GULFPORT ENERGY CORP, S-1/A, 1998-10-30

GULFPORT ENERGY CORP
S-1/A, 1998-10-30
CRUDE PETROLEUM & NATURAL GAS

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<PAGE> 1

AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON OCTOBER 30, 1998

REGISTRATION NO. 333-62603
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SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
---------------------

AMENDMENT NO. 3

FORM S-1
REGISTRATION STATEMENT UNDER THE SECURITIES ACT OF 1933
---------------------

GULFPORT ENERGY CORPORATION
(EXACT NAME OF REGISTRANT AS SPECIFIED IN ITS CHARTER)
<TABLE>

<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: [ ]

CALCULATION OF REGISTRATION FEE

<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------------------------------------
- ------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C>
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
- -------------------------------------------------------------------------------------------------------------------------
Common Stock $0.01 par value per share 200,000,000 shares $0.05 $10,000,000 $2,950(3)
- -------------------------------------------------------------------------------------------------------------------------
Rights(4) -- -- -- --(5)
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</TABLE>

(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) Fee paid with initial filing of the Registration Statement.

(4) Evidencing the rights to subscribe for the shares of Common Stock described
above.

(5) Since both the Rights and the Common Stock underlying the Rights are being
registered for distribution under this Registration Statement, for purpose
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.
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<PAGE> 2

PROSPECTUS

GULFPORT ENERGY CORPORATION

200,000,000 SHARES OF COMMON STOCK
---------------------
Gulfport Energy Corporation, a Delaware corporation formerly known as WRT
Energy Corporation, is distributing to the holders of its Common Stock
non-transferable rights (the "Rights") to subscribe for and purchase an
aggregate of approximately 200,000,000 shares (the "Shares") of Common Stock.
Holders of Common Stock of record as of October 16, 1998 ("Eligible
Stockholders") are entitled to receive one Right for each 0.11038 share of
Common Stock held as of such date. Each Right entitles the holder to subscribe
to purchase one Share for $0.05. Holders of Rights who exercise all of their
Rights will have the right to oversubscribe for additional Shares at $0.05 per
Share, 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 as
the "Rights Offering."

The Rights will expire at 5:00 p.m., New York City time, on November 20,
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. 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 ability of the Company to satisfy its capital requirements and
implement its business strategy is dependent upon the success of the Rights
Offering. The Company believes that it will need at least $7.5 million to pay
outstanding obligations consisting primarily of overdue trade payables and to
meet the Company's immediate and near-term capital requirements consisting
primarily of operating and general and administrative expenses and, to the
extent possible, relatively low cost projects, such as workovers and
recompletions, and may include payments on indebtedness and receivables owed to
affiliates of officers and directors of the Company. See "Use of Proceeds." 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 may lose their
entire investment in the Company. The Company currently has no financing plan to
raise such capital other than the Rights Offering. The Company's predecessor
emerged from bankruptcy in July 1997.

There is no minimum number of Shares that must be subscribed for in the
Rights Offering for it to be completed. Subscription payments will not be placed
in an escrow account. Once a holder has paid the subscription price, the Company
will not refund any portion of such subscription price even if the Company fails
to raise $7.5 million.

The Common Stock is traded in the over-the-counter market under the symbol
"GPOR." On October 28, 1998, the closing bid price of the Common Stock, as
reported on the over-the-counter ("OTC") Bulletin Board, was $0.08. See "Price
Range of Common Stock and Dividend Policy."

SEE "RISK FACTORS" BEGINNING ON PAGE 7 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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<TABLE>
<CAPTION>
SUBSCRIPTION PROCEEDS TO
PRICE COMPANY(1)
<S> <C> <C>
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Per share of Common Stock................................... $ 0.05 $10,000,000
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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 $150,000. 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 OCTOBER 30, 1998

<PAGE> 3

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 in the second paragraph under "-- The
Company"), 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" 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. 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. The Plan was consummated and became
effective on July 11, 1997 (the "Effective Date"). On such 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."

Certain Eligible Stockholders, which own in the aggregate 10,677,894 shares
of Common Stock and will receive Rights to purchase an aggregate of 96,737,579
Shares, are affiliates of Charles E. Davidson, a director of the Company, Mike
Liddell, the Chairman of the Board and Chief Executive Officer of the Company,
or Mark Liddell, the President of the Company. These Eligible Stockholders are
referred to in this Prospectus as the Affiliated Eligible Stockholders. As of
October 7, 1998, the Company owed (i) the Affiliated Eligible Stockholders an
aggregate of $3.0 million under the Stockholder Credit Facility and (ii) three
of the Affiliated Eligible Stockholders approximately $1.6 million as the
holders of a receivable for services provided to the Company under the
Administrative Services Agreement. The Subscription Price for Shares and Excess
Shares, if any, purchased by the 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 to the extent such funds are available. If such
funds are not sufficient, any outstanding amounts will be repaid from other
funds as they become available.

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 Company believes that it will need to raise at least $7.5 million
from the Rights Offering, including any amounts forgiven by the Affiliated
Eligible Stockholders as payment of their Subscription Price. At that level,
assuming that the full $4.6 million owed to the Affiliated Eligible Stockholders
is forgiven as payment of the Subscription Price for Shares, the Company would
receive gross cash proceeds of $2.9 million. Of this amount, approximately $1.5
million would first be used to pay outstanding obligations consisting primarily
of overdue trade payables. The balance of any cash proceeds from the Rights
Offering would be used to meet the Company's immediate and near-term capital
requirements consisting primarily of operating and general and administrative
expenses and, to the extent possible, relatively low risk projects, such as
workovers and recompletions, intended to generate positive cash flow. If the

1
<PAGE> 4

Affiliated Eligible Stockholders do not forgive the full amount owed to them by
the Company in exercise of the Subscription Price, the balance of any cash
proceeds may also be used to repay amounts owed to Affiliated Eligible
Stockholders. At the $7.5 million level, the Company believes that the balance
of the cash proceeds from the Rights offering, together with cash flow from
operations, will be sufficient to meet the Company's capital requirements until
the Company's recent farmouts start generating sufficient cash flow. There can
be no assurance, however, that such funds will be sufficient to meet the
Company's needs. See "Management's Discussion and Analysis of Financial
Condition and Results of Operations -- Liquidity and Capital Resources."
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 is an event of default under the Company's principal credit agreement with
ING (U.S.) Corporation (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 may lose their entire investment in
the Company. The Company currently has no financing plan to raise such capital
other than the Rights Offering.

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 0.11038 share of
Common Stock held of record by such holder at the
close of business on October 16, 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 200,000,000 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 200,000,000 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, 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......... $0.05 per Share.

2
<PAGE> 5

Expiration Date............ 5:00 p.m., New York City time, on November 20, 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
American Stock Transfer & Trust Company, as
subscription agent (the "Subscription Agent"), on
or prior to the Expiration Date to the following
address:

American Stock Transfer & Trust Company
6201 15th Avenue
Brooklyn, NY 11129

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. See "The
Rights Offering -- Exercise of Rights."

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.

Material 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 "Material
Federal Income Tax Considerations."

Use of Proceeds............ Net cash proceeds, if any, from the Rights Offering
will be used by the Company to pay outstanding
obligations consisting primarily of overdue trade
payables and to meet the Company's immediate and
near-term capital requirements. 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......... American Stock Transfer & Trust Company

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.

3
<PAGE> 6

Common Stock Outstanding as
of the Record Date....... 22,076,315 shares

Common Stock Outstanding
after the Rights
Offering................. 222,076,315 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.

4
<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.

