<PAGE> 1
AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON OCTOBER 31, 1997
REGISTRATION NO. 333-38425
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SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
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AMENDMENT NO. 1
TO
FORM S-4
REGISTRATION STATEMENT UNDER THE SECURITIES ACT OF 1933
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STONE ENERGY CORPORATION
(Exact name of Registrant as specified in its charter)
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DELAWARE 1311 72-1235413
(State of other jurisdiction (Primary Standard Industrial (I.R.S. Employer
of incorporation or Classification Code Number) Identification No.)
organization)
625 E. KALISTE SALOOM ROAD ANDREW L. GATES, III
LAFAYETTE, LOUISIANA 70508 VICE PRESIDENT -- LEGAL AND GENERAL COUNSEL
(318) 237-0410 625 E. KALISTE SALOOM ROAD
(Address, including zip code, and telephone LAFAYETTE, LOUISIANA 70508
number, including area code, of registrant's (318) 237-0410
principal executive offices) (Name, Address, including zip code,
and telephone number, including
area code, of agent for service)
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Copy to:
ALAN P. BADEN
VINSON & ELKINS L.L.P.
2300 FIRST CITY TOWER
HOUSTON, TEXAS 77002-6760
(713) 758-2430
Approximate date of commencement of proposed sale of the securities to the
public: As soon as practicable following the effectiveness of this Registration
Statement.
If the securities being registered on this Form are being offered in
connection with the formation of a holding company and there is compliance with
General Instruction G, check the following box. [ ]
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CALCULATION OF REGISTRATION FEE
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TITLE OF EACH CLASS AMOUNT TO AMOUNT OF
OF SECURITIES TO BE REGISTERED BE REGISTERED REGISTRATION FEE
- -----------------------------------------------------------------------------------------------------------
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8 3/4% Senior Subordinated Notes due 2007....... $100,000,000 $30,303
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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 SAID SECTION 8(A),
MAY DETERMINE.
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INFORMATION CONTAINED HEREIN IS SUBJECT TO COMPLETION OR AMENDMENT. A
REGISTRATION STATEMENT RELATING TO THESE SECURITIES HAS BEEN FILED WITH THE
SECURITIES AND EXCHANGE COMMISSION. THESE SECURITIES MAY NOT BE SOLD NOR
MAY OFFERS TO BUY BE ACCEPTED PRIOR TO THE TIME THE REGISTRATION STATEMENT
BECOMES EFFECTIVE. THIS PROSPECTUS SHALL NOT CONSTITUTE AN OFFER TO SELL OR
THE SOLICITATION OF AN OFFER TO BUY NOR SHALL THERE BE ANY SALE OF THESE
SECURITIES IN ANY STATE IN WHICH SUCH OFFER, SOLICITATION OR SALE WOULD BE
UNLAWFUL PRIOR TO REGISTRATION OR QUALIFICATION UNDER THE SECURITIES LAWS
OF ANY SUCH STATE.
SUBJECT TO COMPLETION, DATED OCTOBER 31, 1997
PROSPECTUS
STONE ENERGY CORPORATION
OFFER TO EXCHANGE
8 3/4% SENIOR SUBORDINATED NOTES DUE 2007
THAT HAVE BEEN REGISTERED UNDER THE SECURITIES ACT OF 1933
FOR ALL OUTSTANDING 8 3/4% SENIOR SUBORDINATED NOTES DUE 2007
THE EXCHANGE OFFER WILL EXPIRE AT 5:00 P.M. NEW YORK CITY TIME,
ON DECEMBER 3, 1997, UNLESS EXTENDED
------------------------
Stone Energy Corporation, a Delaware corporation (the "Company"), hereby
offers, upon the terms and subject to the conditions set forth in this
Prospectus and the accompanying letter of transmittal (the "Letter of
Transmittal," and together with this Prospectus, the "Exchange Offer"), to
exchange $1,000 principal amount of its 8 3/4% Senior Subordinated Notes due
2007 (the "Exchange Notes"), which have been registered under the Securities Act
of 1933, as amended (the "Securities Act"), pursuant to a Registration Statement
(as defined) of which this Prospectus constitutes a part, for each $1,000
principal amount of its outstanding 8 3/4% Senior Subordinated Notes due 2007
(the "Old Notes"), of which $100,000,000 principal amount is outstanding. The
form and terms of the Exchange Notes are identical in all material respects to
the form and terms of the Old Notes except for certain transfer restrictions and
registration rights relating to the Old Notes. The Exchange Notes will evidence
the same debt as the Old Notes and will be issued under and be entitled to the
benefits of the Indenture (as defined). The Exchange Notes and the Old Notes are
collectively referred to herein as the "Notes."
The Notes are unsecured obligations of the Company, subordinated in right
of payment to all existing and future Senior Indebtedness (as defined) of the
Company. The Notes rank pari passu with any future Pari Passu Indebtedness (as
defined) of the Company and senior to any future Subordinated Indebtedness (as
defined) of the Company.
The Company will accept for exchange any and all Old Notes that are validly
tendered on or prior to 5:00 p.m., New York City time, on the date the Exchange
offer expires, which will be December 3, 1997, unless the Exchange Offer is
extended. See "The Exchange Offer -- Expiration Date; Extensions; Amendment."
Tenders of Old Notes may be withdrawn at any time prior to 5:00 p.m., New York
City time, on the business day prior to the Expiration Date (as defined), unless
previously accepted for exchange. The Exchange Offer is not conditioned upon any
minimum principal amount of Old Notes being tendered for exchange. However, the
Exchange Offer is subject to certain conditions which may be waived by the
Company and to the terms and provisions of the Registration Agreement (as
defined). Old Notes may be tendered only in denominations of $1,000 principal
amount and integral multiples thereof. The Company has agreed to pay the
expenses of the Exchange Offer. See "The Exchange Offer."
(Cover continued on next page)
------------------------
SEE "RISK FACTORS" BEGINNING ON PAGE 14 OF THIS PROSPECTUS FOR A DISCUSSION
OF CERTAIN FACTORS THAT SHOULD BE CONSIDERED IN EVALUATING AN INVESTMENT IN THE
NOTES.
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.
------------------------
The date of this Prospectus is October 31, 1997
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The Exchange Notes will bear interest at the rate of 8 3/4% per annum,
payable semi-annually on March 15 and September 15 of each year, commencing
March 15, 1998, to holders of record on the March 1 and September 1 immediately
preceding such interest payment date. Holders of Exchange Notes of record on
March 1, 1998 will receive interest on March 15, 1998 from the date of issuance
of the Exchange Notes, plus an amount equal to the accrued interest on the Old
Notes from the date of issuance of the Old Notes, September 19, 1997, to the
date of exchange thereof. Interest on the Old Notes accepted for exchange will
cease to accrue upon issuance of the Exchange Notes.
The Old Notes were sold by the Company on September 19, 1997 to the Initial
Purchasers (as defined) in a transaction not registered under the Securities Act
in reliance upon Section 4(2) of the Securities Act. The Old Notes were
thereupon offered and sold by the Initial Purchasers only to "qualified
institutional buyers" (as defined in Rule 144A under the Securities Act).
Accordingly, the Old Notes may not be offered, resold or otherwise transferred
unless registered under the Securities Act or unless an applicable exemption
from the registration requirements of the Securities Act is available. The
Exchange Notes are being offered hereunder in order to satisfy the obligations
of the Company under the Registration Agreement entered into with the Initial
Purchasers in connection with the offering of the Old Notes. See "The Exchange
Offer" and "Exchange Offer; Registration Rights."
Based on no-action letters issued by the staff of the Securities and
Exchange Commission (the "Commission" or "SEC") to third parties, including
Exxon Capital Holdings Corporation, SEC No-Action Letter (available April 13,
1989), Morgan Stanley & Co. Inc., SEC No-Action Letter (available June 5, 1991)
(the "Morgan Stanley Letter") and Mary Kay Cosmetics, Inc., SEC No-Action Letter
(available June 5, 1991), the Company believes that the Exchange Notes issued
pursuant to the Exchange Offer may be offered for resale, resold and otherwise
transferred by the respective holders thereof (other than a "Restricted Holder,"
being (i) a broker-dealer who purchased Old Notes exchanged for such Exchange
Notes directly from the Company to resell pursuant to Rule 144A or any other
available exemption under the Securities Act or (ii) a person that is an
affiliate of the Company within the meaning of Rule 405 under the Securities
Act), without compliance with the registration and prospectus delivery
provisions of the Securities Act, provided that such Exchange Notes are acquired
in the ordinary course of such holder's business and such holder is not
participating in, and has no arrangement with any person to participate in, the
distribution (within the meaning of the Securities Act) of such Exchange Notes.
Eligible holders wishing to accept the Exchange Offer must represent to the
Company that such conditions have been met. Holders who tender Old Notes in the
Exchange Offer with the intention to participate in a distribution of the
Exchange Notes may not rely upon the Morgan Stanley Letter or similar no-action
letters. See "The Exchange Offer -- General." Each broker-dealer that receives
Exchange Notes for its own account pursuant to the Exchange Offer must
acknowledge that it will deliver a prospectus in connection with any resale of
such Exchange Notes. The Letter of Transmittal states that by so acknowledging
and by delivering a prospectus, a broker-dealer will not be deemed to admit that
it is an "underwriter" within the meaning of the Securities Act. This
Prospectus, as it may be amended or supplemented from time to time, may be used
by a broker-dealer in connection with resales of Exchange Notes received in
exchange for Old Notes where such Exchange Notes were acquired by such broker-
dealer as a result of market-making activities or other trading activities. The
Company has agreed that, starting on the date hereof (the "Expiration Date") and
ending on the close of business 180 days after the Expiration Date, it will make
this Prospectus available to any broker-dealer for use in connection with any
such resale. See "Plan of Distribution."
The Company will not receive any proceeds from the Exchange Offer.
The Exchange Notes will constitute a new issue of securities with no
established trading market, and there can be no assurance as to the liquidity of
any markets that may develop for the Exchange Notes or as to the ability of or
price at which the holders of Exchange Notes would be able to sell their
Exchange Notes. Future trading prices of the Exchange Notes will depend on many
factors, including, among others, prevailing interest rates, the Company's
operating results and the market for similar securities. The Company does not
intend to apply for listing of the Exchange Notes on any securities exchange.
Salomon Brothers Inc, Credit Suisse First Boston Corporation, Howard, Weil,
Labouisse, Friedrichs Incorporated, Morgan Stanley & Co. Incorporated and
NationsBanc Capital Markets, Inc. (together, the "Initial Purchasers") have
informed the Company that they currently intend to make a market for the
2
<PAGE> 4
Exchange Notes. However, they are not so obligated, and any such market making
may be discontinued at any time without notice. Accordingly, no assurance can be
given that an active public or other market will develop for the Exchange Notes
or as to the liquidity of or the trading market for the Exchange Notes.
THE EXCHANGE OFFER IS NOT BEING MADE TO, NOR WILL THE COMPANY ACCEPT
SURRENDERS FOR EXCHANGE FROM, HOLDERS OF OLD NOTES IN ANY JURISDICTION IN WHICH
THE EXCHANGE OFFER OR THE ACCEPTANCE THEREOF WOULD NOT BE IN COMPLIANCE WITH THE
SECURITIES OR BLUE SKY LAWS OF SUCH JURISDICTION.
TABLE OF CONTENTS
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PAGE NO.
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Available Information....................................... 3
Incorporation of Certain Documents by Reference............. 4
Prospectus Summary.......................................... 5
Forward Looking Statements.................................. 14
Risk Factors................................................ 14
Private Placement........................................... 21
Use of Proceeds............................................. 21
Capitalization.............................................. 22
Selected Historical Financial Data.......................... 23
Management's Discussion and Analysis of Financial Condition
and Results of Operations................................. 24
Business.................................................... 30
Management.................................................. 44
Certain Stockholders........................................ 46
Description of Bank Credit Facility......................... 46
The Exchange Offer.......................................... 47
Description of Notes........................................ 55
Exchange Offer; Registration Rights......................... 87
Certain Federal Income Tax Consequences..................... 89
Plan of Distribution........................................ 92
Transfer Restrictions on Old Notes.......................... 93
Legal Matters............................................... 95
Experts..................................................... 96
Glossary of Oil and Gas Terms............................... 97
Index to Financial Statements............................... F-1
</TABLE>
AVAILABLE INFORMATION
The Company is subject to the informational requirements of the Securities
Exchange Act of 1934, as amended (the "Exchange Act"), and, in accordance
therewith, files reports, proxy and information statements and other information
with the Commission. Such reports, proxy and information statements and other
information can be inspected and copied at the public reference facilities
maintained by the Commission at Judiciary Plaza, 450 Fifth Street, N.W.,
Washington, D.C. 20549, and at the following regional offices of the Commission:
Seven World Trade Center, Suite 1300, New York, New York 10048 and Citicorp
Center, 500 West Madison Street, Suite 1400, Chicago, Illinois 60661-2511.
Copies of such materials can be obtained by mail from the Public Reference
Section of the Commission, at Judiciary Plaza, 450 Fifth Street, N.W.,
Washington, D.C. 20549, at prescribed rates. In addition, the Commission
maintains a site on the World Wide Web that contains reports, proxy and
information statements and other information filed electronically by the Company
with the Commission which can be accessed over the Internet at
http://www.sec.gov. While any Old Notes remain outstanding, the Company will
make available, upon request, to any holder and any prospective purchaser of Old
Notes, the information required pursuant to Rule 144A(d)(4) under the Securities
Act during any period in which the Company
3
<PAGE> 5
is not subject to Section 13 or 15(d) of the Exchange Act. Any such request
should be directed to the Secretary of the Company, 625 E. Kaliste Saloom Road,
Lafayette, Louisiana 70508.
This Prospectus constitutes part of a registration statement on Form S-4
(herein, together with all amendments and exhibits, referred to as the
"Registration Statement") filed by the Company with the Commission under the
Securities Act. This Prospectus omits certain of the information set forth in
the Registration Statement. Reference is hereby made to the Registration
Statement and to the exhibits relating thereto for further information with
respect to the Company and the securities offered hereby. Statements contained
herein concerning the provisions of contracts or other documents are not
necessarily complete, and each such statement is qualified in its entirety by
reference to the copy of the applicable contract or other document filed with
the Commission. Copies of the Registration Statement and the exhibits thereto
are on file at the offices of the Commission and may be obtained upon payment of
the fee prescribed by the Commission, or may be examined without charge at the
public reference facilities of the Commission described above.
INCORPORATION OF CERTAIN DOCUMENTS BY REFERENCE
The following documents have been filed by the Company with the Commission
pursuant to the Exchange Act (File No. 1-12074) and are incorporated herein by
reference:
(1) the Company's Annual Report on Form 10-K for the fiscal year ended
December 31, 1996;
(2) the Company's Quarterly Reports on Form 10-Q for the quarterly periods
ended March 31 and June 30, 1997; and
(3) the Company's Current Report on Form 8-K filed on August 15, 1997 as
amended by Form 8-K/A filed on October 15, 1997.
All documents filed by the Company pursuant to Section 13(a), 13(c), 14 or
15(d) of the Exchange Act subsequent to the date of this Prospectus and prior to
the termination of the offering made by this Prospectus shall be deemed to be
incorporated by reference herein and to be a part hereof from the date of filing
thereof. Any statement contained in a document incorporated or deemed to be
incorporated by reference herein shall be deemed to be modified or superseded
for purposes of this Prospectus to the extent that a statement contained herein,
or in any other subsequently filed document that also is or is deemed to be
incorporated by reference herein, modifies or supersedes such statement. Any
such statement so modified or superseded shall not be deemed, except as so
modified or superseded, to constitute a part of this Prospectus.
The Company hereby undertakes to provide without charge to each person,
including any beneficial owner, to whom a copy of this Prospectus has been
delivered, upon the written or oral request of such person, a copy of any or all
of the information that has been incorporated by reference in this Prospectus
(not including exhibits to the information that is incorporated by reference
herein unless such exhibits are specifically incorporated by reference in such
information). Requests for such copies should be directed to the Secretary of
the Company at 625 E. Kaliste Saloom Road, Lafayette, Louisiana 70508.
NO PERSON HAS BEEN AUTHORIZED TO GIVE ANY INFORMATION OR MAKE ANY
REPRESENTATIONS OTHER THAN THOSE CONTAINED OR INCORPORATED BY REFERENCE IN THIS
PROSPECTUS AND THE ACCOMPANYING LETTER OF TRANSMITTAL AND, IF GIVEN OR MADE,
SUCH INFORMATION OR REPRESENTATIONS MUST NOT BE RELIED UPON AS HAVING BEEN
AUTHORIZED BY THE COMPANY OR THE EXCHANGE AGENT. NEITHER THE DELIVERY OF THIS
PROSPECTUS OR THE ACCOMPANYING LETTER OF TRANSMITTAL, OR BOTH TOGETHER, NOR ANY
SALE MADE HEREUNDER SHALL UNDER ANY CIRCUMSTANCES CREATE AN IMPLICATION THAT
THERE HAS BEEN NO CHANGE IN THE AFFAIRS OF THE COMPANY SINCE THE DATE HEREOF.
NEITHER THIS PROSPECTUS NOR THE ACCOMPANYING LETTER OF TRANSMITTAL, OR BOTH
TOGETHER, CONSTITUTE AN OFFER TO SELL OR A SOLICITATION OF AN OFFER TO BUY ANY
OF THE SECURITIES OFFERED HEREBY BY ANYONE 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.
4
<PAGE> 6
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. As used herein, references to the "Company" or
"Stone Energy" mean Stone Energy Corporation and its consolidated subsidiaries,
unless the context requires otherwise. Certain terms relating to the oil and gas
industry are defined in "Glossary of Oil and Gas Terms."
THE COMPANY
Stone Energy Corporation is an independent oil and gas company engaged in
the development, exploration, acquisition and operation of oil and gas
properties onshore and offshore in the Gulf Coast Basin. The Company and its
predecessors have been active in the Gulf Coast Basin since 1973, which gives
the Company extensive geophysical, technical and operational expertise in this
area. As of August 1, 1997, the Company estimated that its proved reserves were
approximately 185.6 Bcf of gas and 18.4 MMBbls of oil, or an aggregate of
approximately 49.4 MMBOE, with a present value of estimated pre-tax future net
cash flows of approximately $372 million. The Company serves as operator of all
of its 14 properties.
The Company's business strategy is to increase production, cash flow and
reserves through the acquisition and development of mature properties located in
the Gulf Coast Basin. The Company seeks properties that have an established
production history, proved undeveloped reserves and multiple prospective
reservoirs that provide significant development opportunities and an attractive
price due to low current production levels and properties in which the Company
would have the ability to control operations. Prior to acquiring a property, the
Company performs a thorough geological, geophysical and engineering analysis of
the property to formulate a comprehensive development plan. Through development
activities, the Company seeks to increase cash flow from existing proved
reserves and to establish additional proved reserves. These activities typically
involve the drilling of new wells, workovers and recompletions of existing
wells, and the application of other techniques designed to increase production.
Stone Energy has budgeted $237 million of capital expenditures for 1997 and
1998, which includes $50 million spent in the first half of 1997. These amounts
compare to $79 million spent in 1996 and $46 million in 1995. Approximately 54%
of the 1997 and 1998 budgeted expenditures has been allocated to two key
properties described below. During the period from July 1, 1997 through December
31, 1998, the Company plans to drill 36 new wells, conduct 24
workovers/recompletions on existing wells and, depending upon the timing and
success of specific development activities, install five new offshore production
platforms.
At South Pelto Block 23, the Company plans capital expenditures of $81
million during 1997 and 1998 for the development and further exploration of a
significant discovery made in 1996. Fourteen new productive sands, as indicated
by electric logs, have been encountered in an area of the leaseblock and at
depths which had not been previously explored. Four wells have been drilled in
this area, all of which the Company believes will be commercially successful,
and the drilling of a fifth well is in progress. Two of the wells have been
placed on production, and the installation of the new "D" production platform is
scheduled for the fourth quarter of 1997 for the production of the other two
wells and, if successful, the fifth well. The Company believes that the
production from the "D" platform has the potential to materially increase the
Company's daily production.
On August 1, 1997, the Company closed its largest acquisition to date with
the purchase of certain interests in the Vermilion Block 255 Field, located
offshore Louisiana, for $36.6 million. Stone Energy serves as the operator of
the field, which consists of four Vermilion blocks. As of August 1, 1997, gross
daily production from this field was approximately 1,227 Bbls of oil and 12.2
MMcf of gas. The acquisition is consistent with the Company's strategy of
acquiring Gulf Coast Basin properties with multiple productive reservoirs and
development potential. The Company plans development expenditures of
approximately $11 million during 1997 and 1998 in this field. In addition, the
Company has arranged to acquire a 3-D seismic survey to more fully evaluate the
field's potential.
The Company's executive offices are located at 625 E. Kaliste Saloom Road,
Lafayette, Louisiana 70508, and its telephone number is (318) 237-0410.
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THE PRIVATE PLACEMENT AND USE OF PROCEEDS
The Old Notes were sold by the Company on September 19, 1997 to the Initial
Purchasers and were thereupon offered and sold by the Initial Purchasers only to
certain qualified buyers. The net proceeds of $96.9 million received by the
Company in connection with the sale of the Old Notes were used to repay all
borrowings outstanding under the term loan and all except $10 million of the
revolving credit loan outstanding under the Bank Credit Facility. It is
anticipated that the remainder of the net proceeds, if any, will be used for
general corporate purposes. See "Private Placement" and "Capitalization."
THE EXCHANGE OFFER
The Exchange Offer relates to the exchange of up to $100,000,000 principal
amount of Exchange Notes for up to $100,000,000 principal amount of Old Notes.
