for such
consideration as the Board of Directors deems appropriate. Holders of Common
Stock have no preemptive rights and have no rights to convert their Common Stock
into any other securities. The outstanding Common Stock is validly authorized
and issued, fully paid, and nonassessable.
PREFERRED STOCK
The Company is authorized to issue up to 1,000,000 shares of
Preferred Stock, par value $.01 per share, of which no shares are outstanding as
of the date hereof. Shares of Preferred Stock may be issued from time to time in
one or more series as the Board of Directors, by resolution or resolutions, may
from time to time determine, each of said series to be distinctively designated.
The voting powers, preferences and relative, participating, optional and other
special rights, and the qualifications, limitations or restrictions thereof, if
any, of each such series of Preferred Stock may differ from those of any and all
other series of Preferred Stock at any time outstanding, and, subject to certain
limitations of the Certificate of Incorporation and the DGCL, the Board of
Directors may fix or alter, by resolution or resolutions, the designation,
number, voting powers, preferences and relative, participating, optional and
other special rights, and qualifications, limitations and restrictions thereof,
of each such series of Preferred Stock.
The issuance of any such Preferred Stock could adversely affect the
rights of the holders of Common Stock and therefore, reduce the value of the
Common Stock. The ability of the Board of Directors to issue Preferred Stock
could discourage, delay, or prevent a takeover of the Company. See "Risk
Factors--Preferred Stock; Possible Anti-Takeover Effects."
50
<PAGE> 54
TRANSFER AGENT AND REGISTRAR
The Transfer Agent and Registrar for the Common Stock is American
Stock Transfer and Trust Company.
CERTAIN FEDERAL INCOME TAX CONSIDERATIONS
GENERAL
The following is a general discussion of certain anticipated federal
income tax consequences of the Rights Offering. This discussion is based on the
provisions of the Code, the Treasury Regulations promulgated thereunder, and
administrative and judicial interpretations thereof, all as in effect as of the
date hereof and all of which are subject to change (possibly on a retroactive
basis). This discussion does not purport to deal with all aspects of federal
income taxation that may be relevant to a particular holder of Rights in light
of such holder's personal investment circumstances (including the tax
consequences of the receipt of Rights by a holder of Common Stock in connection
with compensation) nor does this discussion address special tax implications
which may be applicable to certain types of holders of Rights subject to special
treatment under the Code (including, without limitation, financial institutions,
broker-dealers, regulated investment companies, life insurance companies,
tax-exempt organizations, foreign corporations and non-resident aliens).
Moreover, the discussion is limited to those who will hold the Rights and any
Common Stock acquired upon the exercise of Rights, as capital assets (generally,
property held for investment) within the meaning of Section 1221 of the Code. No
consideration of any aspects of state, local or foreign taxation is included
herein. The Company has not sought, nor does it intend to seek, any rulings from
the IRS relating to the tax issues addressed herein, and such issues may be
subject to substantial uncertainty resulting from the lack of definitive
judicial or administrative authority and interpretations applicable thereto.
EACH EXISTING HOLDER OF COMMON STOCK IS URGED TO CONSULT SUCH
PERSON'S OWN TAX ADVISOR AS TO THE SPECIFIC TAX CONSEQUENCES OF THE RIGHTS
OFFERING WITH RESPECT TO SUCH PERSON'S OWN PARTICULAR TAX SITUATION, INCLUDING
THE APPLICATION AND EFFECT OF THE CODE, AS WELL AS STATE, LOCAL AND FOREIGN
INCOME AND OTHER TAX LAWS.
TAX CONSEQUENCES TO HOLDERS AND RIGHTS
ISSUANCE OF RIGHTS TO EXISTING STOCKHOLDERS
Existing law is not clear as to whether the distribution of Rights
to holders of Common Stock ("Existing Stockholders") would be characterized as a
distribution under Section 305(a) of the Code ("Section 305(a) Distribution")
or, alternatively, as a distribution under Sections 301 and 305(b) of the Code
("Section 301 Distribution"). The Company intends to take the position that the
Rights distribution is properly characterized as a Section 305(a) Distribution.
Assuming that the Rights distribution is properly characterized as a Section
305(a) Distribution, the distribution would be nontaxable without regard to the
Company's earnings and profits. If the Rights distribution were treated as a
Section 301 Distribution, and provided that the Company does not have positive
net earnings during the taxable year in which the Rights Offering occurs, the
value of the Rights distributed would be treated as a nontaxable reduction in
the Existing Stockholder's basis in his Common Stock, and the balance (if any)
in excess of such adjusted basis would be taxed as a capital gain. In this
regard, based on current projections, the Company believes that it is highly
unlikely that it will have positive net earnings during the taxable year in
which the Rights Offering occurs.
BASIS OF RIGHTS
If, as expected, the Rights distribution is properly characterized
as a Section 305(a) Distribution, then, except as provided in the following
sentence, the tax basis of Rights received by an Existing Stockholder in the
Rights distribution would be zero. If, however, (i) the Rights distribution
constitutes a Section 305(a) Distribution and (ii) either the Rights have a
value (on the date of distribution of the Rights) equal to or greater than 15%
of the value of the shares of Common Stock with respect to which the Rights are
distributed or the Existing Stockholder elects to apply the rule described in
this sentence, then upon exercise (but not upon lapse) of the Rights, the
Existing
51
<PAGE> 55
Stockholder would reallocate his tax basis in his Common Stock between the
Rights and the Common Stock based on the relative fair market values of each. If
the Rights distribution were treated as a Section 301 Distribution, an Existing
Stockholder would have a tax basis in the Rights equal to (and, assuming that
the Company does not have positive net earnings during fiscal 1998, the Existing
Stockholder's basis in his Common Stock would be reduced by) an amount equal to
the fair market value of the Rights on the date of the Rights distribution.
HOLDING PERIOD OF RIGHTS
If, as expected, the Rights distribution is treated as a Section
305(a) Distribution, an Existing Stockholder will have a holding period in the
Rights that includes the holding period of the shares of Common Stock to which
the Rights distribution relates. If the Rights distribution were treated as a
Section 301 Distribution, the Existing Stockholder would have a holding period
in the Rights that begins on the date of distribution of the Rights.
EXERCISE OF RIGHTS
A holder of Rights will not be taxed upon exercise of the Rights.
The holder's tax basis in the shares of Common Stock received upon exercise will
equal (i) his basis in the Rights, plus (ii) the exercise price paid for the
Common Stock. The holder's holding period in the Common Stock will begin on the
date of exercise of the Rights.
LAPSE OF RIGHTS
A holder of Rights who allows Rights to lapse would have a capital
loss equal to his basis (determined as described in "--Basis of Rights," above),
if any, in the Rights that lapsed. If the Rights distribution is treated as a
Section 305(a) Distribution, an Existing Stockholder who allows a Right to lapse
will have no basis in the Right and, thus, would realize no capital loss.
DIVIDENDS ON COMMON STOCK
The amount of cash received by a holder as a dividend on shares of
Common Stock will be treated as ordinary dividend income (which, in the case of
holders that are qualifying corporations, would be eligible for the 70%
dividends received deduction), but only to the extent of the Company's current
year or accumulated earnings and profits that are allocable to such Common
Stock. Any remaining amount of such dividend will reduce the holder's tax basis
in its shares of Common stock until such basis is reduced to zero, and any
excess will be treated as capital gain income.
SALE OF COMMON STOCK
Upon a sale of shares of Common Stock, an Existing Stockholder will
generally recognize capital gain or loss in an amount equal to the difference
between the amount received in the sale and such holder's tax basis (determined
as described in "--Exercise of Rights," above) in the shares sold.
LEGAL MATTERS
The validity of the Shares will be passed upon for the Company by
Akin, Gump, Strauss, Hauer & Feld, L.L.P.
EXPERTS
INDEPENDENT ACCOUNTANTS
The audited Consolidated Financial Statements of the Company
included in this Prospectus and elsewhere in the Registration Statement have
been audited by Hogan & Slovacek, independent public accountants, as indicated
in their reports with respect thereto, and are included herein in reliance upon
the authority of said firm as experts in giving said reports.
52
<PAGE> 56
OIL AND GAS CONSULTANTS
The information with respect to the reserve reports prepared by
Netherland, Sewell & Associates, Inc. has been included herein in reliance upon
the authority of said firm as experts in petroleum engineering.
AVAILABLE INFORMATION
The Company has filed with the Securities and Exchange Commission
(the "Commission") a registration statement under the Securities Act on Form S-1
(herein, together with all amendments and exhibits, referred to as the
"Registration Statement") with respect to the shares of Common Stock being
offered in the Rights Offering. This Prospectus does not contain all of the
information set forth in the Registration Statement and the exhibits and
schedules thereto, certain parts of which have been omitted in accordance with
the rules and regulations of the Commission. For further information with
respect to the Company and the Common Stock, reference is made to the
Registration Statement and the exhibits and schedules thereto. Statements
contained in this Prospectus regarding the contents of any contract or other
document are not necessarily complete and in each instance reference is hereby
made to the copy of such contract or document filed as an exhibit to the
Registration Statement. Copies of the Registration Statement may be inspected at
the public reference facilities maintained by the Commission at 450 Fifth
Street, N.W., Washington, D.C. 20549, as well as the New York Regional Office
located at 7 World Trade Center, Suite 1300, New York, New York 10048, and the
Chicago Regional office located at Citicorp Center, 500 West Madison Street,
Suite 1400, Chicago, Illinois 60661-2511, or obtained upon payment of prescribed
rates from the Public Reference Section of the Commission at its principal
office. Such documents may also be obtained through the web site maintained by
the Commission at http:\\www.sec.gov.
The Company is subject to the periodic reporting and other
informational requirements of the Exchange Act. As long as the Company is
subject to such periodic reporting and information requirements, it will file
with the Commission all Commission reports, proxy statements and other
information required thereby, which may be inspected at the public reference
facilities maintained by the Commission at Room 1024, 450 Fifth Street, N.W.,
Washington, D.C. 20549 and at the Commission's regional offices located at
Citicorp Center, 500 West Madison Street, Suite 1400, Chicago, Illinois
60661-2511 and 7 World Trade Center, Suite 1300, New York, New York 10048.
Copies of such material may be obtained by mail from the Public Reference
Section of the Commission at 450 Fifth Street, N.W., Washington, D.C. 20549 at
prescribed rates.
The Company intends to furnish its stockholders annual reports
containing audited financial statements and an opinion thereon expressed by
independent certified public accountants and may furnish its stockholders
quarterly reports for the first three quarters of each fiscal year containing
unaudited summary financial information.
53
<PAGE> 57
GLOSSARY OF CERTAIN OIL AND GAS TERMS
The following are abbreviations and definitions of certain terms commonly
used in the oil and gas industry and this Prospectus. Unless otherwise indicated
in this Prospectus, natural gas volumes are stated at the legal pressure base of
the state or area in which the reserves are located and at 60(degree)
Fahrenheit. Boes are determined using a ratio of six Mcf of natural gas to one
Bbl of oil.
Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume, used herein
in reference to oil or other liquid hydrocarbons.
Bcf. One billion cubic feet.
Bcfe. One billion cubic feet of natural gas equivalent. In reference to
natural gas, natural gas equivalents are determined using the ratio of six Mcf
of natural gas to one Bbl of oil, condensate of natural gas liquids.
Boe. Barrels of oil equivalent.
Developed Acreage. The number of acres which are allocated or assignable
to producing wells or wells capable of production.
Development Well. A well drilled within the proved area of an oil or
natural gas reservoir to the depth of a stratigraphic horizon known to be
productive.
Exploratory Well. A well drilled to find and produce oil or natural gas in
an unproved area, to find a new reservoir in a field previously found to be
productive of oil or gas in another reservoir, or to extend a known reservoir.
Finding and Development Costs. Capital costs incurred in the acquisition,
exploration and development of proved oil and natural gas reserves divided by
proved reserve additions.
Gross. When used with respect to acres or wells, gross refers to the total
acres or wells in which the Company has a working interest.
MBbls. Thousands of barrels of oil.
MBoe. One thousand barrels of oil equivalent.
Mcf. One thousand cubic feet of natural gas.
Mcfe. One thousand cubic feet of natural gas equivalent.
MMBbls. Millions of barrels of oil.
MMBoe. One million barrels of oil equivalent.
MMcf. One million cubic feet of natural gas.
MMcfe. One million cubic feet of natural gas equivalent.
Net Revenue Interest. The interest of each owner of an economic interest
in production from a specified property. The revenue interest normally differs
from the percentage working interest because of nonworking interest in each
property.
Oil. Crude oil or condensate.
Operator. The individual or company responsible for the exploration,
development, and production of an oil or gas well or lease.
G-1
<PAGE> 58
Net. When used with respect to acres or wells, "net" refers to gross acres
of well multiplied, in each case, by the percentage working interest owned by
the Company.
Proved Reserves. The estimated quantities of crude oil, natural gas and
natural gas liquids which geological and engineering data demonstrate with
reasonable certainty to be recoverable in future years from known reservoirs
under existing economic and operating conditions.
Royalty. An interest in an oil and gas lease that gives the owners of the
interest the right to receive a portion of the production from the leased
acreage (or of the proceeds of the sale thereof), but generally does not require
the owner to pay any portion of the costs of drilling or operating the wells on
the leased acreage. Royalties may be either landowner's royalties, which are
reserved by the owner of the leased acreage at the time the lease is granted, or
overriding royalties, which are usually reserved by an owner of the leasehold in
connection with a transfer to a subsequent owner.
3-D Seismic. Seismic data that are acquired and processed to yield a
three-dimensional picture of the subsurface.
Working Interest. An interest in an oil and gas lease that gives the owner
of the interest the right to drill for and produce natural gas and oil on the
leased acreage and requires the owner to pay a share of the costs of drilling
and production operations.
G-2
<PAGE> 59
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
CONSOLIDATED FINANCIAL STATEMENTS FOR THE YEARS ENDED DECEMBER 31, 1997 AND 1996
<TABLE>
<S> <C>
Independent Auditors' Reports ............................................................F-2
Balance Sheets, December 31, 1997 and 1996................................................F-4
Statements of Operations, Periods July 11, 1997 to
December 31, 1997, January 1, 1997 to July 10, 1997, and the Years Ended
December 31, 1996 and 1995................................................................F-5
Statements of Shareholders' Equity, Periods July 11, 1997 to
December 31, 1997, January 1, 1997 to July 10, 1997, and the Years Ended
December 31, 1996 and 1995................................................................F-6
Statements of Cash Flows, Periods July 11, 1997 to
December 31, 1997, January 1, 1997 to July 10, 1997, and the Years Ended
December 31, 1996 and 1995................................................................F-7
Notes to Financial Statements.............................................................F-9
Consolidated Balance Sheets at June 30, 1998 (unaudited) and December 31, 1997.............F-29
Consolidated Statement of Operations for the Six Months Ended June 30, 1998
and 1997 (unaudited)......................................................................F-30
Consolidated Statement of Cash Flows for the Six Months Ended June 30, 1998
and 1997 (unaudited)......................................................................F-31
Notes to Consolidated Financial Statements................................................F-32
</TABLE>
All financial statement schedules are omitted, as the required information is
inapplicable or the information is presented in the financial statements or
related notes.
F-1
<PAGE> 60
INDEPENDENT AUDITORS' REPORT
PRE-EMERGENCE CONSOLIDATED FINANCIAL STATEMENTS
The Board of Directors and
Shareholders of Gulfport Energy Corporation:
We have audited the accompanying consolidated balance sheet of Gulfport
Energy Corporation (formerly WRT Energy Corporation a Texas corporation) (the
"Company") as of December 31, 1996, and the related consolidated statements of
operations, shareholders' equity, and cash flows for the year then ended, and
the consolidated statements of operations, shareholders' equity, and cash flows
the period from January 1, 1997 to July 10, 1997. These consolidated financial
statements are the responsibility of the Company's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above
present fairly, in all material respects, the financial position of the Company
as of December 31, 1996, and the results of its operations, and cash flows for
the year then ended and the period from January 1, 1997 to July 10, 1997, in
conformity with generally accepted accounting principles.
As discussed in Note 1 to the consolidated financial statements, on May 2,
1997 the Company's plan of reorganization (the "Plan") was confirmed by the
bankruptcy court. The Plan was substantially consummated on July 11, 1997 and
the Company emerged from bankruptcy. In connection with its emergence from
bankruptcy, the Company adopted fresh start reporting.
The accompanying financial statements have been prepared assuming that the
Company will continue as a going concern which contemplates among other things,
the realization of assets and liquidation of liabilities in the ordinary course
of business. As discussed in Note 2 to the financial statements, the Company's
independent reserve report which estimates proven reserves , prepared as of
January 1, 1998, indicates that substantial future capital expenditures are
necessary to fully develop its total proven reserves of which only 3.7% are
currently producing. Revenues from these producing properties will not be
sufficient to finance the estimated future capital expenditures necessary to
fully develop the existing proved reserves, nor recover the carrying value of
the Company's oil and natural gas properties. This raises substantial doubt
about the Company's ability to continue as a going concern. Management's plans
regarding the financing of anticipated future development costs are also
discussed in Note 2. The financial statements do not include any adjustments
relating to the recoverability and classification of reported asset amounts or
the amounts and classification of liabilities that might be necessary should the
Company be unable to continue in existence.
HOGAN & SLOVACEK
Oklahoma City, OK
March 27, 1998
F-2
<PAGE> 61
INDEPENDENT AUDITORS' REPORT
POST-EMERGENCE FINANCIAL STATEMENTS
The Board of Directors and
Shareholders of Gulfport Energy Corporation:
We have audited the accompanying balance sheet of Gulfport Energy
Corporation (a Delaware corporation) (formerly WRT Energy Corporation) (the
"Company") as of December 31, 1997, and the related statements of operations,
shareholders' equity, and cash flows for the period from July 11, 1997 to
December 31, 1997. These financial statements are the responsibility of the
Company's management. Our responsibility is to express an opinion on these
financial statements based on our audit.
We conducted our audit in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audit provides a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly,
in all material respects, the financial position of Gulfport Energy Corporation
as of December 31, 1997, and the results of its operations and its cash flows
for the period from July 11, 1997 to December 31, 1997, in conformity with
generally accepted accounting principles.
As discussed in Note 1 to the financial statements, on May 2, 1997, the
Company's plan of reorganization (the "Plan") was confirmed by the bankruptcy
court. The Plan was substantially consummated on July 11, 1997 and the Company
emerged from bankruptcy. In connection with its emergence from bankruptcy, the
Company adopted fresh start reporting. As a result of the adoption of fresh
start reporting, the post-emergence financial statements are not comparable to
the pre-emergence consolidated financial statements.
The accompanying financial statements have been prepared assuming that the
Company will continue as a going concern which contemplates among other things,
the realization of assets and liquidation of liabilities in the ordinary course
of business. As discussed in Note 2 to the financial statements, the Company's
independent reserve report which estimates proven reserves , prepared as of
January 1, 1998, indicates that substantial future capital expenditures are
necessary to fully develop its total proven reserves of which only 3.7% are
currently producing. Revenues from these producing properties will not be
sufficient to finance the estimated future capital expenditures necessary to
fully develop the existing proved reserves, nor recover the carrying value of
the Company's oil and natural gas properties. This raises substantial doubt
about the Company's ability to continue as a going concern. Management's plans
regarding the financing of anticipated future development costs are also
discussed in Note 2. The financial statements do not include any adjustments
relating to the recoverability and classification of reported asset amounts or
the amounts and classification of liabilities that might be necessary should the
Company be unable to continue in existence.
As discussed in Note 1 to the financial statements, on July 11, 1997, the
Company changed its method of accounting for oil and natural gas properties.