<TABLE>
<CAPTION>
GULFPORT
--------------------------

SIX MONTHS JULY 11,
ENDED 1997 TO
JUNE 30, DECEMBER 31,
1998 1997
----------- ------------
(UNAUDITED)
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C>
STATEMENT OF OPERATIONS DATA
Oil and gas sales........... $ 6,722 $ 9,756
-------- -------
Operating expenses.......... 26,590(1) 11,478
-------- -------
Net income (loss) from
operations................. (19,868) (1,713)
-------- -------
Interest expense............ 758 727
Reorganization costs........ -- --
Net income (loss) before
income taxes and
extraordinary item......... (20,280) (1,713)
Extraordinary item.......... -- --
Net income (loss) before
dividends on preferred
stock...................... (20,280) (1,713)
Dividends on preferred
stock(4)................... -- --
Net income (loss)
attributable to common
stock...................... (20,280) (1,713)
Earnings (loss) per common
and common equivalent
share(5)................... (0.92) (0.08)
Average common and common
equivalent shares
outstanding................ 22,076 22,076
Capital expenditures........ $ 805 $ 5,644

<CAPTION>
OLD WRT
-----------------------------------------------------------------------------
SIX MONTHS
TEN DAYS SIX MONTHS
ENDED ENDED YEAR ENDED DECEMBER 31,
JULY 10, JUNE 30, ---------------------------------------------------
1997 1997 1996 1995 1994 1993
---------- ---------- -------- ----------- ----------- -----------
(UNAUDITED) (UNAUDITED) (UNAUDITED)
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C> <C> <C>
STATEMENT OF OPERATIONS DATA
Oil and gas sales........... $10,138 $ 5,381 $ 24,019 $ 24,655 $11,034 $ 4,657
------- ------- -------- --------- ------- -------
Operating expenses.......... 11,002 4,605 40,855(2) 139,497(3) 10,126 5,841
------- ------- -------- --------- ------- -------
Net income (loss) from
operations................. (864) 776 (16,836) (114,842) 908 (1,184)
------- ------- -------- --------- ------- -------
Interest expense............ 1,106 615 5,562 13,759 19 447
Reorganization costs........ 7,771 1,026 7,345 -- -- --
Net income (loss) before
income taxes and
extraordinary item......... (9,615) (815) (29,387) (128,175) 4,266 (1,322)
Extraordinary item.......... 88,723 -- -- -- -- --
Net income (loss) before
dividends on preferred
stock...................... 79,108 (815) (29,387) (128,175) 4,230 (1,322)
Dividends on preferred
stock(4)................... (1,510) (712) (2,846) (2,846) (2,846) (591)
Net income (loss)
attributable to common
stock...................... 77,598 (1,527) (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 N/A N/A
Average common and common
equivalent shares
outstanding................ 9,539 9,539 9,539 9,466 7,792 4,154
Capital expenditures........ $ 2,562 $ 250 $ 4,823 $ 116,730 $40,087 $14,325
</TABLE>

<TABLE>
<CAPTION>
GULFPORT
-----------------------

JUNE 30, DECEMBER 31,
1998 1997
-------- ------------
(IN THOUSANDS)
<S> <C> <C>
BALANCE SHEET DATA
Working capital (deficit)..................... $(4,949) $ (719)
Property, plant and equipment, net............ 62,341 81,501
Total assets.................................. 72,191 92,346
Total long-term debt.......................... 10,660 13,528
Shareholders' equity (deficit)................ 50,000 70,280

<CAPTION>
OLD WRT
-----------------------------------------------------
DECEMBER 31,
JULY 10, -----------------------------------------
1997 1996 1995 1994 1993
--------- --------- --------- ------- -------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
BALANCE SHEET DATA
Working capital (deficit)..................... $(148,231) $(148,932) $(131,601) $ 6,301 $24,270
Property, plant and equipment, net............ 55,698 56,899 63,913 59,042 18,586
Total assets.................................. 67,706 68,076 79,247 81,857 48,233
Total long-term debt.......................... -- -- -- 6,260 205
Shareholders' equity (deficit)................ (91,366) (90,551) (61,869) 63,538 43,394
</TABLE>

5
<PAGE> 8

- ---------------

(1) 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."

(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 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."

(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.

6
<PAGE> 9

RISK FACTORS

In addition to the other information contained in this Prospectus, the
following factors should be considered carefully in evaluating an investment in
the Common Stock offered hereby.

FAILURE TO RAISE $7.5 MILLION BY NOVEMBER 30, 1998 IS AN EVENT OF DEFAULT UNDER
THE AMENDED CREDIT FACILITY AND MAY RESULT IN BANKRUPTCY FILING

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 net losses of
$1.7 million for the period July 11, 1997 to December 31, 1997 and $20.3 million
(which included a non-cash charge of $16.0 million due to a ceiling test
write-down) for 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. As of January 1, 1998, on a Boe basis
approximately 28.5% of the Company's proved reserves were producing and 71.5%
were nonproducing.

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

7
<PAGE> 10

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. During the year ended October 1, 1998, oil and gas
prices have fallen from approximately $21.05 per barrel and $3.12 per Mcf to
$15.43 and $2.41, respectively. 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
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."

8
<PAGE> 11

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 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

9
<PAGE> 12

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."

CONTROL OF COMPANY BY OFFICERS AND DIRECTORS

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.

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 each Share to be issued pursuant to the Rights
Offering will be $0.05. 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.

10
<PAGE> 13

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 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 to 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.

MATERIAL 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 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 "Material Federal Income
Tax Considerations" for a more detailed discussion of the material federal
income tax consequences resulting from the purchase, ownership and disposition
of Rights and shares of Common Stock.

CHANGE OF CONTROL COULD LIMIT THE COMPANY'S USE OF NET OPERATING LOSSES

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 Rights 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 to implement the
Company's business strategy and manage its operations. DLB Equities, LLC is
owned equally by Mike Liddell, the Chairman of the Board and Chief Executive
Officer of the Company, and Mark Liddell, the President of the Company. 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

11
<PAGE> 14

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 96,737,579
Shares, are affiliates of Charles Davidson, a Director of the Company, Mike
Liddell, the Company's Chairman of the Board and Chief Executive Officer, or
Mark Liddell, the Company's President (the "Affiliated Eligible Stockholders").
As of October 1, 1998, the Company owed (i) the Affiliated Eligible Stockholders
an aggregate of $3.0 million as the lenders under 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. 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 to the extent such funds are available. If
such funds are not sufficient, any outstanding amounts will be repaid from other
funds as they become available. 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.
See "Management's Discussion and Analysis of Financial Condition and Results of
Operations."

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.

12
<PAGE> 15

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 $150,000. The net proceeds, if any, from the
Rights Offering will be used by the Company to pay outstanding obligations
consisting primarily of overdue trade payables and to meet the Company's
immediate and near-term capital requirements, and may include payments on
obligations owed by the Company to Affiliated Eligible Stockholders arising from
a $3.0 million revolving credit facility (the "Stockholder Credit Facility") and
an Administrative Services Agreement, dated as of July 10, 1997, by and between
the Company and DLB (the "Administrative Services Agreement"). As of October 7,
1998, the Company owed (i) the Affiliated Eligible Stockholders an aggregate of
$3.0 million as the lenders under 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, of which $2.0 million was used to repay outstanding indebtedness under
the Amended Credit Agreement and the balance was used for working capital and
general corporate purposes, bear interest at LIBOR plus 3% (8.69% at October 7,
1998) and are due on August 17, 1999. 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 $0.05 per Share, the Affiliated Eligible Stockholders could purchase
approximately 96 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 non-transferable 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 to raise at least $7.5 million from the Rights Offering, including
any amounts forgiven by the Affiliated Eligible Stockholders as payment of their
Subscription Price. At that level, assuming that the full $4.6 million owed to
the Affiliated Eligible Stockholders is forgiven as payment of the Subscription
Price for Shares, the Company would receive gross cash proceeds of $2.9 million.
Of this amount, approximately $1.5 million would first be used to pay
outstanding obligations consisting primarily of overdue trade payables. The
balance of any cash proceeds from the Rights Offering would be used to meet the
Company's immediate and near-term capital requirements consisting primarily of
operating and general and administrative expenses and, to the extent possible,
relatively low risk projects, such as workovers and recompletions, intended to
generate positive cash flow. If the Affiliated Eligible Stockholders do not
forgive the full amount owed to them by the Company in exercise of the
Subscription Price, the balance of any cash proceeds may also be used to repay
amounts owed to Affiliated Eligible Stockholders. At the $7.5 million level, the
Company believes that the balance of the cash proceeds from the Rights Offering,
together with cash flow from operations, will be sufficient to meet the
Company's capital requirements until the Company's recent farmouts start
generating sufficient cash flow. There can be no assurance, however, that such
funds will be sufficient to meet the Company's needs.

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 is 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 may lose their entire
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."