The form and terms of the Exchange Notes are identical in all material respects
to the form and terms of the Old Notes except that the Exchange Notes have been
registered under the Securities Act and will not contain certain transfer
restrictions and hence are not entitled to the benefits of the Registration
Agreement relating to the contingent increases in the interest rate provided for
pursuant thereto. The Exchange Notes will evidence the same debt as the Old
Notes and will be issued under and be entitled to the benefits of the Indenture
governing the Old Notes. See "Description of the Notes."
THE EXCHANGE OFFER......... Each $1,000 principal amount of Exchange Notes will
be issued in exchange for each $1,000 principal
amount of outstanding Old Notes. As of the date
hereof, $100,000,000 principal amount of Old Notes
are issued and outstanding. The Company will issue
the Exchange Notes to tendering holders of Old
Notes on or promptly after the Expiration Date.
RESALE..................... The Company believes that the Exchange Notes issued
pursuant to the Exchange Offer generally will be
freely transferable by the holders thereof without
registration or any prospectus delivery requirement
under the Securities Act, except for certain
Restricted Holders who may be required to deliver
copies of this Prospectus in connection with any
resale of the Exchange Notes issued in exchange for
such Old Notes. See "The Exchange Offer -- General"
and "Plan of Distribution."
EXPIRATION DATE............ 5:00 p.m., New York City time, on December 3, 1997,
unless the Exchange Offer is extended, in which
case the term "Expiration Date" means the latest
date to which the Exchange Offer is extended. See
"The Exchange Offer -- Expiration Date; Extensions;
Amendments."
INTEREST ON THE NOTES...... The Exchange Notes will bear interest payable
semi-annually on March 15 and September 15 of each
year, commencing March 15, 1998. Holders of
Exchange Notes of record on March 1, 1998 will
receive interest on March 15, 1998 from the date of
issuance of the Exchange Notes, plus an amount
equal to the accrued interest on the Old Notes from
the date of issuance of the Old Notes, September
19, 1997, to the date of exchange thereof.
Consequently, assuming the Exchange Offer is
consummated prior to the record date in respect of
the March 15, 1998 interest payment for the Old
Notes, holders who exchange their Old Notes for
Exchange Notes will receive the same interest
payment on March 15, 1998 that they would have
received had they not accepted the Exchange Offer.
Interest on the Old Notes accepted for exchange
will cease to accrue upon issuance of the Exchange
Notes. See "The Exchange Offer -- Interest on the
Exchange Notes."
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PROCEDURES FOR TENDERING
OLD NOTES.................. Each holder of Old Notes wishing to accept the
Exchange Offer must complete, sign and date the
Letter of Transmittal, or a facsimile thereof, in
accordance with the instructions contained herein
and therein, and mail or otherwise deliver such
Letter of Transmittal, or such facsimile, or an
Agent's Message (as defined) together with the Old
Notes to be exchanged and any other required
documentation to the Exchange Agent at the address
set forth herein and therein or effect a tender of
Old Notes pursuant to the procedures for book-entry
transfer as provided for herein. See "The Exchange
Offer -- Procedures for Tendering."
SPECIAL PROCEDURES FOR
BENEFICIAL HOLDERS....... Any beneficial holder whose Old Notes are
registered in the name of a broker, dealer,
commercial bank, trust company or other nominee and
who wishes to tender in the Exchange Offer should
contact such registered holder promptly and
instruct such registered holder to tender on the
beneficial holder's behalf. If such beneficial
holder wishes to tender directly, such beneficial
holder must, prior to completing and executing the
Letter of Transmittal and delivering the Old Notes,
either make appropriate arrangements to register
ownership of the Old Notes in such holder's name or
obtain a properly completed bond power from the
registered holder. The transfer of record ownership
may take considerable time. See "The Exchange
Offer -- Procedures for Tendering."
GUARANTEED DELIVERY
PROCEDURES............... Holders of Old Notes who wish to tender their Old
Notes and whose Old Notes are not immediately
available or who cannot deliver their Old Notes and
a properly completed Letter of Transmittal or any
other documents required by the Letter of
Transmittal to the Exchange Agent prior to the
Expiration Date, or who cannot complete the
procedure for book-entry transfer on a timely basis
and deliver an Agent's Message, may tender their
Old Notes according to the guaranteed delivery
procedures set forth in "The Exchange Offer --
Guaranteed Delivery Procedures."
WITHDRAWAL RIGHTS.......... Tenders of Old Notes may be withdrawn at any time
prior to 5:00 p.m., New York City time, on the
business day prior to the Expiration Date, unless
previously accepted for exchange. See "The Exchange
Offer -- Withdrawal of Tenders."
TERMINATION OF THE EXCHANGE
OFFER.................... The Company may terminate the Exchange Offer if it
determines that the Exchange Offer violates any
applicable law or interpretation of the staff of
the SEC. Holders of Old Notes will have certain
rights against the Company under the Registration
Agreement should the Company fail to consummate the
Exchange Offer. See "The Exchange Offer --
Termination" and "Exchange Offer; Registration
Rights."
ACCEPTANCE OF OLD NOTES AND
DELIVERY OF EXCHANGE
NOTES.................... Subject to certain conditions (as summarized above
in "Termination of the Exchange Offer" and
described more fully in "The Exchange
Offer -- Termination"), the Company will accept for
exchange any and all Old Notes which are properly
tendered in the Exchange Offer prior to 5:00 p.m.,
New York City time, on the Expiration Date. The
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<PAGE> 9
Exchange Notes issued pursuant to the Exchange
Offer will be delivered promptly following the
Expiration Date. See "The Exchange
Offer -- General."
EXCHANGE AGENT............. Texas Commerce Bank National Association is serving
as exchange agent (the "Exchange Agent") in
connection with the Exchange Offer. The mailing
address of the Exchange Agent is: Texas Commerce
Bank National Association, Corporate Trust
Services, P.O. Box 2320, Dallas, Texas 75221-2320.
Hand deliveries and deliveries by overnight courier
should be sent to: Texas Commerce Bank National
Association, Corporate Trust Services, 1201 Main
Street, 18th Floor, Dallas, Texas 75202. For
information with respect to the Exchange Offer, the
telephone number for the Exchange Agent is (214)
672-5125 or (800) 275-2048 and the facsimile number
for the Exchange Agent is (214) 672-5746 . See "The
Exchange Offer -- Exchange Agent."
USE OF PROCEEDS............ There will be no cash proceeds payable to the
Company from the issuance of the Exchange Notes
pursuant to the Exchange Offer. See "Use of
Proceeds." For a discussion of the use of the net
proceeds received by the Company from the sale of
the Old Notes, see "Private Placement."
TERMS OF THE NOTES
NOTES OUTSTANDING.......... $100 million aggregate principal amount of 8 3/4%
Senior Subordinated Notes due 2007.
MATURITY DATE.............. September 15, 2007.
INTEREST PAYMENT DATES..... March 15 and September 15 of each year, commencing
on March 15, 1998.
SUBORDINATION OF NOTES..... The Notes are unsecured obligations, subordinated
in right of payment to all existing and future
Senior Indebtedness of the Company. The Notes rank
pari passu with any future Pari Passu Indebtedness
of the Company and senior to any future
Subordinated Indebtedness of the Company. As of
August 1, 1997, after giving effect to the Offering
and the application of the estimated net proceeds
therefrom, (i) the Company would have had $55
million of available borrowing capacity under the
Bank Credit Facility, $10 million of which would
have been outstanding, and $3 million of other
Senior Indebtedness outstanding and (ii) the
Company would have had no Pari Passu Indebtedness
or Subordinated Indebtedness outstanding (other
than the Old Notes). See "Description of the
Notes -- Subordination."
SUBSIDIARY GUARANTIES...... Under certain circumstances, the Notes will in the
future be jointly and severally guaranteed on an
unsecured senior subordinated basis by Restricted
Subsidiaries of the Company. The terms of such
subordination will be the same as those for the
Notes. See "Description of the Notes -- Subsidiary
Guaranties."
OPTIONAL REDEMPTION........ The Notes are redeemable at the option of the
Company, in whole or in part, at any time on or
after September 15, 2002, at the redemption prices
set forth herein, plus accrued and unpaid interest
to the date of redemption. In addition, at any time
and from time to time prior to September 15, 2000,
the Company may redeem up to 33 1/3% of the
aggregate principal amount of the Notes originally
issued at a re-
8
<PAGE> 10
demption price of 108.750% of the principal amount
thereof, plus accrued and unpaid interest, if any,
to the date of redemption, with the net proceeds of
one or more Equity Offerings, provided that at
least 66 2/3% of the aggregate principal amount of
the Notes originally issued remains outstanding
immediately after such redemption.
SINKING FUND............... None.
CHANGE OF CONTROL.......... Upon the occurrence of a Change of Control, the
Company is required to make an offer to repurchase
the Notes at a purchase price in cash equal to 101%
of the principal amount thereof, plus accrued and
unpaid interest, if any, to the date of purchase.
See "Description of the Notes -- Repurchase at the
Option of Holders Upon a Change of Control."
CERTAIN COVENANTS.......... The Indenture for the Notes contains limitations
on, among other things, (a) the ability of the
Company and its Restricted Subsidiaries to incur
additional Indebtedness, (b) the creation of
certain Liens, (c) the making of certain Restricted
Payments including Investments, (d) the issuance
and sale of Capital Stock of Restricted
Subsidiaries, (e) Asset Sales, (f) the ability of
the Company to incur layered Indebtedness, (g)
transactions with Affiliates, (h) payment
restrictions affecting Restricted Subsidiaries and
(i) certain consolidations, mergers and transfers
of assets (the foregoing capitalized terms are
defined in "Description of the Notes -- Certain
Definitions"). All of these limitations are subject
to a number of important qualifications. See
"Description of the Notes."
EXCHANGE OFFER;
REGISTRATION RIGHTS........ The Company agreed to use its reasonable best
efforts to file and cause to become effective the
Exchange Offer Registration Statement (as defined)
relating to the Exchange Offer for the Old Notes
or, in lieu thereof, to file and cause to become
effective the Shelf Registration Statement (as
defined) for the resale of the Old Notes. If (i)
neither the Exchange Offer Registration Statement
nor the Shelf Registration Statement has been filed
with the Commission on or prior to the 60th day
following the original issuance of the Old Notes,
(ii) neither the Exchange Offer Registration
Statement nor the Shelf Registration Statement has
been declared effective by the Commission on or
prior to the 120th day following the original
issuance of the Old Notes, (iii) neither the
Exchange Offer has been consummated nor the Shelf
Registration Statement has been declared effective
on or prior to the 150th day following the original
issuance of the Old Notes or (iv) after either the
Exchange Offer Registration Statement or the Shelf
Registration Statement has been declared effective,
such registration statement thereafter ceases to be
effective or usable (subject to certain exceptions)
in connection with resales of Old Notes or Exchange
Notes in accordance with and during the periods
specified in the Registration Agreement (as
defined), then Special Interest (in addition to the
stated interest on the Old Notes and the Exchange
Notes) will accrue on the Old Notes and the
Exchange Notes. Upon the consummation of the
Registered Exchange Offer or the declaration of
effectiveness of such Shelf Registration Statement
with respect to the Old Notes, the Special Interest
will cease accruing. See "Exchange Offer;
Registration Rights."
9
<PAGE> 11
ABSENCE OF A PUBLIC MARKET
FOR THE NOTES............ The Exchange Notes will be a new issue of
securities for which there is currently no market.
The Company does not intend to apply for listing of
the Notes on any securities exchange or stock
market. Although the Initial Purchasers have
informed the Company that they each currently
intend to make a market in the Notes and, if
issued, the Exchange Notes, they are not obligated
to do so, and any such market making may be
discontinued at any time without notice.
Accordingly, there can be no assurance as to the
development or liquidity of any market for the
Notes. The Old Notes currently trade in The Portal
Market.
RISK FACTORS
Prior to making an investment decision, prospective investors in the Notes
should consider all the information set forth in this Prospectus and should
carefully evaluate the considerations set forth in "Risk Factors."
10
<PAGE> 12
SUMMARY OIL AND GAS RESERVE DATA
The following table sets forth summary information with respect to the
Company's estimated proved oil and gas reserves. All information in this
Prospectus as of December 31, 1994, 1995 and 1996 relating to estimated oil and
gas reserves and the estimated future net cash flows attributable thereto is
based upon the reserve reports (the "Reserve Reports") prepared by Atwater
Consultants, Ltd. and Cawley, Gillespie & Associates, Inc., both independent
petroleum engineers (the "Independent Engineers"), except for the reserves
attributed to Eugene Island Block 243 Field at December 31, 1994, which were
estimated by the Company. All information in this Prospectus as of August 1,
1997 relating to estimated oil and gas reserves and estimated future net cash
flows attributable thereto is based upon estimates by the Company. All
calculations of estimated reserves have been made in accordance with the rules
and regulations of the Commission and, except as otherwise indicated, give no
effect to federal or state income taxes otherwise attributable to estimated
future cash flows from the sale of oil and gas. See "Risk Factors -- Uncertainty
of Estimates of Oil and Gas Reserves," "Business -- Oil and Gas Reserves" and
"Experts."
<TABLE>
<CAPTION>
AS OF AS OF DECEMBER 31,
AUGUST 1, ------------------------------
1997(1) 1996 1995 1994
--------- -------- -------- --------
<S> <C> <C> <C> <C>
Total proved:
Oil (MBbls)............................................... 18,427 12,772 7,985 6,455
Gas (MMcf)................................................ 185,572 144,316 81,179 68,285
Total (MBOE).............................................. 49,356 36,825 21,515 17,836
Proved developed:
Oil (MBbls)............................................... 14,927 9,260 7,055 5,840
Gas (MMcf)................................................ 139,723 109,628 67,797 52,215
Total (MBOE).............................................. 38,214 27,531 18,355 14,543
Estimated future net cash flows before income taxes
(in thousands)............................................ $544,114 $712,379 $259,478 $145,006
Present value of estimated future net cash flows before
income taxes (in thousands)(2)............................ $372,314 $448,895 $179,725 $ 97,391
Prices(3):
Oil (per Bbl)............................................. $ 18.94 $ 25.97 $ 19.40 $ 16.74
Gas (per Mcf)............................................. 2.26 3.94 2.39 1.72
</TABLE>
- ---------------
(1) The increase in the Company's estimate of its proved reserves as of August
1, 1997, from December 31, 1996, is primarily attributable to the
acquisition of the Vermilion Block 255 Field and the development of South
Pelto Block 23.
(2) The present value of estimated future net cash flows attributable to the
Company's reserves was prepared using constant prices as of the calculation
date, discounted at 10% per annum on a pre-tax basis.
(3) Represents weighted average prices received by the Company (net of effects
of hedging), as of the date indicated, and used in calculating "Estimated
future net cash flows before income taxes" and "Present value of estimated
future net cash flows before income taxes."
SUMMARY OPERATING DATA
<TABLE>
<CAPTION>
SIX MONTHS
ENDED
JUNE 30, YEAR ENDED DECEMBER 31,
--------------- -------------------------------------------
1997 1996 1996 1995 1994 1993 1992
------ ------ ------- ------ ------ ------ ------
<S> <C> <C> <C> <C> <C> <C> <C>
Production:
Oil (MBbls)............................... 694 663 1,356 1,400 1,113 1,016 745
Gas (MMcf)................................ 5,990 6,128 11,331 8,399 6,629 4,953 2,941
Oil and gas (MBOE)........................ 1,692 1,684 3,245 2,800 2,218 1,842 1,235
Average sales prices (inclusive of hedging
activities):
Oil (per Bbl)............................. $20.28 $19.75 $ 20.49 $17.70 $16.61 $17.47 $19.54
Gas (per Mcf)............................. 2.49 2.50 2.48 1.66 1.92 2.16 1.96
Per BOE................................... 17.14 16.86 17.21 13.82 14.06 15.46 16.47
Average costs (per BOE):
Normal lease operating expenses........... $ 2.58 $ 2.36 $ 2.66 $ 2.25 $ 2.39 $ 2.35 $ 3.37
General and administrative................ 1.04 0.99 1.08 1.18 1.40 1.22 1.47
Depreciation, depletion and
amortization............................ 6.89 6.06 5.93 5.57 5.15 4.20 3.83
</TABLE>
11
<PAGE> 13
SUMMARY FINANCIAL DATA
<TABLE>
<CAPTION>
SIX MONTHS ENDED
JUNE 30,(1) YEAR ENDED DECEMBER 31,
----------------- -----------------------------------------------
1997 1996 1996 1995 1994 1993 1992
------- ------- ------- ------- ------- ------- -------
(IN THOUSANDS, EXCEPT RATIOS)
<S> <C> <C> <C> <C> <C> <C> <C>
STATEMENT OF OPERATIONS DATA:
Revenues:
Oil production revenue.............. $14,075 $13,091 $27,788 $24,775 $18,482 $17,752 $14,557
Gas production revenue.............. 14,930 15,300 28,051 13,918 12,697 10,718 5,778
Other revenue....................... 894 1,105 2,126 1,858 1,708 1,252 616
------- ------- ------- ------- ------- ------- -------
Total revenues............... 29,899 29,496 57,965 40,551 32,887 29,722 20,951
------- ------- ------- ------- ------- ------- -------
Expenses:
Operating costs and production
taxes............................. 6,347 5,739 12,451 9,797 9,449 7,148 5,869
Depreciation, depletion and
amortization...................... 11,929 10,334 19,564 15,719 11,569 8,028 5,019
Interest expense.................... 1,103 1,537 3,574 2,191 982 1,499 1,743
Other expense....................... -- -- -- -- -- 1,025 365
General and administrative costs.... 1,759 1,662 3,509 3,298 3,099 2,248 1,818
Incentive compensation plan......... 316 278 928 85 1,358 -- --
------- ------- ------- ------- ------- ------- -------
Total expenses............... 21,454 19,550 40,026 31,090 26,457 19,948 14,814
------- ------- ------- ------- ------- ------- -------
Net income before income taxes and
cumulative effect of change in
accounting principle................ 8,445 9,946 17,939 9,461 6,430 9,774 6,137
Provision for income taxes............ 3,252 3,829 6,906 3,645 2,410 943 --
------- ------- ------- ------- ------- ------- -------
Net income before cumulative effect of
change in accounting principle...... 5,193 6,117 11,033 5,816 4,020 8,831 6,137
Cumulative effect of change in
accounting principle(2)............. -- -- -- -- -- -- 1,377
------- ------- ------- ------- ------- ------- -------
Net income............................ $ 5,193 $ 6,117 $11,033 $ 5,816 $ 4,020 $ 8,831 $ 7,514
======= ======= ======= ======= ======= ======= =======
CASH FLOW DATA:
Net cash provided by operating
activities (excluding working
capital changes).................... $20,274 $20,158 $37,295 $25,049 $17,911 $17,852 $11,156
Investment in oil and gas
properties.......................... 40,453 16,321 72,733 48,122 41,174 18,167 9,366
Net cash provided by (used in)
financing activities................ 24,863 5,000 44,906 25,164 6,530 25,166 (4,049)
OTHER FINANCIAL DATA:
EBITDA(3)............................. $21,477 $21,817 $41,077 $27,371 $18,981 $19,301 $12,899
Ratio of earnings to fixed
charges(4).......................... 8.0x 7.3x 5.9x 5.2x 7.5x 7.5x 4.5x
Ratio of EBITDA to interest expense... 19.5x 13.4x 11.2x 11.4x 19.3x 12.9x 7.4x
Ratio of total debt to EBITDA......... -- -- 0.6x 1.7x 1.2x 1.2x 2.2x
</TABLE>
<TABLE>
<CAPTION>
AS OF JUNE 30, 1997(1)
---------------------------
PRO FORMA
HISTORICAL AS ADJUSTED(5)
---------- --------------
(IN THOUSANDS)
<S> <C> <C>
BALANCE SHEET DATA:
Cash and marketable securities.............................. $ 26,399 $ 54,209
Oil and gas properties, net................................. 210,159 241,159
Total assets................................................ 253,556 315,483
Long-term debt, less current portion........................ 51,137 113,064
Stockholders' equity........................................ 149,530 149,530
</TABLE>
(see footnotes on following page)
12
<PAGE> 14
(1) Unaudited.
(2) Represents the adoption of Statement of Financial Accounting Standards No.
109, "Accounting For Income Taxes," effective January 1, 1992.
(3) EBITDA is defined as earnings before interest, taxes, depreciation,
depletion and amortization and certain other non-cash charges. EBITDA is
included as a supplemental disclosure because it is commonly accepted as
providing useful information regarding a company's ability to service and
incur debt. EBITDA, however, should not be considered in isolation or as a
substitute for net income, cash flow provided by operating activities or
other income or cash flow data prepared in accordance with generally
accepted accounting principles or as a measure of a company's profitability
or liquidity.
(4) For purposes of calculating the ratio of earnings to fixed charges, earnings
is defined as income of the Company and its subsidiaries before income taxes
and fixed charges. Fixed charges consist of interest expense, including
amortization of financing costs and any discount or premium related to any
indebtedness.
(5) Historical amounts as adjusted on a pro forma basis for the acquisition of
the Vermilion Block 255 Field, the Offering and the application of the
estimated net proceeds therefrom.