HOGAN & SLOVACEK
Oklahoma City, OK
March 27, 1998
F-3
<PAGE> 62
GULFPORT ENERGY CORPORATION
BALANCE SHEETS
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------------
1997 1996
(REORGANIZED (PREDECESSOR
COMPANY)(1) COMPANY)(1)
------------ ------------
<S> <C> <C>
ASSETS
Current assets:
Cash and cash equivalents $ 1,203,000 $ 5,679,000
Cash, restricted 2,060,000 --
Accounts receivable, net of allowance for doubtful
accounts of $4,966,000 for 1997 and 1996 4,364,000 3,667,000
Prepaid expenses and other 192,000 349,000
------------ ------------
Total current assets 7,819,000 9,695,000
------------ ------------
Property and equipment:
Oil and natural gas properties (2) 84,466,000 77,541,000
Other property and equipment 1,577,000 5,118,000
Accumulated depletion, depreciation and amortization (4,542,000) (25,760,000)
------------ ------------
Property and equipment, net 81,501,000 56,899,000
------------ ------------
Other assets 3,026,000 1,482,000
------------ ------------
TOTAL ASSETS $ 92,346,000 $ 68,076,000
============ ============
LIABILITIES AND SHAREHOLDERS' EQUITY (DEFICIT)
Current liabilities:
Accounts payable and accrued liabilities $ 6,346,000 $ 5,529,000
Current maturities of long-term debt 2,192,000 --
------------ ------------
Total current liabilities 8,538,000 5,529,000
------------ ------------
Prepetition current liabilities:
Subject to compromise -- 136,346,000
Not subject to compromise -- 16,752,000
Total pre-petition current liabilities -- 153,098,000
Long-term debt 13,528,000 --
Total liabilities 22,066,000 158,627,000
Commitments and contingencies -- --
Shareholders' equity (deficit):
Preferred stock - $.01 par value, 2,000,000 authorized,
1,265,000 issued and outstanding at December 31, 1996 -- 27,677,000
Common stock - $.01 par value, 50,000,000 authorized, 22,076,315 and
9,539,207 issued and outstanding at December 31, 1997 and 1996,
respectively 221,000 95,000
Paid-in capital 71,772,000 39,571,000
Accumulated deficit (1,713,000) (157,562,000)
Treasury stock at cost (35,100 shares at December 31, 1996) -- (332,000)
------------ ------------
Total shareholders' equity (deficit) 70,280,000 (90,551,000)
------------ ------------
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY (DEFICIT) $ 92,346,000 $ 68,076,000
============ ============
</TABLE>
See accompanying notes to financial statements.
- ----------
(1) As used herein, "Predecessor Company" means the operations of the Company
prior to July 11, effective date of the order regarding substantial
consummation of the Amended Plan of Reorganization, and "Reorganized
Company" means the operations of the Company subsequent to that date. (See
Note 1)
(2) Effective July 11, 1997, the Company adopted the full cost method of
accounting for oil and natural gas properties
F-4
<PAGE> 63
GULFPORT ENERGY CORPORATION
STATEMENTS OF OPERATIONS
<TABLE>
<CAPTION>
REORGANIZED PREDECESSOR COMPANY
COMPANY ---------------------------------------------
JULY 11, JANUARY 1,
THROUGH THROUGH YEAR ENDED DECEMBER 31,
DECEMBER 1 JULY 10, -----------------------------
1997 1997 1996 1995(Note 1)
----------- ----------- ------------ ------------
<S> <C> <C> <C> <C>
REVENUES:
Gas Sales $ 3,344,000 $ 4,706,000 $ 10,382,000 $ 11,747,000
Oil and condensate sales 6,412,000 5,432,000 13,637,000 12,908,000
Other income, net 736,000 126,000 356,000 426,000
----------- ----------- ------------ ------------
10,492,000 10,264,000 24,375,000 25,081,000
COSTS AND EXPENSES:
Operating expenses including
production taxes 5,397,000 5,514,000 15,095,000 11,673,000
Depletion, depreciation and amortization 4,542,000 3,314,000 7,973,000 12,645,000
General and administrative 1,539,000 2,103,000 3,210,000 4,882,000
Interest 727,000 1,106,000 5,562,000 13,759,000
Provision for doubtful accounts -- 71,000 5,158,000 2,007,000
Restructuring charges -- -- -- 1,433,000
Minimum production guarantee obligation -- -- 5,555,000 3,591,000
Impairment of long-lived assets -- -- 3,864,000 103,266,000
----------- ----------- ------------ ------------
12,205,000 12,108,000 46,417,000 153,256,000
LOSS BEFORE REORGANIZATION
EXPENSES AND INCOME TAXES (1,713,000) (1,844,000) (22,042,000) (128,175,000)
Reorganization expenses -- 7,771,000 7,345,000 --
LOSS BEFORE INCOME TAXES (1,713,000) (9,615,000) (29,387,000) (128,175,000)
Income tax expense -- -- -- --
LOSS FROM OPERATIONS BEFORE
EXTRAORDINARY ITEM - (1,713,000) (9,615,000) (29,387,000) (128,175,000)
LOSS FROM EXTRAORDINARY ITEM -
GAIN ON DISCHARGE OF DEBT -- 88,723,000 -- --
NET INCOME (LOSS) (1,713,000) 79,108,000 (29,387,000) (128,175,000)
Preferred stock dividends, net -- (1,510,000) (2,846,000) (2,846,000)
----------- ----------- ------------ ------------
NET INCOME (LOSS) APPLICABLE TO
COMMON STOCK $(1,713,000) $77,598,000 $(32,233,000) $131,021,000)
=========== =========== ============ ============
PER SHARE OF COMMON STOCK
AMOUNTS:
Loss from continuing operations $ (0.08) N/A N/A N/A
Income from extraordinary item $ -- N/A N/A N/A
----------- ----------- ------------ ------------
NET INCOME (LOSS) $ (0.08) N/A N/A N/A
----------- ----------- ------------ ------------
AVERAGE COMMON AND COMMON
EQUIVALENT SHARES
OUTSTANDING 22,076,000 N/A N/A N/A
=========== =========== ============ ============
</TABLE>
See accompanying notes to financial statements.
F-5
<PAGE> 64
GULFPORT ENERGY CORPORATION
STATEMENTS OF SHAREHOLDERS' EQUITY
<TABLE>
<CAPTION>
Common
Stock
Preferred ------------------------------
Stock Shares Amount
------------- ------------- -------------
<S> <C> <C> <C>
Balance,
December 31, 1995 $ 27,677,000 $ 9,539,207 $ 95,000
Reversal of preferred
stock dividends
previously accrued -- -- --
Net loss before
dividends on
preferred stock -- -- --
Other -- -- --
------------- ------------- -------------
Balance,
December 31, 1996 27,677,000 9,539,207 95,000
Net income -- -- --
Effect of fresh
start reporting (27,677,000) 12,537,108 126,000
------------- ------------- -------------
Balance,
July 11, 1997 -- 22,076,315 221,000
Net loss -- -- --
------------- ------------- -------------
Balance,
December 31, 1997 $ -- $ 22,076,315 $ 221,000
============= ============= =============
<CAPTION>
Additional
Paid-In Accumulated Treasury
Capital Deficit Stock
------------- ------------- -------------
<S> <C> <C> <C>
Balance,
December 31, 1995 $ 38,866,000 $(128,175,000) $ (332,000)
Reversal of preferred
stock dividends
previously accrued 712,000 -- --
Net loss before
dividends on
preferred stock -- (29,387,000) --
Other (7,000) -- --
------------- ------------- -------------
Balance,
December 31, 1996 39,571,000 (157,562,000) (332,000)
Net income -- 79,108,000 --
Effect of fresh
start reporting 32,201,000 78,454,000 332,000
------------- ------------- -------------
Balance,
July 11, 1997 71,772,000 -- --
Net loss -- (1,713,000) --
------------- ------------- -------------
Balance,
December 31, 1997 $ 71,772,000 $ (1,713,000) $ --
============= ============= =============
</TABLE>
See accompanying notes to financial statements.
F-6
<PAGE> 65
GULFPORT ENERGY CORPORATION
STATEMENTS OF CASH FLOWS
<TABLE>
<CAPTION>
REORGANIZED PREDECESSOR COMPANY
COMPANY --------------------------------------------
JULY 11, JANUARY 1,
THROUGH THROUGH YEAR ENDED DECEMBER 31,
DECEMBER 31 JULY 10, ---------------------------
1997 1997 1996 1995(NOTE 1)
----------- ----------- ----------- -----------
<S> <C> <C> <C> <C>
Cash flows from operating activities: $(1,713,000) $79,476,000 $(29,387,000) $(128,175,000)
Net income (loss)
Adjustments to reconcile net income (loss) to net
cash provided by operating activities:
Extraordinary item - gain on debt discharge -- (88,723,000) -- --
Depletion, depreciation and amortization 4,633,000 3,314,000 8,882,000 13,674,000
Provision for doubtful accounts
and notes receivable -- 71,000 5,158,000 2,007,000
Gain on sale of equipment (587,000) -- -- --
Write-off of debt issuance costs
and Senior Notes discount -- -- 5,263,000 --
Impairment of long-lived assets -- -- 3,864,000 103,266,000
Write-off of leasehold improvements -- -- -- 946,000
Gain on sale of oil and gas properties -- -- (5,000) (3,000)
Write-off of accounts receivable
included in production costs -- -- (1,172,000) --
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable (1,077,000) 307,000 (515,000) (2,249,000)
(Increase) decrease in prepaid expenses (117,000) (331,000) 132,000 (349,000)
Increase (decrease) in accounts
payable and accrued liabilities 556,000 301,000 11,365,000 13,551,000
Increase in minimum production
guarantee obligation -- -- 5,555,000 3,591,000
----------- ----------- ----------- -----------
Net cash provided by (used in)
operating activities 1,695,000 (5,585,000) 9,140,000 6,259,000
----------- ----------- ----------- -----------
Cash flows from investing activities:
Decrease in notes and other receivables -- -- -- 69,000
Additions to cash held in escrow (133,000) (22,000) (121,000) (220,000)
Capital expenditures (5,644,000) (2,562,000) (4,823,000) (116,730,000)
Proceeds from sale of oil and gas properties 35,000 -- 5,000 390,000
Proceeds from sale of equipment 2,081,000 -- -- --
Decrease in other assets 138,000 -- -- --
----------- ----------- ----------- -----------
Net cash used in investing activities (3,523,000) (2,584,000) (4,939,000) (116,491,000)
----------- ----------- ----------- -----------
Cash flows from financing activities:
Proceeds from borrowings -- 15,000,000 -- 126,141,000
Payment of pre-petition liabilities
and administrative claims -- (8,105,000) --
Proceeds from issuance of warrants -- 13,300,000 -- 1,600,000
Debt issuance costs -- -- -- (5,722,000)
Principle payments on borrowing (20,000) (15,014,000) (130,000) (19,603,000)
Payment of loan origination fees (200,000) -- -- --
Purchase of treasury stock -- -- -- (17,000)
Proceeds from option and warrant exercises -- -- -- 2,508,000
Common stock filing fees -- -- -- (120,000)
Dividends on preferred stock -- -- -- (2,135,000)
----------- ----------- ----------- -----------
Net cash provided by (used in)
financing activities (218,003) 5,182,997 (128,004) 102,652,000
----------- ----------- ----------- -----------
Net increase (decrease) in cash and
cash equivalents (2,046,003) (2,986,003) 4,072,996 (7,580,000)
Cash and cash equivalents-
beginning of period 5,311,000 5,680,996 1,608,000 9,188,000
----------- ----------- ----------- -----------
Cash and cash equivalents-
end of period $ 3,264,997 $ 2,694,993 $ 5,680,996 $ 1,608,000
=========== =========== =========== ===========
</TABLE>
F-7
<PAGE> 66
GULFPORT ENERGY CORPORATION
STATEMENTS OF CASH FLOWS
(CONTINUED)
<TABLE>
<CAPTION>
REORGANIZED PREDECESSOR COMPANY
COMPANY --------------------------------------------
JULY 11, JANUARY 1,
THROUGH THROUGH YEAR ENDED DECEMBER 31,
DECEMBER 31 JULY 10, ---------------------------
1997 1997 1996 1995(NOTE 1)
----------- ----------- ----------- -----------
<S> <C> <C> <C> <C>
SUPPLEMENTAL DISCLOSURES OF CASH
FLOW INFORMATION:
Interest paid $ 505,000 $ 28,000 $ -- $ 8,232,000
Income taxes paid -- -- -- 36,000
SUPPLEMENTAL INFORMATION OF NON-CASH
INVESTING AND FINANCING ACTIVITIES:
Common stock issued to purchase oil
and gas properties -- -- -- 1,617,000
Note receivable from sale of property
and equipment -- -- -- 3,400,000
Reduction in drilling and workover rigs
and marine equipment notes receivable
and related deferred gain -- -- -- 1,763,000
Accrued dividends on preferred stock -- (1,510,000) (712,000) 712,000
</TABLE>
See accompanying notes to financial statements.
F-8
<PAGE> 67
GULFPORT ENERGY CORPORATION
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 1997, 1996 AND 1995
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Business and Reorganization Proceedings
Gulfport Energy Corporation (the "Company"), formerly known as WRT Energy
Corporation, is a domestic independent energy company engaged in the production
of oil and natural gas. On July 11, 1997, the Company's subsidiaries were merged
into the Company. On the effective date of the reorganization, the state of
incorporation of the reorganized Company was changed from the State of Texas to
the State of Delaware. Prior to July 11, 1997, the financial statements
represented the consolidated financial statements of the Company and its
subsidiaries.
As discussed in Note 3, on February 14, 1996, (the "Petition Date"), the
Company filed a voluntary petition with the Bankruptcy court for the Western
District of Louisiana (the "Bankruptcy Court") for protection under Chapter 11
of the Bankruptcy Code. On May 5, 1997, the Bankruptcy Court confirmed an
Amended Plan of Reorganization (the "Plan") for the Company and on the effective
date an order of substantial consummation regarding the Plan became final and
nonappealable. On the Effective Date, the Debtor was merged with and into a
newly formed Delaware corporation named "WRT Energy Corporation" which on
February 13, 1998, by action of its board of directors underwent a name change
to "Gulfport Energy Corporation". Effective July 11, 1997 (the "Election Date"),
the Company implemented fresh start reporting, as defined by the Accounting
Standards Division of the American Institute of Certified Public Accountants
Statement of Position Number 90-7, "Financial Reporting by Entities in
Reorganization Under the Bankruptcy Code" ("SOP 90-7").
Principles of Consolidation
Until December 31, 1995, the Company owned 100% of the stock of two
subsidiaries, Tesla Resources, Inc. ("Tesla") and Southern Petroleum, Inc.
("Southern Petroleum"). On that date, both Tesla and Southern Petroleum were
merged into the Company with the Company emerging as the sole surviving
corporation. In November 1995, the Company formed a wholly owned subsidiary, WRT
Technologies, Inc., which was established to own and operate the Company's
proprietary, radioactive, cased-hole logging technology. Prior to July 11, 1997,
the financial statements were consolidated and include the accounts of the
Company and its wholly owned subsidiary, WRT Technologies, Inc., which was
merged into the Company on that date. All significant intercompany transactions
were eliminated during the consolidation periods.
Cash and Cash Equivalents
The Company considers all highly liquid investments with an original
maturity of three months or less to be cash equivalents for purposes of the
statement of cash flows.
Fair Value of Financial Instruments
At December 31, 1997, the carrying amounts of all financial instruments
approximate their fair market values.
Oil and Natural Gas Properties
Before July 11, 1997, the Company used the successful efforts method for
reporting oil and gas operations. Commencing with the reorganization, the
Company converted to the full cost pool method of accounting to be in conformity
with the method used by its principal shareholder, DLB Oil & Gas, Inc. ("DLB").
F-9
<PAGE> 68
COMMENCING JULY 11, 1997
In connection with the implementation of fresh start reporting, as
described in Note 3, the Company implemented the full cost pool method of
accounting for oil and gas operations. Accordingly, all costs including
nonproductive costs and certain general and administrative costs associated with
acquisition, exploration and development of oil and natural gas properties are
capitalized. Net capitalized costs are limited to the estimated future net
revenues, after income taxes, discounted at 10% per year, from proved oil and
natural gas reserves and the cost of the properties not subject to amortization.
Such capitalized costs, including the estimated future development costs and
site remediation costs, if any, are depleted by an equivalent
units-of-production method, converting natural gas to barrels at the ratio of
six Mcf of natural gas to one barrel of oil. No gain or loss is recognized upon
the disposal of oil and gas properties, unless such dispositions significantly
alter the relationship between capitalized costs and proved oil and natural gas
reserves.
Oil and natural gas properties not subject to amortization consist of the
cost of undeveloped leaseholds. These costs are reviewed periodically by
management for impairment, with the impairment provision included in the cost of
oil and natural gas properties subject to amortization. Factors considered by
management in its impairment assessment include drilling results by the Company
and other operators, the terms of oil and gas leases not held by production, and
available funds for exploration and development.
PRIOR TO JULY 11, 1997
Prior to July 11, 1997, the Company followed the successful efforts method
of accounting for its oil and gas operations. Under the successful efforts
method, costs of productive wells, development dry holes and productive leases
are capitalized and amortized on a unit-of-production basis over the life of the
remaining proved reserves as estimated by the Company's independent engineers.
The Company's estimate of future dismantlement and abandonment costs was
considered in computing the aforementioned amortization.
Cost centers for amortization purposes were determined based on a
reasonable aggregation of properties with common geological structures or
stratigraphic conditions, such as a reservoir or field. The Company performed a
review for impairment of proved oil and gas properties on a depletable unit
basis when circumstances suggest the need for such a review. For each depletable
unit determined to be impaired, an impairment loss equal to the difference
between the carrying value and the fair value of the depletable unit was
recognized. Fair value, on a depletable unit basis, was estimated to be the
present value of expected future net cash flows computed by applying estimated
future oil and gas prices, as determined by management, to estimated future
production of oil and gas reserves over the economic lives of the reserves.
Exploration expenses, including geological, geophysical and costs of
carrying and retaining undeveloped properties were charged to expense as
incurred.
Unproved properties were assessed periodically and a loss was recognized
to the extent, if any, that the cost of the property had been impaired. If
proved reserves were not discovered within one year after drilling was
completed, costs were charged to expense.
Other Property and Equipment
Depreciation of other property and equipment is provided on a
straight-line basis over estimated useful lives of the related assets, which
range from 7 to 30 years.
Implementation of Statement of Accounting Standards No. 121
Effective December 31, 1995, the Company adopted the provisions of
Financial Accounting Standards No 121 ("SFAS No. 121") which requires that an
impairment loss be recognized whenever the carrying amount of a long-lived asset
exceeds the sum of the estimated future cash flows (undiscounted) of the assets.
As discussed above, impairment losses on oil and gas properties were determined
on a discounted future cash flow basis. For each long-term asset determined to
be impaired, an impairment loss equal to the difference between the carrying
value and the fair value of the asset was recognized.
F-10
<PAGE> 69
During 1995, the Company recorded a non-cash charge of $103,266,000 in
connection with the adoption of this new accounting standard of which
approximately $95,000,000 related to the impairment of oil and gas properties,
the result of significant downward revisions in the Company's proved oil and gas
reserves. At December 31, 1996, the Company incurred an additional non-cash
charge of $2,545,000 related to the further impairment of its oil and gas
properties as well as the impairment of some of its field equipment. Principal
fields suffering further impairment in value in 1996 were the Abbeville Field,
the Lac Blanc Field, and the West Hackberry Field as a result of additional
downward revisions in the proved oil and gas reserves at December 31, 1996.
The Company also recorded non-cash charges related to certain rig, marine
and field equipment owned or securing notes receivable. The Company expected
this equipment would provide drilling field services in the Company's oil and
gas development program. Due to liquidity problems and the reduced level of
development activity, the Company did not expect to utilize these assets in the
near term and, accordingly, recovery of the related carrying cost was deemed
unlikely. As a result of the adoption of SFAS No. 121, the Company recorded an
impairment of $7,900,000 related to this equipment in 1995. During 1996, the
Company incurred an additional non-cash charge of $1,319,000 related to the
further impairment of its office and field equipment. Of this balance, $815,000
relates primarily to a write down of the Company's office equipment and computer
software to its appraised fair market value, and the balance of $504,000 relates
to a write down of the wireline equipment to its appraised fair value.
Earnings (Loss) per Share
Earnings (loss) per share computations are calculated on the
weighted-average of common shares and common share equivalents outstanding
during the year. Common stock options and warrants are considered to be common
share equivalents and are used to calculate earnings per common and common share
equivalents except when they are anti-dilutive.