13
<PAGE> 16

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 200,000,000 Shares offered
by the Company in the Rights Offering. 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
---------- -----------
(IN THOUSANDS)
<S> <C> <C>
Current maturities of long-term debt(1)..................... $ 3,014 $ 1,014
======== ========
Long-term debt(2)........................................... $ 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;
222,076,315 issued and outstanding as adjusted......... $ 221 $ 2,221
Additional paid-in capital................................ 71,772 79,622
Accumulated deficit....................................... (21,993) (21,993)
-------- --------
Total stockholders' equity........................ 50,000 59,850
-------- --------
Total capitalization.............................. $ 63,674 $ 71,524
======== ========
</TABLE>

- ---------------

(1) At June 30, 1998, current maturities of long-term debt included $3.0 million
owed under the Credit Agreement. In connection with the execution of the
Amended Credit Agreement, the Company repaid $2.0 million of this amount
with borrowings made under the Stockholder Credit Facility. See "Use of
Proceeds."

(2) 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
Company's consolidated financial statements included elsewhere in this
Prospectus.

14
<PAGE> 17

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
</TABLE>

<TABLE>
<CAPTION>
YEAR ENDING DECEMBER 31, 1998
-----------------------------
<S> <C> <C>
First Quarter.............................................. $3.36 $4.63
Second Quarter............................................. $1.12 $3.38
Third Quarter.............................................. $0.20 $1.50
Fourth Quarter (through October 28, 1998).................. $0.07 $0.21
</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 October 6, 1998, there were 22,076,315 shares
of Common Stock outstanding held by 319 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.

15
<PAGE> 18

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 0.11038 share 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.

EXPIRATION DATE

The Rights will expire at 5:00 p.m., New York City time, on November 20,
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.

16
<PAGE> 19

DETERMINATION OF SUBSCRIPTION PRICE

The Subscription Price for a Share to be issued pursuant to the Rights will
be $0.05. 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
Shares 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. 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 American Stock Transfer &
Trust Company, as Subscription Agent"; or (ii) wire transfer of funds to the
account maintained by the Subscription Agent for such purpose at American Stock
Transfer & Trust Company. 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 good funds from
payment 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 CHECK MAY TAKE AT LEAST FIVE
BUSINESS DAYS TO CLEAR. ACCORDINGLY, HOLDERS WHO WISH TO PAY THE SUBSCRIPTION
PRICE BY MEANS OF UNCERTIFIED 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 the address 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 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

17
<PAGE> 20

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. (718) 921-8355). Additional copies of
the form of Notice of Guaranteed Delivery are available upon request from
the Subscription 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 interest bearing account pending issuance of such Excess Shares
(which interest will accrue for the benefit of the Company). 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 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 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

18
<PAGE> 21

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 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 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
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 American Stock Transfer & Trust Company 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:

American Stock Transfer & Trust Company
6201 15th Avenue
Brooklyn, NY 11129

19
<PAGE> 22

The Subscription Agent's telephone number is (718) 921-8210 and its
facsimile number is (718) 921-8355.

The Company will pay the fees and expenses of the Subscription Agent in
connection with the Rights Offering.

DILUTIVE EFFECTS OF RIGHTS OFFERING

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. No residents of the State of California
may be issued Rights due to certain restrictions imposed by the securities laws
of such state.

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.

20
<PAGE> 23

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
--------------------------

SIX MONTHS JULY 11,
ENDED 1997 TO
JUNE 30, DECEMBER 31,
1998 1997
----------- ------------
(UNAUDITED)
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C>
STATEMENT OF OPERATIONS
DATA
Oil and gas sales.......... $ 6,722 $ 9,756
-------- -------
Operating expenses......... 26,590(1) 11,478
-------- -------
Net income (loss) from
operations................ (19,868) (1,713)
-------- -------
Interest expense........... 758 727
Reorganization costs....... -- --
Net income (loss) before
income taxes and
extraordinary item........ (20,280) (1,713)
Extraordinary item......... -- --
Net income (loss) before
dividends on preferred
stock..................... (20,280) (1,713)
Dividends on preferred
stock(4).................. -- --
Net income (loss)
attributable to common
stock..................... (20,280) (1,713)
Earnings (loss) per common
and common equivalent
share(5).................. (0.92) (0.08)
Average common and common
equivalent shares
outstanding............... 22,076 22,076
Capital expenditures....... $ 805 $ 5,644

<CAPTION>
OLD WRT
-----------------------------------------------------------------------------
SIX MONTHS
TEN DAYS SIX MONTHS
ENDED ENDED YEAR ENDED DECEMBER 31,
JULY 10, JUNE 30, ---------------------------------------------------
1997 1997 1996 1995 1994 1993
---------- ---------- -------- ----------- ----------- -----------
(UNAUDITED) (UNAUDITED) (UNAUDITED)
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C> <C> <C>
STATEMENT OF OPERATIONS
DATA
Oil and gas sales.......... $10,138 $ 5,381 $ 24,019 $ 24,655 $11,034 $ 4,657
------- ------- -------- --------- ------- -------
Operating expenses......... 11,002 4,605 40,855(2) 139,497(3) 10,126 5,841
------- ------- -------- --------- ------- -------
Net income (loss) from
operations................ (864) 776 (16,836) (114,842) 908 (1,184)
------- ------- -------- --------- ------- -------
Interest expense........... 1,106 615 5,562 13,759 19 447
Reorganization costs....... 7,771 1,026 7,345 -- -- --
Net income (loss) before
income taxes and
extraordinary item........ (9,615) (815) (29,387) (128,175) 4,266 (1,322)
Extraordinary item......... 88,723 -- -- -- -- --
Net income (loss) before
dividends on preferred
stock..................... 79,108 (815) (29,387) (128,175) 4,230 (1,322)
Dividends on preferred
stock(4).................. (1,510) (712) (2,846) (2,846) (2,846) (591)
Net income (loss)
attributable to common
stock..................... 77,598 (1,527) (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 N/A N/A
Average common and common
equivalent shares
outstanding............... 9,539 9,539 9,539 9,466 7,792 4,154
Capital expenditures....... $ 2,562 $ 250 $ 4,823 $ 116,730 $40,087 $14,325
</TABLE>

<TABLE>
<CAPTION>
GULFPORT
-----------------------

21
<PAGE> 24

- ---------------

(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.

22
<PAGE> 25

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 and should be read in conjunction
with the consolidated financial statements and the notes thereto included
elsewhere in this Prospectus.

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.

23
<PAGE> 26

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, 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. 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. 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

24
<PAGE> 27

Company's increased cash holdings in accounts bearing interest and an increase
in overhead income, during the first quarter of 1998.

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 to 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 the comparable
period in 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.

25
<PAGE> 28

Production Costs. Production costs decreased $3.9 million, 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 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 legal proceeding arising
from Tri-Deck's failure to pay for several months of gas production. See
"-- Commitments and Contingencies" and "Business -- Legal Proceedings." On
January 20, 1998, the Company assigned its claims against Tri-Deck to the
Litigation Entity (an independent entity formed pursuant to the Plan to pursue
specified claims of Old WRT) in consideration for the right to receive a
percentage of the net proceeds from the resolution of these claims. The
percentages, which were arrived at through arms-length negotiations, are either
50% or 85% depending on the nature of the claim. 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

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<PAGE> 29

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
nonconventional fuels tax credit provided for under Section 29 of the Internal
Revenue Code. Based on a certification by the Department of Natural Resources
(the "DNR"), a significant amount of the production attributable to the Tricore
JV qualified under the Natural Gas Policy Act (the "NGPA") as gas produced from
geopressured brine. As required under the NGPA, the DNR's determination was
reviewed by the Federal Energy Regulatory Commission (the "FERC") which
ultimately rejected such determination. The FERC's position was subsequently
upheld on appeal to the United States Court of Appeals. The additional accrual
in 1996 was also due in part 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 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.

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<PAGE> 30

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.

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. This impairment was due primarily to a significant
downward revision of the Company's oil and gas reserves as a result of (i)
differences in professional opinions between the Company's current and former
independent engineering firms, (ii) field development activities including
unsuccessful well projects in the Company's East Hackberry and Bayou Penchant
fields and the mechanical failure of the Lac Blanc No. 23 well, and (iii)
production during the year. 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).