13
<PAGE> 15
FORWARD-LOOKING STATEMENTS
This Prospectus includes "forward-looking statements" within the meaning of
Section 27A of the Securities Act and Section 21E of the Exchange Act. All
statements other than statements of historical facts included in this
Prospectus, including without limitation statements under "Summary," "Risk
Factors," "Management's Discussion and Analysis of Financial Condition and
Results of Operations" and "Business" regarding budgeted capital expenditures,
increases in oil and gas production, the Company's financial position, oil and
gas reserve estimates, business strategy and other plans and objectives for
future operations, are forward-looking statements. Although the Company believes
that the expectations reflected in such forward-looking statements are
reasonable, it can give no assurance that such expectations will prove to have
been correct. There are numerous uncertainties inherent in estimating quantities
of proved oil and natural gas reserves and in projecting future rates of
production and timing of development expenditures, including many factors beyond
the control of the Company. Reserve engineering is a subjective process of
estimating underground accumulations of oil and natural gas that cannot be
measured in an exact way, and the accuracy of any reserve estimate is a function
of the quality of available data and of engineering and geological
interpretation and judgment. As a result, estimates made by different engineers
often vary from one another. In addition, results of drilling, testing and
production subsequent to the date of an estimate may justify revisions of such
estimate and such revisions, if significant, would change the schedule of any
further production and development drilling. Accordingly, reserve estimates are
generally different from the quantities of oil and natural gas that are
ultimately recovered. Additional important factors that could cause actual
results to differ materially from the Company's expectations are disclosed under
"Risk Factors" and elsewhere in this Prospectus. Should one or more of these
risks or uncertainties occur, or should underlying assumptions prove incorrect,
the Company's actual results and plans for 1997 and beyond could differ
materially from those expressed in forward-looking statements. All subsequent
written and oral forward-looking statements attributable to the Company or
persons acting on its behalf are expressly qualified in their entirety by such
factors.
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 Exchange Notes.
VOLATILITY OF OIL AND GAS PRICES; MARKETABILITY OF PRODUCTION
The Company's revenue, profitability and future rate of growth are
substantially dependent upon the prevailing prices of, and demand for, oil and
natural gas. Prices for oil and natural gas have been volatile and are likely to
continue to be subject to wide fluctuation in response to relatively minor
changes in the supply of and demand for oil and natural gas, market uncertainty
and a variety of additional factors that are beyond the control of the Company.
These factors include the level of consumer product demand, weather conditions,
domestic and foreign governmental regulations, the price and availability of
alternative fuels, political conditions in the Middle East, the foreign supply
of oil and natural gas, the price of oil and gas imports and overall economic
conditions. From time to time, oil and gas prices have been depressed by excess
domestic and imported supplies. There can be no assurance that current price
levels will be sustained. It is impossible to predict future oil and natural gas
price movements with any certainty. Declines in oil and natural gas prices may
adversely affect the Company's financial condition, liquidity and results of
operations and may reduce the amount of the Company's oil and natural gas that
can be produced economically. Additionally, substantially all the Company's
sales of oil and natural gas are made in the spot market or pursuant to
contracts based on spot market prices and not pursuant to long-term fixed price
contracts. With the objective of reducing price risk, the Company may from time
to time enter into hedging transactions with respect to a portion of its
expected future production. See "-- Risks of Hedging Transactions." There can be
no assurance that such hedging transactions will reduce risk or mitigate the
effect of any substantial or extended decline in oil or natural gas prices. Any
substantial or extended decline in the prices of oil or natural gas would have a
material adverse effect on the Company's financial condition and results of
operations.
14
<PAGE> 16
In addition, the marketability of the Company's production depends upon the
availability and capacity of gas gathering systems, pipelines and processing
facilities. The unavailability or lack of capacity thereof could result in the
shut-in of producing wells or the delay or discontinuance of development plans
for properties. Federal and state regulation of oil and gas production and
transportation, general economic conditions and changes in supply and demand all
could adversely affect the Company's ability to produce and market its oil and
natural 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 represent
a significant risk. See "Management's Discussion and Analysis of Financial
Condition and Results of Operations."
UNCERTAINTY OF ESTIMATES OF OIL AND GAS RESERVES
This Prospectus contains estimates of the Company's proved oil and gas
reserves and the estimated future net revenues therefrom based upon the
Company's own estimates or on Reserve Reports that rely upon various
assumptions, including assumptions required by the Commission as to oil and gas
prices, drilling and operating expenses, capital expenditures, taxes and
availability of funds. The process of estimating oil and gas reserves is
complex, requiring significant decisions and assumptions in the evaluation of
available geological, geophysical, engineering and economic data for each
reservoir. As a result, such estimates are inherently imprecise. Actual future
production, oil and gas prices, revenues, taxes, development expenditures,
operating expenses and quantities of recoverable oil and gas reserves may vary
substantially from those estimated by the Company or contained in the Reserve
Reports. Any significant variance in these assumptions could materially affect
the estimated quantity and value of reserves set forth in this Prospectus. The
Company's properties may also be susceptible to hydrocarbon drainage from
production by other operators on adjacent properties. In addition, the Company's
proved reserves may be subject to downward or upward revision based upon
production history, results of future exploration and development, prevailing
oil and gas prices, mechanical difficulties, government regulation and other
factors, many of which are beyond the Company's control. Actual production,
revenues, taxes, development expenditures and operating expenses with respect to
the Company's reserves will likely vary from the estimates used, and such
variances may be material.
Data included in this Prospectus regarding the Company's reserves as of
August 1, 1997 have not been reported upon by the Independent Engineers.
Approximately 23% of the Company's total proved reserves at August 1, 1997 were
undeveloped, which are by their nature less certain. Recovery of such reserves
will require significant capital expenditures and successful drilling
operations. The Company's reserve data assume that substantial capital
expenditures by the Company will be required to develop such reserves. Although
cost and reserve estimates attributable to the Company's oil and gas reserves
have been prepared in accordance with industry standards, no assurance can be
given that the estimated costs are accurate, that development will occur as
scheduled or that the results will be as estimated. See "Business -- Oil and Gas
Reserves."
The present value of future net revenues referred to in this Prospectus
should not be construed as the current market value of the estimated oil and gas
reserves attributable to the Company's properties. In accordance with applicable
requirements of the Commission, the estimated discounted future net cash flows
from proved reserves are generally based on prices and costs as of the date of
the estimate, whereas actual future prices and costs may be materially higher or
lower. Actual future net cash flows also will be affected by increases in
consumption by gas and oil purchasers and changes in governmental regulations or
taxation. The timing of actual future net cash flows from proved reserves, and
thus their actual present value, will be affected by the timing of both the
production and the incurrence of expenses in connection with development and
production of oil and gas properties. In addition, the 10% discount factor,
which is required by the Commission to be used in calculating discounted future
net cash flows for reporting purposes, is not necessarily the most appropriate
discount factor based on interest rates in effect from time to time and risks
associated with the Company or the oil and gas industry in general.
SUBSTANTIAL CAPITAL REQUIREMENTS
The Company makes, and will continue to make, substantial expenditures for
the development, exploration, acquisition and production of oil and gas
reserves. The Company made capital expenditures
15
<PAGE> 17
of $46 million during 1995 and $79 million during 1996. The Company plans to
make capital expenditures of approximately $144 million in 1997 (which includes
year to date acquisition and development expenditures) and $93 million in 1998,
and none of the amounts budgeted for future expenditures include acquisition
costs. Management believes that the cash provided by operating activities,
borrowings under the Bank Credit Facility and the proceeds from the Offering
will be sufficient to fund planned capital expenditures in 1997 and 1998.
However, if revenues or cash flows from operations decrease as a result of lower
oil and natural gas prices, operating difficulties or other factors, many of
which are beyond the control of the Company, the Company may be limited in its
ability to expend the capital necessary to undertake or complete its drilling
program, or it may be forced to raise additional debt or equity proceeds to fund
such expenditures. There can be no assurance that additional debt or equity
financing or cash generated by operations will be available to meet these
requirements. See "Management's Discussion and Analysis of Financial Condition
and Results of Operations -- Liquidity and Capital Resources."
NEED FOR ACQUISITION AND DEVELOPMENT OF ADDITIONAL RESERVES
The Company's future success, as is generally the case in the industry,
depends upon its ability to find, develop or acquire additional oil and gas
reserves that are economically recoverable. Unless the Company acquires
additional properties containing proved reserves or conducts successful
development and exploitation activities on properties it currently owns, the
Company's proved reserves will decline resulting in lower revenues and cash flow
from operations. The successful acquisition of producing properties requires an
assessment of recoverable reserves, future oil and gas prices and operating
costs, potential environmental and other liabilities, title issues and other
factors. Such assessments are necessarily inexact and their accuracy is
inherently uncertain. In addition, any such assessment will not reveal all
existing or potential problems, nor will it permit the Company to become
sufficiently familiar with the properties to assess fully their deficiencies and
capabilities. The inventory of oil and gas properties offered for sale has
declined over the last several years. This reduced availability of properties,
combined with the emergence during the same period of a number of
well-capitalized independent oil and gas companies, has caused an increase in
the prices paid for properties. See "-- Competition" and "Management's
Discussion and Analysis of Financial Condition and Results of Operations."
The Company's strategy includes increasing its production and reserves by
the implementation of a carefully designed field-wide development plan that is
formulated prior to acquisition of a property. There can be no assurance,
however, that the Company's development projects will result in significant
additional reserves or that the Company will have success drilling productive
wells at economically viable costs. Furthermore, while the Company's revenues
may increase if prevailing oil and gas prices increase, the Company's finding
costs for additional reserves could also increase. The Company's strategy
includes a significant increase in development activities and related capital
expenditures due to, among other things, its significant acquisitions in 1996
and 1997. There can be no assurance that the Company can effectively manage this
increased activity.
DRILLING RISKS; OPERATING DELAYS
Drilling involves numerous risks, including the risk that no commercially
productive oil or gas reservoirs will be encountered. The cost of drilling and
completing wells is often uncertain, and drilling operations may be curtailed,
delayed or canceled as a result of a variety of factors, many of which are
beyond the Company's control, including unexpected drilling conditions, pressure
or irregularities in formations, equipment failures or accidents, weather
conditions, and shortages or delays in the delivery of equipment. Demand for
drilling rigs, production equipment and related services increased significantly
during 1996 and to date in 1997, and the costs associated with these items are
higher than in 1995. The Company has experienced delays in obtaining such
equipment and services, and in some instances the costs incurred are higher than
originally budgeted. There can be no assurance as to the success of the
Company's future drilling activities. See "Management's Discussion and Analysis
of Financial Condition and Results of Operations."
16
<PAGE> 18
OPERATING HAZARDS
The oil and gas business involves a variety of operating risks, including
the risk of fire, explosions, blowouts, 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 which 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 addition to the foregoing, the
Company's offshore operations are subject to the additional hazards of marine
operations, such as capsizing, collision and adverse weather and sea conditions.
In accordance with customary industry practice, the Company maintains insurance
against some, but not all, of the risks described above. There can be no
assurance that any insurance obtained by the Company will be adequate to cover
any losses or liabilities. The Company cannot predict the continued availability
of insurance or the availability of insurance at premium levels that justify its
purchase.
COMPLIANCE WITH GOVERNMENTAL REGULATIONS
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 or political conditions. Matters subject to regulation include
discharge permits for drilling operations, drilling and abandonment bonds or
other financial responsibility requirements, 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 in order to conserve supplies of oil and gas. 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. For example, the Oil Pollution Act of 1990 ("OPA")
requires operators of offshore oil production facilities located in waters of
the United States to establish evidence of financial responsibility to cover
environmental cleanup and restoration costs that could be incurred in connection
with an oil spill, and imposes strict liability on responsible parties, as
defined therein, for such spills, subject to certain limitations. Under OPA and
other environmental protection laws, fines, civil and criminal penalties,
cleanup costs and other damages could be imposed on the Company in connection
with a spill of oil or other pollutants from one of the Company's facilities.
See "Management's Discussion and Analysis of Financial Conditions and Results of
Operations -- Liquidity and Capital Resources -- Regulatory and Litigation
Issues" and "Business -- Regulation."
EFFECTS OF LEVERAGE
As of August 1, 1997, after giving effect to the Offering and the
application of the estimated net proceeds therefrom, the Company's long-term
debt would have been $113 million and the Company would have had $45 million of
additional available borrowing capacity under the Bank Credit Facility. See
"Capitalization." In addition, the Indenture allows the Company to incur
significant amounts of additional Indebtedness under certain circumstances.
The Company's level of indebtedness will have several important effects on
its operations, as well as significant consequences to holders of the Exchange
Notes, including (i) a substantial portion of the Company's cash flow from
operations will be dedicated to the payment of interest on its indebtedness and
will not be available for other purposes, (ii) the covenants contained in the
Indenture and the Bank Credit Facility limit its ability to borrow additional
funds or to dispose of assets and may affect the Company's flexibility in
planning for, and reacting to, changes in business conditions, (iii) the
Company's ability to obtain additional financing in the future for working
capital, capital expenditures (including acquisitions), general corporate
purposes or other purposes may be impaired, (iv) the Company's leveraged
financial position may make the Company more vulnerable to economic downturns
and may limit its ability to withstand competitive pressures, (v) to the extent
that the Company incurs any indebtedness under the Bank Credit Facility, which
indebtedness will be at variable rates, the Company may be vulnerable to
increases in interest rates and (vi) the Company's flexibility in planning for
or
17
<PAGE> 19
reacting to changes in market conditions may be limited. Moreover, future
acquisition or development activities may require the Company to alter its
capitalization significantly. These changes in capitalization may significantly
increase the leverage of the Company. The Company's ability to meet its debt
service obligations and to reduce its total indebtedness will be dependent upon
the Company's future performance, which will be subject to general economic
conditions and to financial, business and other factors affecting the operations
of the Company, many of which are beyond its control. If the Company is unable
to generate sufficient cash flow from operations in the future to service its
indebtedness and to meet its other commitments, the Company will be required to
adopt one or more alternatives, such as refinancing or restructuring its
indebtedness, selling material assets or operations or seeking to raise
additional debt or equity capital. There can be no assurance that any of these
actions could be effected on a timely basis or on satisfactory terms or that
these actions would enable the Company to continue to satisfy its capital
requirements. The terms of the Company's indebtedness, including the Bank Credit
Facility and the Indenture, also may prohibit the Company from taking such
actions. See "Management's Discussion and Analysis of Financial Condition and
Results of Operations -- Liquidity and Capital Resources."
SUBORDINATION OF NOTES
The Notes will be subordinated in right of payment to all present and
future Senior Indebtedness of the Company, including the principal, premium (if
any) and interest with respect to the Bank Credit Facility. The Indenture
limits, but does not prohibit, the incurrence by the Company of additional
Senior Indebtedness and Pari Passu Indebtedness. The amount of such additional
Indebtedness may be substantial. In the event of a bankruptcy, liquidation,
reorganization or other winding up of the Company, the assets of the Company
will be available to pay the obligations on the Notes only after all Senior
Indebtedness of the Company has been paid in full, and there may not be
sufficient assets remaining to pay amounts due on the Notes and any other Pari
Passu Indebtedness. In addition, under certain circumstances, no payments may be
made with respect to principal of, or premium, if any, or interest on, the Notes
if a default exists with respect to any Senior Indebtedness. As of August 1,
1997, after giving effect to the Offering and the application of the estimated
net proceeds therefrom, the Company would have had $55 million of available
borrowing capacity under the Bank Credit Facility, $10 million of which would
have been outstanding, and $3 million of other Senior Indebtedness outstanding.
The terms of the subordination of any Subsidiary Guaranties will be the same as
those for the Notes. See "Description of the Notes -- Subordination."
The Notes are also unsecured and will be effectively subordinated to any
secured indebtedness of the Company. If the Company were unable to repay its
secured borrowings, such lenders could proceed against the collateral. Under
certain circumstances, the lenders under the Bank Credit Facility may require
such facility to be secured by the oil and gas properties of the Company.
PAYMENT UPON A CHANGE OF CONTROL
Upon the occurrence of a Change of Control, each holder of the Notes may
require the Company to purchase all or a portion of such holder's Notes at 101%
of the principal amount of the Notes, together with accrued and unpaid interest,
if any, to the date of purchase. Prior to any such repurchase of the Notes, the
Company may be required to (i) repay all or a portion of indebtedness under the
Bank Credit Facility or other indebtedness of the Company or any Subsidiary
Guarantor or (ii) obtain certain consents to permit the repurchase, including
consents under the Bank Credit Facility. If the Company is unable to repay all
of such indebtedness or is unable to obtain the necessary consents, the Company
would be unable to offer to repurchase the Notes, which would constitute an
Event of Default under the Indenture. There can be no assurance that the Company
will have sufficient funds available at the time of any Change of Control to
make any debt payment (including repurchases of Notes) as described above. See
"Description of the Notes -- Repurchase at the Option of Holders Upon a Change
of Control."
The events that constitute a Change of Control under the Indenture may also
be events of default under the Bank Credit Facility or other indebtedness of the
Company or any Subsidiary Guarantor. Such events may permit the lenders under
such debt instruments to reduce the borrowing base thereunder or to accelerate
the debt and, if the debt is not paid, to enforce security interests on, or to
commence
18
<PAGE> 20
litigation that could ultimately result in a sale of, substantially all the
assets of the Company, thereby limiting the Company's ability to raise cash to
repurchase the Notes. In such circumstances, the subordination provisions in the
Indenture would likely prohibit payments to holders of the Notes.
FRAUDULENT CONVEYANCE CONSIDERATIONS RELATING TO FUTURE SUBSIDIARY GUARANTIES
Although the Company currently has no Restricted Subsidiaries, the
Company's obligations under the Notes may under certain circumstances be
guaranteed on an unsecured senior subordinated basis by future Restricted
Subsidiaries. Various fraudulent conveyance laws have been enacted for the
protection of creditors and may be utilized by a court of competent jurisdiction
to subordinate or avoid any Subsidiary Guaranty issued by a Subsidiary
Guarantor. It is also possible that under certain circumstances a court could
hold that the direct obligations of a Subsidiary Guarantor could be superior to
the obligations under the Subsidiary Guaranty.
To the extent that a court were to find that at the time a Subsidiary
Guarantor entered into a Subsidiary Guaranty either (x) the Subsidiary Guaranty
was incurred by a Subsidiary Guarantor with the intent to hinder, delay or
defraud any present of future creditor or that a Subsidiary Guarantor
contemplated insolvency with a design to favor one or more creditors to the
exclusion in whole or in part of others or (y) the Subsidiary Guarantor did not
receive fair consideration or reasonably equivalent value for issuing the
Subsidiary Guaranty and, at the time it issued the Subsidiary Guaranty, the
Subsidiary Guarantor (i) was insolvent or rendered insolvent by reason of the
issuance of the Subsidiary Guaranty, (ii) was engaged or about to engage in a
business or transaction for which the remaining assets of the Subsidiary
Guarantor constituted unreasonably small capital or (iii) intended to incur, or
believed that it would incur, debts beyond its ability to pay such debts as they
matured, the court could avoid or subordinate the Subsidiary Guaranty in favor
or the Subsidiary Guarantor's other creditors. Among other things, a legal
challenge of a Subsidiary Guaranty issued by a Subsidiary Guarantor on
fraudulent conveyance grounds may focus on the benefits, if any, realized by the
Subsidiary Guarantor as a result of the issuance by the Company of the Notes. To
the extent a Subsidiary Guaranty is avoided as a fraudulent conveyance or held
unenforceable for any other reason, the Holders of the Notes would cease to have
any claim in respect of such Subsidiary Guarantor and would be creditors solely
of the Company.
RELIANCE ON KEY PERSONNEL
The Company's operations are dependent upon a relatively small group of key
management and technical personnel. There can be no assurance that such
individuals will remain with the Company for the immediate or foreseeable
future. The unexpected loss of the services of one or more of these individuals
could have a detrimental effect on the Company. See "Management."
RISKS OF HEDGING TRANSACTIONS
In order to manage its exposure to price risks in the marketing of its oil
and gas, the Company has in the past and expects to continue to enter into oil
and gas price hedging arrangements with respect to a portion of its expected
production. The Company's hedging policy provides that, without the prior
approval of the Board of Directors, generally not more than 50% of its
production quantities can be hedged, and that any such hedges shall not be
longer than one year in duration. These arrangements may include futures
contracts on the New York Mercantile Exchange ("NYMEX"). While intended to
reduce the effects of volatility of the price of oil and gas, such transactions
may limit potential gains by the Company if oil and gas prices were to rise
substantially over the price established by the hedge. In addition, such
transactions may expose the Company to the risk of financial loss in certain
circumstances, including instances in which (i) production is less than
expected, (ii) there is a widening of price differentials between delivery
points for the Company's production and the delivery point assumed in the hedge
arrangement, (iii) the counterparties to the Company's future contracts fail to
perform the contract or (iv) a sudden, unexpected event materially impacts oil
or gas prices. See "Management's Discussion and Analysis of Financial Condition
and Results of Operations -- Liquidity and Capital Resources."
19
<PAGE> 21
ABSENCE OF PUBLIC MARKET FOR THE NOTES
The Notes will be new securities for which currently there is no trading
market. The Company does not intend to apply for listing of the Notes on any
securities exchange or stock market. The Notes are expected to be eligible for
trading in The Portal Market. Although the Initial Purchasers have informed the
Company that they currently intend to make a market in the Notes, the Initial
Purchasers are not obligated to do so, and any such market making may be subject
to certain limitations and may be discontinued at any time without notice. The
liquidity of any market for the Notes will depend upon the number of holders of
the Notes, the interest of securities dealers in making a market in the Notes
and other factors. Accordingly, there can be no assurance as to the development
or liquidity of any market for the Notes.
If the Notes are traded after their initial issuance, they may trade at a
discount from their initial offering price, depending on prevailing interest
rates, the market for similar securities, general economic conditions and the
financial condition of the Company. Historically, the market for noninvestment
grade debt has been subject to disruptions that have caused substantial
volatility in the prices of securities similar to the Notes. There can be no
assurance that the market, if any, for the Notes will not be subject to similar
disruptions. Any such disruptions may have an adverse effect on the holders of
the Notes.
CONFLICTS OF INTEREST
Certain employees of the Company, including James H. Stone, the Company's
Chairman of the Board and Chief Executive Officer, own working interests in
certain of the Company's oil and gas properties acquired prior to 1995 and will
have the opportunity to participate as working interest owners in certain of the
Company's future drilling activities on such properties. In addition, certain
officers of the Company were granted net profits interests in certain of the oil
and gas properties of the Company acquired prior to the Company's initial public
offering in 1993. The recipients of the net profits interests are not required
to pay capital costs incurred on the properties burdened by such interests.