Income Taxes
The Company uses the asset and liability method of accounting for income
taxes. Under the asset and liability method, deferred tax assets and liabilities
are recognized for the future tax consequences attributable to differences
between the financial statement carrying amounts and the tax basis of existing
assets and liabilities and operating loss and tax credit carryforwards. Deferred
income tax assets and liabilities are based on enacted tax rates applicable to
the future period when those temporary differences are expected to be recovered
or settled. The effect of a change in tax rates on deferred tax assets and
liabilities is recognized in income during the period the rate change is
enacted. Deferred tax assets are recognized in income in the year in which
realization becomes determinable.
Revenue Recognition
Natural gas revenues are recorded in the month produced using the
entitlement method, whereby any production volumes received in excess of the
Company's ownership percentage in the property are recorded as a liability. If
less than the Company's entitlement is received, the underproduction is recorded
as a receivable. Oil revenues are recognized in the month produced.
Concentration of Credit Risk
The Company operates in the oil and natural gas industry principally in
the state of Louisiana with sales to refineries, re-sellers such as pipeline
companies, and local distribution companies. While certain of these customers
are affected by periodic downturns in the economy in general or in their
specific segment of the natural gas industry, the Company believes that its
level of credit-related losses due to such economic fluctuations has been
immaterial and will continue to be immaterial to the Company's results of
operations in the long term. Unrelated to economic fluctuations, during 1996,
the Company incurred a bad debt in the amount of $4,278,000 related to marketing
of its oil and gas by Tri-Deck Oil & Gas Company ("Tri-Deck"). See Notes 5 and
15 for further discussion.
F-11
<PAGE> 70
During the year ended December 31, 1997, approximately 99%, of the
Company's revenues from oil and natural gas sales were attributable to sales to
five primary customers: Prior Energy, Wickford Energy Marketing, Gathering and
Energy Marketing Corp., Texaco Trading and Transportation and Mobil Oil
Corporation. During the years ended December 31, 1996 and 1995, approximately
89% and 79%, respectively, of the Company's revenues from oil and gas sales were
attributable to sales to five primary customers: Tri-Deck, Plains Marketing and
Transportation, Inc., Texas-Ohio Gas, Inc., Riverside Pipeline Company and Prior
Energy.
The Company maintains cash balances at several banks. Accounts at each
bank are insured by the Federal Deposit Insurance Corporation up to $100,000.
Cash balances in excess of insured limits total $3,163,000 at December 31, 1997.
Use of Estimates
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates, judgements
and assumptions that affect the reported amounts of assets and liabilities as of
the date of the financial statements and revenues and expenses during the
reporting period. The financial statements are highly dependent on oil and gas
reserve estimates, which are inherently imprecise. Actual results could differ
materially from those estimates.
Stock Options and Warrant Agreements
Effective at the date of reorganization, all previously issued stock
option plans of the Company were terminated and all outstanding options were
cancelled. At that date a Warrant Agreement went into effect. These warrants are
exercisable at $10 per share and will expire on July 11, 2002. The Plan
authorized the issuance of up to 1,104,000 warrants. As of December 31, 1997,
there were 221,000 warrants issued and outstanding.
Commitments and Contingencies
Liabilities for loss contingencies arising from claims, assessments,
litigation or other sources are recorded when it is probable that a liability
has been incurred and the amount can be reasonably estimated.
1995 Information not covered by Auditors Reports
On December 10, 1997, the Company received notice from its former
Certified Public Accountants that they had terminated their client-auditor
relationship. The former independent certified public accountants annual report
covering the fiscal years ended December 31, 1996 and 1995, did not include any
adverse opinion or disclaimer of opinion, and was not qualified or modified as
to uncertainty, audit scope or accounting principles. The opinion, however, did
include an explanatory paragraph expressing, among other things, substantial
doubts about the Company's ability to continue as a going concern.
The former independent certified public accountants have, however, not
given consent to the use of their report on the consolidated financial
statements for the year 1995. Therefore, all reference to 1995 financial
information should be treated as unaudited information.
Reclassifications
Certain Amounts from prior years have been reclassified to conform to the
current year presentation.
2. GOING CONCERN CONSIDERATIONS
The accompanying financial statements of the Company have been prepared on
a going concern basis, which contemplates the realization of assets and the
liquidation of liabilities in the ordinary course of business.
As of January 1, 1998, based on the Company's independent reserve report,
the Company had 27,746,000 barrel of oil equivalents ("Boe") in total proved
reserves of which proved developed producing reserves were only 1,033,000 Boe.
The Company's independent reserve report prepared as of that date anticipated
future capital
F-12
<PAGE> 71
expenditures of $166,812,000 to fully develop its total proved reserves. As of
December 31, 1997, based on the independent reserve report, the Company's proved
developed producing reserves will not generate sufficient revenues to recover
the carrying value of the Company's producing oil and gas properties. The future
development of the Company's undeveloped proved reserves is dependent upon its
ability to finance the development of these properties.
Possible sources of financing for the development of these properties
include cash flows generated from future operations, sale of additional common
stock to current shareholders through a stock rights offering or to the public
through a public offering, borrowings and through farm out type arrangements
where third party investors pay the development costs in exchange for a working
interest in the developed properties.
The inability to obtain adequate financing of these projected future
development costs would severely impair the value of the Company's oil and gas
properties, its cash flows, and ultimately its continued existence. The
uncertainty about the Company's ability to finance future development costs
raises substantial doubt about the Company's ability to continue as a going
concern. The financial statements do not include any adjustments relating to the
impairment related to the recoverability and classification of recorded assets,
or the amounts and classification of liabilities that might be necessary in the
event the Company cannot continue as a going concern. Management is currently
attempting to negotiate certain farm out agreements in which third party
investors would pay certain development costs. It is not possible, however, to
predict at this time the success of these negotiations.
3. REORGANIZATION PROCEEDING
On February 14, 1996, the Company filed a voluntary petition in the United
States Bankruptcy Court for the Western District of Louisiana (the "Bankruptcy
Court") for reorganization pursuant to Chapter 11 of the Federal Bankruptcy Code
(the "Reorganization Proceeding"). During the balance of 1996 and a portion of
1997, the Company operated as a debtor-in-possession, continuing in possession
of its estate and the operation of its business and management of its property.
On May 5, 1997, the Bankruptcy Court confirmed an Amended Plan of Reorganization
(the "Plan") for the Company. On July 11, 1997, the Bankruptcy Court determined
that the Plan had been substantially consummated, and the Bankruptcy Court's
order of substantial consummation became final and nonappealable on July 11,
1997 (the "Effective Date").
As a result of the consummation of the Plan and due to (1) the
reallocation of the voting rights of equity interest owners and (2) the
reorganization value of the Company's assets being less than the total of all
post-petition liabilities and allowed claims, the effects of the Reorganization
Proceeding were accounted for in accordance with fresh start reporting standards
promulgated under SOP 90-7.
In conjunction with implementing fresh start reporting, management
determined a reorganized value of the Company's assets and liabilities in the
following manner:
The reorganized value of proved oil and natural gas properties was
determined based on future net revenues discounted to present value utilizing a
rate of approximately twenty five percent (25%). For the purpose of calculating
future revenues of oil and natural gas properties, oil and gas prices in effect
at December 31, 1996, were used. The reorganized value of oil and gas properties
also included $5,000,000 allocated to nonproducing properties.
DLB Oil & Gas, Inc. ("DLB") contributed certain interests previously owned
by Texaco Exploration and Production. Inc. ("TEPI") in the West Cote Blanche Bay
Field ("WCBB Assets") along with a $1,000,000 deposit to a plugging and
abandonment trust for 5,616,300 shares of the reorganized Company's common
stock. This transaction was recorded at DLB's net basis in the WCBB Assets of
$15,144,000. In connection with this acquisition, the Reorganized Company
assumed the obligation to contribute approximately $18,000 per month through
March 2004 to this plugging and abandonment trust and the obligation to plug a
minimum of 20 wells per year for 20 years commencing March 11, 1997. TEPI
retained a security interest in production from these properties and the
plugging and abandonment trust until such time the Company's obligations for
plugging and abandonment to TEPI have been fulfilled. Once the plugging and
abandonment trust is fully funded, the Company can access it for use in plugging
and abandonment charges associated with the property.
F-13
<PAGE> 72
In accordance with the Plan, $3,000,000 was set aside by the Company to
form a Litigation Entity. The Company owns a 12% interest in this Litigation
Entity. The entire $3,000,000 was included in reorganization expense on the
financial statements for the six months and eleven day period ended July 10,
1997. No value was assigned to the Company's interest in the Litigation Entity
on the reorganized balance sheet as management was not able to determine with
any certainty the amount, if any, that the Company might recover from this
investment.
Current assets and liabilities were recorded at book value which
approximates their fair market value. Long-term liabilities were recorded at
present values of amounts to be paid and the pre-consummation stockholders'
deficit was adjusted to reflect the par value of pre-consummation equity
interests and the recognition of $88,723,000 in debt forgiveness income. On the
effective date, the shareholders' deficit was closed into paid in capital and
the Company started with no deficit or retained earnings.
It should be noted that the reorganized value was determined by management
on the basis of its best judgement of what it considers to be current fair
market value of the Company's assets and liabilities after reviewing relevant
facts concerning the price at which similar assets are being sold between
willing buyers and sellers. However, there can be no assurances that the
reorganized value and the fair market value are comparable and the difference
between the Company's calculated reorganized value and the fair market value
may, in fact, be material.
F-14
<PAGE> 73
As of July 11, 1997, the effect on the Company's balance sheet of
consummating the Plan and implementing the fresh start reporting was:
<TABLE>
<CAPTION>
JULY 11, 1997 SUBSTANTIAL FRESH START REORGANIZED
PRIOR TO CONSUMMATION REPORTING BALANCE
CONSUMMATION ADJUSTMENTS ADJUSTMENTS SHEET
------------- -------------- ------------- -------------
<S> <C> <C> <C> <C>
ASSETS
Current assets:
Cash and cash equivalents.......................... $ 3,714,000 $ 1,598,000 $ $ 5,312,000
Accounts receivable, net........................... 3,287,000 3,287,000
Prepaid expenses and other......................... 870,000 870,000
------------- -------------- ------------- -------------
Total current assets......................... 7,871,000 1,598,000 9,469,000
------------- -------------- ------------- -------------
Property and equipment:
Properties subject to depletion.................... 80,120,000 15,144,000 (20,187,000) 75,077,000
Properties not subject to depletion................ -- 5,000,000 5,000,000
Other property, plant, and equipment............... 5,300,000 (2,362,000) 2,938,000
------------- -------------- ------------- -------------
85,420,000 15,144,000 (17,549,000) 83,015,000
Less accumulated depreciation, ....................
depletion and amortization................... (29,274,000) 29,274,000 --
------------- -------------- ------------- -------------
56,146,000 15,144,000 11,725,000 83,015,000
------------- -------------- ------------- -------------
Other assets ....................................... 1,231,000 94,000 (285,000) 1,040,000
------------- -------------- ------------- -------------
$ 65,248,000 $ 16,836,000 $ 11,440,000 $ 93,524,000
============= ============== ============= =============
LIABILITIES AND SHAREHOLDERS' EQUITY Current liabilities:
Accounts payable and accrued liabilities........... $ 9,545,000 $ (3,771,000) $ -- $ 5,774,000
Pre-petition secured debt.......................... 16,915,000 (16,915,000) --
------------- ------------- ------------- ------------
Total current liabilities.......................... 26,460,000 (20,686,000) 5,774,000
------------- -------------- ------------- ------------
Pre-petition current liabilities subject to compromise:
Unsecured debt..................................... 136,818,000 (7,012,000) (129,806,000) --
------------- -------------- ------------- ------------
Long-term liabilities:
Other non-current liabilities...................... -- 757,000 757,000
Notes payable...................................... -- 15,000,000 15,000,000
------------- -------------- ------------- ------------
-- 15,757,000 15,757,000
------------- -------------- ------------- ------------
Stockholders' equity (deficit):
Common stock....................................... 95,000 104,000 22,000 221,000
Preferred stock.................................... 27,677,000 (27,677,000) --
Additional paid in capital......................... 39,570,000 31,673,000 529,000 71,772,000
Treasury stock..................................... (333,000) 333,000 --
Retained earnings.................................. (165,039,000) (3,000,000) 168,039,000 --
------------- -------------- -------------- ------------
(98,030,000) 28,777,000 141,246,000 71,993,000
------------- -------------- -------------- -------------
$ 65,248,000 $ 16,836,000 $ 11,440,000 $ 93,524,000
============= ============== ============== =============
</TABLE>
Substantial consummation adjustments are those involving cash transactions
occurring on the Effective Date. Fresh Start Reporting adjustments are those
involving non-cash transactions occurring on the Effective Date.
In accordance with the provisions of the Plan, the Company:
o Issued to its unsecured creditors, on account of their allowed
claims, an aggregate of 10 million shares of the Reorganized
Company's common stock. At the effective date, 1,412,000 of the
above-described shares were held in escrow to cover the settlement
of disputed unsecured claims in the amount of $18,339,000. Through
December 31, 1997, $10,413,000 of these claims have been settled for
$7,045,000 resulting in the issuance from the escrow account, of
547,000 shares of the Reorganized Company's common stock.
o Issued 3,800,000 shares of the Reorganized Company's common stock
for $13,300,000 in cash in connection with a stock rights offering
to it's unsecured creditors.
F-15
<PAGE> 74
o Issued 952,000 shares of the Reorganized Company's common stock in
payment of $3,332,000 in secured claims.
o Issued 1,703,000 shares of the Reorganized Company's common stock in
payment of a $5,961,000 claim purchased by DLB from Texaco
Exploration and Production, Inc. ("TEPI").
o Issued 5,616,000 shares of the Reorganized Company's common stock in
exchange for the WCBB Assets acquired by DLB from TEPI along with
the associated P&A trust fund and associated funding and plugging
obligations. In connection with this transaction the Company
transferred to TEPI certain assets and non-producing acreage.
The Company paid $1,672,000 in administrative and priority claims,
$1,145,000 in secured claims, and $143,000 convenience claims. At December 31,
1997, $1,493,000 was being held in escrow to cover settlement of disputed
priority, administrative and secured claims.
The Company transferred $3,000,000 to a Litigation Trust along with the
Company's rights to any and all causes of action, claims, rights of actions,
suits or proceedings which have been or could be asserted by it except for (a)
the action to recover unpaid production proceeds payable to the Company by
Tri-Deck Oil & Gas Company and (b) the foreclosure action to recover title to
certain assets (See Note 17 regarding the subsequent transfer of these claims to
the Litigation Entity). This transfer was treated as a pre-reorganization
expense on the financial statements for the six months and ten day period ended
July 10, 1997. The Reorganized Company owns a 12% economic interest in the
Litigation Entity and the remainder of the economic interests in the Litigation
Entity was allocated to former unsecured creditors based on their ownership
percentage of the 10 million shares as described above.
4. RELATED PARTY TRANSACTIONS
Subsequent to the Effective Date of the Plan of Reorganization,
substantially all of the Company's former unsecured creditors became
shareholders. In the ordinary course of business, the Company still conducts
business activities with a substantial number of these shareholders.
DLB Oil & Gas, Inc. ("DLB") and Wexford Management LLC ("Wexford") were,
along with the Company, co-proponents in the Plan of Reorganization. As of
December 31, 1997, DLB and Wexford own approximately 49% and 8%, respectively,
of the Company's outstanding common stock.
DLB paid $1,515,000 in reorganization costs incurred on the Company's
behalf, which was satisfied by the issuance of stock in connection with the
Company's stock rights offering described above, and cash. These costs were
included in reorganization cost incurred during the six months and 10 days ended
July 10, 1997. In addition, DLB charged the Company $465,000 for management
services provided to it during the period July 11, 1997 through December 31,
1997. During the period May 1, 1997 through July 10, 1997, DLB was the operator
on the WCBB properties in which the Company had a 50% working interest at that
time. Subsequent to that date, the WCBB properties were contributed to the
Company for common stock, as described above, and the Company became the
operator of these properties. As of December 31, 1997, the Company owes DLB
$1,728,000 which consists of unpaid management fees, capital expenditures, and
operating expenses paid by DLB on the Company's behalf.
During the period July 11, 1997 through December 31, 1997, the Company
sold $4,335,000 in oil to a DLB subsidiary. These sales occurred at prices which
the Company could be expected to obtain from an unrelated third party.
F-16
<PAGE> 75
5. PROPERTY AND EQUIPMENT
The major categories of property and equipment and related accumulated
depreciation, depletion and amortization as of December 31, 1997 and 1996 are as
follows:
<TABLE>
<CAPTION>
1997 1996
------------ ------------
<S> <C> <C>
Oil and gas properties ..................................... $ 84,466,000 $ 77,541,000
Equipment .................................................. -- 2,954,000
Office furniture and fixtures .............................. 1,100,000 1,669,000
Building ................................................... 217,000 235,000
Land ....................................................... 260,000 260,000
------------ ------------
Total property and equipment ............................... 86,043,000 82,659,000
Accumulated depreciation, depletion and amortization ....... (4,542,000) (25,760,000)
------------ ------------
Property and equipment, net ................................ $ 81,501,000 $ 56,899,000
============ ============
</TABLE>
On the Effective Date, DLB transferred its interest in the WCBB Assets to
the Reorganized Company in exchange for five million (5,000,000) shares of the
Reorganized Company Common Stock and the assumption by the Company of certain
plugging and abandonment obligations related to the West Cote Blanche Bay Field
(See Note 3 for further details). This transaction was valued at $12,987,000,
which included a $1,000,000 plugging and abandonment escrow account required by
TEPI. In connection with this transaction, DLB paid an additional $2,157,000 in
development costs on these properties for which it received an additional
616,000 shares of the Reorganized Company common stock.
In December 1994, the Company sold four drilling and workover rigs,
obtained in connection with certain oil and gas property acquisitions, to an oil
field service contractor for a total consideration of $3,900,000. The purchaser
gave a 6% secured promissory note in exchange. No gain or loss was recognized at
the date of the sale. The $1,000,000 gain on the sale was deferred and was being
realized over the life of the note. Concerns about the ability of the purchaser
to perform pursuant to the terms of the contract resulted in the Company
reversing the deferred gain in September 1995. At December 31, 1995, the related
note receivable was canceled. The Company has hired counsel and currently is
seeking to recover the collateral securing these notes.
In December 1994 and May 1995, the Company sold to the same oil field
service contractor marine and oil field service equipment for a total
consideration of $5,200,000. The purchaser gave two 6% secured promissory notes
in exchange. No gain or loss was recognized at the date of the sale. The
$800,000 gain on the sale was deferred and was being realized over the life of
the notes. Concerns about the ability of the purchaser to perform pursuant to
the terms of the contracts resulted in the Company reversing in September 1995
the deferred gain. At December 31, 1995, the two related promissory notes were
fully canceled. The Company has hired counsel and is currently seeking to
recover the collateral securing these notes.
No value has been assigned to any potential recoveries related to the
above two transactions in the fresh start accounting.
During December 1997, the Company sold substantially all of its field
equipment for approximately $2,100,000 resulting in a net gain on the sale of
$594,000.
6. PROVISION FOR DOUBTFUL RECEIVABLES
The Company has recorded provisions for certain receivables in which
collectibility is uncertain as follows:
In April 1995, the Company allegedly entered into a marketing agreement
with Tri-Deck pursuant to which Tri-Deck would market all of the Company's oil
and natural gas production. Subsequent to the agreement,
F-17
<PAGE> 76
Tri-Deck's principal, James Florence, who was also serving as the Company's
Director of Marketing, assigned to Plains Marketing its right to market the
Company's oil production and entered into a contract with Perry Oil and Gas to
market the Company's gas production. During the early stages of the Company's
Reorganization Case, Tri-Deck failed to make payments to the Company
attributable to several months of the Company's gas production. Due to the
uncertainty of the amount that will be recovered from Tri-Deck, the Company has
recorded an allowance for this receivable in the amount of $4,278,000. Of this
amount, approximately $1,700,000 related to the receivable from Tri-Deck for the
purchase of the Company's April and May, 1996 gas production and has been
deposited into a depository account with the Bankruptcy Court's registry.
The Company has a long-term receivable, recovery of which is made in the
form of a production payment from the oil and gas revenues in certain Company
operated oil and gas properties. The most significant well underlying the
production payment ceased production during the third quarter of 1995 due to
mechanical failure of the well bore. As a result, the ultimate recovery of the
remaining receivable is uncertain. The Company wrote-off the remaining $472,000
receivable balance in 1995.