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<PAGE> 31

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 was 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 and pursuant to the Plan, the Company received gross
proceeds of $13,300,000 from the exercise of rights to purchase 3,800,000 shares
of Common Stock at $3.50 per share (the "1997 Rights Offering"), of which
$3,248,000 was used to pay the interest and loan fees in connection with an
outstanding loan (the "Prior Credit Facility") from International Nederlanden
(U.S.) Capital Corporation ("INCC"), $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 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 Prior Credit Facility with INCC, a
predecessor to ING, 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. The interest
rate was 8.69% at October 7, 1998. The Credit Agreement provided for principal
payments of $1,000,000 each 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 was 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

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<PAGE> 32

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. The exercise price for the warrants
will equal the average of the closing sale prices for the Common Stock for the
30 trading days following consummation of the Rights Offering. If, however, the
Rights Offering is not consummated within 30 days after the date of this
Prospectus, then the exercise price shall be $0.25. The warrants expire five
years after the date the exercise price is established.

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% (8.69% at October 7, 1998). 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 October 7, 1998, $3.0 million was outstanding
under the Stockholder Credit Facility. The Company repaid $2.0 million of
principal under the Amended Credit Facility with borrowings under the
Stockholder Credit Facility. The remaining $1.0 million was 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 to the extent such funds are
available. If such funds are not sufficient, any outstanding amounts will be
repaid from other funds as they become available. 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 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. During the period extending from the Effective Date through December 31,
1997, the Company spent approximately $4.4 million for these purposes. However,
these expenditures did not generate the anticipated cash flow on the projected
schedule. At the same time, the Company's revenues were adversely affected by
declining oil and gas prices. As a result, cash flow from operations has not
been sufficient to meet the Company's capital requirements.

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<PAGE> 33

In an effort to reduce the Company's capital requirements while at the same
time developing its properties as quickly as possible, the Company is
implementing its business strategy of utilizing farmout arrangements, in which
investors pay the development costs in exchange for a working interest in the
project, and selling nonstrategic properties. See "-- Recent Developments and
Plans" below for a discussion of recent farmouts and sales of properties. The
Company also intends to continue to undertake internally financed, low risk
projects to the extent permitted by its financial position.

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 non-transferable 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 to raise at least $7.5 million from the Rights Offering, including
any amounts forgiven by the Affiliated Eligible Stockholders as payment of their
Subscription Price, to pay outstanding obligations consisting primarily of
overdue trade payables and to meet the Company's immediate and near-term capital
requirements. At that level, assuming that the full $4.6 million owed to the
Affiliated Eligible Stockholders is forgiven as payment for the Subscription
Price for Shares, the Company would receive gross cash proceeds of $2.9 million.
Of this amount, approximately $1.5 million would first be used to pay
outstanding obligations consisting primarily of overdue trade payables. The
balance of any cash proceeds from the Rights Offering would be used to meet the
Company's immediate and near-term capital requirements consisting primarily of
operating and general and administrative expenses and, to the extent possible,
relatively low risk projects, such as workovers and recompletions, intended to
generate positive cash flow. If the Affiliated Eligible Stockholders do not
forgive the full amount owed to them by the Company in exercise of the
Subscription Price, the balance of any cash proceeds may also be used to repay
amounts owed to Affiliated Eligible Stockholders. At the $7.5 million level, the
Company believes that the balance of the cash proceeds from the Rights Offering,
together with cash flow from operations, will be sufficient to meet the
Company's capital requirements until the Company's recent farmouts start
generating sufficient cash flow. There can be no assurance, however, that such
funds will be sufficient to meet the Company's needs.

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 may lose their
entire investment in the Company. The Company currently has no financing plan to
raise such capital other than the Rights Offering.

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

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<PAGE> 34

completes all three phases of the program, it will earn a 50% interest in the
WCBB field. The effectiveness of the Tri-C agreement is subject to the prior
consent of Texaco Exploration and Production, Inc. ("TEPI"). There can be no
assurance that such consent will be obtained.

Farmout of Recompletion and Rework Opportunities. On October 6, 1998, the
Company and Plymouth Resources 1998, LLC ("Plymouth") executed a wellbore
farmout on West Cote Blanche Bay in which Plymouth agreed to rework 15 wells in
the first year of the farmout. Each year thereafter, Plymouth agreed to rework
at least 22 wells a year. The Company will receive a 50% reversionary interest
calculated on a well by well basis. Once Plymouth has spent $4.0 million in the
field, Gulfport's reversionary interest will decrease to 45%. Additionally,
Plymouth assumed 50% of the plugging liability for the farmout wells. The
effectiveness of such agreement is subject to the prior consent of TEPI. There
can be no assurance that such consent will be obtained.

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 is
actively seeking partners to accomplish the following goals in this field: (i)
begin 3-D seismic data acquisition by the fourth quarter of 1998 to enable the
Company to explore the field more effectively and at a lower risk, (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.

In September 1998, the Company and an affiliate of Castex entered into an
agreement in which it agreed to purchase the Castex Operated Properties from the
Company (the "Castex Sale") for approximately

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$7.8 million plus overriding royalties and reversionary interests in the
properties. However, the transaction is expected to close in November. However,
the transaction is subject to certain conditions, including the consent of ING.
In addition, in September 1998, LLOG obtained a consent order prohibiting any
sale of the Castex Operated Properties pending a preliminary injunction hearing
which is set for November 9, 1998. Accordingly, there can be no assurance that
the transaction will close. Net cash proceeds from the Castex Sale would be used
to reduce borrowings under the Amended Credit Facility.

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 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 October 1, 1998, the independent study had not been commenced. Accordingly,
the Company is unable to determine the amount and payment towards the future
obligation related to these commitments. See "Business -- Regulation -- Orphaned
Well Act."

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. 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 is current in these plugging and abandonment obligations.

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.

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<PAGE> 36

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 31, 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. The cost of this well is estimated to be approximately
$250,000.

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 funded $13,000, $23,000, $32,000, and
$22,000, respectively, in matching contributions expense associated with this
plan.

Tri-Deck/Perry Gas Litigation

On January 20, 1998, the Company and the Litigation Entity entered into a
Clarification Agreement whereby the rights to pursue Old WRT's claims against
Tri-Deck 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 with these claims. As
additional consideration for the contribution of this claim to the Litigation
Entity, the Company is entitled to 85% of the recovery of all monies held in the
court registry and 50% of the recovery from all other Tri-Deck litigation
pursued by the Litigation Entity.

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. Revenue attributable to mineral production from
the acreage in dispute has been held in suspense by Plains Resource &
Transportation, Inc. and Wickford Energy Marketing, Inc. (the "Stakeholders")
since the time the notice of possible title failure was received by the Company.
On February 28, 1998, the Company entered into a settlement agreement with
Wildwing. The settlement provides that the Company direct the Stakeholders to
deliver to Wildwing, in full and final compromise of the Wildwing claims, the
sum of $269,500, and Wildwing would convey, assign, transfer, sell, setover and
deliver to the Company, all of Wildwing's right, title and interest in the
leases subject to dispute. Additional revenue attributable to mineral production
from this acreage, held in suspense by the Stakeholders, was or will be
distributed to the lessors of the property with the balance of approximately
$370,000 distributed to the Company.

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<PAGE> 37

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.

Year 2000 Compliance

Many currently installed computer systems and software products are coded
to accept only two digit entries in the data code field. These data code fields
will need to accept four digit entries to distinguish the 21st century dates
from 20th century dates. As a result, computer systems and software used by many
companies may need to be upgraded to comply with such "Year 2000" requirements.

The Company is currently in the process of evaluating its information
technology infrastructure for the Year 2000 compliance. To date, the Company has
not incurred significant costs related to Year 2000 compliance and does not
expect that the cost to modify and replace its information technology
infrastructure to be Year 2000 compliant will be material to its financial
condition or results of operations. The Company does not anticipate any material
disruption in its operations as a result of any failure by the Company to be in
compliance. The costs of these projects and the date on which the Company plans
to complete modifications and replacements are based on management's best
estimates, which were derived utilizing numerous assumptions of future events
including the continued availability of certain resources, third party
modification plans and other factors. However, there can be no guarantee that
these estimates will be achieved and actual results could differ materially from
those plans.