Therefore, a conflict of interest may exist between the Company and such
employees and officers with respect to the drilling of additional wells or other
development operations. The Company and James H. Stone also continue to manage
programs formed prior to 1993, and James H. Stone continues to individually
participate in various oil and gas operations and ventures. It is possible, as a
result of these activities, that conflicts of interest could arise.
CONTROL BY MANAGEMENT
Executive officers and directors of the Company beneficially own
approximately 27.3% of the outstanding Common Stock of the Company (the "Common
Stock"). This percentage ownership is based on the number of shares of Common
Stock outstanding at August 11, 1997 and the beneficial ownership of such
persons at such date. As a result, these persons may be in a position to control
the Company through their ability to determine the outcome of elections of the
Company's directors and certain other matters requiring the vote or consent of
the Company's stockholders.
COMPETITION
The Company operates in a highly competitive environment. The Company
competes with major and independent oil and gas companies for the acquisition of
desirable oil and gas properties, as well as for the equipment and labor
required to develop and operate such properties. Many of these competitors have
financial, technical and other resources substantially greater than those of the
Company.
20
<PAGE> 22
PRIVATE PLACEMENT
On September 19, 1997, the Company completed the private sale to the
Initial Purchasers of $100,000,000 principal amount of the Old Notes at a price
of 97.033% of the principal amount thereof in a transaction not registered under
the Securities Act in reliance upon Section 4(2) of the Securities Act. The
Initial Purchasers thereupon offered and resold the Old Notes only to qualified
institutional buyers at an initial price to such purchasers of 99.283% of the
principal amount thereof. The net proceeds of $96.9 million received by the
Company in connection with the sale of the Old Notes was used to repay all
borrowings outstanding under the term loan and all except $10 million of the
revolving credit loan outstanding under the Bank Credit Facility. It is
anticipated that the remainder of the net proceeds, if any, will be used for
general corporate purposes.
USE OF PROCEEDS
The Company will not receive any cash proceeds from the issuance of the
Exchange Notes offered hereby. In consideration for issuing the Exchange Notes
as contemplated in this Prospectus, the Company will receive in exchange a like
principal amount of Old Notes, the terms of which are identical in all material
respects to the Exchange Notes. The Old Notes surrendered in exchange for the
Exchange Notes will be retired and canceled and cannot be reissued. Accordingly,
issuance of the Exchange Notes will not result in any change in capitalization
of the Company.
21
<PAGE> 23
CAPITALIZATION
The following table sets forth as of June 30, 1997: (i) the historical
capitalization of the Company, (ii) the pro forma capitalization of the Company
after giving effect to the debt incurred to purchase the Vermilion Block 255
Field and (iii) the pro forma as adjusted capitalization of the Company after
giving effect to (ii) above and the Offering and the application of the
estimated net proceeds therefrom as set forth in "Summary -- The Private
Placement and Use of Proceeds." This table should be read in conjunction with
"Management's Discussion and Analysis of Financial Condition and Results of
Operations" and the Financial Statements of the Company and the related notes
thereto included elsewhere in this Prospectus. For a description of the Bank
Credit Facility and the borrowing capacity thereunder, see "Description of Bank
Credit Facility."
<TABLE>
<CAPTION>
AS OF JUNE 30, 1997
--------------------------------------
PRO FORMA
HISTORICAL PRO FORMA AS ADJUSTED
---------- --------- -----------
(IN THOUSANDS)
<S> <C> <C> <C>
Cash and marketable securities.......................... $ 26,399 $ 26,399 $ 54,209
======== ======== ========
Current portion of long-term debt....................... $ 78 $ 78 $ 78
======== ======== ========
Long-term debt:
Bank Credit Facility.................................. $ 48,073 $ 79,073 $ 10,000
FNBC Loan............................................. 3,064 3,064 3,064
Offered Notes......................................... -- -- 100,000
-------- -------- --------
Total long-term debt.......................... 51,137 82,137 113,064
-------- -------- --------
Stockholders' equity:
Common stock.......................................... 150 150 150
Paid-in capital....................................... 118,502 118,502 118,502
Retained earnings..................................... 30,878 30,878 30,878
-------- -------- --------
Total stockholders' equity.................... 149,530 149,530 149,530
-------- -------- --------
Total capitalization.......................... $200,667 $231,667 $262,594
======== ======== ========
</TABLE>
22
<PAGE> 24
SELECTED HISTORICAL FINANCIAL DATA
The following table sets forth a summary of selected historical financial
data for the Company for the six months ended June 30, 1997 and 1996 and the
five years ended December 31, 1996. The year end information is derived from the
audited consolidated financial statements of the Company and the related notes
thereto. The financial data for the six month periods ended June 30, 1997 and
1996 is unaudited and reflects all adjustments (consisting only of normal
recurring adjustments) which are, in the opinion of management, necessary for a
fair presentation of the financial position and operating results for such
interim periods. The results of operations for the six month period ended June
30, 1997 are not necessarily indicative of results for the full year. See the
Company's Financial Statements and the related notes thereto included elsewhere
in this Prospectus and "Management's Discussion and Analysis of Financial
Condition and Results of Operations."
<TABLE>
<CAPTION>
SIX MONTHS ENDED
JUNE 30, YEAR ENDED DECEMBER 31,
------------------- --------------------------------------------------
1997 1996 1996 1995 1994 1993 1992
-------- -------- -------- -------- -------- ------- -------
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS AND RATIOS)
<S> <C> <C> <C> <C> <C> <C> <C>
STATEMENT OF OPERATIONS DATA:
Revenues:
Oil production revenue......................... $ 14,075 $ 13,091 $ 27,788 $ 24,775 $ 18,482 $17,752 $14,557
Gas production revenue......................... 14,930 15,300 28,051 13,918 12,697 10,718 5,778
Other revenue.................................. 894 1,105 2,126 1,858 1,708 1,252 616
-------- -------- -------- -------- -------- ------- -------
Total revenues........................... 29,899 29,496 57,965 40,551 32,887 29,722 20,951
-------- -------- -------- -------- -------- ------- -------
Expenses:
Normal lease operating expenses................ 4,362 3,968 8,625 6,294 5,312 4,326 4,164
Major maintenance expenses..................... 486 260 427 446 1,834 822 148
Production taxes............................... 1,499 1,511 3,399 3,057 2,303 2,000 1,557
Depreciation, depletion and amortization....... 11,929 10,334 19,564 15,719 11,569 8,028 5,019
Interest expense............................... 1,103 1,537 3,574 2,191 982 1,499 1,743
Other expense.................................. -- -- -- -- -- 245 365
General and administrative costs............... 1,759 1,662 3,509 3,298 3,099 2,248 1,818
Incentive compensation plan.................... 316 278 928 85 1,358 -- --
Exchange offer expenses........................ -- -- -- -- -- 780 --
-------- -------- -------- -------- -------- ------- -------
Total expenses........................... 21,454 19,550 40,026 31,090 26,457 19,948 14,814
-------- -------- -------- -------- -------- ------- -------
Net income before income taxes and cumulative
effect of change in accounting principle....... 8,445 9,946 17,939 9,461 6,430 9,774 6,137
Provision for income taxes....................... 3,252 3,829 6,906 3,645 2,410 943 --
-------- -------- -------- -------- -------- ------- -------
Net income before cumulative effect of change in
accounting principle........................... 5,193 6,117 11,033 5,816 4,020 8,831 6,137
Cumulative effect of change in accounting
principle(1)................................... -- -- -- -- -- -- 1,377
-------- -------- -------- -------- -------- ------- -------
Net income....................................... $ 5,193 $ 6,117 $ 11,033 $ 5,816 $ 4,020 $ 8,831 $ 7,514
======== ======== ======== ======== ======== ======= =======
Earnings per common share:
Net income per share before accounting
principle change............................. $ 0.33 $ 0.51 $ 0.89 $ 0.49 $ 0.34 $ 0.88 $ 0.71
Cumulative effect of accounting principle
change(1).................................... -- -- -- -- -- -- 0.16
-------- -------- -------- -------- -------- ------- -------
Net income per common share.................... $ 0.33 $ 0.51 $ 0.89 $ 0.49 $ 0.34 $ 0.88 $ 0.87
======== ======== ======== ======== ======== ======= =======
Average shares outstanding..................... 15,312 11,954 12,356 11,818 11,801 10,087 8,664
======== ======== ======== ======== ======== ======= =======
CASH FLOW AND OTHER FINANCIAL DATA:
Net cash provided by operating activities
(excluding working capital changes)............ $ 20,274 $ 20,158 $ 37,295 $ 25,049 $ 17,911 $17,852 $11,156
Net cash provided by operating activities........ 16,714 12,819 32,333 27,499 9,609 13,857 14,417
Ratio of earnings to fixed charges(2)............ 8.0x 7.3x 5.9x 5.2x 7.5x 7.5x 4.5x
BALANCE SHEET DATA (AT END OF PERIOD):
Cash and marketable securities................... $ 26,399 $ 23,585 $ 20,195 $ 16,518 $ 20,326 $28,123 $ 7,214
Working capital (deficit)........................ 2,728 6,283 6,683 5,379 4,437 18,421 (6,655)
Oil and gas properties, net...................... 210,159 125,082 171,396 111,248 81,291 60,097 49,722
Total assets..................................... 253,556 162,294 209,406 139,460 109,956 98,770 65,117
Long-term debt, less current portion............. 51,137 52,717 26,172 47,754 22,725 21,620 26,659
Stockholders' equity(3).......................... 149,530 73,078 144,441 66,927 61,045 56,997 2,046
</TABLE>
- ---------------
(1) Represents the adoption of Statement of Financial Accounting Standards No.
109, "Accounting For Income Taxes," effective January 1, 1992.
(2) For purposes of calculating the ratio of earnings to fixed charges, earnings
is defined as income of the Company and its subsidiaries before income taxes
and fixed charges. Fixed charges consist of interest expense, including
amortization of financing costs and any discount or premium related to any
indebtedness.
(3) Mandatorily redeemable preferred stock outstanding at December 31, 1992 of
$15,203 is not included in stockholders' equity.
23
<PAGE> 25
MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion is intended to assist in an understanding of the
Company's financial position and results of operations for each year of the
three year period ended December 31, 1996 and for the unaudited six month
periods ended June 30, 1997 and 1996. The Company's Financial Statements and the
related notes thereto included elsewhere in this Prospectus contain detailed
information that should be referred to in conjunction with the following
discussion.
FORMATION OF STONE ENERGY
The Company was formed in March 1993 to become a holding company for The
Stone Petroleum Corporation ("TSPC"), its subsidiaries and certain partnership
interests, and approximately 8.1 million shares of Common Stock were issued to
holders of interests in those entities. The Company is in the process of
liquidating TSPC. In July 1993, the Company also sold approximately 3.7 million
shares of newly issued Common Stock in its initial public offering. In November
1996, the Company completed a secondary offering which resulted in the issuance
of an additional 3.2 million shares of Common Stock.
OPERATING ENVIRONMENT
At present, the Company does not expect that changes in the rates of
overall economic growth or inflation will significantly impact product prices in
the short-term. While gas prices seem most dependent on weather in North America
and corresponding usage, oil prices are more subject to global economic forces
and supply. Because all of these factors are beyond the control of the Company,
its marketing efforts have been devoted to achieving the best price available in
each geographic location. The Company has engaged in a limited amount of fixed
price sales and hedging transactions to take advantage of short-term prices it
believes to be attractive.
Demand for drilling rigs, production equipment and related services
increased significantly during 1996 and to date in 1997, and the costs
associated with these items are higher than in 1995. The Company has experienced
delays in obtaining such equipment and services, and in some instances the costs
incurred are higher than originally budgeted. Despite these changes in the
market for drilling supplies and services, the Company does not expect these
current conditions to have a material impact on the timing or long-term
profitability of its planned activities.
The inventory of oil and gas properties offered for sale has declined over
the last several years. This reduced availability of properties, combined with
the emergence during the same period of a number of well-capitalized independent
oil and gas companies, has caused an increase in the prices paid for properties.
24
<PAGE> 26
RESULTS OF OPERATIONS
The following table sets forth certain operating information with respect
to the oil and gas operations of the Company and summary information with
respect to the Company's estimated proved oil and gas reserves. See
"Business -- Oil and Gas Reserves."
<TABLE>
<CAPTION>
SIX MONTHS ENDED
JUNE 30, YEAR ENDED DECEMBER 31,
------------------ -----------------------------
1997 1996 1996 1995 1994
------- ------- ------- ------- -------
<S> <C> <C> <C> <C> <C>
Production:
Oil (MBbls)........................ 694 663 1,356 1,400 1,113
Gas (MMcf)......................... 5,990 6,128 11,331 8,399 6,629
Oil and gas (MBOE)................. 1,692 1,684 3,245 2,800 2,218
Sales data (in thousands):
Total oil sales.................... $14,075 $13,091 $27,788 $24,775 $18,482
Total gas sales.................... 14,930 15,300 28,051 13,918 12,697
Average sales prices:
Oil (per Bbl)...................... $ 20.28 $ 19.75 $ 20.49 $ 17.70 $ 16.61
Gas (per Mcf)...................... 2.49 2.50 2.48 1.66 1.92
Per BOE............................ 17.14 16.86 17.21 13.82 14.06
Average costs (per BOE):
Normal lease operating
expenses(1)..................... $ 2.58 $ 2.36 $ 2.66 $ 2.25 $ 2.39
General and administrative......... 1.04 0.99 1.08 1.18 1.40
Depreciation, depletion and
amortization.................... 6.89 6.06 5.93 5.57 5.15
</TABLE>
- ---------------
(1) Excludes major maintenance expenses.
<TABLE>
<CAPTION>
AS OF AS OF DECEMBER 31,
AUGUST 1, -------------------------------
1997(1) 1996 1995 1994
--------- -------- -------- -------
<S> <C> <C> <C> <C>
Reserves:
Oil (MBbls)................................ 18,427 12,772 7,985 6,455
Gas (MMcf)................................. 185,572 144,316 81,179 68,285
Oil and gas (MBOE)......................... 49,356 36,825 21,515 17,836
Present value of estimated future net cash
flows before income taxes (in
thousands)(2).............................. $372,314 $448,895 $179,725 $97,391
Prices(3):
Oil (per Bbl).............................. $ 18.94 $ 25.97 $ 19.40 $ 16.74
Gas (per Mcf).............................. 2.26 3.94 2.39 1.72
</TABLE>
- ---------------
(1) The increase in the Company's estimate of its proved reserves as of August
1, 1997, from December 31, 1996, is primarily attributable to the
acquisition of the Vermilion Block 255 Field and the development of South
Pelto Block 23.
(2) The present value of estimated future net cash flows attributable to the
Company's reserves was prepared using constant prices as of the calculation
date, discounted at 10% per annum on a pre-tax basis.
(3) Represents weighted average prices received by the Company (net of effects
of hedging) as of the date indicated, and used in calculating "Present value
of estimated future net cash flows before income taxes."
SIX MONTHS ENDED JUNE 30, 1997 COMPARED TO SIX MONTHS ENDED JUNE 30,
1996. For the first six months of 1997, net income was $5.2 million, as compared
to $6.1 million for the comparable 1996 period.
Total oil and gas revenues for the first six months of 1997 were $29.0
million, and were comprised of $14.9 million of gas revenues and $14.1 million
of oil revenues. Overall production quantities were essentially equal to the
levels achieved in the first six months of 1996, as new production from
25
<PAGE> 27
acquisitions and successful development activities offset production declines at
more mature properties. The average oil price received in the first six months
of 1997 of $20.28 per barrel was approximately 2.7% higher than year earlier
levels, and the average gas price of $2.49 per Mcf was essentially the same as
that of the first six months of 1996.
Normal lease operating expenses per BOE for the first six months of 1997
were $2.58, which included unscheduled repairs at South Pelto Block 23 and Lake
Hermitage and unitization expenses at West Weeks Island. Major maintenance
expenses during the first six months of 1997 included the portion of the costs
of a well blowout at South Timbalier Block 8 which was not covered by insurance.
For the first six months of 1997, general and administrative expenses increased
slightly from the same period in 1996 to $1.8 million in total, or to $1.04 per
BOE.
Interest expense decreased to $1.1 million for the six months ended June
30, 1997 from $1.5 million for the comparable 1996 period due to lower levels of
long-term debt. Depreciation, depletion and amortization ("DD&A") expense
attributable to oil and gas properties increased to $11.7 million for the first
half of 1997 from the $10.2 million reported for same period of 1996 primarily
due to higher finding costs.
1996 COMPARED TO 1995. Net income for the year ended December 31, 1996 was
$11.0 million, an increase of 90% from 1995 earnings of $5.8 million. Earnings
per share rose to $0.89 in 1996, as compared to $0.49 in 1995.
For 1996, oil and gas revenues were $55.8 million as compared to $38.7
million in 1995, a 44% increase. Proceeds from sales of production in 1996 were
50% oil and 50% gas, as compared to 64% and 36%, respectively, for 1995.
Production volumes for 1996 were 1.4 MMBbls and 11.3 Bcf of gas. Oil production
volumes for 1996 were essentially the same as for 1995, and gas deliveries
increased 35% from the 1995 amount of 8.4 Bcf of gas.
The increase in oil and gas revenues in 1996 resulted from overall
production growth of 16% for the year and a 25% increase in the average price
received per BOE. The average gas price per Mcf increased 49% to $2.48 in 1996
from the 1995 amount of $1.66, and the average oil price per barrel climbed 16%
from $17.70 in 1995 to $20.49 in 1996.
Normal lease operating expenses for 1996 increased in total to $8.6 million
from $6.3 million in 1995 due to an increased number of properties and higher
production rates. The primary reason for the increase in such costs on a unit of
production basis ($2.66 per BOE in 1996 versus $2.25 per BOE in 1995) was
certain nonrecurring repairs and generally higher costs of services, although
the 1996 unit amount is within the Company's budgeted range for these costs.
DD&A expense attributable to oil and gas properties increased because of
higher production rates and investments in the Company's properties. This
non-cash expense increased to $19.3 million or $5.93 per BOE in 1996 from $15.6
million or $5.57 per BOE in 1995.
During 1996, the Company borrowed funds pursuant to its bank credit
facility to finance a portion of its capital expenditures budget, and interest
expense increased to $3.6 million in 1996 from $2.2 million in 1995. General and
administrative costs also increased in total to $3.5 million in 1996 from $3.3
million in 1995, but on a unit basis declined 9% to $1.08 per BOE in 1996 from
$1.18 per BOE in 1995. Due to higher bonus awards during the year, the expenses
of the Company's incentive compensation plan increased to $0.9 million in 1996
from $0.1 million in 1995.
Pre-tax income increased to $17.9 million in 1996 from $9.5 million in
1995, and therefore the tax provision increased to $6.9 million in 1996 from
$3.6 million in 1995. Except for an estimated minimum tax liability of $0.2
million, the remainder of the tax provision is deferred and does not require
current funding.
The Company's reserves at December 31, 1996 were 36.8 MMBOE and represent
an increase of 71% from the comparable amount one year earlier of 21.5 MMBOE.
Oil reserves increased to 12.8
26
<PAGE> 28
MMBbls at the end of 1996 from 8.0 MMBbls at the beginning of the year, and gas
reserves increased to 144.3 Bcf at December 31, 1996 from 81.2 Bcf at December
31, 1995.
1995 COMPARED TO 1994. Net income for the year ended December 31, 1995 was
$5.8 million or $0.49 per share, an increase of 45% from 1994 earnings of $4.0
million or $0.34 per share. Net cash flow from operations before working capital
changes for 1995 increased 40% to $25.0 million or $2.11 per share, from
comparable 1994 amounts of $17.9 million or $1.51 per share.
For 1995, oil and gas revenues were $38.7 million as compared to $31.2
million in 1994, a 24% increase. Proceeds from sales of production in 1995 were
64% oil and 36% gas, as compared to 59% and 41%, respectively, for 1994.
Production volumes for 1995 were 1.4 MMBbls of oil and 8.4 Bcf of gas. Oil
production was up 26%, and gas deliveries increased 27% from the 1994 amounts of
1.1 MMBbls of oil and 6.6 Bcf of gas. The increase in revenues in 1995 resulted
from overall production growth of 26% for the year, despite a 2% decline in the
average prices received per equivalent barrel. The average gas price per Mcf
decreased by 14% to $1.66 in 1995 from the 1994 amount of $1.92, but the average
oil price per barrel climbed 7% from $16.61 in 1994 to $17.70 in 1995.
Normal lease operating expenses for 1995 increased in total to $6.3 million
from $5.3 million in 1994 due to an increased number of properties and higher
production rates. When stated on a unit basis, such costs were $2.25 per BOE in
1995 and $2.39 per BOE in 1994, a 6% improvement. Major maintenance expenses, or
workover costs of producing zones, were $0.4 million in 1995 as compared to $1.8
million in 1994.
DD&A expense attributable to oil and gas properties increased because of
higher production rates and investments in the Company's properties. This
non-cash expense increased to $15.6 million or $5.57 per BOE in 1995 from $11.4
million or $5.15 per BOE in 1994.
During 1995, the Company borrowed funds pursuant to its bank credit
facility to finance a portion of its capital expenditures budget, and interest
expense increased to $2.2 million in 1995 from $1.0 million in 1994. General and
administrative costs also increased in total to $3.3 million in 1995 from $3.1
million in 1994, but on a unit basis declined 16% to $1.18 per BOE in 1995 from
$1.40 per BOE in 1994. The expenses of the Company's bonus plan declined to $0.1
million in 1995 from $1.4 million in 1994.
Pre-tax income increased to $9.5 million in 1995 from $6.4 million in 1994,
and therefore the tax provision increased to $3.6 million in 1995 from $2.4
million in 1994. Except for an estimated minimum tax liability of $0.1 million,
the remainder of the tax provision is deferred and does not require current
funding.