During 1994, the Company made two personal loans of $62,500 and $300,000
to an executive officer of the Company on an unsecured basis payable on the last
day of February and June 1995, respectively. The loan for $62,500 was repaid in
March 1995 and the $300,000 loan maturity date was extended until December 31,
1995. The loan was not repaid when due on December 31, 1995 and the Company has
recorded an allowance of $300,000 for this note. The executive resigned from the
Company in January 1995. The executive officer filed for personal debt
protection subsequent to December 1996.
During the period ended July 10, 1997, the Company charged $71,000 to bad
debts expense.
7. OTHER ASSETS
Other assets as of December 31, 1997 and 1996, consist of the following:
<TABLE>
<CAPTION>
DECEMBER 31,
-----------------------------
1997 1996
------------ ------------
<S> <C> <C>
Plugging and abandonment escrow account
on the Lac Blanc properties - See Note 15 ............ $ 871,000 $ 831,000
Plugging and abandonment escrow account
on the WCBB properties - See Note 15 ................. 1,203,000 --
Prepaid loan fees, net of amortization ..................... 296,000 367,000
CD's securing Letter of credit ............................. 400,000 --
Deposits ................................................... 256,000 284,000
------------ ------------
$ 3,026,000 $ 1,482,000
============ ============
</TABLE>
8. RESTRUCTURING CHARGES AND REORGANIZATION COSTS
The Company incurred certain restructuring costs in connection with its
change in strategy and corporate structure. During 1995, these costs consisted
primarily of the write-off of approximately $1,000,000 in leasehold improvements
related to the relocation of the Company's operations from The Woodlands, Texas,
approximately $300,000 in severance costs related to staff reductions and
changes in senior management and $100,000 in legal fees and other costs directly
related to the Company's Reorganization Case.
During 1996, the Company incurred $7,345,000 in reorganization costs,
primarily consisting of professional fees totaling $2,594,000 and the write-off
of previously capitalized debt issuance costs on the Senior Notes (herein
defined) in the amount of $3,834,000.
During 1997, the Company incurred $7,771,000 in reorganization costs,
consisting of $3,000,000 contributed to the Litigation Trust (See Note 17 for
further details), $1,515,000 in reimbursements to DLB for
F-18
<PAGE> 77
restructuring costs it incurred on the Company's behalf, professional fees
totaling $2,213,000, and an accrual of $1,044,000 for estimated future costs to
be incurred in connection with the reorganization.
9. LONG-TERM LIABILITIES
As of December 31, 1997 and 1996, a break down of long term debt is as
follows:
<TABLE>
<CAPTION>
1997 1996
------------- -------------
<S> <C> <C>
Long-term debt:
Credit facility........................................................ $ 15,000,000 $ --
Priority tax claims.................................................... 527,000 --
Building loan.......................................................... 193,000 --
------------- -------------
15,720,000 --
Less current portion................................................... 2,192,000 --
------------- -------------
$ 13,528,000 $ --
============= =============
Long-term debt in default treated as current liabilities:
Credit facility........................................................ $ -- $ 15,000,000
Senior Notes........................................................... -- 98,572,000
Other .............................................................. -- 377,000
------------- ------------
$ -- $113,949,000
============= ============
</TABLE>
Credit Facility
In December 1994, the Company entered into a $40,000,000 credit facility
with International Nederlanden (U.S.) Capital Corporation ("INCC") ("Credit
Facility") that was secured by substantially all of the Company's assets. At
December 31, 1996, the Company had borrowings outstanding of $15,000,000, the
maximum amount of borrowings available under the Credit Facility. At December
31, 1995, the revolving loan borrowings were converted to a term loan whereby
quarterly principal payments of one-sixteenth of the outstanding indebtedness
were due and payable. Amounts outstanding under the Credit Facility bore
interest at an annual rate selected by the Company of either (i) the London
Inter-Bank offered rate ("LIBOR") plus 3%, or (ii) the Lender's prime lending
rate plus 1.25%. The estimated fair value of the Company's indebtedness under
its Credit Facility approximates the principal balance outstanding, as the
facility bears interest at rates tied to market rates and is secured by
substantially all of the Company's assets.
At December 31, 1996, the Company was in default under certain financial
covenants of the Credit Facility. Accordingly, the Company classified the debt
as current at December 31, 1996. While in bankruptcy, INCC was stayed from
enforcing certain remedies provided for in the credit agreement and the
indenture. On the Effective Date, this loan was repaid in full along with
$3,154,000 in accrued interest and legal fees.
On the Effective Date, ING (U.S.) Capital Corporation (successor to INCC)
("ING") entered into a new $15,000,000 loan agreement with the Company. Terms of
this loan call for initial loan fees of $188,000 to be paid on or prior to
closing with two additional loan fee payments of $100,000 each payable on or
prior to December 31, 1997 and December 31, 1998. The loan matures on July 11,
1999, with interest to be paid quarterly and with three interim principal
payments of $1,000,000 each to be made in September 1998, December 1998, and
March 1999. This loan bears interest at the option of the Company at either (1)
LIBOR plus 3% or (2) ING's fluctuating "reference rate" plus 1.25%. This loan is
collateralized by substantial all of the Company's assets. At 12/31/97 this rate
was 8.8125%.
At December 31, 1997, the Company held $2,060,000 in cash representing the
proceeds from the sale of its field equipment as further described in Note 5
above. As of the date of this report, ING has not released these funds for
general use by the Company.
F-19
<PAGE> 78
13 7/8% Senior Notes Offering
In February 1995, the Company offered 100,000 Units consisting of
$100,000,000 aggregate principal amount of 13 7/8% Senior Notes and Warrants
("Warrants") to purchase an aggregate of 800,000 shares of the Company's Common
Stock ("Offering").
The Senior Notes were unsecured obligations of the Company ranking senior
in right of payment to any subordinated indebtedness of the Company.
The Senior Notes were issued under an indenture. The Company was not in
compliance with the provisions of the indenture at December 31, 1996,
accordingly, the Company classified the debt as current at that date.
The Company, pursuant to an order of the Bankruptcy Court, did not make
the scheduled interest payment of $6,938,000 on March 1, 1996, nor had the
Company made any interest payments since that date. In accordance with SOP 90-7,
the Company has not recorded interest expense on the Senior Notes subsequent to
the Petition Date. At December 31, 1996, interest accrued related to the Senior
Notes was $6,359,000. Had the Company accrued interest on the Senior Notes for
the period subsequent to the Petition Date through December 31, 1996, an
additional $12,141,000 of interest expense would have been recorded as of
December 31, 1996.
On the effective date, the Senior Notes were cancelled and the note
holders received a pro rata share of 10,000,000 shares of common stock in the
Reorganized Company along with all other unsecured creditors.
Priority Tax Claims
In accordance with the Plan of Reorganization, priority taxes totaling
$703,000 are to be paid in four annual installments without interest. The first
annual installment of $176,000 was made on the Effective Date.
Building Loan
During early 1996, the Company entered into a loan agreement with M C Bank
and Trust Company to finance the acquisition of land and a building located in
Lafayette, Louisiana. The original loan balance was $215,000 and called for
monthly principal and interest payments totaling $3,000 per month through 2005
with the unpaid balance due at that time. The loan bears interest at 9.5% per
annum and is collateralized by the land and building.
Long Term Debt Maturities
Following are the maturities of long-term liabilities for each of the next
five years:
<TABLE>
<S> <C>
1998......................................... $ 2,192,000
1999......................................... 13,193,000
2000......................................... 195,000
2001......................................... 21,000
2002......................................... 23,000
Thereafter................................... 96,000
-------------
$ 15,720,000
</TABLE>
10. PREFERRED STOCK OFFERING
Public Offering of Preferred Stock
On October 27, 1993, the Company completed its public offering of
1,265,000 shares of 9% Convertible Preferred Stock ("Preferred Stock") at a
price of $25 per share. The offering resulted in cash proceeds to the Company of
$27,700,000, net of underwriting fees, commissions and offering costs. The
proceeds of the offering
F-20
<PAGE> 79
were used to purchase additional oil and gas properties, to conduct oil and gas
property development, to develop and fabricate logging tools and for general
purposes.
The Preferred Stock had a liquidation preference of $25 per share and was
convertible, at the option of the holder, into 2.083 shares of the Company's
common stock. The Preferred Stock was not redeemable before October 20, 1995.
Dividends on the Preferred Stock were to accrue and were cumulative from October
20, 1993, and were payable quarterly in arrears when declared by the Board of
Directors. The Company was precluded under the terms of the Senior Note
Indenture and Credit Facility from declaring any dividends during 1996. As a
result of this and the bankruptcy proceedings, the Company did not accrue
dividends payable on its Preferred Stock during 1996. In addition, accrued and
unpaid Preferred Stock dividends at December 31, 1995 have been reversed in the
1996 financial statements. All outstanding Preferred Stock was cancelled
effective July 11, 1997, and the former preferred shareholders were given
Warrants exercisable at a price of $10 per share for a total of 221,000 shares
in the Reorganized Company Common Stock.
11. COMMON STOCK OPTIONS AND WARRANTS
All outstanding stock options and warrants issued prior to July 11, 1997,
were cancelled in connection with the Plan of Reorganization.
On July 10, 1997, the Company entered into an employment agreement with
Mr. Ray Landry, the Company's former president, to perform certain services for
the Company. In connection with this employment agreement, Mr. Landry was
granted Incentive Stock Options to acquire 60,000 shares of the Company's common
stock for $3.50 per share. The employment agreement does not specify the life of
these options.
In connection with the Plan of Reorganization, new warrants for 221,000
shares of the Reorganized Company common stock were issued to the former
preferred shareholders. In addition, to the extent that any securities
litigation claims based on preferred or common stock ownership are allowed as a
"Class Proof of Claim", the Company has the obligation to issue this class an
additional 221,000 in warrants to purchase common stock in the Reorganized
Company. These warrants are each exercisable for one share of common stock at an
exercise price of $10 per share. The warrants will expire on July 11, 2007. In
accordance with the Plan of Reorganization, the Company has the right to issue
up to 1,104,000 warrants.
F-21
<PAGE> 80
12. INCOME TAXES
A reconciliation of the statutory federal income tax amount to the recorded
expense follows:
<TABLE>
<CAPTION>
JULY 11, 1997
THROUGH JANUARY 1, 1997
DECEMBER 31, THROUGH
1997 JULY 10, 1997 1996 1995
----------- ------------- ------------ -------------
<S> <C> <C> <C> <C>
Income (loss) before Federal income
taxes ........................................... $(1,713,000) $79,108,000 $(29,387,000) $(128,175,000)
----------- ------------- ------------ -------------
Expected income tax (benefit)
at statutory rate ............................... (651,000) 30,061,000 (10,285,000) (44,861,000)
Valuation allowance ................................... 651,000 -- 9,358,000 44,977,000
Tax deduction in excess of book for
stock options exercised ......................... -- -- -- (144,000)
Net operating loss carryforward utilized .............. -- (30,061,000) -- --
Reorganization costs .................................. -- -- 923,000 --
Other ................................................. -- -- 4,000 28,000
----------- ----------- ------------ ------------
Income tax expense recorded ........................... $ -- $ -- $ -- $ --
=========== =========== ============ ============
</TABLE>
The tax effects of temporary differences and net operating loss carry
forwards, which give rise to deferred tax assets (liabilities) at December 31,
1997 and 1996, respectively, are as follows:
<TABLE>
<CAPTION>
1997 1996
------------ ------------
<S> <C> <C>
Net operating loss carryforward ............................ $ 3,740,000 $ 19,002,000
Oil and gas property basis difference ...................... 22,362,000 28,971,000
Other ...................................................... 1,953,000 6,702,000
------------ ------------
Total deferred tax asset ................................... 28,055,000 54,675,000
Valuation allowance ........................................ (28,055,000) (54,607,000)
------------ ------------
Deferred tax asset ......................................... -- 68,000
------------ ------------
Deferred tax liability ..................................... -- (68,000)
------------ ------------
Net deferred tax asset (liability) ......................... $ -- $ --
============ ============
</TABLE>
The Company filed a short period tax return for the six months and ten
days ended July 10, 1997. On that return, the Company utilized $30,061,000 of
it's deferred tax asset. Since the deferred tax asset was fully reserved by a
valuation allowance at December 31, 1996, no income tax expense was recognized
on the financial statements for the period January 1 to July 10, 1997.
The Company has an available tax net operating loss carry forward of
approximately $10,000,000 as of December 31, 1997. This carryforward will expire
in the year 2012.
13. EARNINGS (LOSS) PER SHARE
Earnings per share for all periods were computed based on common stock
equivalents outstanding on that date during the applicable periods.
14. JOINT VENTURE AGREEMENT
By a Joint Venture Agreement dated October 18, 1991, the Company entered
into a joint venture to develop certain oil and gas properties with Tricore
Energy Venture, L.P., a Texas limited partnership ("Tricore") and Stag Energy
Corporation ("Stag").
F-22
<PAGE> 81
Under the terms of the Tricore agreements Tricore contributed the
capitalization required to complete the development of selected prospects, and
Stag and the Company contributed, or arranged for contribution of, the prospects
to be developed.
The Company provided Tricore with a limited production guarantee based on
the minimum production schedule attached to the Tricore joint venture agreement.
As a result of significant production declines from jointly-owned
properties, the Company has recorded in 1996 and 1995, minimum production
guarantee charges of $5,555,000 and $3,591,000, respectively. The $9,146,000
liability recognized at December 31, 1996 represented the Company's estimated
ultimate obligation to the joint venture, including the disallowance of certain
tax credits.
On December 9, 1997, this claim was settled as an Allowed General
Unsecured Claim in the amount of $6,800,000 for which Tricore received 524,000
shares of the Reorganized Company common stock and 524,000 Litigation Entity
interests. As a part of this settlement, Tricore transferred its interest in the
Joint Venture to the Company with the stipulation that if the Company sells any
of the Joint Venture's properties within one year, the Company will pay to
Tricore the net proceeds from such sale.
15. COMMITMENTS
Leases
As of December 31, 1997, the Company had no long-term, non-cancelable
operating lease commitments.
Rental expense for all operating leases for the period commencing July 11,
1997 and ending December 31, 1997, the period commencing January 1, 1997 and
ending July 10, 1997, and for the years ended December 31, 1996, and 1995 was
$77,000, $109,000, $207,000, and $482,000, respectively.
During 1996, the Company terminated its office lease covering
approximately 24,000 square feet in The Woodlands, Texas. The lessor asserted a
secured claim in connection with the Company's reorganization case in the amount
of $250,000 and an unsecured claim in the amount of $127,000, attributable to
rental obligations and lease rejection damages associated with such lease. On
April 22, 1997, the Bankruptcy Court granted the claimant an allowed secured
claim of $118,000 and an allowed unsecured claim in the amount of $150,000.
Lac Blanc Escrow Account
In connection with its purchase of a 91% working interest in the Lac Blanc
Field, the Company deposited $170,000 in a segregated trust account and agreed
to make additional deposits of $20,000 per month until the accumulated balance
of the trust account reaches $1,700,000. These funds are held in a segregated
account for the benefit of the State of Louisiana to insure that the wells in
the Lac Blanc Field are properly plugged upon cessation of production. In return
for this financial commitment, the State has granted the sellers an
unconditional release from their contingent liability to the state to plug and
abandon the wells. When all existing wells in the Lac Blanc Field have been
properly plugged and abandoned, the funds in the trust account, should any
remain, will revert to the Company. Due to the filing of the Reorganization Case
in June 1996, the Company ceased contributions to the segregated account. At
December 31, 1997, the balance in this escrow account was $871,000.
Under the Plan, the Company will fund the unfunded portion of the escrow
and maintain future funding requirements.
Plugging and Abandonment Funds
The Company is contractually committed in its purchase contracts for the
Initial LLOG Property and Remaining LLOG Properties to establish plugging and
abandonment funds as allowed by Louisiana's Orphaned Well Act. The State of
Louisiana, upon completion of an independent study to be commissioned by the
Company, will establish the amount of and terms of payment into each fund. As of
December 31, 1997, the independent study
F-23
<PAGE> 82
has not been completed. Accordingly, the Company is unable to determine the
amount and payment towards the future obligation related to these commitments.
Under the Plan, the Company will fund the unfunded portion of the escrow
and maintain future funding requirements.
In connection with the acquisition of the remaining 50% interest in the
WCBB properties, the Reorganized Company assumed the obligation to contribute
approximately $18,000 per month through March 2004 to a plugging and abandonment
trust and the obligation to plug a minimum of 20 wells per year for 20 years
commencing March 11, 1997. TEPI retained a security interest in production from
these properties and the plugging and abandonment trust until such time the
Company's obligations plugging and abandonment obligations to TEPI have been
fulfilled. Once the plugging and abandonment trust is fully funded, the Company
can access it for use in plugging and abandonment charges associated with the
property.
Texaco Global Settlement
Pursuant to the terms of a global settlement between Texaco and the State
of Louisiana which includes the State Lease No. 50 portion of the Company's East
Hackberry Field, the Company is obligated to commence a well or other qualifying
development operation on certain non-producing acreage in the field prior to
March 1998. On January 8, 1998, the Company applied for and was granted a permit
to conduct seismic operations on the East Hackberry Field as well as other
Company properties. The Company is planning on shooting the seismic as soon as
practical. If the Company fails to shoot the seismic or commence the drilling of
a well on this non-producing acreage within a reasonable period of time, it will
be required by the State of Louisiana to surrender approximately 440
non-producing acres in this field.
Reimbursement of Employee Expenses & Contributions to 401(k) Plan
The Company sponsors a 401(k) savings plan under which eligible employees
may choose to contribute up to 15% of salary income on a pre-tax basis, subject
to certain IRS limits. The Company contribution to the 401(k) plan is
discretionary and currently is 25% of employee contributions up to 6% of their
salary. This benefit vests to employees over a five-year employment period or at
a rate of 20% per each year of participation. During the period commencing July
11, 1997 and ending on December 31, 1997, the period commencing January 1, 1997
and ending on July 10, 1997, and the years ended December 31, 1996 and 1995, the
Company incurred $13,000, $23,000, $32,000, and $22,000, respectively, in
matching contributions expense associated with this plan.
Stay Bonus
The Company's Board of Directors determined that it was necessary to
provide a "stay bonus" to facilitate retention of employees during the
Reorganization Case in view of the uncertainties of the future of the Company.
On November 6, 1996, the Bankruptcy Court entered an order authorizing the stay
bonuses. The Company accrued $614,000 for these stay bonuses in December of 1996
and the bonuses were paid in June 1997.
16. CONTINGENCIES
Tri-Deck/Perry Gas Litigation
During 1995, the Company entered into a marketing agreement with Tri-Deck
Oil and Gas Company ("Tri-Deck") pursuant to which Tri-Deck would market all of
the Company's oil and gas production. Subsequent to the agreement, Tri-Deck's
principal and the Company's Director of Marketing, James Florence, assigned to
Plains Marketing its right to market the Company's oil production and assigned
to Perry Oil & Gas its right to market the Company's gas production. During
early 1996, Tri-Deck failed to make payments to the Company attributable to
several months of its gas production. Consequently, the Company responded in two
ways. First, on May 20, 1996, the Company filed a Motion to Reject the Tri-Deck
Marketing Agreement. Second, on May 29, 1996, the Company initiated an adversary
proceeding against Tri-Deck and Perry Oil and Gas ("Perry Gas"). Perry Gas was
the party, which ultimately purchased the Company's gas production for the
months in question.
F-24
<PAGE> 83
With respect to the Motion to Reject, the Bankruptcy Court authorized the
rejection and directed Tri-Deck and the Company to determine the amount of
production proceeds attributable to the Company's June gas production which were
payable to the Company. Consequently, Perry Gas thereafter made payment to the
Company of the June gas proceeds less $75,000 for a set-off claim by Perry Gas,
which is subject to further consideration by the Bankruptcy Court.