The Company does not currently have any information concerning the Year
2000 compliance status of its suppliers and customers. The Company intends to
initiate communications with significant suppliers and customers to evaluate the
risk of their failure to be Year 2000 compliant and the extent to which the
Company may be vulnerable to such failure. In the event that any of the
Company's significant suppliers or customers do not successfully and timely
achieve Year 2000 compliance, the Company's business or operations could be
adversely affected.

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<PAGE> 38

BUSINESS

The Company owns and operates mature oil and gas properties in the
Louisiana Gulf Coast area. The Company's business strategy is to increase its
reserves, production and cash flow primarily through exploration and development
activities. 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 relatively
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 with INCC 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

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<PAGE> 39

Prior 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.

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

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<PAGE> 40

administrative expenses. As liquidity 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, and
(vii) the distribution of warrants to purchase Common Stock at an exercise price
of $10.00 per share to holders of

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<PAGE> 41

certain securities litigation claims against Old WRT and to holders of Old WRT's
common stock and preferred stock. The Plan also provided for 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 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
WELLS WELLS ACREAGE PROVED RESERVES(2)
------------ ------------- --------------- -------------------------
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(3).......... 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(4)..... 10 10.0 4 4.0 1,360 1,360 803 23 826
Bayou Pigeon Field(4)....... 9 8.0 6 4.0 1,490 1,490 21 267 288
Deer Island Field(4)........ 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(4)...... 1 1.0 0 0.0 171 171 153 23 176
Lac Blanc Field(4).......... 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.............. 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) The Company's lease for this field has expired due to lack of production.

(4) Operated by Castex as of September 1, 1998 and a property included in the
Castex Sale. See "Management's Discussion and Analysis of Financial
Condition and results of Operations -- Recent Developments and Plans."

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

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<PAGE> 42

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 15 wells (nine producing and six shut in wells, approximately 80%
average NRI).

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.

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<PAGE> 43

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.

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."

41
<PAGE> 44

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>

- ---------------

(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 and
61 gross (43 net) acres attributable to the Abbeville 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 Company's
lease for the Abbeville field expired due to lack of production. Excludes
8,188 gross and net acres attributable to the Castex Operated Properties
which are the subject of the Castex Sale. See "Management's Discussion and
Analysis of Financial Condition and Results of Operations -- Recent
Developments and Plans." Also excludes 43 gross (36.7 net) acres in the
Bayon Pigeon field that had been the subject of a dispute with Wildwing.
That dispute has now been settled. See "-- Legal Proceedings."

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>

42
<PAGE> 45

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 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 approximately 43 acres in the Bayou Pigeon
Field that had been the subject of a dispute with Wildwing that is now settled.
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(1) DEVELOPED(1) UNDEVELOPED(1) TOTAL
------------------ ------------ -------------- -----------
<S> <C> <C> <C>
Oil (MBbls)(2)....................................... 7,220 18,597 25,817
Gas (MMcf)........................................... 8,259 3,317 11,576
MBoe(2).............................................. 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) See "Glossary" for the definition of "proved reserves," "proved developed
reserves" and "proved undeveloped reserves."

(2) Includes 1,860 MBoe of oil and gas attributable to the properties that are
the subject of the Castex Sale, 189 MBoe of oil attributable to the
Napoleonville field and 12 MBoe attributable to the Abbeville field. The
Castex Sale is expected to close in November 1998; however the transaction
is subject to certain conditions and there can be no assurance that it will
be completed. 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." The Company's
lease for the Abbeville field expired due to lack of production.

Total proved 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.

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."

43
<PAGE> 46

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.

The oil and gas reserve information set forth above 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.

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.

<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.

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<PAGE> 47

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 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

45
<PAGE> 48

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 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 October 1, 1998, the independent study had
not yet been commenced. Accordingly, Gulfport is unable to determine the amount
and payment towards the future obligation related to these commitments. In
September 1998, LLOG obtained a consent order prohibiting any sale of the LLOG
Properties (which are the subject of the Castex Sale) pending a preliminary
injunction hearing, which is set for November 9, 1998. LLOG is claiming that it
has a continuing security interest in certain real property and equipment to
secure the claim for plugging and abandonment obligations. The Company is
currently negotiating with LLOG to settle the matter.

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. On August 8, 1998, the Environmental Protection Agency
("EPA") added four petroleum refining wastes to the list of Resource
Conservation and Recovery Act ("RCRA") hazardous wastes. While the full impact
of this new rule has yet to be determined, the rule may, as of February 1999,
impose increased expenditures and operating expenses on the Company, which may
take on additional obligations relating to the treatment, storage,
transportation and disposal of certain petroleum refining wastes that were not
previously regulated as hazardous waste. 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. Certain
environmental laws including, but not limited to, the Comprehensive
Environmental Response. Compensation and Liability Act ("CERCLA") and analogous
state statutes, provide for joint and several strict liability for remediation
of releases of hazardous substances, rendering an owner or operator liable for
environmental damage without regard to negligence or fault. In addition, the
Company may be subject to claims alleging personal injury or property damage as
a result of exposure to hazardous substances. Such laws and regulations may
expose the Company to liability arising out of the conduct of operations or
conditions caused by others, or for the acts of the Company which were in
compliance with all applicable laws at the time such acts were performed.

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
46
<PAGE> 49

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".

Pursuant to the federal Clean Water Act ("CWA") and Louisiana Department of
Environmental Quality ("LDEQ") regulations, oil and gas production facilities
for which produced water is a natural byproduct must either discharge the
produced water or inject it into an injection well approved by the Louisiana
Department of Natural Resources ("LDNR"). Those LDEQ permits and LDEQ Emergency
Rules that provided for continued discharges of produced water have expired,
except in very limited situations. On November 4, 1997, EPA Region 6 issued a
National Pollutant Discharge Elimination System ("NPDES") General Permit for the
Oil and Gas Extraction Point Source Category, in the Territorial Seas of
Louisiana. Among other things, the NPDES General Permit governs the discharge of
produced water to the Territorial Seas of Louisiana from Offshore Subcategory
facilities located in the Outer Continental Shelf ("OCS") water off Louisiana,
unless such produced water discharges are otherwise prohibited by LDEQ
regulations. Louisiana Administrative Code 33.IX.708. In June 1995, the Company
began underground injection at its East Hackberry facility and discontinued
overboard discharge of produced water. In addition, the Company has filed for
and obtained a NPDES General Permit for coverage of the applicable Company
facilities.

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 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
47
<PAGE> 50

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 October 1, 1998, the Company employed 12 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.

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

48
<PAGE> 51

approximately 43 acres in the Bayou Pigeon Field. Revenue attributable to
mineral production from the acreage in dispute has been held in suspense by
Plains Resource & Transportation, Inc. and Wickford Energy Marketing, Inc. (the
"Stakeholders") since the time the notice of possible title failure was received
by the Company. On February 28, 1998, the Company entered into a settlement
agreement with Wildwing. The settlement provides that the Company direct the
Stakeholders to deliver to Wildwing in full and final compromise of the Wildwing
claims, the sum of $269,500, and Wildwing would convey, assign, transfer, sell,
setover and deliver to the Company, all of Wildwing's right, title and interest
in the leases subject to dispute. Additional revenue attributable to mineral
production from this acreage, held in suspense by the Stakeholders, was or will
be distributed to the lessors of the property with the balance of approximately
$370,000 to 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 regarding the rights
of the Company and the Litigation Entity to prosecute certain causes of action
arising from the Tri-Deck matter. 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 receive 85%
of the recovery of all monies held in the court registry and 50% of the recovery
from all other Tri-Deck litigation pursued by the Litigation Entity.

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 sought monetary
damages in the amount of $388,131.76 plus interest, certain legal costs and 10%
in attorney's fees. This matter was settled by the parties on September 10, 1998
with the Company paying $364,000.

For information concerning pending litigation relating to the purchase of
the Initial LLOG Property and the Remaining LLOG Properties, see
"-- Regulation -- Orphaned Well Act."

49
<PAGE> 52

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
Charles E. Davidson................... 44 Director
Robert E. Brooks...................... 50 Director
David L. Houston...................... 45 Director
</TABLE>

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.

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 an 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.

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

50
<PAGE> 53

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
ANNUAL COMPENSATION
COMPENSATION(1)(2) AWARDS ALL OTHER
NAME AND -------------------- ------------ COMPENSATION
PRINCIPAL POSITION YEAR SALARY($) BONUS($) OPTIONS(#) ($)(2)
- ------------------ ---- --------- -------- ------------ ------------
<S> <C> <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.