The Company's reserves at December 31, 1995 were 21.5 MMBOE and represent
an increase of 21% from the comparable amount one year earlier of 17.8 MMBOE.
Oil reserves increased to 8.0 MMBbls at the end of 1995 from 6.5 MMBbls at the
beginning of the year, and gas reserves increased to 81.2 Bcf at December 31,
1995 from 68.3 Bcf at December 31, 1994.
LIQUIDITY AND CAPITAL RESOURCES
On August 1, 1997, the Company borrowed $31.0 million under the term loan
portion of the Bank Credit Facility to finance the acquisition of the Vermilion
Block 255 Field. The Company will use the net proceeds of the Offering to repay
all of the term loan and all except $10.0 million of the revolving credit loan
outstanding under the Bank Credit Facility and to finance certain capital
expenditures. The Company believes that its existing working capital (including
the remaining net proceeds of the Offering), combined with expected cash flow
from operations and borrowings under the revolving loan portion of the Bank
Credit Facility, will be sufficient to fund its budgeted operations and
development activities through the end of 1998.
WORKING CAPITAL AND CASH FLOW. Working capital at June 30, 1997 was $2.7
million. Net cash flow from operations before working capital changes for the
first six months of 1997 was $20.3 million.
27
<PAGE> 29
During the first six months of 1997, the Company invested $50.4 million in
its oil and gas properties, as compared to investments of $24.0 million during
the comparable 1996 period. The investments for the first six months of 1997
include $1.2 million of capitalized general and administrative costs.
HEDGING. The Company's production is sold on month-to-month contracts at
prevailing prices. From time to time, however, the Company has entered into
hedging transactions or fixed price sales contracts for its oil and gas
production. The purpose of these transactions is to reduce the Company's
exposure to future oil and gas price declines. This hedging policy provides
that, unless prices change by more than 25% during a quarter, not more than
one-half of the Company's production quantities can be hedged without the
consent of the Company's Board of Directors. Such swap agreements typically
provide for monthly payments by (if prices rise) or to (if prices decline) the
Company based on the difference between the strike price and the average closing
price of the near month NYMEX futures contract for each month of the agreement.
Because its properties are located in the Gulf Coast Basin, the Company believes
that fluctuations in the NYMEX futures prices will closely match changes in the
market prices for its production. As of August 15, 1997, the Company had no
forward positions.
The Company's net losses from hedging transactions were $11,000, $3.8
million and $0.7 million for the years ended December 31, 1995 and 1996 and the
six months ended June 30, 1997, respectively.
HISTORICAL FINANCING SOURCES. From 1990 through the first half of 1993, the
Company financed the acquisition and exploitation of oil and gas properties with
funds provided by mezzanine financing sources, joint ventures with an industry
partner, limited partnerships and cash flow from operations. Since the Company's
initial public offering in July 1993, the Company has financed its activities
with offering proceeds, cash flow from operations, borrowings under its bank
credit facility described below and investments by two partnerships formed
before the initial public offering which had uncommitted funds. All funds of
these partnerships have been committed, and the Company is not required to offer
participation in subsequently acquired properties to these entities, unless such
acquisitions represent additional interests in properties already owned by the
partnerships.
On July 30, 1997, the Company amended its bank credit facility with its
bank group, which is led by NationsBank. The total Bank Credit Facility amount
is $150 million and is comprised of a three-year revolving credit loan and a
term loan due on January 1, 1999. The current weighted average interest rate of
the facility is 7.3% per annum. As of August 1, 1997, the total outstanding
principal balance was $79.1 million and letters of credit totaling $6.5 million
had been issued pursuant to the facility.
The revolver provided for total availability of $100 million with a
limitation on total outstanding borrowings based on a borrowing base amount
established by the banks for the Company's oil and gas properties, which, at the
time of the Offering, was $80 million. The borrowing base was reduced to $55
million after the Offering and will be redetermined at year-end based on a
revaluation of the Company's oil and gas properties. The term loan of $50
million was established to finance the acquisition of the Vermilion Block 255
Field and certain development costs. All of the amounts outstanding under the
term loan were paid in full with net proceeds of the Offering, and the term loan
is no longer available to the Company. See "Description of Bank Credit
Facility."
On November 30, 1995, the Company executed a Term Loan Agreement with First
National Bank of Commerce ("FNBC") in the original principal amount of $3.3
million (the "FNBC Loan") for the purchase of the RiverStone office building, a
portion of which is used by the Company for its Lafayette office. The loan has a
five-year term bearing interest at a rate of 7.45% per annum over the entire
term of the loan. Principal and interest are payable monthly and are based upon
a 20-year amortization period. The indebtedness under the agreement is
collateralized by the building. This loan agreement contains covenants and
restrictions which are similar to those of the Bank Credit Facility.
LONG-TERM FINANCING. Stone Energy has budgeted $237 million for capital
expenditures in 1997 and 1998, which includes $50 million spent in the first
half of 1997. Approximately 54% of the 1997 and 1998 budgeted expenditures has
been allocated to South Pelto Block 23 and the Vermilion Block 255 Field.
Significant investments are also planned for the Vermilion Block 46, Eugene
Island Block 243,
28
<PAGE> 30
Cut Off and Clovelly fields. The planned development operations include projects
which seek to increase cash flow from proved reserves and provide additions to
the Company's reserve base. It is anticipated that these investments will be
funded from a combination of the net proceeds of the Offering, available working
capital, cash flow from operations and borrowings under the Bank Credit
Facility. The Company may seek additional capital to finance development
activities beyond its current plans or future acquisitions.
REGULATORY AND LITIGATION ISSUES. In December 1995, Goodrich Leasehold
L.L.C. and Goodrich Drillers L.L.C. filed a civil action against the Company in
an attempt to set aside a farmout agreement affecting portions of the West Flank
of the Weeks Island Field in Iberia Parish, Louisiana. Management believes that
this claim is without merit and intends to vigorously defend this action.
The Company is also named as a defendant in certain lawsuits and is a party
to certain regulatory proceedings arising in the ordinary course of business.
These regulatory proceedings include three instances in which the U.S.
Environmental Protection Agency (the "EPA") has indicated that it believes that
the Company is a potentially responsible party ("PRP") for the cleanup of
oilfield waste facilities. Management does not expect these matters,
individually or in the aggregate, to have a material adverse effect on the
financial condition of the Company.
Since November 26, 1993, new levels of lease and areawide bonds have been
required of lessees taking certain actions with regard to Outer Continental
Shelf ("OCS") leases. Operators in the OCS waters of the Gulf of Mexico,
including the Company, have been or may be required to increase their areawide
bonds and individual lease bonds to $3.0 million and $1.0 million, respectively,
unless exemptions or reduced amounts are allowed by the MMS. The Company
currently has an areawide pipeline bond of $0.3 million and an areawide lease
bond of $3.0 million issued in favor of the MMS for its existing offshore
properties. The MMS also has discretionary authority to require supplemental
bonding in addition to the foregoing required bonding amounts but this authority
is only exercised on a case-by-case basis at the time of filing an assignment of
record title interest for MMS approval. Based upon certain financial parameters,
the Company has been granted exempt status by the MMS, which exempts the Company
from the supplemental bonding requirements. Under certain circumstances, the MMS
may require any Company operations on federal leases to be suspended or
terminated. Any such suspension or termination could materially and adversely
affect the Company's financial condition and operations.
As amended by the Coast Guard Authorization Act of 1996, OPA requires
responsible parties for offshore facilities to provide financial assurance in
the amount of $35 million to cover potential OPA liabilities. This amount is
subject to upward regulatory adjustment up to $150 million. In 1996, the
Statement of Position 96-1 ("SOP 96-1"): Environmental Remediation Liabilities
was issued. The Company will apply SOP 96-1 in 1997. The Company believes
adoption of SOP 96-1 will not have a material effect on its results of
operations or financial position.
The Company operates under numerous state and federal laws enacted for the
protection of the environment. In the ordinary course of business, the Company
conducts an ongoing review of the effects of these various environmental laws on
its business and operations. The estimated cost of continued compliance with
current environmental laws, based upon the information currently available, is
not material to the Company's financial position or results of operations. It is
impossible to determine whether and to what extent the Company's future
performance may be affected by environmental laws; however, management believes
that such laws will not have a material adverse effect on the Company's
financial position or results of operations.
29
<PAGE> 31
BUSINESS
OVERVIEW
Stone Energy Corporation is an independent oil and gas company engaged in
the development, exploration, acquisition and operation of oil and gas
properties onshore and offshore in the Gulf Coast Basin. The Company and its
predecessors have been active in the Gulf Coast Basin since 1973, which gives
the Company extensive geophysical, technical and operational expertise in this
area. As of August 1, 1997, the Company estimated that its proved reserves were
approximately 185.6 Bcf of gas and 18.4 MMBbls of oil, or an aggregate of
approximately 49.4 MMBOE, with a present value of estimated pre-tax future net
cash flows of approximately $372.3 million. The Company serves as operator of
all of its 14 properties.
The Company's business strategy is to increase production, cash flow and
reserves through the acquisition and development of mature properties located in
the Gulf Coast Basin. The Company seeks properties that have an established
production history, proved undeveloped reserves and multiple prospective
reservoirs that provide significant development opportunities and an attractive
price due to low current production levels and properties in which the Company
would have the ability to control operations. Prior to acquiring a property, the
Company performs a thorough geological, geophysical and engineering analysis of
the property to formulate a comprehensive development plan. Through development
activities, the Company seeks to increase cash flow from existing proved
reserves and to establish additional proved reserves. These activities typically
involve the drilling of new wells, workovers and recompletions of existing
wells, and the application of other techniques designed to increase production.
STRATEGY
Acquisition. From 1990 to 1993, the Company acquired its properties by
purchases, primarily from major oil companies. In response to a changing
acquisition environment, the Company has also utilized arrangements other than
the purchase of ownership interests, including farmins and partnering ventures.
The Company's flexibility in structuring transactions allows it to apply its
development capital and technical expertise to properties owned by those major
and independent oil companies that have an inventory of development
opportunities that require resources beyond their budgets and technical staff
dedicated to operations in the Gulf Coast Basin. Although the Company is
currently evaluating several potential property acquisitions, it does not have
any contracts, understandings or other arrangements with respect to any such
acquisitions.
In its acquisition efforts the Company seeks properties with the following
characteristics:
- Gulf Coast Concentration. The Gulf Coast Basin is the Company's primary
area of operations and expertise. This geographic concentration allows
the Company to closely manage costs and to develop detailed geological
and other information relating to its properties, thereby increasing
their exploitation potential. In addition, large offshore blocks are
highly desirable because of the quality and availability of seismic data
and the fact that large areas can be held by production while development
plans are formulated and implemented. The Gulf Coast Basin, both onshore
and in shallow water offshore, has a substantial existing infrastructure,
including gathering systems, platforms, pipelines and drilling and
service companies, which facilitates cost effective operations and the
timely development of discoveries.
- Multiple Reservoirs/Opportunities. Properties with multiple sandstone
reservoirs provide increased potential for return by having a number of
opportunities that, individually or in the aggregate, could make the
properties profitable. Wells drilled in the Gulf Coast Basin frequently
have more than one productive horizon.
- Mature Properties with Established Production History. Properties
discovered in the late 1950s through the early 1970s were frequently
completed in the one or two thickest sands on a property that offered the
highest production rates. These original completions are often depleted
or near
30
<PAGE> 32
depletion, and, in many cases, thinner sands were overlooked or bypassed
completely. Additionally, historical production data is used to project
future rates of production and ultimate recoverable reserves.
- Low Current Production. Low production levels reduce bidding competition
from purchasers who favor proved producing reserves. A low level of cash
flow also increases the likelihood that the current property owner will
consider proposals made by the Company.
- Proved Undeveloped and Nonproducing Reserves. The existence of
significant remaining proved undeveloped and nonproducing reserves
provides the opportunity to increase production significantly through the
drilling of new wells, workovers, recompletions and other non-drilling
activities.
- Lack of Recent Development Activity. The Company often identifies
additional opportunities with respect to properties that have had little
or no recent mapping or consideration for development potential by the
sellers. The Company applies recent advances in well evaluation
techniques and seismic technology and processing that have often not been
applied to mature properties by the sellers.
- Control of Operations. The Company believes that its position as field
operator is essential to control costs and initiate development
operations, including the timing and extent of such operations through
the first phase of development.
Development. In connection with its business strategy, prior to each
property acquisition, the Company performs a thorough geological, geophysical
and engineering analysis of the property, including 3-D seismic surveys in
certain cases. The Company utilizes its geological and engineering assessments
to formulate a comprehensive development plan for the property which typically
involves identification of additional undeveloped formations, the drilling of
new wells in developed and undeveloped formations, the workover or recompletion
of existing wells and the application of other techniques designed to increase
production. As the Company executes its initial development plan for a property,
it frequently identifies incremental opportunities for further development of
the property.
The Company believes that significant additional development potential
exists in its current asset base of 14 properties. For the period from July 1,
1997 through December 31, 1998, the Company has budgeted capital expenditures of
approximately $150 million to fund plans to drill 36 new wells, conduct 24
workovers/recompletions on existing wells and, depending upon the timing and
success of specific development activities, install five new offshore production
platforms. Investments in the properties described below in "-- Properties"
constitute 84% of budgeted 1997 capital expenditures (including actual
expenditures through June 30, 1997) and 85% of budgeted 1998 capital
expenditures.
Results to Date. From the beginning of 1990, when the Company commenced the
implementation of its current business strategy, through June 30, 1997 (giving
effect to the acquisition of the Vermilion Block 255 Field), the Company
invested approximately $289.4 million in new properties and realized $160.1
million of net operating cash flow from these properties. The Company estimated
that the net present value of its proved reserves from these properties was
$372.3 million at August 1, 1997. Proved reserve additions from the beginning of
1990 through August 1, 1997 totaled 58.9 MMBOE and were purchased and developed
for an average finding cost of $6.13 per BOE (including property acquisitions
and incurred and estimated future development costs). Operating costs, including
major maintenance expenses, for these properties since their acquisition
averaged $2.76 per BOE.
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<PAGE> 33
The Company's strategy has resulted in significantly higher levels of
average net daily production, as shown in the table below:
<TABLE>
<CAPTION>
AVERAGE NET DAILY PRODUCTION RATES
------------------------------------
OIL GAS OIL
PRODUCTION PRODUCTION AND GAS
(MBBLS/D) (MMCF/D) (MBOE/D)
---------- ---------- --------
<S> <C> <C> <C>
1991............................................. 1.5 4.2 2.2
1992............................................. 2.0 8.1 3.4
1993............................................. 2.8 13.6 5.1
1994............................................. 3.0 18.2 6.1
1995............................................. 3.8 23.0 7.7
1996............................................. 3.7 31.0 8.9
First six months of 1997......................... 3.8 33.1 9.4
</TABLE>
The Company has grown principally through the acquisition and subsequent
development and exploitation of properties purchased from major oil companies.
The Company's proved oil and gas reserves at August 1, 1997 were concentrated in
14 properties, eight of which are in the Gulf of Mexico offshore Louisiana and
six of which are onshore Louisiana. The Company currently manages eight
partnerships formed prior to its initial public offering, and less than 5% of
the Company's assets are owned through these entities.
OIL AND GAS RESERVES
The following table sets forth summary information with respect to the
Company's estimated proved oil and gas reserves. All information in this
Prospectus as of December 31, 1994, 1995 and 1996 relating to estimated oil and
gas reserves and the estimated future net cash flows attributable thereto is
based upon the Reserve Reports prepared by the Independent Engineers, except for
the reserves attributed to Eugene Island Block 243 Field at December 31, 1994,
which were estimated by the Company. All information in this Prospectus as of
August 1, 1997 relating to estimated oil and gas reserves and estimated future
net cash flows attributable thereto is based upon estimates by the Company. All
calculations of estimated reserves have been made in accordance with the rules
and regulations of the Commission and, except as otherwise indicated, give no
effect to federal or state income taxes otherwise attributable to estimated
future cash flows from the sale of oil and gas.
<TABLE>
<CAPTION>
AS OF AS OF DECEMBER 31,
AUGUST 1, ------------------------------
1997(1) 1996 1995 1994
--------- -------- -------- --------
<S> <C> <C> <C> <C>
Total proved:
Oil (MBbls).......................... 18,427 12,772 7,985 6,455
Gas (MMcf)........................... 185,572 144,316 81,179 68,285
Total (MBOE)......................... 49,356 36,825 21,515 17,836
Proved developed:
Oil (MBbls).......................... 14,927 9,260 7,055 5,840
Gas (MMcf)........................... 139,723 109,628 67,797 52,215
Total (MBOE)......................... 38,214 27,531 18,355 14,543
Estimated future net cash flows before
income taxes (in thousands).......... $544,114 $712,379 $259,478 $145,006
Present value of estimated future net
cash flows before income taxes
(in thousands)(2).................... $372,314 $448,895 $179,725 $ 97,391
Prices(3):
Oil (per Bbl)........................ $ 18.94 $ 25.97 $ 19.40 $ 16.74
Gas (per Mcf)........................ 2.26 3.94 2.39 1.72
</TABLE>
(see footnotes on following page)
32
<PAGE> 34
- ---------------
(1) The increase in the Company's estimate of its proved reserves as of August
1, 1997, from December 31, 1996, is primarily attributable to the
acquisition of the Vermilion Block 255 Field and the development of South
Pelto Block 23.
(2) The present value of estimated future net cash flows attributable to the
Company's reserves was prepared using constant prices as of the calculation
date, discounted at 10% per annum on a pre-tax basis.
(3) Represents weighted average prices received by the Company (net of effects
of hedging) as of the date indicated, and used in calculating "Estimated
future net cash flows before income taxes" and "Present value of estimated
future net cash flows before income taxes."
There are numerous uncertainties inherent in estimating quantities of
proved reserves and in projecting future rates of production and the timing of
development expenditures, including many factors beyond the control of the
Company. The reserve data set forth herein represent only estimates. Reserve
engineering is a subjective process of estimating underground accumulations of
oil and gas that cannot be measured in an exact way, and the accuracy of any
reserve estimate is a function of the quality of available data and of
engineering and geological interpretation and judgment and the existence of
development plans. As a result, estimates of reserves made by different
engineers for the same property will often vary. Results of drilling, testing
and production subsequent to the date of an estimate may justify a revision of
such estimates. Accordingly, reserve estimates are generally different from the
quantities of oil and gas that are ultimately produced. Further, the estimated
future net revenues from proved reserves and the present value thereof are based
upon certain assumptions, including geological success, prices, future
production levels and costs that may not prove to be correct. Predictions about
prices and future production levels are subject to great uncertainty, and the
meaningfulness of such estimates depends on the accuracy of the assumptions upon
which they are based.
As an operator of domestic oil and gas properties, the Company has filed
Department of Energy Form EIA-23, "Annual Survey of Oil and Gas Reserves," as
required by Public Law 93-275. There are differences between the reserves as
reported on Form EIA-23 and as reported herein. The differences are attributable
to the fact that Form EIA-23 requires that an operator report on the total
reserves attributable to wells which are operated by it, without regard to
ownership (i.e., reserves are reported on a gross operated basis, rather than on
a net interest basis).
ACQUISITION, PRODUCTION AND DRILLING ACTIVITY
Acquisition and Development Costs. The following table sets forth certain
information regarding the costs incurred by the Company in its development and
acquisition activities during the periods indicated.
<TABLE>
<CAPTION>
SIX MONTHS YEAR ENDED DECEMBER 31,
ENDED -----------------------------
JUNE 30, 1997 1996 1995 1994
------------- ------- ------- -------
(IN THOUSANDS)
<S> <C> <C> <C> <C>
Acquisition costs.................... $ 1,362 $26,650 $ 8,074 $11,465
Development costs.................... 27,809 24,090 27,383 22,241
Exploratory costs.................... 20,003 26,339 8,261 4,719
------- ------- ------- -------
Subtotal................... 49,174 77,079 43,718 38,425
General and administrative costs, net
of fees and reimbursements......... 1,247 2,325 1,790 2,749
------- ------- ------- -------
Total costs incurred....... $50,421 $79,404 $45,508 $41,174
======= ======= ======= =======
</TABLE>
33
<PAGE> 35
Productive Well and Acreage Data. The following table sets forth certain
statistics for the Company regarding the number of productive wells and
developed and undeveloped acreage as of December 31, 1996.
<TABLE>
<CAPTION>
GROSS NET
--------- ---------
<S> <C> <C>
Productive Wells:
Oil(1).................................................... 52.00 35.07
Gas(2).................................................... 30.00 20.65
--------- ---------
Total............................................. 82.00 55.72
========= =========
Developed Acres:
Onshore................................................... 2,806.60 1,903.49
Offshore.................................................. 7,200.00 4,065.01
--------- ---------
Total............................................. 10,006.60 5,968.50
========= =========
Undeveloped Acres(3):
Onshore Louisiana......................................... 17,606.67 15,320.83
Offshore Louisiana........................................ 27,338.88 17,914.04
--------- ---------
Total............................................. 44,945.55 33,234.87
========= =========
</TABLE>
- ---------------
(1) Four gross wells each have dual completions.
(2) Nine gross wells each have dual completions.
(3) Leases covering approximately 0.99% of the Company's undeveloped acreage
will expire in 1997, 1.93% in 1998, 0.37% in 1999, 7.85% in 2000 and 5.55%
in 2001. Leases covering the remainder of the Company's undeveloped gross
acreage (83.31%) are held by production.
Drilling Activity. The following table sets forth the Company's drilling
activity for the periods indicated.
<TABLE>
<CAPTION>
GROSS NET
------ -----
<S> <C> <C>
Wells drilled during the years ended December 31,
1996:
Exploratory............................................ 4.00 3.73
Development............................................ 5.00 4.50
1995:
Exploratory............................................ 3.00 2.94
Development............................................ 6.00 4.40
1994:
Exploratory............................................ 2.00 1.75
Development............................................ 12.00 7.64
</TABLE>
All wells drilled were productive except for three gross development wells
(2.34 net) which were drilled in 1994, two gross exploratory wells (1.94 net)
and one gross development well (0.38 net) which were drilled in 1995 and three
gross exploratory wells (2.75 net) and one gross development well (0.76 net)
which were drilled in 1996.