Next, with respect to the adversary proceeding, the Company sought
turnover by Tri-Deck and/or Perry Gas of all unpaid production proceeds payable
to the Company under the marketing agreement and the issuance of a temporary
restraining order and preliminary injunction against both parties to prevent
further disposition of such proceeds pending outcome of the proceedings. On May
31, 1996, the Bankruptcy Court entered a consensual temporary restraining order
against both Tri-Deck and Perry Gas. On June 18, 1996, a Preliminary Injunction
was entered by the Court which required Perry Gas to segregate into a separate
depository account the funds due for the purchase of the Company's April and May
1996 gas production from Tri-Deck. Subsequently, upon motion by the Company the
Court ordered such funds to be placed into the Bankruptcy Court's registry, as
Perry Gas had made certain withdrawals from the separate depository account
without authorization by the Court. Currently, funds in the amount of
approximately $1,700,000 remain in the registry of the Court. Additionally, a
dispute exists between the Company and Perry Gas as to additional funds owed by
Perry Gas for the purchase of the Company's April and May 1996 gas production.
Currently, the adversary proceeding remains pending as to the ultimate issue of
ownership of proceeds. Tri-Deck has also filed an answer and counterclaim in
which Tri-Deck is asserting, among other items, damages for tortoise
interference of its contractual relationships with others. Recovery of the
$1,700,000 receivable is dependent on the court rendering a favorable ruling on
the issue. As of the date of the report, the court has not ruled on this issue.
Although management believes that Tri-Deck's claim to the funds in the registry
of the court is invalid, and the aforementioned counterclaim is without merit,
for financial reporting purposes the receivable from Tri-Deck was fully reserved
for as of December 31, 1997.
On January 20, 1998, the Company and the Litigation Trust entered into a
Clarification Agreement whereby the rights to pursue the Tri-Deck claim were
assigned to the Litigation Trust. In connection with this agreement, the
Litigation Trust agreed to reimburse the Company $100,000 for legal fees the
Company had incurred in connection this and other related claims. As additional
consideration for the contribution of this claim to the Litigation Trust, the
Company is entitled to 85% of the net proceeds from this claim.
Title to Oil and Gas Properties
During 1996, WRT received notice from a third party claiming that the
Company's title has failed as to approximately 43 acres in the Bayou Pigeon
Field. Some or all of the acreage in dispute is considered to be productive in
three separate production units. Under the assumption that the Company's title
is flawed, it's working interest in three units may be reduced to approximately
7% (5% Net Revenue Interest, ("NRI")) 75% (63% NRI), and 95% (72% NRI). The
financial statements as of and for period commencing July 11, 1997 and ending
December 31, 1997, the period commencing January 1, 1997 and ending July 10,
1997, and for the years ended December 31, 1996 and 1995, reflect operating
results and proved reserves discounted for of this possible title failure. As
the title failure predates its ownership of the field, the Company is currently
evaluating its recourse against the predecessors-in-title relative to this
issue. The Company is currently negotiating a settlement with the Third Party,
pursuant to their claim.
Other litigation
The Company has been named as a defendant on various other litigation
matters. The ultimate resolution of these matters is not expected to have a
material adverse effect on the Company's financial condition or results of
operations for the periods presented in the financial statements.
17. LITIGATION TRUST ENTITY
On August 13, 1996, the Bankruptcy Court executed and entered its Order
Appointing Examiner directing the United States Trustee to appoint a
disinterested person as examiner in the Company's bankruptcy case.
F-25
<PAGE> 84
The Court ordered the appointed examiner ("Examiner") to file a report of
the investigation conducted, including any fact ascertained by the examiner
pertaining to fraud, dishonesty, incompetence, misconduct, mismanagement or
irregularity in the management of the affairs of the Company.
The Examiner's final report dated April 2, 1997, recommended numerous
actions for recovery of property or damages for the Company's estate which
appear to exist and should be pursued. Management does not believe the
resolution of the matters referred to in the Examiner's report will have a
material impact on the Company's consolidated financial statements or results of
operations.
Pursuant to the Plan of Reorganization, all of the Company's possible
causes of action against third parties (with the exception of certain litigation
related to recovery of marine and rig equipment assets and claims against
Tri-Deck), existing as of the effective date of the Plan, were transferred into
a "Litigation Trust" controlled by an independent party for the benefit of most
of the Company's existing unsecured creditors. The litigation related to
recovery of marine and rig equipment and the Tri-Deck claims were subsequently
transferred to the litigation trust as described below.
The Litigation Entity was funded by a $3,000,000 cash payment from the
Company, which was made on the Effective Date. The Company owns a 12% interest
in the Litigation Trust with the other 88% being owned by the former general
unsecured creditors of the Company. For financial statement reporting purposes,
the Company has not recognized the potential value of recoveries which may
ultimately be obtained, if any, as a result of the actions of the Litigation
Trust, treating the entire $3,000,000 payment as a reorganization cost incurred
during the period commencing January 1, 1997 and ending on July 10, 1997.
On January 20, 1998, the Company and the Litigation Entity entered into a
Clarification Agreement whereby the rights to pursue various claims reserved by
the Company in the Plan of Reorganization were assigned to the Litigation Trust.
In connection with this agreement, the Litigation Trust agreed to reimburse the
Company $100,000 for legal fees the Company had incurred in connection these
claims. As additional consideration for the contribution of this claim to the
Litigation Trust, the Company is entitled to 20% to 80% of the net proceeds from
these claims.
18. SUPPLEMENTAL INFORMATION ON OIL AND GAS EXPLORATION AND PRODUCTION
ACTIVITIES (UNAUDITED)
The following is historical revenue and cost information relating to the
Company's oil and gas operations located entirely in the southeastern United
States:
Capitalized Costs Related to Oil and Gas Producing Activities
<TABLE>
<CAPTION>
1997 1996
------------ ------------
<S> <C> <C>
Proved Properties .......................................... $ 79,349,000 $ 77,541,000
Accumulated depreciation, depletion and amortization ....... (4,371,000) (23,401,000)
------------ ------------
Proved properties , net .................................... $ 74,978,000 $ 54,140,000
============ ============
</TABLE>
Costs Incurred in Oil and Gas Property Acquisition and Development Activities
<TABLE>
<CAPTION>
1997 1996 1995
------------ ------------ ------------
<S> <C> <C> <C>
Acquisition ................................ $ 15,144,000 $ -- $ 87,379,000
Development ................................ 6,787,000 4,282,000 27,225,000
------------ ------------ ------------
$ 21,931,000 $ 4,282,000 $114,604,000
============ ============ ============
</TABLE>
F-26
<PAGE> 85
Results of Operations for Producing Activities
The following schedule sets forth the revenues and expenses related to the
production and sale of oil and gas. The income tax expense is calculated by
applying the current statutory tax rates to the revenues after deducting costs,
which include depreciation, depletion and amortization allowances, after giving
effect to the permanent differences. The results of operations exclude general
office overhead and interest expense attributable to oil and gas production.
<TABLE>
<CAPTION>
JULY 11, 1997
THROUGH JANUARY 1, 1997
DECEMBER 31, THROUGH
1997 JULY 10, 1997 1996 1995
----------- ------------- ----------- -----------
<S> <C> <C> <C> <C>
Revenues .................................... $ 9,756,000 $10,138,000 $24,019,000 $24,655,000
Production costs ............................ 5,397,000 5,514,000 15,095,000 11,673,000
Depletion ................................... 4,371,000 3,314,000 7,973,000 12,645,000
----------- ----------- ----------- -----------
12,000 1,310,000 951,000 337,000
Income tax expense .......................... -- -- 34,000 7,000
----------- ----------- ----------- -----------
Results of operations
From producing activities ............. $ 12,000 $ 1,310,000 $ 917,000 $ 330,000
=========== =========== =========== ===========
</TABLE>
Oil and Gas Reserves
The following table presents estimated volumes of proved and proved
developed oil and gas reserves, prepared by independent reserve engineers, as of
December 31, 1997, 1996 and 1995 and changes in proved reserves during the last
three years, assuming continuation of economic conditions prevailing at the end
of each year. Estimated volumes as of July 11, 1997 were extrapolated from the
December 31, 1997 numbers and were not prepared by independent reserve
engineers. Volumes for oil are stated in thousands of barrels (MBbls) and
volumes for natural gas are stated in millions of cubic feet (Mmcf). The
weighted average prices at December 31, 1997 used for reserve report purposes
are $17.91 and $2.62 for oil and gas reserves, respectively.
The Company emphasizes that the volumes of reserves shown below are
estimates which, by their nature, are subject to revision. The estimates are
made using all available geological and reservoir data, as well as production
performance data. These estimates are reviewed annually and revised, either
upward or downward, as warranted by additional performance data.
<TABLE>
<CAPTION>
JULY 11 TO
DECEMBER 31, JANUARY 1 TO
1997 JULY 10, 1997
------------------------ ------------------------
OIL GAS OIL GAS
---------- ---------- ---------- ----------
<S> <C> <C> <C> <C>
Proved Reserves:
Beginning of the period ......... 13,677 13,409 13,923 15,121
Purchases of oil and gas
reserves in place ........... 11,612 163 -- --
Extensions, discoveries and
other additions ............. -- -- -- --
Revisions of prior reserve
estimates ................... 848 (890) (89) (381)
Current production .............. (320) (1,106) (246) (1,712)
Sales of oil and gas
reserves in place ........... -- -- -- --
---------- ---------- ---------- ----------
End of period ................... 25,817 11,576 13,677 13,409
========== ========== ========== ==========
Proved developed reserves ....... 7,219 8,259 7,248 8,252
========== ========== ==========
<CAPTION>
1996 1995
------------------------ ------------------------
OIL GAS OIL GAS
---------- ---------- ---------- ----------
<S> <C> <C> <C> <C>
Proved Reserves:
Beginning of the period ......... 14,627 19,131 7,431 28,797
Purchases of oil and gas
reserves in place ........... -- -- 15,068 39,204
Extensions, discoveries and
other additions ............. 960 4,235
Revisions of prior reserve
estimates ................... (7,821) (44,859)
Current production .............. (615) (3,629) (778) (7,403)
Sales of oil and gas
reserves in place ........... -- -- (233) (843)
---------- ---------- ---------- ----------
End of period ................... 13,923 15,121 14,627 19,131
========== ========== ========== ==========
Proved developed reserves ....... 9,550 11,687 10,209 16,663
========== ========== ==========
</TABLE>
F-27
<PAGE> 86
Discounted Future Net Cash Flows
Estimates of future net cash flows from proved oil and gas reserves were
made in accordance with SFAS No. 69, "Disclosures about Oil and Gas Producing
Activities." The following tables present the estimated future cash flows, and
changes therein, from the Company's proved oil and gas reserves as of December
31, 1997, 1996 and 1995, assuming continuation of economic conditions prevailing
at the end of each year.
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil
and Gas Reserves
<TABLE>
<CAPTION>
1997 1996 1995
------------ ------------ ------------
<S> <C> <C> <C>
Future cash flows ..................................... $492,680,000 $421,954,000 $311,419,000
Future development costs .............................. (166,812,000) (107,627,000) (96,460,000)
Future production costs ............................... (119,235,000) (90,558,000) (89,187,000)
Future production taxes ............................... (58,807,000) (46,703,000) (35,411,000)
------------ ------------ ------------
Future net cash flows before income taxes ............. 147,826,000 177,066,000 90,361,000
10% annual discount for estimated timing of
cash flows ...................................... (71,396,000) (78,399,000) (38,994,000)
------------ ------------ ------------
Discounted future net cash flows ...................... 76,430,000 98,667,000 51,367,000
Future income taxes, net of 10% annual discount ....... -- -- --
------------ ------------ ------------
Standardized measure of discounted future
net cash flows .................................. $ 76,430,000 $ 98,667,000 $ 51,367,000
============ ============ ============
</TABLE>
Changes in Standardized Measure of Discounted Future Net Cash Flows Relating to
Proved Oil and Gas Reserves
<TABLE>
<CAPTION>
1997 1996 1995
------------ ------------ ------------
<S> <C> <C> <C>
Sales and transfers of oil and gas produced, net of
production costs ................................ $ (9,352,000) $ (8,924,000) $(12,982,000)
Net changes in prices and development and
production costs ................................ (50,101,000) 55,345,000 (26,418,000)
Acquisition of oil and gas reserves in place, less
related production costs ........................ 27,195,000 -- 62,974,000
Extensions, discoveries and improved recovery,
less related costs .............................. -- -- 4,859,000
Revisions of previous quantity estimates, less
related production costs ........................ 5,720,000 (914,000) (44,100,000)
Sales of reserves in place ............................ -- -- (1,089,000)
Accretion of discount ................................. 6,248,000 5,137,000 6,452,000
Net change in income taxes ............................ -- -- 11,600,000
Other ................................................. (1,947,000) (3,344,000) (2,851,000)
------------ ------------ ------------
Total change in standardized measure of
discounted future net cash flows ................ $(22,237,000) $ 47,300,000 $ (1,555,000)
============ ============ ============
</TABLE>
F-28
<PAGE> 87
GULFPORT ENERGY CORPORATION
CONSOLIDATED BALANCE SHEETS
<TABLE>
<CAPTION>
JUNE 30, 1998 DECEMBER 31, 1997
------------- -----------------
(unaudited)
<S> <C> <C>
ASSETS
Current assets:
Cash and cash equivalents ............................................ $ 2,264,000 $ 1,203,000
Cash, restricted ..................................................... 14,000 2,060,000
Accounts receivable, net of allowance for doubtful
accounts of $4,996,000 for June 30, 1998 and
December 31, 1997, respectively ................................ 4,167,000 4,364,000
Prepaid expenses and other ........................................... 137,000 192,000
------------ ------------
Total current assets ........................................... 6,582,000 7,819,000
------------ ------------
Property and equipment:
Oil and natural gas properties ....................................... 85,119,000 84,466,000
Other property and equipment ......................................... 1,800,000 1,577,000
Accumulated depletion, depreciation and amortization ................. (24,578,000) (4,542,000)
------------ ------------
Property and equipment, net .................................... 62,341,000 81,501,000
------------ ------------
Other assets .............................................................. 3,268,000 3,026,000
------------ ------------
TOTAL ASSETS .............................................................. $ 72,191,000 $ 92,346,000
============ ============
LIABILITIES AND SHAREHOLDERS' EQUITY Current liabilities:
Accounts payable and accrued liabilities ............................. $ 8,517,000 $ 6,346,000
Current maturities of long-term debt ................................. 3,014,000 2,192,000
------------ ------------
Total current liabilities ...................................... 11,531,000 8,538,000
------------ ------------
Other long-term liabilities ............................................... 236,000 528,000
Long term debt ............................................................ 10,424,000 13,000,000
------------ ------------
Total liabilities .................................................... 22,191,000 22,066,000
------------ ------------
Shareholders' equity:
Commonstock - $.01 par value, 50,000,000 authorized,
22,076,315 issued and outstanding at June 30,
1998 and December 31, 1997, respectively ....................... 221,000 221,000
Paid-in-capital ...................................................... 71,772,000 71,772,000
Accumulated deficit .................................................. (21,993,000) (1,713,000)
------------ ------------
Total shareholders' equity ..................................... 50,000,000 70,280,000
------------ ------------
Commitments and contingencies ............................................. -- --
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY ................................ $ 72,191,000 $ 92,346,000
============ ============
</TABLE>
See accompanying notes to consolidated financial statements
F-29
<PAGE> 88
GULFPORT ENERGY CORPORATION
CONSOLIDATED STATEMENT OF OPERATIONS
(UNAUDITED)
<TABLE>
<CAPTION>
SIX MONTHS ENDED JUNE 30,
------------------------------
1998 1997
(REORGANIZED (PREDECESSOR
COMPANY) COMPANY)
------------ ------------
<S> <C> <C>
Revenues:
Gas sales $ 2,847,000 $ 4,495,000
Oil and condensate sales 3,875,000 5,161,000
Other Income, net 346,000 120,000
------------ ------------
Total revenues 7,068,000 9,776,000
------------ ------------
Expenses:
Production costs 5,170,000 5,239,000
Depreciation, depletion and amortization 20,098,000 3,124,000
General and administrative expenses 1,322,000 1,990,000
Provision for doubtful accounts -- 71,000
------------ ------------
26,590,000 10,424,000
------------ ------------
Income (loss) from operations (19,522,000) (648,000)
Interest expense 758,000 1,032,000
------------ ------------
Income (loss) before reorganization costs and income taxes (20,280,000) 1,680,000
Reorganization costs -- 3,727,000
------------ ------------
Loss before income taxes (20,280,000) (5,407,000)
Income tax expense -- --
Net loss (20,280,000) (5,407,000)
Undeclared dividends on preferred stock -- (1,423,000)
------------ ------------
Net loss available to common shareholders $(20,280,000) $ (6,830,000)
============ ============
Per common share:
Income (loss) per common and common equivalent share $ (0.92) *
============ ============
Average common and common equivalent shares outstanding 22,076,000 *
============ ============
</TABLE>
* Amounts not meaningful as a result of the reorganization.
See accompanying notes to consolidated financial statements
F-30
<PAGE> 89
GULFPORT ENERGY CORPORATION
CONSOLIDATED STATEMENT OF CASH FLOWS
(UNAUDITED)
<TABLE>
<CAPTION>
SIX MONTHS ENDED JUNE 30,
------------------------------
1998 1997
(REORGANIZED (PREDECESSOR
COMPANY) COMPANY)
------------ ------------
<S> <C> <C>
Cash flow from operating activities:
Net (loss) $(20,280,000) $ (5,407,000)
Adjustments to reconcile net loss to net cash provided by
operating activities:
Depreciation, depletion, and amortization 20,035,000 3,124,000
Provision for doubtful accounts and notes receivable -- 71,000
Amortization of debt issuance costs 97,000 83,000
(Gain) on sale of asset (70,000) --
Changes in operating assets and liabilities:
Decrease (increase) in accounts receivable 198,000 (287,000)
(Increase) decrease in prepaid expenses and other 54,000 (237,000)
Increase in accounts payable and accrued liabilities 1,980,000 3,450,000
(Decrease) in other long-term liabilities (116,000) --
Pre-petition liabilities subject to compromise -- (267,000)
Pre-petition liabilities not subject to compromise -- (1,000)
------------ ------------
Net cash provided by operating activities 1,898,000 529,000
Cash flow from investing activities:
Additions to cash held in escrow -- (20,000)
Additions to other assets (339,000) --
Additions to property and equipment (805,000) (2,561,000)
Net cash used in investing activities (1,144,000) (2,581,000)
Cash flow from financing activities:
Principal payments on borrowings (1,739,000) (16,000)
------------ ------------
Net cash used in financing activities (1,739,000) (16,000)
Net increase (decrease) in cash and cash equivalents (985,000) (2,068,000)
Cash and cash equivalents - beginning of period 3,263,000 5,679,000
------------ ------------
Cash and cash equivalents - end of period $ 2,278,000 $ 3,611,000
============ ============
Supplemental Disclosures of Cash Flow Information
Interest paid $ 358,000 $ 28,000
Income taxes paid -- --
Supplemental Information of Non-Cash Investing And Financing Activities
Accrued dividends on preferred stock (Undeclared on
Predecessor Company) -- (1,423,000)
</TABLE>
See accompanying notes to consolidated financial statements
F-31
<PAGE> 90
GULFPORT ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Business and Reorganization Proceedings
The following summary is qualified in its entirety by the more detailed
information and financial statements (including the notes thereto) appearing
elsewhere in this document. Unless otherwise stated, the term "Company" means
Gulfport Energy Corporation, formerly known as WRT Energy Corporation, and its
subsidiaries taken as a whole, either prior to or after the Effective Date (as
defined herein), as the context requires and the term "WRT" or "Debtor" means
WRT Energy Corporation and its subsidiaries taken as a whole prior to the
Effective Date.
Gulfport Energy Corporation owns and operates mature oil and gas
properties in the Louisiana Gulf Coast area. Currently, the Company is seeking
to achieve reserve growth and increase its cash flow by entering into strategic
alliances with companies possessing Gulf Coast exploration experience and by
undertaking lower risk development projects. In July 11, 1997, WRT's
subsidiaries were merged into the Company. On the effective date of the
reorganization, the state of incorporation of the reorganized Company was
changed from the State of Texas to the State of Delaware. Prior to July 11,
1997, the financial statements represented the consolidated financial statements
of WRT and its subsidiaries.