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<PAGE> 54

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 ASSUMED ANNUAL
NUMBER OF # OF TOTAL RATES AT OF STOCK PRICE
SECURITIES OPTIONS APPRECIATION FOR OPTION
UNDERLYING GRANTED TERMS(1)
OPTIONS EMPLOYERS EXERCISE PRICE EXPIRATION -----------------------
NAME 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.

52
<PAGE> 55

PRINCIPAL STOCKHOLDERS

The following table sets forth certain information concerning the
beneficial ownership of the Common Stock as of October 1, 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
Robert E. Brooks............................................ * *
David L. Houston............................................ * *
All directors and executive officers as a group (6
individuals).............................................. 10,677,894 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.

53
<PAGE> 56

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 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, and Mark
Liddell, President, are provided under the Administrative Services Agreement.
DLB Equities, LLC is owned equally by Mike and Mark Liddell.

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. The fees provided for in the Administrative Services Agreement were
approved by the Bankruptcy Court as part of the Plan and the Company believes
that such fees are comparable to those that would be charged by an independent
third party.

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

54
<PAGE> 57

outstanding amount in cash with a portion of the proceeds from the Rights
Offering to the extent such funds are available. If such funds are not
sufficient, any outstanding amounts will be repaid from other funds as they
become available. 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 August
17, 1999 and bear interest at LIBOR plus 3% (8.69% at October 7, 1998). 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 October 7, 1998, $3.0 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 repaid $2.0 million of
principal under the Amended Credit Facility with borrowings under the
Stockholder Credit Facility. The remaining $1.0 million was 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 to the extent such funds
are available. If such funds are not sufficient, any outstanding amounts will be
repaid from other funds as they become available. 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 319 stockholders of record as of October 6, 1998. The
Company's Board of Directors has approved, and stockholders owning more than 50%
of the Company's outstanding Common Stock have executed written consents
approving an amendment to the Company's Certificate of Incorporation to increase
the number of authorized shares of Common Stock to 250,000,000. It is expected
that such amendment will be filed with the State of Delaware by mid-November
1998. 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.

55
<PAGE> 58

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."

TRANSFER AGENT AND REGISTRAR

The Transfer Agent and Registrar for the Common Stock is American Stock
Transfer and Trust Company.

MATERIAL FEDERAL INCOME TAX CONSIDERATIONS

GENERAL

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. It
is the opinion of Akin, Gump, Strauss, Hauer & Feld, L.L.P., counsel to the
Company, that the following discussion reflects the material tax considerations
of the Rights Offering to a U.S. holder of Rights. Such opinion does not include
any conclusions regarding the tax consequences to the Company resulting from the
Rights Offering regarding the use of tax benefits or loss thereof with respect
to the NOLs of the Company.

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.

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<PAGE> 59

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 believes 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 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 on the date of
distribution of the Rights. 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, but not below zero, 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"), 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.

57
<PAGE> 60

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 generally 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") 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.

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

58
<PAGE> 61

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.

59
<PAGE> 62

GLOSSARY

The following are abbreviations and definitions of certain terms used in
this Prospectus and the oil and gas industry. Unless otherwise indicated in this
Prospectus, natural gas volumes are stated at the legal pressure base 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.

Administrative Services Agreement. That certain agreement dated as of July
10, 1997, by and between the Company and DLB under which DLB agreed to make
available to WRT personnel, services, facilities, supplies, and equipment as WRT
may need including executive and managerial, accounting, auditing and tax,
engineering, geological and geophysical, legal, land, administrative and
clerical services, as assigned by DLB to DLB Investments, LLC as of April 28,
1998.

Amended Credit Agreement. That certain $15,000,000 credit agreement entered
into as of the Effective Date, by and between DLB and ING (U.S.) Corporation,
that is secured by substantially all of the Company's assets, as amended on
August 18, 1998.

Bankruptcy Code. The United States Bankruptcy Code.

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.

Common Stock. The common stock, par value $0.01 per share, of Gulfport
Energy Corporation, a Delaware corporation formerly known as WRT Energy
Corporation.

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.

DLBW. Refers to the co-proponents in the Reorganization Case, DLB and
Wexford Management.

Effective Date. Refers to July 11, 1997, the date on which the Plan was
consummated and became effective.

Excess Shares. All of the shares not initially subscribed for through the
exercise of the Basic Subscription Privilege by the Eligible Stockholders.

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.

Initial LLOG Property. That certain working interest in the Bayou Penchant
Field purchased as of December 19, 1994 from LLOG Exploration Company.

LDEQ. Refers to the Louisiana Department of Environmental Quality.

Litigation Entity. An entity established pursuant to the Plan that is
controlled by an independent party for the benefit of most of Old WRT's
unsecured creditors and to which any and all causes of action, claims,
G-1
<PAGE> 63

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) were transferred.

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. 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.

Net Revenue Interest or NRI. 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.

Old WRT. Refers to WRT Energy Corporation and its subsidiaries taken as a
whole prior to the Effective Date.

Operator. The individual or company responsible for the exploration,
development, and production of an oil or gas well or lease.

Plan. That certain Joint Plan of Reorganization of Old WRT confirmed by the
Bankruptcy Court by Order dated May 5, 1997.

Proved Developed Reserves. The oil and gas reserves that can be expected to
be recovered through existing wells with existing equipment and operating
methods (additional oil and gas reserves expected to be obtained through the
application of fluid injection or other improved recovery techniques for
supplementing the natural forces and mechanisms of primary recovery are included
only after testing by a pilot project or after the operation of an installed
program has confirmed through production response that increased recovery will
be achieved).

Proved Reserves. The estimated quantities of oil and gas which geological
and engineering data demonstrate with reasonable certainty to be recoverable in
future years from known reservoirs under existing economic and operating
conditions, i.e., prices and costs as of the date the estimate is made. Prices
included consideration of changes in existing prices provided only by
contractual arrangements, but not on escalations based upon future conditions.

Proved Undeveloped Reserves. The oil and gas reserves expected to be
recovered from new wells on undrilled acreage, or from existing wells where
relatively major expenditure is required for recompletion. Reserves on undrilled
acreage shall be limited to those drilling units offsetting productive units
that are reasonably certain of production when drilled. Proved reserves for
other undrilled units can be claimed only where it can be demonstrated with
certainty that there is continuity of production from the existing productive
formation. Under no circumstances shall estimates for proved undeveloped
reserves be attributable to any acreage for which an application of fluid
injection or other improved recovery technique is contemplated, unless such
techniques have been proved effective by actual tests in the area and in the
same reservoir.

G-2
<PAGE> 64

Remaining LLOG Properties. Additional oil and gas properties purchased in
March 1995 in four south Louisiana fields which had formerly been owned by LLOG
Exploration Company.

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.

Stockholder Credit Facility. A $3,000,000 revolving credit facility entered
into on August 18, 1998, by and among the Company and the Affiliated Eligible
Stockholders.

Subscription Price. $0.05 per share.

Tri-Deck. Refers to Tri-Deck Oil & Gas Co.

Wexford Management. Refers to Wexford Management, LLC.

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.

3-D Seismic. Seismic data that are acquired and processed to yield a
three-dimensional picture of the subsurface.

G-3
<PAGE> 65

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-8
Consolidated Balance Sheets at June 30, 1998 (unaudited) and
December 31, 1997......................................... F-30
Consolidated Statement of Operations for the Six Months
Ended June 30, 1998 and 1997 (unaudited).................. F-31
Consolidated Statement of Cash Flows for the Six Months
Ended June 30, 1998 and 1997 (unaudited).................. F-32
Notes to Consolidated Financial Statements.................. F-33
</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> 66

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. 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 that might result from the outcome of this uncertainty.

HOGAN & SLOVACEK

Oklahoma City, OK
March 27, 1998

F-2
<PAGE> 67

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. 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 that might result from the outcome of this uncertainty.

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> 68

GULFPORT ENERGY CORPORATION

BALANCE SHEETS

ASSETS

<TABLE>
<CAPTION>
DECEMBER 31,
-----------------------------
1997 1996
(REORGANIZED (PREDECESSOR
COMPANY)(1) COMPANY)(1)
------------ -------------
<S> <C> <C>
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>

- ---------------

(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

See accompanying notes to financial statements.