TITLE TO PROPERTIES
The Company has obtained title opinions on substantially all of its
producing properties and believes it has satisfactory title to such properties
in accordance with standards generally accepted in the oil and gas industry. The
Company's properties are subject to customary royalty interests, liens for
current taxes and other burdens which the Company believes do not materially
interfere with the use of or affect the value of such properties. The title
investigation performed by the Company prior to acquiring undeveloped properties
is thorough but less vigorous than that conducted prior to drilling, consistent
with
34
<PAGE> 36
standard practice in the oil and gas industry. Prior to the commencement of
drilling operations, a thorough title examination is conducted and curative work
is performed with respect to significant defects. A thorough title examination
has been performed with respect to substantially all producing properties owned
by the Company.
PROPERTIES
The Company owns and operates a controlling interest in all of its 14
properties, eight of which are offshore and six of which are onshore Louisiana.
The offshore properties contain 25 production platforms and the Company
currently owns an interest in 105 producing wells. Eight of its significant
properties are described below. Production volumes are presented on a gross well
basis, unless otherwise indicated.
SOUTH PELTO BLOCK 23. South Pelto Block 23 is located in federal waters in
the Gulf of Mexico, approximately 80 miles southwest of New Orleans. The Company
owns an approximate 98% working interest in this field, which was purchased from
a major oil company in June 1990. The Company's net revenue interest in the
field currently ranges from approximately 65% to 78%. The Company's investment
in the property through June 30, 1997 was approximately $63.9 million, including
$2.0 million of acquisition and bonding costs and $61.9 million of costs for
field development, facilities enhancements and modifications.
The field was discovered in 1962 and subsequently developed by a major oil
company. Cumulative production from eight sands and 10 wells is over 12 MMBbls
of oil and 13 Bcf of gas since going onstream in 1963. Subsequent to the
acquisition of the field by the Company, the initial phase of development
included three workovers and the drilling of two new wells. In the first six
months of 1997, the field produced at the average daily rate net to the Company
of 586 Bbls of oil and 3.1 MMcf of gas.
The Company's recent development activity is based on the interpretation of
a proprietary 3-D seismic survey obtained in 1994, and the Company made a
significant discovery on the block in 1996. Fourteen new productive sands, as
indicated by electric logs, have been encountered in an area of the leaseblock
and at depths which had not been previously explored. Four wells have been
drilled in this area, all of which the Company believes will be commercially
successful, and the drilling of a fifth well is in progress. Two of the wells
have been placed on production, and the installation of the new "D" production
platform is scheduled for the fourth quarter of 1997 for the production of the
other two wells and, if successful, the fifth well. The Company believes that
the production from the "D" platform has the potential to materially increase
the Company's daily production. The "D" Platform will have a maximum daily
production capacity of 100 MMcf of gas and 15,000 Bbls of oil. Also in 1997, the
Company plans to drill its Swordfish Prospect to 18,500 feet to test multiple
objectives. This well will be drilled from a separate surface location than the
"D" Platform and, if successful, would require additional production facilities.
Total investments for the last half of 1997 at South Pelto Block 23 are
budgeted at approximately $24.0 million. Plans for 1998 include the drilling of
four new wells and the installation of additional facilities, pending the
outcome of the Swordfish Prospect well, at a budgeted cost of approximately
$30.7 million.
VERMILION BLOCK 255. On August 1, 1997, the Company acquired certain
interests in the Vermilion Block 255 Field, which consists of four Vermilion
blocks (255, 256, 267 and 268), for $36.6 million. The working interests
acquired range from 66.7% to 83.3% and the net revenue interests range from
55.6% to 69.4%. Eight platforms and 48 wells presently exist on the field, with
10 wells currently producing at aggregate daily rates of approximately 1,227
Bbls of oil and 12.2 MMcf of gas. The Company has consolidated the operations in
the field which were previously conducted by two operators, and believes that it
will benefit from increased operating and development efficiencies. The
remaining interests in the property are owned by CNG Producing Company.
The Vermilion Block 255 Field was discovered in 1964 and is located
approximately 75 miles offshore Louisiana in water depths ranging from 130 to
175 feet. The field is a major oil and gas complex
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consisting of both water drive oil and gas reservoirs and pressure depletion gas
reservoirs. Oil and gas accumulations have been encountered in 25 sands in
multiple faults and stratigraphic traps in both normally-pressured and
geopressured reservoirs between 7,500 and 12,300 feet. The field has produced
approximately 15 MMBbls of oil and 360 Bcf of gas since May 1970.
Based on its initial analysis of the field, the Company plans to conduct
significant operations for its further development, targeting both proved and
probable objectives. For 1998, the Company has budgeted $9.6 million for
drilling three wells and two workover operations. In addition, the Company has
arranged to acquire a 3-D seismic survey to more fully evaluate the field's
potential. These planned activities will be reviewed and revised as necessary
during the remainder of 1997.
LAKE HERMITAGE. On August 1, 1996, the Company increased its interest in
approximately 6,500 acres in the Lake Hermitage Field by purchasing the
interests of a group of privately-held companies in the field for $6.5 million.
The Company had previously drilled six successful wells (including four dually
completed wells) on designated areas in the field under a farmout agreement
entered into in 1994 with the prior owners. Pursuant to prior contractual
obligations, the Company assigned a portion of the acquired interest to two
partnerships it manages for a proportionate share of the purchase price. After
giving effect to these transactions, the Company holds an approximate 76%
working interest and an approximate 61% net revenue interest in the field except
for certain deep rights held by a major oil company, which are below the
horizons currently being targeted by the Company.
The Lake Hermitage Field is located onshore in Plaquemines Parish,
Louisiana, approximately 25 miles south southeast of New Orleans. The field is a
salt dome structure discovered in 1928 and has produced significant quantities
of oil and gas from multiple sandstone reservoirs between 3,100 and 14,200 feet.
In August 1997, the field was producing at aggregate daily rates of 289 Bbls of
oil and 9.1 MMcf of gas.
The Company intends to acquire a proprietary 3-D seismic survey in late
1997 at a cost of approximately $4.1 million, and the data from this survey will
be used to plan future field development. In addition to its leasehold position
of 6,500 acres, the Company has another 7,800 acres under option to lease with
plans to drill two wells in this field at a budgeted cost of $2.9 million,
pending evaluation of the new seismic data.
VERMILION BLOCK 46. On September 27, 1996, the Company acquired a 62.5%
working interest in the Vermilion Block 46 Field for $15.4 million. The Company
acquired this interest from a major oil company and became operator of the block
at that time. In a separate transaction with a different company in 1993, the
Company purchased a 37.5% working interest in this field for $3.7 million.
Pursuant to prior contractual obligations, the Company assigned a portion of the
acquired interests to two partnerships it manages in consideration for a pro
rata portion of the purchase price, and the Company retained a 76% working
interest with an approximate 65% net revenue interest in the field.
The Vermilion Block 46 Field is located approximately 10 miles offshore
Louisiana in 30 feet of water. Production was established on the block in 1956,
and cumulative production from the field is approximately 115 Bcf of gas and 1.2
MMBbls of oil. The interests acquired in Vermilion Block 46 consist of
approximately 2,500 acres in the northern half of the block. Productive
reservoirs have historically been encountered between 3,000 and 15,500 feet.
In the remainder of 1997, the Company plans to complete the recently
drilled No. 6 well as a dual completion and install a flowline from it back to
the "A" Platform. First production from the No. 6 well is expected in October
1997. The Company's plans for 1998 include drilling two deep test wells on
prospects identified from a newly acquired 3-D seismic survey covering the
block. Expenditures for 1998 are budgeted at $10.2 million.
VERMILION BLOCK 131. On September 27, 1996, the Company acquired a 50%
working interest with a 41% net revenue interest in the Vermilion Block 131
Field from a major oil company for $5.1 million. In addition to the purchase
price, a letter of credit in the amount of $1.8 million was established to
secure the Company's obligation to plug and abandon the property. The Company is
the operator of the
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property, and the remaining 50% interest is owned by a major oil company. The
acquisition included interests in six producing wells and six shut-in wells.
The Vermilion Block 131 Field is located approximately 30 miles offshore
Louisiana in 60 feet of water. The field was discovered in 1960 and placed on
production in 1963. Field development has consisted of 19 productive wells and
seven dry holes. A total of 65 commercial completions have been established in
27 sandstone reservoirs between 4,800 and 14,300 feet.
Cumulative production from the property is 488 Bcf of gas and 8.5 MMBbls of
oil. Since acquiring this property in 1996, the Company has conducted workover
operations on two wells and drilled a sidetrack well from an idle wellbore. In
August 1997, the field was producing at aggregate daily rates of 81 Bbls of oil
and 13.3 MMcf of gas. A new evaluation of the property is currently in progress
utilizing the Company's recently acquired 3-D seismic data. The Company plans
another major workover in 1997 at a budgeted cost of $1.1 million.
CUT OFF. The Cut Off Field is located onshore in Lafourche Parish,
Louisiana. The Company owns a 98% working interest in this field, which was
purchased from two major and two independent oil companies in August 1991. The
Company currently has an approximate 61% to 65% net revenue interest in the
field.
The field was discovered in 1953 and is covered by both land and inland
water. Cumulative production from the field at the time of the acquisition was
110 Bcf of gas and 39 MMBbls of oil. Since the Company assumed operations of the
field in 1991, it has produced approximately 2.1 MMBbls of oil and 7.9 Bcf of
gas.
The Cut Off Field is located approximately two miles from the Clovelly
Field, one of the Company's other significant properties which is described
below. Each field is dominated geologically by a prominent salt dome structure.
Although significant development drilling has been conducted at each property
near the salt, a substantial portion of the surrounding acreage has received
little exploration attention.
In order to attempt to better understand the complex fault patterns near
the salt and to evaluate other potential drilling opportunities in this region,
the Company completed a $4.5 million 3-D seismic survey of a 61-square-mile area
which includes the Cut Off Field, the Clovelly Field and a significant amount of
contiguous acreage. The processed data was received by the Company in September
1996. The Company owns or controls through lease options approximately 70% of
the survey area.
Although the future development of the Cut Off Field will be guided by the
interpretation of the 3-D data, one purpose of the survey was the confirmation
of pre-existing development plans derived from more traditional methods. The
Company has drilled one well and worked over two wells during the first half of
1997 and plans to deepen the Jones No. 23 well during the remainder of 1997.
Interpretation of the proprietary 3-D seismic survey acquired over the Cut Off
Field has yielded a number of prospects to be drilled in 1998. Current plans for
1998 include drilling three new wells and one sidetrack well and workover
operations on one well at a budgeted cost of $8.5 million to the Company.
CLOVELLY. In July 1995, the Company acquired for $4.5 million a 100%
working interest and an 89.5% net revenue interest in the Clovelly Field from a
major oil company. The field, located onshore in Lafourche Parish, Louisiana, is
comprised of approximately 3,200 acres on the north and east flanks of a salt
dome structure that has produced in excess of 32 MMBbls of oil and 167 Bcf of
gas since its discovery in 1950. The purchase included interests in seven oil
and two gas producing wells which are operated by the Company. In August 1996,
the Company acquired a 40% working interest in 2,840 acres on the south and west
flanks of the salt dome structure in exchange for 3-D seismic data.
Historically, field production has been derived from wells which developed
multiple sandstone reservoirs trapped against the salt. From the time of the
acquisition through June 30, 1997, the average daily production from the
property net to the Company was 350 Bbls of oil and 1.7 MMcf of gas.
As described in the above discussion of the Cut Off Field, a 3-D seismic
survey over the Cut Off Field, the Clovelly Field and surrounding acreage was
acquired in September 1996. Interpretation of the
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3-D seismic survey has resulted in several new drilling locations in this field.
The Company is currently adding to existing waterflood injection capacity in the
main field reservoir sand and reviving a waterflood in the southeastern portion
of the field in the No. 37 sand, one of the shallower reservoirs. There is
significant acreage under lease-option to the Company outside of the currently
developed acreage. The Company plans to drill five wells and workover one well
during the second half of 1997 through the end of 1998 at a budgeted cost to the
Company of $11.8 million.
EUGENE ISLAND BLOCK 243. Eugene Island Block 243 consists of two federal
lease blocks located offshore Louisiana in the Gulf of Mexico in approximately
150 feet of water. The Company owns an approximate 58% working interest in this
field, which it acquired for $10.0 million from a major oil company in December
1994. The acquisition included a production platform and five producing wells.
Prior to its acquisition by Stone Energy, the field had produced 65 Bcf of
gas from nine sandstone reservoirs between 3,300 feet and 12,500 feet. At the
time of purchase, five wells were producing intermittently at a rate of
approximately 4 MMcf/d of gas. During the first six months of 1997, average
daily production from the field net to the Company was 96 Bbls of oil and 8.0
MMcf of gas.
Prior to acquiring the property, the Company mapped the entire field area
utilizing 3-D seismic data. The interpretation indicated the presence of
additional reserves and prospective drilling locations. The Company's initial
well, the C-1, was drilled and placed on production in 1995. The well logged gas
pay in three sands thought to be previously depleted and found gas pay in a
deeper sand, which is the currently producing interval.
In late 1996, the Company formed a joint operating area covering portions
of Eugene Island Blocks 224 and 243 with a major oil company. A jointly-owned
well was drilled on Block 224, and this well encountered oil and gas in four
reservoir sands stratigraphically deeper than any pay sands previously
encountered on Blocks 242 and 243. A second jointly-owned well is planned in the
second half of 1997 at an approximate cost of $2.6 million to the Company. Plans
for 1998 include drilling two wells at an estimated cost of $9.9 million.
REGULATION
Regulation of Production. In all areas where the Company conducts
activities, there are statutory provisions regulating the production of oil and
natural gas under which administrative agencies may promulgate rules in
connection with the operation and production of both oil and gas wells,
determine the reasonable market demand for oil and gas, and establish allowable
rates of production. Such regulatory orders may restrict the rate at which the
Company's wells produce oil or gas below the rate at which such wells would be
produced in the absence of such regulatory orders, with the result that the
amount or timing of the Company's revenues could be adversely affected.
Federal Leases. The Company has oil and gas leases in the Gulf of Mexico,
which were granted by the federal government and are administered by the MMS.
Such leases are issued through competitive bidding, contain relatively
standardized terms and require compliance with detailed MMS regulations and
orders pursuant to the Outer Continental Shelves Lands Act ("OCSLA") which are
subject to change by the MMS. For offshore operations, lessees must obtain MMS
approval for exploration plans and development and production plans prior to the
commencement of such operations. In addition to permits required from other
agencies (such as the Coast Guard, the Army Corps of Engineers and the EPA),
lessees must obtain a permit from the MMS prior to the commencement of drilling.
The MMS has promulgated regulations requiring offshore production facilities
located on the OCS to meet stringent engineering and construction
specifications. The MMS proposed additional safety-related regulations
concerning the design and operating procedures for OCS production platforms and
pipelines. These proposed regulations were withdrawn pending further discussions
among interested federal agencies. The MMS also has regulations restricting the
flaring or venting of natural gas, and has proposed to amend such regulations to
prohibit the flaring of liquid hydrocarbons and oil without prior authorization.
Similarly, the MMS has promulgated other regulations governing the plugging and
abandoning of wells located offshore and the removal of all production
facilities. With respect to any Company operations conducted
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on offshore federal leases, liability may generally be imposed under OCSLA for
costs of clean-up and damages caused by pollution resulting from such
operations, other than damages caused by acts of war or the negligence of third
parties. To cover the various obligations of lessees on the OCS, the MMS
generally requires that lessees post substantial bonds or other acceptable
assurances that such obligations will be met. The cost of such bonds or other
surety can be substantial and there is no assurance that bonds or other surety
can be obtained in all cases.
Since November 26, 1993, new levels of lease and areawide bonds have been
required of lessees taking certain actions with regard to OCS leases. Operators
in the OCS waters of the Gulf of Mexico, including the Company, have been or may
be required to increase their areawide bonds and individual lease bonds to $3.0
million and $1.0 million, respectively, unless exemptions or reduced amounts are
allowed by the MMS. The Company currently has an areawide pipeline bond of $0.3
million and an area-wide lease bond of $3.0 million issued in favor of the MMS
for its existing offshore properties. The MMS also has discretionary authority
to require supplemental bonding in addition to the foregoing required bonding
amounts but this authority is only exercised on a case-by-case basis at the time
of filing an assignment of record title interest for MMS approval. Based upon
certain financial parameters, the Company has been granted exempt status by the
MMS, which exempts the Company from the supplemental bonding requirements. Under
certain circumstances, the MMS may require any Company operations on federal
leases to be suspended or terminated. Any such suspension or termination could
materially and adversely affect the Company's financial condition and
operations.
The MMS issued a notice of proposed rulemaking in which it proposed to
amend its regulations governing the calculation of royalties and the valuation
of crude oil produced from federal leases. The proposed rule would modify the
valuation procedures for both arm's length and non-arm's length crude oil
transactions to decrease reliance on posted prices and assign a value to crude
oil that better reflects market value, establish a new MMS form for collecting
value differential data and amend the valuation procedure for the sale of
federal royalty oil. The Company cannot predict at this stage of the rulemaking
proceeding how it might be affected by this amendment to the MMS regulations.
Oil Price Controls and Transportation Rates. Sales of crude oil, condensate
and gas liquids by the Company are not currently regulated and are made at
negotiated prices. Commencing in October 1993, the U.S. Federal Energy
Regulatory Commission (the "FERC") issued a series of rules (Order Nos. 561 and
561-A) establishing an indexing system under which oil pipelines will be able to
change their transportation rates, subject to prescribed ceiling levels. The
indexing system, which allows or may require pipelines to make rate changes to
track changes in the Producer Price Index for Finished Goods, minus one percent,
became effective January 1, 1995. The FERC's decision in this matter was
recently affirmed by the Court. The Company is not able at this time to predict
the effects of Order Nos. 561 and 561-A, if any, on the transportation costs
associated with oil production from the Company's oil producing operations.
Federal Regulation of Sales and Transportation of Natural
Gas. Historically, the transportation and sale for resale of natural gas in
interstate commerce have been regulated pursuant to the Natural Gas Act of 1938
(the "NGA"), the Natural Gas Policy Act of 1978 (the "NGPA") and the regulations
promulgated thereunder by the FERC. In the past, the Federal government has
regulated the prices at which gas could be sold. While sales by producers of
natural gas can currently be made at uncontrolled market prices, Congress could
reenact price controls in the future. Deregulation of wellhead natural gas sales
began with the enactment of the NGPA. In 1989, Congress enacted the Natural Gas
Wellhead Decontrol Act (the "Decontrol Act"). The Decontrol Act removed all NGA
and NGPA price and non-price controls affecting wellhead sales of natural gas
effective January 1, 1993.
Several major regulatory changes have been implemented by the FERC from
1985 to the present that affect the economics of natural gas production,
transportation and sales. In addition, the FERC continues to promulgate
revisions to various aspects of the rules and regulations affecting those
segments of the natural gas industry, most notably interstate natural gas
transmission companies, which remain subject to the FERC's jurisdiction. These
initiatives may also affect the intrastate transportation of
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gas under certain circumstances. The stated purpose of many of these regulatory
changes is to promote competition among the various sectors of the gas industry.
The ultimate impact of these complex and overlapping rules and regulations, many
of which are repeatedly subjected to judicial challenge and interpretation,
cannot be predicted.
Commencing in April 1992, the FERC issued Order Nos. 636, 636-A, 636-B, and
636-C (collectively, "Order No. 636"), which, among other things, require
interstate pipelines to "restructure" to provide transportation separate, or
"unbundled," from the pipelines' sales of gas. Also, Order No. 636 requires
pipelines to provide open-access transportation on a basis that is equal for all
gas supplies. Order No. 636 has been implemented through negotiated settlements
in individual pipeline service restructuring proceedings. In many instances, the
result of Order No. 636 and related initiatives have been to substantially
reduce or bring to an end the interstate pipelines' traditional roles as
wholesalers of natural gas in favor of providing only storage and transportation
services. The FERC has issued final orders in virtually all pipeline
restructuring proceedings, and has completed a series of one year reviews to
determine whether refinements are required regarding individual pipeline
implementations of Order No. 636.
Although Order No. 636 does not directly regulate natural gas producers
such as the Company, the FERC has stated that Order No. 636 is intended to
foster increased competition within all phases of the natural gas industry. It
is unclear what impact, if any, increased competition within the natural gas
industry under Order No. 636 will have on the Company and its natural gas
marketing efforts. The United States Court of Appeals for the District of
Columbia Circuit (the "Court") recently issued its decision in the appeals of
Order No. 636. The Court largely upheld the basic tenets of Order No. 636,
including the requirements that interstate pipelines "unbundle" their sales of
gas from transportation and that pipelines provide open-access transportation on
a basis that is equal for all gas suppliers. The Court remanded five relatively
narrow issues for further explanation by the FERC. In doing so, the Court made
it clear that the FERC's existing rules on the remanded issues would remain in
effect pending further consideration. The issues remanded for further action do
not appear to materially affect the Company. A number of parties have appealed
the Court's ruling to the United States Supreme Court and proceedings on the
remanded issues are currently ongoing before the FERC following its issuance of
Order No. 636-C in February 1997. It is not possible to predict what effect, if
any, the ultimate outcome of this judicial review process will have on the
Company. Although Order No. 636 could provide the Company with additional market
access and more fairly applied transportation service rates, terms and
conditions, it could also subject the Company to more restrictive pipeline
imbalance tolerances and greater penalties for violations of those tolerances.
The Company does not believe, however, that it will be affected by any action
taken with respect to Order No. 636 materially differently than other natural
gas producers and marketers with which it competes.