As discussed in Note 3, on February 14, 1996, (the "Petition Date"), WRT
filed a voluntary petition with the Bankruptcy court for the Western District of
Louisiana (the "Bankruptcy Court") for protection under Chapter 11 of the
Bankruptcy Code. On May 5, 1997, the Bankruptcy Court confirmed an Amended Plan
of Reorganization (the "Plan") for WRT and on the effective date an order of
substantial consummation regarding the Plan became final and nonappealable. On
the Effective Date, the Debtor was merged with and into a newly formed Delaware
corporation named "WRT Energy Corporation". Effective July 11, 1997 (the
"Election Date"), the Company implemented fresh start reporting, as defined by
the Accounting Standards Division of the American Institute of Certified Public
Accountants Statement of Position Number 90-7, "Financial Reporting by Entities
in Reorganization Under the Bankruptcy Code" ("SOP 90-7"). Effective March 30,
1998, WRT Energy Corporation underwent a name change to "Gulfport Energy
Corporation".
Principles of Consolidation
In November 1995, WRT formed a wholly owned subsidiary, WRT Technologies,
Inc., which was established to own and operate WRT's proprietary, radioactive,
cased-hole logging technology. Prior to July 11, 1997, the financial statements
were consolidated and include the accounts of WRT and its wholly owned
subsidiary, WRT Technologies, Inc., which was merged into WRT on that date. All
significant intercompany transactions were eliminated during the consolidation
periods.
Cash and Cash Equivalents
The Company considers all highly liquid investments with an original
maturity of three months of less to be cash equivalents for purposes of the
statement of cash flows.
Fair Value of Financial Instruments
At June 30, 1998 and December 31, 1997, the carrying amounts of all
financial instruments approximate their fair market values.
F-32
<PAGE> 91
Oil and Natural Gas Properties
Before July 11, 1997, WRT used the successful efforts method for reporting
oil and gas operations. Commencing with the reorganization, the Company
converted to the full cost pool method of accounting to be in conformity with
the method used by its then principal shareholder, DLB Oil & Gas, Inc. ("DLB").
In connection with the implementation of fresh start reporting commencing
on July 11, 1997 (as described in Note 2), the Company implemented the full cost
pool method of accounting for oil and gas operations. Accordingly, all costs
including nonproductive costs and certain general and administrative costs
associated with acquisition, exploration and development of oil and natural gas
properties are capitalized. Net capitalized costs are limited to the estimated
future net revenues, after income taxes, discounted at 10% per year, from proved
oil and natural gas reserves and the cost of the properties not subject to
amortization. Such capitalized costs, including the estimated future development
costs and site remediation costs, if any, are depleted by an equivalent
units-of-production method, converting natural gas to barrels at the ratio of
six Mcf of natural gas to one barrel of oil. No gain or loss is recognized upon
the disposal of oil and gas properties, unless such dispositions significantly
alter the relationship between capitalized costs and proved oil and natural gas
reserves.
Oil and natural gas properties not subject to amortization consist of the
cost of undeveloped leaseholds. These costs are reviewed periodically by
management for impairment, with the impairment provision included in the cost of
oil and natural gas properties subject to amortization. Factors considered by
management in its impairment assessment include drilling results by the Company
and other operators, the terms of oil and gas leases not held by production, and
available funds for exploration and development.
Prior to July 11, 1997, WRT followed the successful efforts method of
accounting for its oil and gas operations. Under the successful efforts method,
costs of productive wells, development dry holes and productive leases are
capitalized and amortized on a unit-of-production basis over the life of the
remaining proved reserves as estimated by the WRT's independent engineers. WRT's
estimate of future dismantlement and abandonment costs was considered in
computing the aforementioned amortization.
Cost centers for amortization purposes were determined based on a
reasonable aggregation of properties with common geological structures or
stratigraphic conditions, such as a reservoir or field. WRT performed a review
for impairment of proved oil and gas properties on a depletable unit basis when
circumstances suggest the need for such a review. For each depletable unit
determined to be impaired, an impairment loss equal to the difference between
the carrying value and the fair value of the depletable unit was recognized.
Fair value, on a depletable unit basis, was estimated to be the present value of
expected future net cash flows computed by applying estimated future oil and gas
prices, as determined by management, to estimated future production of oil and
gas reserves over the economic lives of the reserves.
Exploration expenses, including geological, geophysical and costs of
carrying and retaining undeveloped properties were charged to expense as
incurred.
Unproved properties were assessed periodically and a loss was recognized
to the extent, if any, that the cost of the property had been impaired. If
proved reserves were not discovered within one year after drilling was
completed, costs were charged to expense.
Other Property and Equipment
Depreciation of other property and equipment is provided on a
straight-line basis over estimated useful lives of the related assets, which
range from 7 to 30 years.
Implementation of Statement of Accounting Standards No. 121
Effective December 31, 1995, WRT adopted the provisions of Financial
Accounting Standards No 121 ("SFAS No. 121") which requires that an impairment
loss be recognized whenever the carrying amount of a long-lived asset exceeds
the sum of the estimated future cash flows (undiscounted) of the assets.
F-33
<PAGE> 92
Earnings (Loss) per Share
Earnings (loss) per share computations are calculated on the
weighted-average of common shares and common share equivalents outstanding
during the year. Common stock options and warrants are considered to be common
share equivalents and are used to calculate earnings per common and common share
equivalents except when they are anti-dilutive.
Income Taxes
The Company uses the asset and liability method of accounting for income
taxes. Under the asset and liability method, deferred tax assets and liabilities
are recognized for the future tax consequences attributable to differences
between the financial statement carrying amounts and the tax basis of existing
assets and liabilities and operating loss and tax credit carryforwards. Deferred
income tax assets and liabilities are based on enacted tax rates applicable to
the future period when those temporary differences are expected to be recovered
or settled. The effect of a change in tax rates on deferred tax assets and
liabilities is recognized in income during the period the rate change is
enacted. Deferred tax assets are recognized as income in the year in which
realization becomes determinable.
Revenue Recognition
Natural gas revenues are recorded in the month produced using the
entitlement method, whereby any production volumes received in excess of the
Company's ownership percentage in the property are recorded as a liability. If
less than the Company's entitlement is received, the underproduction is recorded
as a receivable. Oil revenues are recognized in the month produced.
Concentration of Credit Risk
The Company operates in the oil and natural gas industry in the state of
Louisiana with sales to refineries, re-sellers such as pipeline companies, and
local distribution companies. While certain of these customers are affected by
periodic downturns in the economy in general or in their specific segment of the
natural gas industry, the Company believes that its level of credit-related
losses due to such economic fluctuations has been immaterial and will continue
to be immaterial to the Company's results of operations in the long term.
The Company maintains cash balances at several banks. Accounts at each
bank are insured by the Federal Deposit Insurance Corporation up to $100,000.
Cash balances in excess of insured limits total $3, 987,000 and $3,163,000 at
June 30, 1998 and December 31, 1997, respectively.
Use of Estimates
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates, judgements
and assumptions that affect the reported amounts of assets and liabilities as of
the date of the financial statements and revenues and expenses during the
reporting period. The financial statements are highly dependent on oil and gas
reserve estimates, which are inherently imprecise. Actual results could differ
materially from those estimates.
Stock Options and Warrant Agreements
Effective at the date of reorganization, all previously issued stock
option plans of WRT were terminated and all outstanding options were canceled.
At that date a Warrant Agreement went into effect. These warrants are
exercisable at $10 per share and will expire on July 11, 2002. The Plan
authorized the issuance of up to 1,104,000 warrants. As of June 30, 1998 and
December 31, 1997, there were 221,000 warrants issued and outstanding. See Note
6 for further details.
F-34
<PAGE> 93
Commitments and Contingencies
Liabilities for loss contingencies arising from claims, assessments,
litigation or other sources are recorded when it is probable that a liability
has been incurred and the amount can be reasonably estimated. See Note 8 for
further details.
2. REORGANIZATION PROCEEDING
On February 14, 1996, WRT filed a voluntary petition in the United States
Bankruptcy Court for the Western District of Louisiana (the "Bankruptcy Court")
for reorganization pursuant to Chapter 11 of the Federal Bankruptcy Code (the
"Reorganization Proceeding"). During the balance of 1996 and a portion of 1997,
WRT operated as a debtor-in-possession, continuing in possession of its estate
and the operation of its business and management of its property. On May 5,
1997, the Bankruptcy Court confirmed an Amended Plan of Reorganization (the
"Plan") for WRT. On July 11, 1997, the Bankruptcy Court determined that the Plan
had been substantially consummated, and the Bankruptcy Court's order of
substantial consummation became final and nonappealable on July 11, 1997 (the
"Effective Date").
As a result of the consummation of the Plan and due to; (i) the
reallocation of the voting rights of equity interest owners and (ii) the
reorganization value of WRT's assets being less than the total of all
post-petition liabilities and allowed claims, the effects of the Reorganization
Proceeding were accounted for in accordance with fresh start reporting standards
promulgated under SOP 90-7.
In conjunction with implementing fresh start reporting, management
determined a reorganized value of WRT's assets and liabilities in the following
manner:
The reorganized value of proved oil and natural gas properties was
determined based on future net revenues discounted to present value utilizing a
rate of approximately twenty five percent (25%). For the purpose of calculating
future revenues of oil and natural gas properties, oil and gas prices in effect
at December 31, 1996, were used. The reorganized value of oil and gas properties
also included $5,000,000 allocated to nonproducing properties.
DLB Oil & Gas, Inc. ("DLB") contributed certain interests previously owned
by Texaco Exploration and Production. Inc. ("TEPI") in the West Cote Blanche Bay
Field ("WCBB Assets") along with a $1,000,000 deposit to a plugging and
abandonment trust in exchange for 5,616,000 shares of the reorganized Company's
common stock. This transaction was recorded at DLB's net basis in the WCBB
Assets of $15,144,000. In connection with this acquisition, the Reorganized
Company assumed the obligation to contribute approximately $18,000 per month
through March 2004 to this plugging and abandonment trust and the obligation to
plug a minimum of 20 wells per year for 20 years commencing March 11, 1997. TEPI
retained a security interest in production from these properties and the
plugging and abandonment trust until such time the Company's obligations for
plugging and abandonment to TEPI have been fulfilled. Once the plugging and
abandonment trust is fully funded, the Company can access it for use in plugging
and abandonment charges associated with the property.
In accordance with the Plan, $3,000,000 was set aside by WRT to form a
Litigation Entity (defined herein). The Company owns a 12% interest in this
Litigation Entity. The entire $3,000,000 was included in reorganization expense
on the financial statements for the six months and ten day period ended July 10,
1997. No value was assigned to the Company's interest in the Litigation Entity
on the reorganized balance sheet as management was not able to determine with
any certainty the amount, if any, that the Company might recover from this
investment.
Current assets and liabilities were recorded at book value which
approximates their fair market value. Long-term liabilities were recorded at
present values of amounts to be paid and the pre-consummation stockholders'
deficit was adjusted to reflect the par value of pre-consummation equity
interests and the recognition of $88,723,000 in debt forgiveness income. On the
Effective Date, the shareholders' deficit was closed into paid in capital and
the Company started with no deficit or retained earnings.
F-35
<PAGE> 94
It should be noted that the reorganized value was determined by management
on the basis of its best judgement of what it considers to be current fair
market value of the Company's assets and liabilities after reviewing relevant
facts concerning the price at which similar assets are being sold between
willing buyers and sellers. However, there can be no assurances that the
reorganized value and the fair market value are comparable and the difference
between the Company's calculated reorganized value and the fair market value
may, in fact, be material.
As of July 11, 1997, the effect on the Company's balance sheet of
consummating the Plan and implementing the fresh start reporting was:
<TABLE>
<CAPTION>
JULY 11, 1997 SUBSTANTIAL FRESH START REORGANIZED
PRIOR TO CONSUMMATION REPORTING BALANCE
CONSUMMATION ADJUSTMENTS ADJUSTMENTS SHEET
------------- ------------- ------------- -------------
<S> <C> <C> <C> <C>
ASSETS
Current assets:
Cash and cash equivalents .......................... $ 3,714,000 $ 1,598,000 $ $ 5,312,000
Accounts receivable, net ........................... 3,287,000 3,287,000
Prepaid expenses and other ......................... 870,000 870,000
------------- ------------- ------------- -------------
Total current assets ......................... 7,871,000 1,598,000 9,469,000
------------- ------------- ------------- -------------
Property and equipment:
Properties subject to depletion .................... 80,120,000 15,144,000 (20,187,000) 75,077,000
Properties not subject to depletion ................ -- 5,000,000 5,000,000
Other property, plant, and equipment ............... 5,300,000 (2,362,000) 2,938,000
------------- ------------- ------------- -------------
85,420,000 15,144,000 (17,549,000) 83,015,000
Less accumulated depreciation,
depletion and amortization ................... (29,274,000) 29,274,000 --
------------- ------------- ------------- -------------
56,146,000 15,144,000 11,725,000 83,015,000
------------- ------------- ------------- -------------
Other assets ............................................. 1,231,000 94,000 (285,000) 1,040,000
------------- ------------- ------------- -------------
$ 65,248,000 $ 16,836,000 $ 11,440,000 $ 93,524,000
============= ============= ============= =============
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities:
Accounts payable and accrued liabilities ........... $ 9,545,000 $ (3,771,000) $ $ 5,774,000
Pre-petition secured debt .......................... 16,915,000 (16,915,000) --
------------- ------------- ------------- -------------
Total current liabilities .................... 26,460,000 (20,686,000) 5,774,000
------------- ------------- ------------- -------------
Pre-petition current liabilities subject to compromise:
Unsecured debt ..................................... 136,818,000 (7,012,000) (129,806,000) --
------------- ------------- ------------- -------------
Long-term liabilities:
Other non-current liabilities ...................... -- 757,000 757,000
Notes payable ...................................... -- 15,000,000 15,000,000 --
------------- ------------- ------------- -------------
-- -- 15,757,000 15,757,000
------------- ------------- ------------- -------------
Stockholders' equity (deficit):
Common stock ....................................... 95,000 104,000 22,000 221,000
Preferred stock .................................... 27,677,000 (27,677,000)
Additional paid in capital ......................... 39,570,000 31,673,000 529,000 71,772,000
Treasury stock ..................................... (333,000) 333,000 --
Retained earnings .................................. (165,039,000) (3,000,000) 168,039,000 --
------------- ------------- ------------- -------------
(98,030,000) 28,777,000 141,246,000 71,993,000
------------- ------------- ------------- -------------
$ 65,248,000 $ 16,836,000 $ 11,440,000 $ 93,524,000
============= ============= ============= =============
</TABLE>
Substantial consummation adjustments are those involving cash transactions
occurring on the Effective Date. Fresh start reporting adjustments are those
involving non-cash transactions occurring on the Effective Date.
F-36
<PAGE> 95
In accordance with the provisions of the Plan, the Company:
o Issued to its unsecured creditors, on account of their allowed
claims, an aggregate of 10 million shares of the Reorganized
Company's common stock. At the effective date, 1,412,000 of the
above-described shares were held in escrow to cover the settlement
of disputed unsecured claims in the amount of $18,339,000. Through
June 30, 1998, $10,422,000 of these claims has been settled for
$7,102,000 resulting in the issuance from the escrow account, of
850,000 shares of the Reorganized Company's common stock. Issued
3,800,000 shares of the Reorganized Company's common stock for
$13,300,000 in cash in connection with a stock rights offering to
it's unsecured creditors.
o Issued 952,000 shares of the Reorganized Company's common stock in
payment of $3,332,000 in secured claims.
o Issued 1,703,000 shares of the Reorganized Company's common stock in
payment of a $5,961,000 claim purchased by DLB from TEPI.
o Issued 5,616,000 shares of the Reorganized Company's common stock in
exchange for the WCBB Assets acquired by DLB from TEPI along with
the associated P&A trust fund and associated funding and plugging
obligations. In connection with this transaction, WRT transferred to
TEPI certain assets and non-producing acreage.
The Company paid $1,672,000 in administrative and priority claims,
$1,145,000 in secured claims and $143,000 in convenience claims. At June 30,
1998, $995,000 was being held in escrow to cover settlement of disputed
priority, administrative and secured claims.
The Company transferred $3,000,000 to a Litigation Trust along with the
Company's rights to any and all causes of action, claims, rights of actions,
suits or proceedings which have been or could be asserted by it except for (a)
the action to recover unpaid production proceeds payable to the Company by
Tri-Deck Oil & Gas Company ("Tri-Deck") and (b) the foreclosure action to
recover title to certain assets (See Note 9 regarding the subsequent transfer of
these claims to the Litigation Entity). This transfer was treated as a
pre-reorganization expense on the financial statements for the six months and
ten day period ended July 10, 1997. The Reorganized Company owns a 12% economic
interest in the Litigation Entity and the remainder of the economic interests in
the Litigation Entity was allocated to former unsecured creditors based on their
ownership percentage of the 13.8 million shares as described above.
On January 20, 1998, the Company and the Litigation Trust entered into a
Clarification Agreement whereby the rights to pursue various claims reserved by
the Company in the Plan of Reorganization were assigned to the Litigation Trust.
In connection with this agreement, the Litigation Trust agreed to reimburse the
Company $100,000 for legal fees the Company had incurred in connection with
these claims. As additional consideration for the contribution of this claim to
the Litigation Trust, the Company is entitled to 20% to 80% of the net proceeds
from these claims.
3. RELATED PARTY TRANSACTIONS
Subsequent to the Effective Date of the Plan of Reorganization,
substantially all of the Company's former unsecured creditors became
shareholders. The Company still conducts business on an arms length basis with a
substantial number of these shareholders.
DLB Oil & Gas, Inc. ("DLB") and Wexford Management LLC ("Wexford") were,
along with the Company, co-proponents in the Plan of Reorganization. As of June
30, 1998 and December 31, 1997, DLB and Wexford owned approximately 49% and 8%,
respectively, of the Company's outstanding common stock.
F-37
<PAGE> 96
DLB paid $1,515,000 in reorganization costs incurred on WRT's behalf,
which amount was repaid to DLB on the Effective Date. These costs were included
in reorganization cost incurred during the six months and 10 days ended July 10,
1997. In addition, DLB charged WRT $465,000 for management services provided to
it during the period July 11, 1997 through December 31, 1997. During the period
May 1, 1997 through July 10, 1997, DLB was the operator of the WCBB properties
in which WRT had a 50% working interest at that time. Subsequent to July 10,
1997, the WCBB properties were contributed to the Company for common stock, as
described above, and WRT became the operator of these properties. As of June 30,
1998, the Company owed $1,728,000 to a related party. As of December 31, 1997,
the Company owed $1,728,000 to DLB.
Pursuant to the terms and conditions of an Administrative Services
Agreement dated as of July 10, 1997, by and between the Company and DLB (the
"Services Agreement"), DLB agreed to make available to the Company such
personnel, services, facilities, supplies, and equipment as the Company may need
including executive and managerial, accounting, auditing and tax, engineering,
geological and geophysical, legal, land, and administrative and clerical
services. The initial term (the "Initial Term") is one year beginning on the
date of the Services Agreement. The Services Agreement will continue for
subsequent one-year periods unless terminated by either party by written notice
no less than 60 days prior to the anniversary date of the Services Agreement. In
return for the services rendered, the Company agreed to pay DLB a monthly
service charge based on the pro rata proportion of the Company's use of DLB
services, personnel, facilities, supplies, and equipment as determined by DLB in
a good-faith, reasonable manner. The service charge is calculated as the sum of
(1) DLB's fully allocated internal costs of providing personnel and/or
performing services, (2) the actual costs to DLB of any third-party services
required, (3) the equipment, occupancy, rental, usage, or depreciation and
interest charges, and (4) the actual cost to DLB for supplies. During the year
ended December 31, 1997, the services of Gary C. Hanna and Ronald D. Youtsey,
the Company's President and Secretary respectively, were provided under this
agreement. On April 28, 1998, the rights and obligations of DLB under the
Service Agreement were assigned to DLB Equities, L.L.C. As of March 31, 1998,
Gulfport owed DLB approximately $1,557,000 for services rendered in connection
with this Service Agreement (and for invoices paid by DLB on Gulfport's behalf).
During the three and six months ended June 30, 1998, the Company sold
$877,000 in oil to a DLB subsidiary. During the period July 11, 1997 through
December 31, 1997, the Company sold $4,335,000 in oil to a DLB subsidiary. These
sales occurred at prices which the Company could be expected to obtain from an
unrelated third party.