F-4
<PAGE> 69

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> 70

GULFPORT ENERGY CORPORATION

STATEMENTS OF SHAREHOLDERS' EQUITY

<TABLE>
<CAPTION>
COMMON STOCK ADDITIONAL
PREFERRED ---------------------- PAID-IN ACCUMULATED TREASURY
STOCK SHARES AMOUNT CAPITAL DEFICIT STOCK
------------ ----------- -------- ----------- ------------- ---------
<S> <C> <C> <C> <C> <C> <C>
Balance, December 31, 1995..... $ 27,677,000 $ 9,539,207 $ 95,000 $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..... 27,677,000 9,539,207 95,000 39,571,000 (157,562,000) (332,000)
Net income................... -- -- -- -- 79,108,000 --
Effect of fresh start
reporting................. (27,677,000) 12,537,108 126,000 32,201,000 78,454,000 332,000
------------ ----------- -------- ----------- ------------- ---------
Balance, July 11, 1997......... -- 22,076,315 221,000 71,772,000 -- --
Net loss..................... -- -- -- -- (1,713,000) --
------------ ----------- -------- ----------- ------------- ---------
Balance, December 31, 1997..... $ -- $22,076,315 $221,000 $71,772,000 $ (1,713,000) $ --
============ =========== ======== =========== ============= =========
</TABLE>

See accompanying notes to financial statements.

F-6
<PAGE> 71

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
=========== ============ ============ =============
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-7
<PAGE> 72

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-8
<PAGE> 73
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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.

Included in costs capitalized to the full cost pool during the period
commencing July 10, 1997 and ending December 31, 1997, is $417,000 in general
and administrative costs. General and administrative costs capitalized to the
full cost pool are those incurred directly related to exploration and
development activities such as geological costs and other administrative costs
associated with overseeing the exploration and development activities. All
general and administrative costs not directly associated with exploration and
development activities were charged to expense as they were incurred.

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.

F-9
<PAGE> 74
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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.

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.

F-10
<PAGE> 75
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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.

The Company maintains cash balances at several banks. Accounts at each
institution are insured by the Federal Deposit Insurance Corporation up to
$100,000. At December 31, 1997 and 1996 the Company held cash in excess of
insured limits in these banks totaling $803,000 and $5,262,000 respectively.

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.

F-11
<PAGE> 76
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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 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.

F-12
<PAGE> 77
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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:

To determine the value allocated to the reorganized Company's assets, the
Company looked to the fair value of its equity securities. On the date of
reorganization there were 22,100,000 shares outstanding to which a value of
$71,993,000 or $3.26 per share was assigned. The Company believes that the 1997
Rights Offering of 3.8 million shares at $3.50 per share, in addition to
approximately 2,655,000 shares issued to fully secured creditors in exchange for
the conversion of their fully secured claims to equity at an exchange rate of
$3.50 per share, help to support the $3.26 value per share used in the fresh
start accounting. Once the value of the Company was established, the value
allocated to assets complied with the procedures outlined in APB Opinion 16.

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.

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.

F-13
<PAGE> 78
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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> 79
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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 FRESH START STOCK STOCK ISSUED TEXACO ACQUISITION
PRIOR TO CONSUMMATION RIGHTS FOR SECURED CLAIM PAID OF WCBB
CONSUMMATION ADJUSTMENTS(1) OFFERING(2) DEBT(3) WITH STOCK(4) ASSETS(5)
------------- -------------- ----------- ------------ ------------- -----------
<S> <C> <C> <C> <C> <C> <C>
ASSETS

Current assets:
Cash and cash
equivalents............ $ 3,714,000 $ $13,300,000 $ $ $
Accounts receivable,
net.................... 3,287,000
Prepaid expenses and
other.................. 870,000
------------- ------------- ----------- ----------- ----------- -----------
Total current
assets........... 7,871,000 13,300,000
------------- ------------- ----------- ----------- ----------- -----------
Property and equipment:
Properties subject to
depletion.............. 80,120,000 (20,187,000) 15,144,000
Properties not subject to
depletion.............. -- 5,000,000
Other property, plant and
equipment.............. 5,300,000 (2,362,000)
------------- ------------- ----------- ----------- ----------- -----------
85,420,000 (17,549,000) 15,144,000
Less accumulated
depreciation, depletion
and amortization....... (29,274,000) 29,274,000
------------- ------------- ----------- ----------- ----------- -----------
56,146,000 11,725,000 15,144,000
------------- ------------- ----------- ----------- ----------- -----------
Other assets............... 1,231,000 (285,000)
------------- ------------- ----------- ----------- ----------- -----------
$ 65,248,000 $ 11,440,000 $13,300,000 $ $ $15,144,000
============= ============= =========== =========== =========== ===========

LIABILITIES AND SHAREHOLDERS' EQUITY

Current liabilities:
Accounts payable and
accrued liabilities.... $ 9,545,000 $ (757,000) $ $ $ $
Pre-petition secured
debt................... 16,915,000
------------- ------------- ----------- ----------- ----------- -----------
Total current
liabilities...... 26,460,000 (757,000)
------------- ------------- ----------- ----------- ----------- -----------
Pre-petition current
liabilities subject to
compromise:
Unsecured debt........... 136,818,000 (123,845,000) (3,332,000) (5,962,000)
------------- ------------- ----------- ----------- ----------- -----------
Long-term liabilities:
Other non-current
liabilities............ 757,000
Notes payable............
------------- ------------- ----------- ----------- ----------- -----------
757,000
------------- ------------- ----------- ----------- ----------- -----------
Stockholders' equity
(deficit):
Common stock............. 95,000 5,000 38,000 9,000 17,000 57,000
Preferred stock.......... 27,677,000 (27,677,000)
Additional paid in
capital................ 39,570,000 (5,415,000) 13,262,000 3,323,000 5,945,000 15,087,000
Treasury stock........... (333,000) 333,000
Retained earnings........ (165,039,000) 168,039,000
------------- ------------- ----------- ----------- ----------- -----------
(98,030,000) 135,285,000 13,300,000 3,332,000 5,962,000 15,144,000
------------- ------------- ----------- ----------- ----------- -----------
$ 65,248,000 $ 11,440,000 $13,300,000 $ $ $15,144,000
============= ============= =========== =========== =========== ===========

<CAPTION>
PAYMENT OF
REFINANCING CLAIMS AND REORGANIZED
OF SECURED LITIGATION BALANCE
DEBT - NOTE 9 TRUST(6&7) SHEET
------------- ---------- -----------
<S> <C> <C> <C>
ASSETS
Current assets:
Cash and cash
equivalents............ $(3,247,000) $(8,455,000) $ 5,312,000
Accounts receivable,
net.................... 3,287,000
Prepaid expenses and
other.................. 870,000
----------- ----------- -----------
Total current
assets........... (3,247,000) (8,455,000) 9,469,000
----------- ----------- -----------
Property and equipment:
Properties subject to
depletion.............. 75,077,000
Properties not subject to
depletion.............. 5,000,000
Other property, plant and
equipment.............. 2,938,000
----------- ----------- -----------
83,015,000
Less accumulated
depreciation, depletion
and amortization....... --
----------- ----------- -----------
83,015,000
----------- ----------- -----------
Other assets............... 94,000 1,040,000
----------- ----------- -----------
$(3,153,000) $(8,455,000) $93,524,000
=========== =========== ===========
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities:
Accounts payable and
accrued liabilities.... $(1,238,000) $(1,776,000) $ 5,774,000
Pre-petition secured
debt................... (16,915,000)
----------- ----------- -----------
Total current
liabilities...... (18,153,000) (1,776,000) 5,774,000
----------- ----------- -----------
Pre-petition current
liabilities subject to
compromise:
Unsecured debt........... (3,679,000) --
----------- ----------- -----------
Long-term liabilities:
Other non-current
liabilities............ 757,000
Notes payable............ 15,000,000 15,000,000
----------- ----------- -----------
15,000,000 15,757,000
----------- ----------- -----------
Stockholders' equity
(deficit):
Common stock............. 221,000
Preferred stock..........
Additional paid in
capital................ 71,772,000
Treasury stock........... --
Retained earnings........ (3,000,000) --
----------- ----------- -----------
(3,000,000) 71,993,000
----------- ----------- -----------
(3,153,000) $(8,455,000) $93,524,000
=========== =========== ===========
</TABLE>

F-15
<PAGE> 80
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

- ---------------

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:

(1) 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.