The FERC issued a statement of policy and a request for comments concerning
alternatives to its traditional cost-of-service rate making methodology. This
policy statement articulates the criteria that the FERC will use to evaluate
proposals to charge market-based rates for the transportation of natural gas.
The policy statement also provides that the FERC will consider proposals for
negotiated rates for individual shippers of natural gas, so long as a
cost-of-service based rate is available. The FERC requested comments on whether
it should allow gas pipelines the flexibility to negotiate the terms and
conditions of transportation service with prospective shippers. The Company
cannot predict what further action the FERC will take on these matters. However,
the Company does not believe that it will be affected by any action taken
materially differently than other natural gas producers and marketers with which
it competes.
The FERC has announced its intention to re-examine certain of its
transportation-related policies, including the appropriate manner in which
interstate pipelines release transportation capacity under Order No. 636. While
any resulting FERC action would affect the Company only indirectly, any new
rules and policy statements may have the effect of enhancing competition in the
natural gas markets by, among other things, encouraging non-producer natural gas
marketers to engage in certain purchase and sale transactions. The Company
cannot predict what action the FERC will take on these matters, nor can
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it accurately predict whether the FERC's actions will achieve the goal of
increasing competition in markets in which the Company's natural gas is sold.
However, the Company does not believe that it will be affected by any action
taken materially differently than other natural gas producers and marketers with
which it competes.
The FERC has issued a policy statement on how interstate natural gas
pipelines can recover the costs of new pipeline facilities after Order No. 636.
While the FERC's policy statement on new construction cost recovery affects the
Company only indirectly, the new policy, in its present form, should enhance
competition in natural gas markets and facilitate construction of gas supply
laterals. However, requests for rehearing of this policy statement are currently
pending.
The OCSLA requires that all pipelines operating on or across the OCS
provide open-access, non-discriminatory service. Although the FERC has opted not
to impose the regulations of Order No. 509, in which the FERC implemented the
OCSLA, on gatherers and other non-jurisdictional entities, the FERC has retained
the authority to exercise jurisdiction over those entities if necessary to
permit non-discriminatory access to service on the OCS.
Through a series of orders, the FERC has indicated how it intends to
regulate natural gas gathering facilities owned (or previously owned but either
"spun down" to an affiliate or "spun off" to a nonaffiliate) by interstate
pipeline companies after Order No. 636. As a general matter, gathering is exempt
from the FERC's jurisdiction; however, the courts have held that where the
gathering is performed by the interstate pipelines in association with the
pipeline's jurisdictional transportation activities, the FERC retains regulatory
control over the associated gathering services to prevent abuses. In respect of
interstate pipeline-owned gathering, the FERC has approved the spin down or spin
off by several interstate pipelines of their gathering facilities. These
approvals were given despite the strong protests of a number of producers
concerned that any diminution in FERC's oversight pipeline-related gathering
services might result in a denial of open access or otherwise enhance the
pipeline's monopoly power. While the FERC has stated that it will retain limited
jurisdiction over such gathering facilities and will hear complaints concerning
any denial of access, it is unclear what effect the FERC's new gathering policy
will have on producers such as the Company and the Company cannot predict what
further action the FERC will take on these matters. The new gathering policy
thus far announced by the FERC does not address its jurisdiction over pipelines
operating on or across the OCS pursuant to OCSLA. If the FERC were to apply
Order No. 509 to gatherers in the OCS, eliminate the exemption of gathering
lines, and redefine its jurisdiction over gathering lines, then these acts could
result in a reduction in available pipeline space for existing offshore
shippers, such as the Company.
The FERC has issued a policy statement on how interstate natural gas
pipelines can recover the costs of new pipeline facilities. While the FERC's
policy statement on new construction cost recovery affects the Company only
indirectly, in its present form, the new policy should enhance competition in
natural gas markets and facilitate construction of gas supply laterals. However,
requests for rehearing of this policy statement are currently pending. In
February 1997, the FERC also announced a broad inquiry into issues facing the
natural gas industry to assist the FERC in establishing regulatory goals and
priorities in the post-Order No. 636 environment.
Additional proposals and proceedings that might affect the natural gas
industry are pending before Congress, the FERC and the courts. The natural gas
industry historically has been very heavily regulated; therefore, there is no
assurance that the less stringent regulatory approach recently pursued by the
FERC and Congress will continue. Notwithstanding the foregoing, the Company does
not anticipate that compliance with existing federal, state and local laws,
rules and regulations will have a material or significantly adverse effect upon
the capital expenditures, earnings or competitive position of the Company.
Environmental Regulations. The Company's operations are subject to numerous
laws and regulations governing the discharge of materials into the environment
or otherwise relating to environmental protection. These laws and regulations,
which impose increasingly strict requirements, may require the acquisition of a
permit before drilling commences, restrict the types, quantities and
concentration of
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various substances, including naturally occurring radioactive materials, that
can be released into the environment in connection with drilling and production
activities, limit or prohibit drilling activities on certain lands lying within
wilderness, wetlands and other protected areas, and impose substantial
liabilities for pollution resulting from the Company's operations. Legislation
has been proposed in Congress from time to time that would reclassify certain
oil and gas exploration and production wastes as "hazardous wastes," which would
make the reclassified wastes subject to much more stringent handling, disposal
and cleanup requirements. If such legislation were to be enacted, it could have
a significant impact on the operating costs of the Company, as well as the oil
and gas industry in general. Initiatives to further regulate the disposal of oil
and gas wastes are also pending in certain states, and these various initiatives
could have a similar impact on the Company. Management believes that the Company
is in substantial compliance with current applicable environmental laws and
regulations and that continued compliance with existing requirements will not
have a material adverse impact on the Company.
OPA and regulations thereunder impose a variety of requirements 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. OPA assigns
liability to each responsible party for oil cleanup 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 likewise do not
apply. Even if applicable, the liability limits for offshore facilities require
the responsible party to pay all removal costs, plus up to $75 million in other
damages. Few defenses exist to the liability imposed by OPA.
OPA imposes ongoing requirements on a responsible party, including the
preparation of oil spill response plans and proof of financial responsibility to
cover environmental cleanup and restoration costs that could be incurred in
connection with an oil spill. As amended by the Coast Guard Authorization Act of
1996, OPA requires responsible parties for offshore facilities to provide
financial assurance in the amount of $35 million to cover potential OPA
liabilities. This amount can be increased up to $150 million if a formal risk
assessment indicates that an amount higher than $35 million should be required.
On March 25, 1997, the MMS promulgated a proposed rule implementing these OPA
financial responsibility requirements. The Company does not anticipate that it
will experience any difficulty in satisfying the MMS's requirements for
demonstrating financial responsibility for its offshore facilities under the OPA
amendments or the proposed rule.
In 1996, the American Institute of Certified Public Accountants issued its
SOP 96-1, which provides guidance on accounting for environmental remediation
liabilities. SOP 96-1 interprets existing Financial Accounting Standards Board
standards applicable to public companies. The Company will apply SOP 96-1 in
1997. The Company believes adoption of SOP 96-1 will not have a material adverse
effect on its results of operations or financial position.
The Comprehensive Environmental Response, Compensation, and Liability Act
("CERCLA"), also known as the "Superfund" law, imposes liability, without regard
to fault or the legality of the original conduct, on certain classes of persons
that are considered to be responsible for the release of a "hazardous substance"
into the environment. These persons include the owner or operator of the
disposal site or sites where the release occurred and companies that disposed or
arranged for the disposal of the hazardous substances found at the site. Persons
who are or were responsible for releases of hazardous substances under CERCLA
may be subject to joint and several liability for the costs of cleaning up the
hazardous substances that have been released into the environment and for
damages to natural resources, and it is not uncommon for neighboring landowners
and other third parties to file claims for personal injury and property damage
allegedly caused by the hazardous substances released into the environment. The
Company may be potentially responsible for costs and liabilities associated with
alleged releases of hazardous substances at three Superfund sites. See "Legal
Proceedings -- Environmental."
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The Federal Water Pollution Control Act ("FWPCA") imposes restrictions and
strict controls regarding the discharge of produced waters and other oil and gas
wastes into navigable waters. Permits must be obtained to discharge pollutants
to waters and to conduct construction activities in waters and wetlands. The
FWPCA and similar state laws provide for civil, criminal and administrative
penalties for any unauthorized discharges of pollutants and unauthorized
discharges of reportable quantities of oil and other hazardous substances. Many
state discharge regulations and the Federal National Pollutant Discharge
Elimination System general permits prohibit the discharge of produced water and
sand, drilling fluids, drill cuttings and certain other substances related to
the oil and gas industry to coastal waters. Although the costs to comply with
recently-enacted zero discharge mandates under federal or state law may be
significant, the entire industry is expected to experience similar costs and the
Company believes that these costs will not have a material adverse impact on the
Company's financial condition and operations. In 1992, the EPA adopted
regulations requiring certain oil and gas exploration and production facilities
to obtain permits for storm water discharges. Costs may be associated with the
treatment of wastewater or developing and implementing storm water pollution
prevention plans but management does not expect these costs to have a material
adverse effect on the Company.
EMPLOYEES
At August 1, 1997, the Company had 81 full time employees. The Company
believes that its relationships with its employees are satisfactory. None of the
Company's employees are covered by a collective bargaining agreement. From time
to time, the Company utilizes the services of independent contractors to perform
various field and other services.
LEGAL PROCEEDINGS
Environmental. In August 1989, TSPC, a wholly-owned subsidiary of the
Company in liquidation, was advised by the EPA that it believed TSPC to be a PRP
for the cleanup of three oil field waste disposal facilities located near
Abbeville, Louisiana, which were included on CERCLA's National Priority List
(the "Superfund List") by the EPA. In addition to TSPC, numerous other parties
were named as potentially responsible for the cleanup of these sites. While the
Company's records do not indicate that any drilling wastes generated by TSPC
were disposed of at these sites, it is possible that one or more waste haulers
contracted by TSPC may have disposed of wastes at these sites. Given the large
number of PRPs at these sites and that the Company is a de minimis PRP at each
site, management does not believe that any liability for these sites would
materially adversely affect the financial condition of the Company. The three
sites are (i) the D.L. Mud Site, (ii) the PAB Oil Site and (iii) the Gulf Coast
Vacuum Services Site. The Company entered into a Settlement Agreement, dated
September 16, 1996, with Dow Chemical Corporation, whose subsidiary is a current
owner of the D.L. Mud Site, and the Company signed an EPA Consent Decree
releasing the Company from any anticipated claims at the D. L. Mud Site. The
Company also executed an EPA Consent Order, dated effective as of November 27,
1995, settling its potential liabilities at the PAB Oil Site. The Company
declined the opportunity to enter into a similar order relative to the Gulf
Coast Vacuum Site because the Company believes that its connection, if any, to
said site is speculative.
Other Proceedings. In December 1995, Goodrich Leasehold L.L.C. and Goodrich
Drillers L.L.C. filed a civil action (No. 95-61313) in the 333rd Judicial
District Court, Harris County, Texas, against the Company in an attempt to set
aside a farmout agreement affecting portions of the West Flank of the Weeks
Island Field in Iberia Parish, Louisiana. Management believes that this claim is
without merit and intends to vigorously defend this action.
The Company is also named as a defendant in certain lawsuits and is a party
to certain regulatory proceedings arising in the ordinary course of business.
Management does not expect these matters, individually or in the aggregate, to
have a material adverse effect on the financial condition of the Company.
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<PAGE> 45
MANAGEMENT
DIRECTORS AND EXECUTIVE OFFICERS
The following table sets forth the names, ages and titles of the directors
and executive officers of the Company.
<TABLE>
<CAPTION>
NAME AGE POSITION
---- --- --------
<S> <C> <C>
James H. Stone 71 Chairman of the Board and Chief Executive
Officer
Joe R. Klutts 63 Vice Chairman of the Board
D. Peter Canty 50 President, Chief Operating Officer and
Director
Michael L. Finch 42 Executive Vice President, Chief Financial
Officer and Director
Phillip T. Lalande 48 Vice President -- Engineering
James H. Prince 55 Vice President, Chief Accounting Officer and
Controller
Andrew L. Gates, III 50 Secretary and General Counsel
E. J. Louviere 48 Vice President -- Land
Craig L. Glassinger 49 Vice President -- Acquisitions
David R. Voelker 43 Director
John P. Laborde 73 Director
Robert A. Bernhard 68 Director
Raymond B. Gary 68 Director
B. J. Duplantis 58 Director
</TABLE>
The following biographies describe the business experience of the directors
and executive officers of the Company.
James H. Stone has served as Chairman of the Board and Chief Executive
Officer of the Company since March 1993, and as Chairman of the Board of TSPC
(the predecessor of the Company and now a wholly owned subsidiary of the Company
which is being dissolved) since 1981 and served as President of TSPC from
September 1992 to July 1993. Mr. Stone is a director of Newpark Resources, Inc.
and is a member of the Advisory Committee of the St. Louis Rams Football
Company.
Joe R. Klutts has served as Vice Chairman of the Board since March 1994 and
as a Director since March 1993. He has also served as a Director of TSPC since
1981. He served as President of the Company from March 1993 to February 1994,
and as Executive Vice President -- Exploration and President of TSPC from 1981
to 1993 and from July 1993 to May 1994, respectively.
D. Peter Canty served as an Executive Vice President of the Company from
March 1993 to March 1994, when he was named President of the Company. He has
also served as Chief Operating Officer and as a Director of the Company since
March 1993. Mr. Canty was a Vice President and the Chief Geologist of TSPC from
1987 to May 1994, when he was named President of TSPC.
Michael L. Finch has served as Executive Vice President, Chief Financial
Officer and Director since March 1993. From 1988 through July 1993, he was a
partner in the firm of Finch & Pierret, CPAs, which performed a substantial
amount of financial reporting, tax compliance and financial advisory services
for TSPC and its affiliates.
Phillip T. Lalande has served as Vice President -- Engineering of the
Company since March 1995. He served as the Company's Operations Manager from
July 1993 to March 1995, and as a consulting engineer to TSPC from 1988 to July
1993.
James H. Prince has served as Vice President, Chief Accounting Officer and
Controller of the Company since March 1993 and as Vice President and Controller
of TSPC since 1981, as Treasurer since 1989, as Secretary from 1989 to 1991 and
as Assistant Secretary since 1992.
44
<PAGE> 46
Andrew L. Gates, III has served as Vice President -- Legal, Secretary and
General Counsel of the Company since August 1995. Prior to joining Stone Energy
in 1995, he was a partner in the law firm of Ottinger, Gates, Hebert & Sikes
from 1987 to August 1995.
E. J. Louviere has served as Vice President -- Land since June 1995. He
served as the Land Manager of TSPC and the Company from July 1981 to June 1995.
Craig L. Glassinger has served as Vice President -- Acquisitions of the
Company since December 1995. He served TSPC and Stone Energy from October 1992
to December 1995 as Acquisitions Manager. Prior to joining TSPC, he was a
division geologist for Forest Oil Corporation for approximately ten years.
David R. Voelker has served as a Director of the Company since March 1993
and as a Director of TSPC since 1991. He is currently engaged in private
investments. He was a partner of Johnson Rice & Company from 1989 to February
1994.
John P. Laborde has served as a Director of the Company since May 1993. He
is currently a consultant to Tidewater Inc. He served as Chief Executive Officer
and Chairman of the Board of Tidewater Inc. from 1956 and 1968, respectively, to
his retirement in October 1994. Mr. Laborde also served as President of
Tidewater Inc. from 1958 to 1981 and from 1988 to his retirement. Mr. Laborde is
currently a director of Tidewater Inc., American Bureau of Shipping and Stolt
Comex Seaway, S.A.
Robert A. Bernhard has served as a Director of the Company since May 1993.
He has also served as Co-Chairman of Munn, Bernhard & Associates, Inc., an
investment advisory firm, since 1990. Mr. Bernhard was formerly Chairman of
Ichor Technology, Inc., a privately-held company that filed for bankruptcy under
Chapter 7 of the U.S. Bankruptcy Code in February 1993.
Raymond B. Gary has served as a Director of the Company since May 1993. He
has also served as an advisory director of Morgan Stanley & Co. Incorporated
since his retirement as a managing director and partner of Morgan Stanley & Co.
Incorporated in 1983.
B. J. Duplantis has served as a Director of the Company since May 1993. He
is a senior partner of the law firm Gordon, Arata, McCollam & Duplantis.
45
<PAGE> 47
CERTAIN STOCKHOLDERS
The following table sets forth as of August 11, 1997 certain information
regarding the number of shares of Common Stock beneficially owned by (i) each
director and executive officer of the Company and (ii) all directors and
executive officers of the Company as a group, and the percentage of the
outstanding shares of Common Stock that such shares represent.
<TABLE>
<CAPTION>
NAME SHARES HELD PERCENTAGE
---- ----------- ----------
<S> <C> <C>
James H. Stone(1)......................................... 1,617,815 10.8%
David R. Voelker(2)....................................... 721,153 4.8
Joe R. Klutts............................................. 483,270 3.2
Michael L. Finch.......................................... 380,671 2.5
D. Peter Canty(3)......................................... 379,970 2.5
James H. Prince........................................... 277,522 1.9
Robert A. Bernhard(4)..................................... 158,000 1.1
Raymond B. Gary(5)........................................ 54,259 *
Phillip T. Lalande........................................ 28,100 *
John P. Laborde........................................... 17,000 *
B. J. Duplantis........................................... 16,000 *
E. J. Louviere............................................ 15,300 *
Andrew L. Gates, III...................................... 10,100 *
Craig L. Glassinger....................................... 9,100 *
All directors and executive officers as a group........... 4,168,260 27.3%
</TABLE>
- ---------------
* less than one percent
(1) Includes shares owned by two partnerships known as James H. Stone Interests
and James H. Stone Interests II to which Mr. Stone disclaims any pecuniary
interest with respect to 47,017 and 16,234 shares, respectively. Also
includes 6,080 shares held by Mr. Stone as trustee for the benefit of his
two minor children to which Mr. Stone disclaims any pecuniary interest.
(2) Includes 104,347 shares owned by the KGB Trust, of which Mr. Voelker is the
sole trustee, 72,440 shares owned by two trusts for the benefit of Mr.
Stone's minor children, of which Mr. Voelker is a trustee, and 479,570
shares owned by Frantzen/Investments, L.L.C. Mr. Voelker disclaims any
pecuniary interest with respect to the shares owned by the trusts for the
benefit of Mr. Stone's children.
(3) Includes 200 shares owned by Mr. Canty's wife.
(4) Includes 30,000 shares held by the Bernhard Trust "B" of which Mr. Bernhard
is the trustee and a potential beneficiary, and 12,000 shares held by Mr.
Bernhard's wife.
(5) Includes 20,000 shares owned by Mr. Gary's wife.
DESCRIPTION OF BANK CREDIT FACILITY
On July 30, 1997, the Company executed its Third Amended and Restated
Credit Agreement (the "Bank Credit Facility") with NationsBank as agent for a
group of banks which includes NationsBank, First National Bank of Commerce,
Hibernia National Bank and BankBoston, N.A. The total Bank Credit Facility
amount is $150 million and is comprised of a three-year revolving credit loan
and a term loan due on January 1, 1999. The current weighted average interest
rate of the facility is 7.3% per annum. As of August 1, 1997, the total
outstanding principal balance was $79.1 million and letters of credit totaling
$6.5 million have been issued pursuant to the facility.
The revolver provided for total availability of $100 million with a
limitation on total outstanding borrowings based on a borrowing base amount
established by the banks for the Company's oil and gas properties, which, at the
time of the Offering, was $80 million. In connection with the Offering, the
Company repaid all except $10 million of the revolving credit loan outstanding
under the Bank Credit
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<PAGE> 48
Facility. The borrowing base was reduced to $55 million after the Offering and
will be redetermined at year-end based on a revaluation of the Company's oil and
gas properties. The Company may reborrow amounts available under the revolving
credit portion of the Bank Credit Facility to fund the Company's ongoing capital
expenditure program and for general working capital purposes. A commitment fee
of 0.375% per annum is payable quarterly on the unused portion of the revolving
commitment. The term loan of $50 million was established to finance the
acquisition of the Vermilion Block 255 Field and certain development costs. All
of the amounts outstanding under the term loan were paid in full with proceeds
of the Offering, and the term loan is no longer available to the Company. See
"Use of Proceeds."
Under certain circumstances, the lenders under the Bank Credit Facility may
require the facility to be secured by the oil and gas properties of the Company.
The Bank Credit Facility requires the Company to comply with various customary
covenants including, but not limited to, negative covenants regarding (i) liens,
(ii) debt, guaranties and other obligations, (iii) mergers and consolidations,
(iv) asset sales and (v) speculative hedging. Events of default under the Bank
Credit Facility include (i) failure to make payments under the Bank Credit
Facility, (ii) false representations and warranties, (iii) breach of certain
covenants, (iv) failure to make payments on other debt of the Company in the
amount of $500,000 or more and (vi) a change of control of the Company. Upon the
occurrence of such a default, the obligations of the Company may be accelerated
by the lenders under the Bank Credit Facility. The Bank Credit Facility includes
provisions for optional repayment, and for mandatory repayment of term advances
with the proceeds of any debt issuance by the Company.
THE EXCHANGE OFFER
GENERAL
In connection with the sale of the Old Notes, the purchasers thereof became
entitled to the benefits of certain registration rights under the Registration
Agreement. The Exchange Notes are being offered hereunder in order to satisfy
the obligations of the Company under the Registration Agreement. See "Exchange
Offer; Registration Rights."
For each $1,000 principal amount of Old Notes surrendered to the Company
pursuant to the Exchange Offer, the holder of such Old Notes will receive $1,000
principal amount of Exchange Notes. Upon the terms and subject to the conditions
set forth in this Prospectus and in the accompanying Letter of Transmittal, the
Company will accept all Old Notes properly tendered prior to 5:00 p.m., New York
City time, on the Expiration Date. Holders may tender some or all of their Old
Notes pursuant to the Exchange Offer in integral multiples of $1,000 principal
amount.