4. RESTRUCTURING CHARGES AND REORGANIZATION COSTS
WRT incurred certain restructuring costs in connection with its change in
strategy and corporate structure. These costs consisted primarily of the
write-off of approximately $1,000,000 in leasehold improvements related to the
relocation of WRT's operations from The Woodlands, Texas, approximately $300,000
in severance costs related to staff reductions and changes in senior management
and $100,000 in legal fees and other costs directly related to the WRT's
Reorganization Case.
During 1996, WRT incurred $7,345,000 in reorganization costs, primarily
consisting of professional fees totaling $2,594,000 and the write-off of
previously capitalized debt issuance costs on the Senior Notes (herein defined)
in the amount of $3,834,000.
During 1997, WRT incurred $7,771,000 in reorganization costs, consisting of
$3,000,000 contributed to the Litigation Trust (See Note 9 for further details),
$1,515,000 in reimbursements to DLB for restructuring costs it incurred on WRT's
behalf, professional fees totaling $2,213,000, and an accrual of $1,044,000 for
estimated future costs to be incurred in connection with the reorganization. As
of June 30, 1998, the balance of an accrual for estimated future costs to be
incurred in connection with the reorganization was $545,000.
F-38
<PAGE> 97
5. LONG-TERM LIABILITIES
As of June 30, 1998 and December 31, 1997, long term liabilities include
the following:
<TABLE>
<CAPTION>
1998 1997
------------ ------------
<S> <C> <C>
Debt:
Credit facility ...................................... $ 13,229,000 $ 15,000,000
Priority tax claims .................................. 527,000 527,000
Building loan ........................................ 209,000 193,000
------------ ------------
13,931,000 15,720,000
Less current portion ................................. 3,306,000 2,192,000
------------ ------------
$ 10,659,000 $ 13,528,000
============ ============
</TABLE>
Credit Facility
In December 1994, WRT entered into a $40,000,000 credit facility with
International Nederlanden (U.S.) Capital Corporation ("INCC") ("Credit
Facility") that was secured by substantially all of WRT's assets. At December
31, 1996, WRT had borrowings outstanding of $15,000,000, the maximum amount of
borrowings available under the Credit Facility. At December 31, 1995, the
revolving loan borrowings were converted to a term loan whereby quarterly
principal payments of one-sixteenth of the outstanding indebtedness were due and
payable. Amounts outstanding under the Credit Facility bore interest at an
annual rate selected by WRT of either (i) the London Inter-Bank offered rate
("LIBOR") plus 3%, or (ii) the Lender's prime lending rate plus 1.25%.
At December 31, 1996, WRT was in default under certain financial covenants
of the Credit Facility. Accordingly, WRT classified the debt as current at
December 31, 1996. While in bankruptcy, INCC was stayed from enforcing certain
remedies provided for in the credit agreement and the indenture. On the
Effective Date, this loan was repaid in full along with $3,154,000 in accrued
interest and legal fees.
On the Effective Date, the Company entered into a new $15,000,000 Credit
Agreement (the "Credit Agreement") with ING (U.S.) Capital Corporation
(successor to INCC) ("ING") that was secured by substantially all of the
Company's assets. Initial loan fees of $188,000 were paid on or prior to the
Effective Date, an additional loan fee of $100,000 was made on December 31, 1997
and a final loan fee of $100,000 is due on or before December 31, 1998. The loan
matures on July 11, 1999, with interest to be paid quarterly and with three
interim principal payments of $1,000,000 each to be made in September 1998,
December 1998, and March 1999. This loan bears interest at the option of the
Company at either (1) LIBOR plus 3% or (2) ING's fluctuating "reference rate"
plus 1.25%. This loan is collateralized by substantially all of the Company's
assets. At June 30, 1998, this rate was 8.6875%.
The Credit Agreement contains restrictive covenants which impose limitations on
the Company with respect to, among other things: (i) the maintenance of current
assets equal to at least 110% of current liabilities (excluding any current
portion of the Credit Agreement); (ii) the incurrence of debt outside the
ordinary course of business; (iii) dividends and similar payments; (iv) the
creation of additional liens on, or the sale of, the Company's oil and gas
properties and other assets; (v) the Company's ability to enter into forward,
future, swap or hedging contracts; (vi) mergers or consolidations; (vii) the
issuance of securities other that Common Stock and options or warrants granting
the right to purchase Common Stock; (viii) the sale, transfer, lease, exchange,
alienation or disposal of Company properties or assets; (ix) investments outside
the ordinary course of business; (x) transactions with affiliates; (xi) general
and administrative expenditures in excess of $1 million during any fiscal
quarter or in excess of $3 million during each fiscal year; and (xii) the
maintenance of an aggregate net present value attributable to all collateral as
determined from engineering reports equal to 120% of the principal amount of the
Credit Agreement on such date.
On August 18, 1998, the Company amended the Credit Agreement (the "Amended
Credit Agreement" to, among other things: (i) delete the coverage ration set
forth in the Credit Agreement, and (ii) require interest payments to be made by
the Company on a monthly basis. The principal amount and the interest rate set
forth in the Credit Agreement remain unchanged. In connection with the execution
and delivery of the Amended Credit Agreement, ING waived certain provisions of
the Credit Agreement to permit certain actions by
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<PAGE> 98
the Company. In consideration for entering into the Amended Credit Agreement and
granting certain waivers, the Company and ING further agreed that (a) the
Company will pay a $250,000 amendment fee to ING on July 11, 1999, provided that
such amendment fee will be waived if the amounts owed to ING under the Amended
Credit Agreement have been paid in full by July 10, 1999; and (b) the Company
shall issue warrants to ING, in that such warrants will permit ING to purchase
2% of the outstanding shares of Common Stock on a fully diluted basis after
giving effect to future Rights Offerings.
At December 31, 1997, the Company held $2,060,000 in a restricted cash
account. These funds represent the proceeds from the sale of its field
equipment. As of June 30, 1998, the Company had applied $1,778,000 of these
funds to the outstanding principal balance of the ING loan.
Priority Tax Claims
In accordance with the Plan of Reorganization, priority taxes totaling
$1,168,000 are to be paid in four annual installments without interest. The
first annual installment of $292,000 was made on July 11, 1997 and the second
annual installment of $291,000 was made on July 11, 1998.
Building Loan
During early 1996, WRT entered into a loan agreement with M C Bank and
Trust Company to finance the acquisition of land and a building located in
Lafayette, Louisiana. The original loan balance was $215,000 and called for
monthly principal and interest payments totaling $3,000 per month through 2005
with the unpaid balance due at that time. The loan bears interest at 9.5% per
annum and is collateralized by the land and building.
6. COMMON STOCK OPTIONS AND WARRANTS
All outstanding stock options and warrants issued prior to July 11, 1997,
were cancelled in connection with the Plan of Reorganization.
On July 10, 1997, WRT entered into an employment agreement with Mr. Ray Landry,
WRT's former president, to perform certain services for the Company. In
connection with this employment agreement, Mr. Landry was granted Incentive
Stock Options to acquire 60,000 shares of the Company's common stock for $3.50
per share. The employment agreement does not specify the life of these options.
In connection with the Plan of Reorganization, new warrants for 221,000
shares of the Reorganized Company common stock were issued to the former
preferred shareholders. In addition, to the extent that any securities
litigation claims based on preferred or common stock ownership are allowed as a
"Class Proof of Claim", the Company has the obligation to issue this class an
additional 221,000 in warrants to purchase common stock in the Reorganized
Company. These warrants are each exercisable for one share of common stock at an
exercise price of $10 per share. The warrants will expire on July 11, 2007. In
accordance with the Plan of Reorganization, the Company has the right to issue
up to 1,104,000 warrants.
7. EARNINGS (LOSS) PER SHARE
Earnings per share for all periods were computed based on common stock
equivalents outstanding on that date during the applicable periods.
8. COMMITMENTS AND CONTINGENCIES
Lac Blanc Escrow Account
In connection with its purchase of a 91% working interest in the Lac Blanc
Field, the Company deposited $170,000 in a segregated trust account and agreed
to make additional deposits of $20,000 per month until the
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accumulated balance of the trust account reached $1,700,000. These funds are
held in a segregated account for the benefit of the State of Louisiana to insure
that the wells in the Lac Blanc Field are properly plugged upon cessation of
production. In return for this financial commitment, the State of Louisiana has
granted the sellers an unconditional release from their contingent liability to
the State to plug and abandon the wells. When all existing wells in the Lac
Blanc Field have been properly plugged and abandoned, the funds in the trust
account, should any remain, will revert to the Company. Due to the filing of the
Reorganization Case in February 1996, the Company ceased making contributions to
the segregated account. Under the Plan, the Company is obligated to fund the
unfunded portion of this obligation and maintain future funding requirements. At
June 30, 1998, the balance in this trust account was $871,000. In addition, the
Company has accrued $200,000 at June 30, 1998; such accrual representing the
unfunded portion of this obligation since the Effective Date.
Plugging and Abandonment Funds
The Company is contractually committed in its purchase contracts for the
Initial LLOG Property (defined herein) and Remaining LLOG Properties (defined
herein) to establish plugging and abandonment funds as allowed by Louisiana's
Orphaned Well Act. The State of Louisiana, upon completion of an independent
study to be commissioned by the Company, will establish the amount of and terms
of payment into each fund. As of June 30, 1998, the independent study had not
been completed. Accordingly, the Company is unable to determine the amount and
payment towards the future obligation related to these commitments.
In connection with the acquisition of the remaining 50% interest in
certain WCBB properties, the Company assumed the obligation to contribute
approximately $18,000 per month through March 2004, to a plugging and
abandonment trust fund and the obligation to plug a minimum of 20 wells per year
for 20 years commencing March 11, 1997. TEPI retained a security interest in
production from these properties and the plugging and abandonment trust account
until such time the Company's plugging and abandonment obligations to TEPI have
been fulfilled. Once the plugging and abandonment trust is fully funded, the
Company can access the fund for use in plugging and abandonment costs associated
with the WCBB property. The Company satisfied its plugging and abandonment
obligations through the year ended March 10, 1998.
Tri-Deck/Perry Gas Litigation
During 1995, WRT entered into a marketing agreement with Tri-Deck Oil and
Gas Company ("Tri-Deck") pursuant to which Tri-Deck would market all of WRT's
oil and gas production. Subsequent to the agreement, Tri-Deck's principal and
WRT's Director of Marketing, James Florence, assigned to Plains Marketing its
right to market WRT's oil production and assigned to Perry Oil & Gas its right
to market WRT's gas production. During early 1996, Tri-Deck failed to make
payments to WRT attributable to several months of its gas production.
Consequently, WRT responded in two ways. First, on May 20, 1996, WRT filed a
Motion to Reject the Tri-Deck Marketing Agreement. Second, on May 29, 1996, WRT
initiated an adversary proceeding against Tri-Deck and Perry Oil and Gas ("Perry
Gas"). Perry Gas was the party, which ultimately purchased WRT's gas production
for the months in question.
With respect to the Motion to Reject, the Bankruptcy Court authorized the
rejection and directed Tri-Deck and WRT to determine the amount of production
proceeds attributable to WRT's June gas production which were payable to WRT.
Consequently, Perry Gas thereafter made payment to WRT of the June gas proceeds
less $75,000 for a set-off claim by Perry Gas, which is subject to further
consideration by the Bankruptcy Court.
Next, with respect to the adversary proceeding, WRT sought turnover by
Tri-Deck and/or Perry Gas of all unpaid production proceeds payable to WRT under
the marketing agreement and the issuance of a temporary restraining order and
preliminary injunction against both parties to prevent further disposition of
such proceeds pending outcome of the proceedings. On May 31, 1996, the
Bankruptcy Court entered a consensual temporary restraining order against both
Tri-Deck and Perry Gas. On June 18, 1996, a Preliminary Injunction was entered
by the Court which required Perry Gas to segregate into a separate depository
account the funds due for the purchase of WRT's April and May 1996 gas
production from Tri-Deck. Subsequently, upon motion by WRT the Court ordered
such funds to be placed into the Bankruptcy Court's registry, as Perry Gas had
made certain withdrawals from the separate depository account without
authorization by the Court. Currently, funds in the amount of approximately
$1,700,000 remain in the registry of the Court. Additionally, a dispute exists
between WRT and Perry Gas as to
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additional funds owed by Perry Gas for the purchase of WRT's April and May 1996
gas production. Currently, the adversary proceeding remains pending as to the
ultimate issue of ownership of proceeds. Tri-Deck has also filed an answer and
counterclaim in which Tri-Deck is asserting, among other items, damages for
tortoise interference of its contractual relationships with others. Recovery of
the $1,700,000 receivable is dependent on the court rendering a favorable ruling
on the issue. As of the date of the report, the court has not ruled on this
issue. Although management believes that Tri-Deck's claim to the funds in the
registry of the court is invalid, and the aforementioned counterclaim is without
merit, for financial reporting purposes the receivable from Tri-Deck was fully
reserved for as of June 30, 1998.
On January 20, 1998, the Company and the Litigation Trust entered into a
Clarification Agreement whereby the rights to pursue the Tri-Deck claim were
assigned to the Litigation Trust. In connection with this agreement, the
Litigation Trust agreed to reimburse the Company $100,000 for legal fees the
Company had incurred in connection with this and other related claims. As
additional consideration for the contribution of this claim to the Litigation
Trust, the Company is entitled to 85% of the net proceeds from this claim.
Title to Oil and Gas Properties
During 1996, WRT received notice from Wildwing Investments, Inc.
("Wildwing") claiming that WRT's title had failed as to approximately 43 acres
in the Bayou Pigeon Field. Some or all of the acreage in dispute is considered
to be productive in three separate production units. The Company's working
interest in three units was reduced to approximately 7% (5% Net Revenue
Interest, ("NRI")) 75% (63% NRI), and 95% (72% NRI). The financial statements as
of and for the periods ending June 30, 1998 and December 31, 1997, reflect
operating results and proved reserves discounted for of this possible title
failure. As the title failure predates its ownership of the field, the Company
is currently evaluating its recourse against the predecessors-in-title relative
to this issue.
During 1997, Wildwing initiated litigation against the Company entitled
"Wildwing Investments, Inc. v. WRT Energy Corporation," pending in the Fifteenth
Judicial District Court, Parish of Lafayette, State of Louisiana ("Lafayette
Litigation"). This case was settled on February 28, 1998. The terms of the
settlement are that Plains Resource & Transportation, Inc. ("Plains") and
Wickford Energy Marketing, L.C. ("Wickford")(collectively "Stakeholders"), who
are currently holding funds in suspense attributable to oil production from the
lease made subject of the lawsuit, will be instructed by the Company and
Wildwing to distribute $270,000 to Wildwing in full and final compromise of the
Lafayette Litigation. Additional sums held by the Stakeholders are to be
distributed to the lessors of the leases made the subject of the Lafayette
Litigation an amount for payment of royalties due and owing up to the date of
this filing. The balance held by the Stakeholders will thereafter be distributed
to the Company.
One June 29, 1998, Plains remitted to the Company, the balance of funds
held in suspense attributable to this lease. As of this filing date, final
distribution to the lessors was not complete. On July 31, 1998, Wickford
distributed suspended oil proceeds to the lessors and remitted the balance to
the Company.
On July 20, 1998, Sanchez Oil & Gas Corporation ("Sanchez") initiated
litigation against the Company in the Fifteenth Judicial District Court, Parish
of Lafayette, State of Louisiana. In it petition, Sanchez alleges, among other
things, that the Company was obligated, by virtue of the terms of a letter dated
June 26, 1997, between Sanchez and the Company (the "Sanchez Letter"), to grant
a sublease to Sanchez for an undivided 50% interest in two of the Company's oil,
gas and mineral leases covering land located in the North Bayou Penchant area of
Terrebonne Parish, Louisiana. Pursuant to this lawsuit, Sanchez is seeking: (i)
specific performance by the Company of the contractual obligation that Sanchez
alleges to be present in the Sanchez Letter, and (ii) monetary damages. The
litigation is in its earliest stages and discovery has not yet begun. In
addition, the Company is currently reviewing the claims set forth in the lawsuit
to determine the appropriate response thereto.
Year 2000 Compliance
The Company has and will continue to make certain investments in software
systems and applications to ensure it is year 2000 complaint. The financial
impact to the Company to ensure year 2000 compliance has not been and is not
anticipated to be material to its financial position or results of operations.
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Other litigation
The Company has been named as a defendant on various other litigation
matters. The ultimate resolution of these matters is not expected to have a
material adverse effect on the Company's financial condition or results of
operations for the periods presented in the financial statements.
9. LITIGATION TRUST ENTITY
On August 13, 1996, the Bankruptcy Court executed and entered its "Order
Appointing Examiner", directing the United States Trustee to appoint a
disinterested person as examiner in the WRT's bankruptcy case.
The Court ordered the appointed examiner ("Examiner") to file a report of
the investigation conducted, including any fact ascertained by the examiner
pertaining to fraud, dishonesty, incompetence, misconduct, mismanagement or
irregularity in the management of the affairs of WRT.
The Examiner's final report dated April 2, 1997, recommended numerous
actions for recovery of property or damages for WRT's estate which appear to
exist and should be pursued. Management does not believe the resolution of the
matters referred to in the Examiner's report will have a material impact on
WRT's consolidated financial statements or results of operations.
Pursuant to the Plan of Reorganization, all of WRT's possible causes of
action against third parties (with the exception of certain litigation related
to recovery of marine and rig equipment assets and claims against Tri-Deck),
existing as of the effective date of the Plan, were transferred into a
"Litigation Trust" controlled by an independent party for the benefit of most of
WRT's existing unsecured creditors. The litigation related to recovery of marine
and rig equipment and the Tri-Deck claims were subsequently transferred to the
litigation trust as described below.
The Litigation Trust was funded by a $3,000,000 cash payment from the
Company, which was made on the Effective Date. The Company owns a 12% interest
in the Litigation Trust with the other 88% being owned by the former general
unsecured creditors of WRT. For financial statement reporting purposes, the
Company has not recognized the potential value of recoveries which may
ultimately be obtained, if any, as a result of the actions of the Litigation
Trust, treating the entire $3,000,000 payment as a reorganization cost incurred
during the period commencing January 1, 1997 and ending on July 10, 1997.
On January 20, 1998, the Company and the Litigation Trust entered into a
Clarification Agreement whereby the rights to pursue various claims reserved by
the Company in the Plan of Reorganization were assigned to the Litigation Trust.
In connection with this agreement, the Litigation Trust agreed to reimburse the
Company $100,000 for legal fees the Company had incurred in connection with
these claims. As additional consideration for the contribution of this claim to
the Litigation Trust, the Company is entitled to 20% to 80% of the net proceeds
from these claims.
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================================================================================
NO DEALER, SALESPERSON OR ANY OTHER PERSON HAS BEEN AUTHORIZED TO GIVE ANY
INFORMATION OR MAKE ANY REPRESENTATIONS IN CONNECTION WITH THE OFFER CONTAINED
HEREIN, OTHER THAN THOSE CONTAINED IN THIS PROSPECTUS, AND, IF GIVEN OR MADE,
SUCH INFORMATION OR REPRESENTATIONS MUST NOT BE RELIED UPON AS HAVING BEEN
AUTHORIZED BY THE COMPANY. THIS PROSPECTUS DOES NOT CONSTITUTE AN OFFER TO SELL
OR A SOLICITATION OF AN OFFER TO BUY ANY SECURITY OTHER THAN THOSE TO WHICH IT
RELATES NOR DOES IT CONSTITUTE AN OFFER TO SELL, OR A SOLICITATION OF AN OFFER
TO BUY, ANY SECURITY TO ANY PERSON IN ANY JURISDICTION IN WHICH SUCH OFFER OR
SOLICITATION IS NOT AUTHORIZED, OR IN WHICH THE PERSON MAKING SUCH OFFER OR
SOLICITATION IS NOT QUALIFIED TO DO SO, OR TO ANY PERSON TO WHOM IT IS UNLAWFUL
TO MAKE SUCH OFFER OR SOLICITATION. NEITHER THE DELIVERY OF THIS PROSPECTUS NOR
ANY SALE MADE HEREUNDER SHALL, UNDER ANY CIRCUMSTANCES, CREATE ANY IMPLICATION
THAT THERE HAS BEEN NO CHANGE IN THE AFFAIRS OF THE COMPANY SINCE THE DATE
HEREOF OR THAT THE INFORMATION CONTAINED HEREIN IS CORRECT AS OF ANY TIME
SUBSEQUENT TO THE DATE HEREOF.