(2) 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 its
unsecured creditors.

(3) Issued 952,000 shares of the Reorganized Company's common stock in payment
of $3,332,000 in secured claims.

(4) 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").

(5) 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.

(6) The Company paid $2,492,000 in administrative claims and $2,963,000 in
secured and priority claims.

(7) 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
F-16
<PAGE> 81
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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.

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.

F-17
<PAGE> 82
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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, 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>

F-18
<PAGE> 83
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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 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,

F-19
<PAGE> 84
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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 December 31, 1997
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.

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 has 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 canceled 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.

F-20
<PAGE> 85
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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 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> 86
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

12. INCOME TAXES

A reconciliation of the statutory federal income tax amount to the recorded
expense follows:

<TABLE>
<CAPTION>
JULY 11, 1997 JANUARY 1, 1997
THROUGH THROUGH
DECEMBER 31, JULY 10,
1997 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.

F-22
<PAGE> 87
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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").

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.

F-23
<PAGE> 88
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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 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.

F-24
<PAGE> 89
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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.

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

F-25
<PAGE> 90
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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.

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.

F-26
<PAGE> 91
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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>

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 JANUARY 1, 1997
THROUGH THROUGH
DECEMBER 31, JULY 10,
1997 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.

F-27
<PAGE> 92
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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 JANUARY 1 TO
DECEMBER 31, JULY 10,
1997 1997 1996 1995
--------------- --------------- ---------------- ---------------
OIL GAS OIL GAS OIL GAS OIL GAS
------ ------ ------ ------ ------ ------- ------ ------
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Proved Reserves:
Beginning of the period................ 13,677 13,409 13,923 15,121 14,627 19,131 7,431 28,797
Purchases of oil and gas reserves in
place................................ 11,612 163 -- -- -- -- 15,068 39,204
Extensions, discoveries and other
additions............................ -- -- -- -- 960 4,235
Revisions of prior reserve estimates... 848 (890) (89) (381) (7,821) (44,859)
Current production..................... (320) (1,106) (246) (1,712) (615) (3,629) (778) (7,403)
Sales of oil and gas reserves in
place................................ -- -- -- -- -- -- (233) (843)
------ ------ ------ ------ ------ ------- ------ ------
End of period.......................... 25,817 11,576 13,677 13,409 13,923 15,121 14,627 19,131
====== ====== ====== ====== ====== ======= ====== ======
Proved developed reserves.............. 7,219 8,259 7,248 8,252 9,550 11,687 10,209 16,663
====== ====== ====== ====== ====== ======= ====== ======
</TABLE>

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>

F-28
<PAGE> 93
GULFPORT ENERGY CORPORATION

NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)

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>

Comparison of Standardized Measure of Discounted Future Net Cash Flows to
the Net Carrying Value of Proved Oil and Gas Properties at December 31, 1997 and
1996 is as follows:

<TABLE>
<CAPTION>
1997 1996
----------- ------------
<S> <C> <C>
Standardized measure of discounted future net cash flows.... $76,430,000 $ 98,667,000
----------- ------------
Proved oil and gas properties............................... 79,349,000 77,541,000
Less accumulated depreciation, depletion and amortization... (4,371,000) (23,401,000)
----------- ------------
Net carrying value of proved oil and gas properties......... 74,978,000 54,140,000
----------- ------------
Standardized measure of discounted future net cash flows in
excess of net carry value of proved oil and gas
properties................................................ $ 1,452,000 $ 44,527,000
=========== ============
</TABLE>

F-29
<PAGE> 94

GULFPORT ENERGY CORPORATION

CONSOLIDATED BALANCE SHEETS

ASSETS

<TABLE>
<CAPTION>
JUNE 30, DECEMBER 31,
1998 1997
------------- -----------------
(UNAUDITED)
<S> <C> <C>
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:
Common stock -- $.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-30
<PAGE> 95

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-31
<PAGE> 96

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-32
<PAGE> 97

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.

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").

F-33
<PAGE> 98
GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) -- (CONTINUED)

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.

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.

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-34
<PAGE> 99
GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) -- (CONTINUED)

Earnings (Loss) per Share

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

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.

Use of 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-35
<PAGE> 100
GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) -- (CONTINUED)

Commitments and Contingencies

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.

F-36
<PAGE> 101
GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) -- (CONTINUED)

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.

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>

F-37
<PAGE> 102
GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) -- (CONTINUED)

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:

- 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.

- Issued 952,000 shares of the Reorganized Company's common stock in
payment of $3,332,000 in secured claims.

- 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.

- 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.

F-38
<PAGE> 103
GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) -- (CONTINUED)

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.

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 costs 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.

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

F-39
<PAGE> 104
GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) -- (CONTINUED)

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.

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

F-40
<PAGE> 105
GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) -- (CONTINUED)

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 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.

F-41
<PAGE> 106
GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) -- (CONTINUED)

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 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

F-42
<PAGE> 107
GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) -- (CONTINUED)

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 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 tortious 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
F-43
<PAGE> 108
GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) -- (CONTINUED)

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.

Other litigation

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 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.

F-44
<PAGE> 109
GULFPORT ENERGY CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) -- (CONTINUED)

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.

F-45
<PAGE> 110

------------------------------------------------------
------------------------------------------------------

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......................... 7
Use of Proceeds...................... 13
Capitalization....................... 14
Price Range of Common Stock and
Dividend Policy.................... 15
The Rights Offering.................. 16
Selected Historical Financial Data... 21
Management's Discussion and Analysis
of Financial Condition and Results
of Operations...................... 23
Business............................. 36
Management........................... 50
Principal Stockholders............... 53
Certain Transactions................. 54
Description of Securities............ 55
Material Federal Income Tax
Considerations..................... 56
Legal Matters........................ 58
Experts.............................. 58
Glossary............................. G-1
Index To Consolidated Financial
Statements......................... F-1
</TABLE>

------------------------------------------------------
------------------------------------------------------
------------------------------------------------------
------------------------------------------------------

200,000,000 SHARES

GULFPORT ENERGY
CORPORATION

COMMON STOCK
--------------------

PROSPECTUS
--------------------

OCTOBER 30, 1998

------------------------------------------------------
------------------------------------------------------
<PAGE> 111

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........................................... 20,000
Legal fees and expenses................................................... 100,000
Accounting fees and expenses.............................................. 10,000
Blue sky fees and expenses................................................ 2,000
Transfer agent and registrar fees and expenses............................ 15,000
Miscellaneous............................................................. 50
------------
Total............................................................... $ 150,000
============
</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

II-1
<PAGE> 112

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.

II-2
<PAGE> 113

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.

4.6** -- Warrant issued to ING.

5** -- Opinion of Akin, Gump, Strauss, Hauer & Feld, L.L.P.

8** -- 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.(7)
</TABLE>

II-3
<PAGE> 114

- ----------
* Filed herewith.
** Previously filed.
(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.
(7) Filed with Form 10-Q dated June 30, 1998.

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> 115

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> 116

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 October 29, 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 October 29, 1998.

<TABLE>
<CAPTION>
NAME TITLE
---- -----
<S> <C>

/s/ MARK LIDDELL President and Director (Principal
- --------------------------------------------- Executive Officer)
Mark Liddell

/s/ MIKE LIDDELL Chief Executive Officer, Acting
- --------------------------------------------- Chief Financial Officer and Director
Mike Liddell

/s/ CHARLES E. DAVIDSON Director
- ---------------------------------------------
Charles E. Davidson

/s/ Director
- ---------------------------------------------
Robert Brooks

/s/ Director
- ---------------------------------------------
David Houston
</TABLE>

S-1
<PAGE> 117

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)

2.5 -- 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.

4.6** -- Warrant issued to ING.

5** -- Opinion of Akin, Gump, Strauss, Hauer & Feld, L.L.P.

8** -- 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)

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.(7)

</TABLE>

- ----------
* Filed herewith.
** Previously filed.
(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.
(7) Filed with Form 10-Q dated June 30, 1998.

<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
October 29, 1998