---------------------
TABLE OF CONTENTS
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
Prospectus Summary.....................................................1
Risk Factors...........................................................5
Use of Proceeds.......................................................11
Capitalization........................................................12
Price Range of Common Stock and Dividend Policy.......................13
The Rights Offering...................................................14
Selected Historical Financial Data....................................19
Management's Discussion and Analysis of Financial Condition
and Results of Operations...........................................20
Business..............................................................32
Management............................................................45
Principal Stockholders................................................48
Certain Transactions..................................................49
Description of Securities.............................................50
Certain Federal Income Tax Considerations.............................51
Legal Matters.........................................................52
Experts...............................................................52
Glossary of Certain Oil and Gas Terms................................G-1
Index To Consolidated Financial Statements...........................F-1
</TABLE>
================================================================================
================================================================================
100,000,000 SHARES
GULFPORT ENERGY CORPORATION
COMMON STOCK
----------------
PROSPECTUS
----------------
_______________, 1998
================================================================================
<PAGE> 103
PART II
INFORMATION NOT REQUIRED IN PROSPECTUS
ITEM 13. OTHER EXPENSES OF ISSUANCE AND DISTRIBUTION.
The estimated expenses in connection with the issuance and distribution of
the securities being registered are set forth in the following table. All of
such expenses will be borne by the Registrant.
<TABLE>
<S> <C>
SEC registration fees..................................................... $ 2,950
Printing and engraving expenses........................................... *
Legal fees and expenses................................................... *
Accounting fees and expenses.............................................. *
Blue sky fees and expenses................................................ *
Transfer agent and registrar fees and expenses............................ *
Miscellaneous............................................................. *
------------
Total............................................................... $ *
============
</TABLE>
*To be filed by amendment
ITEM 14. INDEMNIFICATION OF DIRECTORS AND OFFICERS
The Registrant, a Delaware corporation, is empowered by Section 145 of the
DGCL, subject to the procedures and limitations stated therein, to indemnify
certain parties. Section 145 of the DGCL provides in part that a corporation
shall have the power to indemnify any person who was or is a party or is
threatened to be made a party to any threatened, pending or completed action,
suit or proceeding (other than an action by or in the right of the corporation)
by reason of the fact that such person is or was a director, officer, employee
or agent of the corporation or is or was serving at the request of the
corporation as a director, officer, employee or agent of another corporation or
other enterprise, against expenses (including attorneys' fees), judgments, fines
and amounts paid in settlement actually and reasonably incurred by him in
connection with such action, suit or proceeding if he acted in good faith and in
a manner he reasonably believed to be in or not opposed to the best interests of
the corporation, and with respect to any criminal action or proceeding, had no
reasonable cause to believe his conduct was unlawful. Similar indemnity is
authorized for such persons against expenses (including attorneys' fees)
actually and reasonably incurred in the defense or settlement of any threatened,
pending or completed action or suit by or in the right of the corporation, if
such person acted in good faith and in a manner he reasonably believed to be in
or not opposed to the best interests of the corporation, and provided further
that (unless a court of competent jurisdiction otherwise provides) such person
shall not have been adjudged liable to the corporation. Any such indemnification
may be made only as authorized in each specific case upon a determination by the
stockholders or disinterested directors that indemnification is proper because
the indemnitee has met the applicable standard of conduct. Where an officer or a
director is successful on the merits or otherwise in the defense of any action
referred to above, the corporation must indemnify him against the expenses which
such officer or director actually or reasonably incurred. Section 145 provides
further that indemnification pursuant to its provisions is not exclusive of
other rights of indemnification to which a person may be entitled under any
bylaw, agreement, vote of stockholders or disinterested directors or otherwise.
The Registrant's Bylaws provide that the Registrant shall indemnify and
advance expenses to each person who is a director or officer of the Registrant
to the fullest extent permitted under Section 145 of the DGCL, and such
indemnity and advancement of expenses shall continue as to a person who has
ceased to be a director or officer and shall inure to the benefit of the heirs,
executors and administrators of such a person.
Article VI of the Registrant's Certificate of Incorporation eliminates the
personal liability of the Registrant's directors to the fullest extent permitted
under Section 102(b)(7) of the DGCL, as amended. Such section permits a
company's certificate of incorporation to eliminate or limit the personal
liability of a director to the corporation or its stockholders for monetary
damages for breach of fiduciary duty as a director, provided that such provision
shall not eliminate or limit the liability of a director: (i) for any breach of
the director's duty of loyalty to the corporation
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<PAGE> 104
or its stockholders; (ii) for acts or omissions not in good faith or which
involve intentional misconduct or a knowing violation of law; (iii) under
Section 174 of the DGCL (which addresses director liability for unlawful payment
of a dividend or unlawful stock purchase or redemption) or (iv) for any
transaction from which the director derived an improper personal benefit.
Article VI of the Bylaws of the Registrant provides that the Registrant
shall, to the fullest extent permitted by Delaware law, indemnify any and all
persons whom it shall have power to indemnify against any and all of the costs,
expenses, liabilities or other matters incurred by them by reason of having been
officers or directors of the Registrant, any such subsidiary of the Registrant
or of any other corporation for which he acted as officer or director at the
request of the Registrant.
The Registrant maintains director and officer liability insurance
providing insurance protection for specified liabilities under specified terms.
The Registrant has adopted provisions in its Bylaws and in its Certificate
which provide for indemnification of its officers and directors to the maximum
extent permitted under the DGCL. In addition, the Registrant has entered into
separate indemnification agreements with each of its directors which may require
the Registrant, among other things, to indemnify them against certain
liabilities that may arise by reason of their status or service as directors to
the maximum extent permitted under the DGCL, to advance their expenses incurred
as a result of any proceeding against them as to which they could be
indemnified, and to establish a trust for the provision of such expenses under
certain circumstances.
ITEM 15. RECENT SALES OF UNREGISTERED SECURITIES
The following information relates to all securities issued or sold by the
Registrant since inception and not registered under the Securities Act.
Each of the transactions described below was conducted in reliance upon
the exemption from registration for securities issued pursuant to a plan of
reorganization provided in section 1145 of the Bankruptcy Code.
By order dated May 2, 1997, the Bankruptcy Court confirmed a Plan of Old
WRT and co-proponents DLB and Wexford Management. The Plan was consummated and
became effective on July 11, 1997 when Old WRT was merged with and into
Gulfport. Along with the cancellation of Old WRT's common stock and preferred
stock, the Plan involved (i) the issuance by Gulfport to Old WRT's unsecured
creditors, on account of their allowed claims, of an aggregate of 10,000,000
shares of Common Stock, (ii) the issuance by Gulfport to Old WRT's unsecured
creditors, on account of their allowed claims, of the right to purchase an
additional 3,800,000 of Common Stock at a purchase price of $3.50 per share,
(iii) the issuance by Gulfport to DLBW and affiliates of the number of shares of
Common Stock obtained by dividing DLBW's Secured Claim amount by a conversion
price of $3.50 per share, (iv) the purchase by DLBW of all shares of Common
Stock not otherwise purchased pursuant to the 1997 Rights Offering, (v) the
transfer by DLB of the WCBB Assets to Gulfport along with the associated P&A
Trust fund and associated funding obligation in exchange for 5,000,000 of Common
Stock, and (vi) the distribution of warrants to purchase Common Stock at an
exercise price of $10.00 per share to holders of certain securities litigation
claims against Old WRT and to holders of Old WRT's common stock and preferred
stock.
On August 18, 1998, as consideration for ING entering into the Amended
Credit Agreement and granting certain waivers, the Registrant issued warrants to
purchase 2% of the outstanding shares of Common Stock on a fully diluted basis
after giving effect to the Rights Offering (subject to a reduction to 1.5% if
certain farmout agreements proposed by the Company are not approved by ING) at
per share exercise price of the average of the closing sales prices of the
Common Stock over the 30-day period following the consummation of the Rights
Offering.
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ITEM 16. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
(a) Exhibits:
<TABLE>
<CAPTION>
EXHIBIT NO. DESCRIPTION
----------- -----------
<S> <C> <C>
2.1 -- Final order authorizing use of proceeds from oil and gas operations(1)
2.2 -- Letter agreement by and among WRT Energy Corporation, DLB Oil & Gas, Inc. and
Wexford Management, LLC, dated October 22, 1996 and amended October 28, 1996.(2)
2.3 -- Debtor's and DLBW's First Amended Joint Plan of Reorganization Under chapter 11
of the United States Bankruptcy Code, dated January 20, 1997.(3)
2.4 -- First Amended Disclosure Statement Under 11 U.S.C.ss. 1125 In Support of
Debtor's and DLBW's First Amended Joint Plan of Reorganization Under Chapter 11
of the United States Bankruptcy Code, dated January 20, 1997.(3)
2.5 -- Agreement and Plan of Merger, dated as of July 10, 1997 by and between WRT
Energy Corporation, a Texas corporation and WRT Energy Corporation, a Delaware
corporation.(4)
3.1 -- Restated Certificate of Incorporation.(6)
3.2 -- Certificate of Amendment of the Restated Certificate of Incorporation.(6)
3.3 -- Bylaws.(6)
4.1* -- Form of Rights Certificate.
4.2* -- Form of Transmittal Letter from registrant to stockholders in connection with
the Rights Offering.
4.3 -- Credit Agreement, dated as of July 10, 1997, by and between WRT Energy
Corporation and ING (U.S.) Capital Corporation ("ING").(6)
4.4* -- Amendment No. 1 to Credit Agreement, dated as of August 18, 1998, by and between
the Company and ING.
4.5* -- Subordination Agreement, dated as of August 18, 1998, by and between ING and the
Subordinated Creditors named therein.
5* -- Opinion of Akin, Gump, Strauss, Hauer & Feld, L.L.P.
10.1 -- Employment Agreement, dated as of July 10, 1997 by and between WRT Energy Corporation
and Raymond P. Landry.(6)
10.2* -- Revolving Line of Credit Agreement, dated as of August 18, 1998, by and among
the Company, Wexford Special Situations 1996, L.P., Wexford Special Situations
1996 Institutional, L.P., Wexford Special Situations 1996, Limited,
Wexford-Euris Special Situations 1996, L.P., Wexford Spectrum Investors LLC,
Wexford Capital Partners II, L.P., Wexford Overseas Partners I, L.P., CD Holding
Company LLC, Liddell Investments LLC and Liddell Holdings LLC.
23.1** -- Consent of Hogan & Slovacek, independent public accountants.
23.2** -- Consent of Netherland, Sewell & Associates, independent petroleum engineers.
24.1** -- Power of Attorney (included on signature page of this Registration Statement).
27.1* -- Financial Data Schedule.
</TABLE>
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- ----------
* To be filed by amendment.
** Filed herewith.
(1) FILED WITH FORM 8-K DATED MARCH 14, 1997.
(2) Filed with Form 8-K dated November 6, 1996.
(3) Filed with Form 8-K dated March 3, 1997.
(4) Filed with Form 8-K dated July 22, 1997.
(5) Filed with Form 10-Q dated May 15, 1998.
(6) Filed with Form 10-Q dated December 1, 1997.
ITEM 17. UNDERTAKINGS
(a) The undersigned registrant hereby undertakes:
(1) To file, during any period in which offers or sales are
being made, a post-effective amendment to this Registration Statement:
(i) To include any prospectus required by Section 10(a)(3)
of the Securities Act;
(ii) To reflect in the prospectus any facts or events
arising after the effective date of this Registration Statement (or the
most recent post-effective amendment thereof) which, individually or in
the aggregate, represent a fundamental change in the information set
forth in the Registration Statement;
(iii) To include any material information with respect to
the plan of distribution not previously disclosed in this Registration
Statement or any material change to such information in this Registration
Statement;
provided, however, that paragraphs (a)(1)(i) and (a)(1)(ii) do not apply if the
Registration Statement is on Form S-3 or Form S-8 and the information required
to be included in a post-effective amendment by those paragraphs is contained in
periodic reports filed with or furnished to the Commission by the registrant
pursuant to Section 13 or 15(d) of the Exchange Act that are incorporated by
reference in the Registration Statement.
(2) That, for the purpose of determining any liability under the
Securities Act, each such post-effective amendment shall be deemed to be a new
registration statement relating to the securities offered therein, and the
offering of such securities at that time shall be deemed to be the initial bona
fide offering thereof.
(3) To remove from registration by means of a post-effective
amendment any of the securities being registered which remain unsold at the
termination of the offering.
(b) The undersigned registrant hereby undertakes that:
(1) For purposes of determining any liability under the Securities
Act, the information omitted from the form of prospectus filed as part of
this registration statement in reliance upon Rule 430A and contained in a
form of prospectus filed by the registrant pursuant to Rule 424(b)(1) or
(4) or 497(h) under the Securities Act shall be deemed to be part of this
Registration Statement as of the time it was declared effective.
(2) For purposes of determining any liability under the Securities
Act, each post-effective amendment that contains a form of prospectus
shall be deemed to be a new registration statement relating to the
securities offered therein, and the offering of such securities at that
time shall be deemed to be the initial bona fide offering thereof.
(c) Insofar as indemnification for liabilities arising under the
Securities Act may be permitted to directors, officers, and controlling persons
of the registrant pursuant to the foregoing provisions, or otherwise, the
registrant has been advised that in the opinion of the Commission such
indemnification is against public policy as expressed in the Securities Act and
is, therefore, unenforceable. In the event that a claim for indemnification
against such liabilities (other than the payment by the registrant of expenses
incurred or paid by a director, officer or controlling person of the registrant
in the successful defense of any action, suit or proceeding) is asserted by such
II-4
<PAGE> 107
director, officer or controlling person in connection with the securities being
registered, the registrant will, unless in the opinion of its counsel the matter
has been settled by controlling precedent, submit to a court of appropriate
jurisdiction the question whether such indemnification by it is against public
policy as expressed in the Securities Act and will be governed by the final
adjudication of such issue.
II-5
<PAGE> 108
SIGNATURES
Pursuant to the requirements of the Securities Act of 1933, the registrant
has duly caused this Registration Statement to be signed on its behalf by the
undersigned, thereunto duly authorized, in the City of Oklahoma City, State of
Oklahoma, on August 31, 1998.
GULFPORT ENERGY CORPORATION
By: /s/ MARK LIDDELL
----------------------------------
The undersigned directors and officers of Gulfport Energy Corporation
hereby constitute and appoint Mark Liddell and Mike Liddell, and each of them,
with full power to act without the other and with full power of substitution and
resubstitution, our true and lawful attorneys-in-fact with full power to execute
in our name and behalf in the capacities indicated below any and all amendments
(including post-effective amendments and amendments thereto) to this
Registration Statement and any registration statement for the same offering that
is to be effective upon filing pursuant to Rule 462(b) under the Securities Act
of 1933, as amended, and to file the same, with all exhibits thereto and other
documents in connection therewith with the Securities and Exchange Commission
and hereby ratify and confirm all that such attorneys-in-fact, or either of
them, or their substitutes shall lawfully do or cause to be done by virtue
hereof.
Pursuant to the requirements of the Securities Act of 1933, as amended,
this Registration Statement has been signed by the following persons in the
capacities indicated on August 31, 1998.
<TABLE>
<CAPTION>
NAME TITLE
---- -----
<S> <C>
/s/ MARK LIDDELL President and Director (Principal
- --------------------------------------------- Executive Officer)
Mark Liddell
/s/ MIKE LIDDELL Chief Executive Officer and Director
- ---------------------------------------------
Mike Liddell
/s/ RONALD D. YOUTSEY Chief Financial Officer, Secretary and
- --------------------------------------------- Treasurer (Principal Financial Officer)
Ronald D. Youtsey
/s/ CHARLES E. DAVIDSON Director
- ---------------------------------------------
Charles E. Davidson
/s/ Director
- ---------------------------------------------
Robert Brooks
/s/ Director
- ---------------------------------------------
David Houston
</TABLE>
S-1
<PAGE> 109
INDEX TO EXHIBITS
<TABLE>
<CAPTION>
EXHIBIT NO. DESCRIPTION
----------- -----------
<S> <C> <C>
2.1 -- Final order authorizing use of proceeds from oil and gas operations(1)
2.2 -- Letter agreement by and among WRT Energy Corporation, DLB Oil & Gas, Inc. and
Wexford Management, LLC, dated October 22, 1996 and amended October 28, 1996.(2)
2.3 -- Debtor's and DLBW's First Amended Joint Plan of Reorganization Under chapter 11
of the United States Bankruptcy Code, dated January 20, 1997.(3)
2.4 -- First Amended Disclosure Statement Under 11 U.S.C.ss. 1125 In Support of
Debtor's and DLBW's First Amended Joint Plan of Reorganization Under Chapter 11
of the United States Bankruptcy Code, dated January 20, 1997.(3)
2.5 -- Agreement and Plan of Merger, dated as of July 10, 1997 by and between WRT
Energy Corporation, a Texas corporation and WRT Energy Corporation, a Delaware
corporation.(4)
3.1 -- Restated Certificate of Incorporation.(6)
3.2 -- Certificate of Amendment of the Restated Certificate of Incorporation.(6)
3.3 -- Bylaws.(6)
4.1* -- Form of Rights Certificate.
4.2* -- Form of Transmittal Letter from registrant to stockholders in connection with
the Rights Offering.
4.3 -- Credit Agreement, dated as of July 10, 1997, by and between WRT Energy
Corporation and ING (U.S.) Capital Corporation ("ING").(6)
4.4* -- Amendment No. 1 to Credit Agreement, dated as of August 18, 1998, by and between
the Company and ING.
4.5* -- Subordination Agreement, dated as of August 18, 1998, by and between ING and the
Subordinated Creditors named therein.
5* -- Opinion of Akin, Gump, Strauss, Hauer & Feld, L.L.P.
10.1 -- Employment Agreement, dated as of July 10, 1997 by and between WRT Energy Corporation
and Raymond P. Landry.(6)
10.2* -- Revolving Line of Credit Agreement, dated as of August 18, 1998, by and among
the Company, Wexford Special Situations 1996, L.P., Wexford Special Situations
1996 Institutional, L.P., Wexford Special Situations 1996, Limited,
Wexford-Euris Special Situations 1996, L.P., Wexford Spectrum Investors LLC,
Wexford Capital Partners II, L.P., Wexford Overseas Partners I, L.P., CD Holding
Company LLC, Liddell Investments LLC and Liddell Holdings LLC.
23.1** -- Consent of Hogan & Slovacek, independent public accountants.
23.2** -- Consent of Netherland, Sewell & Associates, independent petroleum engineers.
24.1** -- Power of Attorney (included on signature page of this Registration Statement).
27.1* -- Financial Data Schedule.
</TABLE>
* To be filed by amendment.
** Filed herewith.
(1) FILED WITH FORM 8-K DATED MARCH 14, 1997.
(2) Filed with Form 8-K dated November 6, 1996.
(3) Filed with Form 8-K dated March 3, 1997.
(4) Filed with Form 8-K dated July 22, 1997.
(5) Filed with Form 10-Q dated May 15, 1998.
(6) Filed with Form 10-Q dated December 1, 1997.
<PAGE> 1
HOGAN & SLOVACEK
A Professional Corporation
Certified Public Accounts
Harvey Parkway
301 N.W. 63rd, Suite 290
Oklahoma City, Oklahoma 73116
Office (405) 848-2020 Fax (405) 848-7359
INDEPENDENT AUDITOR'S CONSENT
We consent to the use of our reports dated March 27, 1998, with respect to
the pre-emergence and post emergence financial statements of Gulfport Energy
Corporation included in this Form S-1 of Gulfport Energy Corporation.
/s/ HOGAN & SLOVACEK
Oklahoma City, Oklahoma
August 31, 1998
<PAGE> 1
EXHIBIT 23.2
[NETHERLAND, SEWELL & ASSOCIATES, INC. LETTERHEAD]
CONSENT OF INDEPENDENT PETROLEUM ENGINEERS
We hereby consent to the use of our report dated February 24, 1998, of the
estimates of proved oil and gas reserves and their present values, as of January
1, 1998, in the Registration Statement on Form S-1, and to all references of our
firm included in this Registration Statement.
NETHERLAND, SEWELL & ASSOCIATES, INC.
By: /s/ DANNY D. SIMMONS
----------------------------------
Danny D. Simmons
Senior Vice President
Houston, Texas
August 27, 1998