Under existing interpretations of the staff of the SEC, including Exxon
Capital Holdings Corporation, SEC No-Action Letter (available April 13, 1989),
the Morgan Stanley Letter and Mary Kay Cosmetics, Inc., SEC No-Action Letter
(available June 5, 1991), the Company believes that the Exchange Notes would in
general be freely transferable after the Exchange Offer without further
registration under the Securities Act by the respective holders thereof (other
than a "Restricted Holder," being (i) a broker-dealer who purchased Old Notes
exchanged for such Exchange Notes directly from the Company to resell pursuant
to Rule 144A or any other available exemption under the Securities Act or (ii) a
person that is an affiliate of the Company within the meaning of Rule 405 under
the Securities Act), without compliance with the registration and prospectus
delivery provisions of the Securities Act, provided that such Exchange Notes are
acquired in the ordinary course of such holder's business and such holder is not
participating in, and has no arrangement with any person to participate in, the
distribution (within the meaning of the Securities Act) of such Exchange Notes.
Eligible holders wishing to accept the Exchange Offer must represent to the
Company that such conditions have been met. Any holder of Old Notes who tenders
in the Exchange Offer for the purpose of participating in a distribution of the
Exchange Notes could not rely on the interpretation by the staff of the SEC
enunciated in the Morgan Stanley Letter and similar no-action letters, and must
comply with the registration and prospectus delivery requirements of the
Securities Act in connection with any resale transaction.
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<PAGE> 49
Each holder of Old Notes who wishes to exchange Old Notes for Exchange
Notes in the Exchange Offer will be required to make certain representations,
including that (i) it is neither an affiliate of the Company nor a broker-dealer
tendering Old Notes acquired directly from the Company for its own account, (ii)
any Exchange Notes to be received by it are being acquired in the ordinary
course of its business and (iii) it is not participating in, and it has no
arrangement with any person to participate in, the distribution (within the
meaning of the Securities Act) of the Exchange Notes. Each broker-dealer (a
"Participating Broker-Dealer") that receives Exchange Notes for its own account
in exchange for Old Notes, where such Old Notes were acquired by such
broker-dealer as a result of market-making activities or other trading
activities, must acknowledge that it will deliver a prospectus in connection
with any resale of such Exchange Notes. See "Plan of Distribution." The staff of
the SEC has taken the position in no-action letters issued to third parties
including Shearman & Sterling, SEC No-Action Letter (available July 2, 1993),
that Participating Broker-Dealers may fulfill their prospectus delivery
requirements with respect to the Exchange Notes (other than a resale of an
unsold allotment from the original sale of Old Notes) with this Prospectus, as
it may be amended or supplemented from time to time. Under the Registration
Agreement, the Company is required to allow Participating Broker-Dealers to use
this Prospectus, as it may be amended or supplemented from time to time, in
connection with the resale of such Exchange Notes. See "Plan of Distribution."
The Exchange Offer shall be deemed to have been consummated upon the
earlier to occur of (i) the Company having exchanged Exchange Notes for all
outstanding Old Notes (other than Old Notes held by a Restricted Holder)
pursuant to the Exchange Offer and (ii) the Company having exchanged, pursuant
to the Exchange Offer, Exchange Notes for all Old Notes that have been tendered
and not withdrawn on the date that is 30 days following the commencement of the
Exchange Offer. In such event, holders of Old Notes seeking liquidity in their
investment would have to rely on exemptions to registration requirements under
the securities laws, including the Securities Act.
As of the date of this Prospectus, $100,000,000 aggregate principal amount
of Old Notes are issued and outstanding. In connection with the issuance of the
Old Notes, the Company arranged for the Old Notes to be eligible for trading in
The Portal Market, the National Association of Securities Dealers' screen based,
automated market trading of securities eligible for resale under Rule 144A.
The Company shall be deemed to have accepted for exchange validly tendered
Old Notes when, as and if the Company has given oral or written notice thereof
to the Exchange Agent. See "-- Exchange Agent." The Exchange Agent will act as
agent for the tendering holders of Old Notes for the purpose of receiving
Exchange Notes from the Company and delivering Exchange Notes to such holders.
If any tendered Old Notes are not accepted for exchange because of an invalid
tender or the occurrence of certain other events set forth herein, certificates
for any such unaccepted Old Notes will be returned, without expense, to the
tendering holder thereof as promptly as practicable after the Expiration Date.
Holders of Old Notes who tender in the Exchange Offer will not be required to
pay brokerage commissions or fees or, subject to the instructions in the Letter
of Transmittal, transfer taxes with respect to the exchange of Old Notes
pursuant to the Exchange Offer. The Company will pay all charges and expenses,
other than certain applicable taxes, in connection with the Exchange Offer. See
"-- Fees and Expenses."
This Prospectus, together with the accompanying Letter of Transmittal, is
being sent to all registered holders as of the date of this Prospectus.
EXPIRATION DATE; EXTENSIONS; AMENDMENTS
The term "Expiration Date" shall mean December 3, 1997 unless the Company,
in its sole discretion, extends the Exchange Offer, in which case the term
"Expiration Date" shall mean the latest date to which the Exchange Offer is
extended. In order to extend the Expiration Date, the Company will notify the
Exchange Agent of any extension by oral or written notice and will mail to the
record holders of Old Notes an announcement thereof, each prior to 9:00 a.m.,
New York City time, on the next business day after the previously scheduled
Expiration Date. Such announcement may state that the Company is extending the
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<PAGE> 50
Exchange Offer for a specified period of time. The Company reserves the right
(i) to delay acceptance of any Old Notes, to extend the Exchange Offer or to
terminate the Exchange Offer and to refuse to accept Old Notes not previously
accepted, if any of the conditions set forth herein under "-- Termination" shall
have occurred and shall not have been waived by the Company (if permitted to be
waived by the Company), by giving oral or written notice of such delay,
extension or termination to the Exchange Agent, and (ii) to amend the terms of
the Exchange Offer in any manner deemed by it to be advantageous to the holders
of the Old Notes. Any such delay in acceptance, extension, termination or
amendment will be followed as promptly as practicable by oral or written notice
thereof. If the Exchange Offer is amended in a manner determined by the Company
to constitute a material change, the Company will promptly disclose such
amendment in a manner reasonably calculated to inform the holders of the Old
Notes of such amendment. Without limiting the manner in which the Company may
choose to make public announcements of any delay in acceptance, extension,
termination or amendment of the Exchange Offer, the Company shall have no
obligation to publish, advertise, or otherwise communicate any such public
announcement, other than by making a timely release to the Dow Jones News
Service.
INTEREST ON THE EXCHANGE NOTES
The Exchange Notes will bear interest payable semi-annually on March 15 and
September 15 of each year, commencing March 15, 1998. Holders of Exchange Notes
of record on March 1, 1998 will receive interest on March 15, 1998 from the date
of issuance of the Exchange Notes, plus an amount equal to the accrued interest
on the Old Notes from the date of issuance of the Old Notes, September 19, 1997,
to the date of exchange thereof. Consequently, assuming the Exchange Offer is
consummated prior to the record date in respect of the March 15, 1998 interest
payment for the Old Notes, holders who exchange their Old Notes for Exchange
Notes will receive the same interest payment on March 15, 1998 that they would
have received had they not accepted the Exchange Offer. Interest on the Old
Notes accepted for exchange will cease to accrue upon issuance of the Exchange
Notes.
PROCEDURES FOR TENDERING
To tender in the Exchange Offer, a holder must complete, sign and date the
Letter of Transmittal, or a facsimile thereof, have the signatures thereon
guaranteed if required by the Letter of Transmittal, and mail or otherwise
deliver such Letter of Transmittal or such facsimile, or an Agent's Message,
together with the Old Notes and any other required documents, to the Exchange
Agent prior to 5:00 p.m., New York City time, on the Expiration Date. In
addition, either (i) the certificates for such Old Notes must be received by the
Exchange Agent along with the Letter of Transmittal or (ii) a timely
confirmation of a book-entry transfer (a "Book-Entry Confirmation") of such Old
Notes, if such procedure is available, into the Exchange Agent's account at The
Depository Trust Company (the "Book-Entry Transfer Facility") pursuant to the
procedure for book-entry transfer described below, must be received by the
Exchange Agent along with an Agent's Message prior to the Expiration Date or
(iii) the Holder must comply with the guaranteed delivery procedures described
below. The tender by a holder of Old Notes will constitute an agreement between
such holder and the Company in accordance with the terms and subject to the
conditions set forth herein and in the Letter of Transmittal. Delivery of all
documents must be made to the Exchange Agent at its address set forth herein.
Holders may also request that their respective brokers, dealers, commercial
banks, trust companies or nominees effect such tender for such holders.
The term "Agent's Message" means a message, transmitted by the Book-Entry
Transfer Facility to, and received by, the Exchange Agent and forming a part of
a Book-Entry Confirmation, which states that such Book-Entry Transfer Facility
has received an express acknowledgment from the participant in such Book-Entry
Transfer Facility tendering Old Notes which are the subject of such Book-Entry
Confirmation that such participant has received and agrees to be bound by the
terms of the Letter of Transmittal, and that the Company may enforce such
agreement against such participant.
The method of delivery of Old Notes and the Letter of Transmittal and all
other required documents to the Exchange Agent is at the election and risk of
the holders. Instead of delivery by mail, it is recommended that holders use an
overnight or hand delivery service. In all cases, sufficient time should
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<PAGE> 51
be allowed to assure timely delivery. No Letter of Transmittal or Old Notes
should be sent to the Company. Only a holder of Old Notes may tender such Old
Notes in the Exchange Offer. The term "holder" with respect to the Exchange
Offer means any person in whose name Old Notes are registered on the books of
the Company or any other person who has obtained a properly completed stock
power from the registered holder.
Any beneficial holder whose Old Notes are registered in the name of such
holder's broker, dealer, commercial bank, trust company or other nominee and who
wishes to tender should contact such registered holder promptly and instruct
such registered holder to tender on behalf of the registered holder. If such
beneficial holder wishes to tender directly, such beneficial holder must, prior
to completing and executing the Letter of Transmittal and delivering his Old
Notes, either make appropriate arrangements to register ownership of the Old
Notes in such holder's name or obtain a properly completed bond power from the
registered holder. The transfer of record ownership may take considerable time.
If the Letter of Transmittal is signed by the record holder(s) of the Old Notes
tendered thereby, the signature must correspond with the name(s) written on the
face of the Old Notes without alteration, enlargement or any change whatsoever.
If the Letter of Transmittal is signed by a participant in Depositary Trust
Company ("DTC"), the signature must correspond with the name as it appears on
the security position listing as the holder of the Old Notes. Signatures on a
Letter of Transmittal or a notice of withdrawal, as the case may be, must be
guaranteed by a member firm of a registered national securities exchange or of
the National Association of Securities Dealers, Inc., a commercial bank or trust
company having an office or correspondent in the United States or an "eligible
guarantor institution" within the meaning of Rule 17Ad-15 under the Exchange Act
(an "Eligible Institution") unless the Old Notes tendered pursuant thereto are
tendered (i) by a registered holder (or by a participant in DTC whose name
appears on a security position listing as the owner) who has not completed the
box entitled "Special Issuance Instructions" or "Special Delivery Instructions"
on the Letter of Transmittal and the Exchange Notes are being issued directly to
such registered holder (or deposited into the participant's account at DTC) or
(ii) for the account of an Eligible Institution. If the Letter of Transmittal is
signed by a person other than the registered holder of any Old Notes listed
therein, such Old Notes must be endorsed or accompanied by appropriate bond
powers which authorize such person to tender the Old Notes on behalf of the
registered holder, in either case signed as the name of the registered holder or
holders appears on the Old Notes. If the Letter of Transmittal or any Old Notes
or bond powers are signed by trustees, executors, administrators, guardians,
attorneys-in-fact, officers of corporations or others acting in a fiduciary or
representative capacity, such persons should so indicate when signing, and
unless waived by the Company, evidence satisfactory to the Company of their
authority to so act must be submitted with the Letter of Transmittal.
A tender will be deemed to have been received as of the date when the
tendering holder's duly signed Letter of Transmittal accompanied by Old Notes
(or a timely confirmation received of a book-entry transfer of Old Notes into
the Exchange Agent's account at DTC with an Agent's Message) or a Notice of
Guaranteed Delivery from an Eligible Institution is received by the Exchange
Agent. Issuances of Exchange Notes in exchange for Old Notes tendered pursuant
to a Notice of Guaranteed Delivery by an Eligible Institution will be made only
against delivery of the Letter of Transmittal (and any other required documents)
and the tendered Old Notes (or a timely confirmation received of a book-entry
transfer of Old Notes into the Exchange Agent's account at DTC with an Agent's
Message) with the Exchange Agent.
All questions as to the validity, form, eligibility (including time of
receipt), acceptance and withdrawal of the tendered Old Notes will be determined
by the Company in its sole discretion, which determination will be final and
binding. The Company reserves the absolute right to reject any and all Old Notes
not properly tendered or any Old Notes the Company's acceptance of which would,
in the opinion of the Company or its counsel, be unlawful. The Company also
reserves the absolute right to waive any conditions of the Exchange Offer or
defects or irregularities in tender as to particular Old Notes. The Company's
interpretation of the terms and conditions of the Exchange Offer (including the
instructions in the Letter of Transmittal) shall be final and binding on all
parties. Unless waived, any defects or
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<PAGE> 52
irregularities in connection with tenders of Old Notes must be cured within such
time as the Company shall determine. Neither the Company, the Exchange Agent nor
any other person shall be under any duty to give notification of defects or
irregularities with respect to tenders of Old Notes nor shall any of them incur
any liability for failure to give such notification. Tenders of Old Notes will
not be deemed to have been made until such irregularities have been cured or
waived. Any Old Notes received by the Exchange Agent that are not properly
tendered and as to which the defects or irregularities have not been cured or
waived will be returned without cost by the Exchange Agent to the tendering
holder of such Old Notes unless otherwise provided in the Letter of Transmittal,
as soon as practicable following the Expiration Date. In addition, the Company
reserves the right in its sole discretion to (i) purchase or make offers for any
Old Notes that remain outstanding subsequent to the Expiration Date, or, as set
forth under "-- Termination," to terminate the Exchange Offer and (ii) to the
extent permitted by applicable law, purchase Old Notes in the open market, in
privately negotiated transactions or otherwise. The terms of any such purchases
or offers may differ from the terms of the Exchange Offer.
BOOK-ENTRY TRANSFER
The Exchange Agent will establish an account with respect to the Old Notes
at DTC within two business days after the date of this Prospectus, and any
financial institution which is a participant in DTC may make book-entry delivery
of the Old Notes by causing DTC to transfer such Old Notes into the Exchange
Agent's account in accordance with DTC's procedure for such transfer. Although
delivery of Old Notes may be effected through book-entry transfer into the
Exchange Agent's account at DTC, an Agent's Message must be transmitted to and
received by the Exchange Agent on or prior to the Expiration Date at one of its
addresses set forth below under "-- Exchange Agent", or the guaranteed delivery
procedure described below must be complied with. DELIVERY OF DOCUMENTS TO DTC
DOES NOT CONSTITUTE DELIVERY TO THE EXCHANGE AGENT. All references in this
Prospectus to deposit or delivery of Old Notes shall be deemed to include DTC's
book-entry delivery method.
GUARANTEED DELIVERY PROCEDURES
Holders who wish to tender their Old Notes and whose Old Notes are not
immediately available or who cannot deliver their Old Notes, the Letter of
Transmittal or any other required documents to the Exchange Agent prior to the
Expiration Date, or who cannot complete the procedure for book-entry transfer on
a timely basis and deliver an Agent's Message, may effect a tender if: (i) the
tender is made by or through an Eligible Institution; (ii) prior to the
Expiration Date, the Exchange Agent receives from such Eligible Institution a
properly completed and duly executed Notice of Guaranteed Delivery (by facsimile
transmission, mail or hand delivery) setting forth the name and address of the
holder of the Old Notes, the registration number or numbers of such Old Notes
(if applicable), and the total principal amount of Old Notes tendered, stating
that the tender is being made thereby and guaranteeing that, within five
business days after the Expiration Date, the Letter of Transmittal, together
with the Old Notes in proper form for transfer (or a confirmation of a
book-entry transfer into the Exchange Agent's account at DTC with an Agent's
Message) and any other documents required by the Letter of Transmittal, will be
deposited by the Eligible Institution with the Exchange Agent; and (iii) such
properly completed and executed Letter of Transmittal, together with the
certificate(s) representing all tendered Old Notes in proper form for transfer
(or a confirmation of such a book-entry transfer) and all other documents
required by the Letter of Transmittal are received by the Exchange Agent within
five business days after the Expiration Date.
TERMS AND CONDITIONS OF THE LETTER OF TRANSMITTAL
The Letter of Transmittal contains, among other things, certain terms and
conditions which are summarized below and are part of the Exchange Offer.
Each holder who participates in the Exchange Offer will be required to
represent that any Exchange Notes received by it will be acquired in the
ordinary course of its business, that such holder is not
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<PAGE> 53
participating in, and has no arrangement with any person to participate in, the
distribution (within the meaning of the Securities Act) of the Exchange Notes,
and that such holder is not a Restricted Holder.
Old Notes tendered in exchange for Exchange Notes (or a timely confirmation
of a book-entry transfer of such Old Notes into the Exchange Agent's account at
DTC) must be received by the Exchange Agent, with the Letter of Transmittal or
an Agent's Message and any other required documents, by the Expiration Date or
within the time periods set forth above pursuant to a Notice of Guaranteed
Delivery from an Eligible Institution. Each holder tendering the Old Notes for
exchange sells, assigns and transfers the Old Notes to the Exchange Agent, as
agent of the Company, and irrevocably constitutes and appoints the Exchange
Agent as the holder's agent and attorney-in-fact to cause the Old Notes to be
transferred and exchanged. The holder warrants that it has full power and
authority to tender, exchange, sell, assign and transfer the Old Notes and to
acquire the Exchange Notes issuable upon the exchange of such tendered Old
Notes, that the Exchange Agent, as agent of the Company, will acquire good and
unencumbered title to the tendered Old Notes, free and clear of all liens,
restrictions, charges and encumbrances, and that the Old Notes tendered for
exchange are not subject to any adverse claims when accepted by the Exchange
Agent, as agent of the Company. The holder also warrants and agrees that it
will, upon request, execute and deliver any additional documents deemed by the
Company or the Exchange Agent to be necessary or desirable to complete the
exchange, sale, assignment and transfer of the Old Notes. All authority
conferred or agreed to be conferred in the Letter of Transmittal by the holder
will survive the death, incapacity or dissolution of the holder and any
obligation of the holder shall be binding upon the heirs, personal
representatives, successors and assigns of such holder.
WITHDRAWAL OF TENDERS
Except as otherwise provided herein, tenders of Old Notes may be withdrawn
at any time prior to 5:00 p.m., New York City time, on the business day prior to
the Expiration Date, unless previously accepted for exchange. To withdraw a
tender of Old Notes in the Exchange Offer, a written or facsimile transmission
notice of withdrawal must be received by the Exchange Agent at its address set
forth herein prior to 5:00 p.m., New York City time, on the business day prior
to the Expiration Date and prior to acceptance for exchange thereof by the
Company. Any such notice of withdrawal must (i) specify the name of the person
having deposited the Old Notes to be withdrawn (the "Depositor"), (ii) identify
the Old Notes to be withdrawn (including, if applicable, the registration number
or numbers and total principal amount of such Old Notes), (iii) be signed by the
Depositor in the same manner as the original signature on the Letter of
Transmittal by which such Old Notes were tendered (including any required
signature guarantees) or be accompanied by documents of transfer sufficient to
permit the Trustee with respect to the Old Notes to register the transfer of
such Old Notes into the name of the Depositor withdrawing the tender, (iv)
specify the name in which any such Old Notes are to be registered, if different
from that of the Depositor and (v) if applicable because the Old Notes have been
tendered pursuant to the book-entry procedures, specify the name and number of
the participant's account at DTC to be credited, if different than that of the
Depositor. All questions as to the validity, form and eligibility (including
time of receipt) of such withdrawal notices will be determined by the Company,
whose determination shall be final and binding on all parties. Any Old Notes so
withdrawn will be deemed not to have been validly tendered for purposes of the
Exchange Offer and no Exchange Notes will be issued with respect thereto unless
the Old Notes so withdrawn are validly retendered. Any Old Notes which have been
tendered but which are not accepted for exchange will be returned to the holder
thereof without cost to such holder as soon as practicable after withdrawal,
rejection of tender or termination of the Exchange Offer. Properly withdrawn Old
Notes may be retendered by following one of the procedures described above under
"-- Procedures for Tendering" at any time prior to the Expiration Date.
TERMINATION
Notwithstanding any other term of the Exchange Offer, the Company will not
be required to accept for exchange any Old Notes not theretofore accepted for
exchange, and may terminate the Exchange
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<PAGE> 54
Offer if it determines that the Exchange Offer violates any applicable law or
interpretation of the staff of the SEC.
If the Company determines that it may terminate the Exchange Offer, as set
forth above, the Company may (i) refuse to accept any Old Notes and return any
Old Notes that have been tendered to the holders thereof, (ii) extend the
Exchange Offer and retain all Old Notes tendered prior to the Expiration of the
Exchange Offer, subject to the rights of such holders of tendered Old Notes to
withdraw their tendered Old Notes or (iii) waive such termination event with
respect to the Exchange Offer and accept all properly tendered Old Notes that
have not been withdrawn. If such waiver constitutes a material change in the
Exchange Offer, the Company will disclose such change by means of a supplement
to this Prospectus that will be distributed to each registered holder of Old
Notes, and the Company will extend the Exchange Offer for a period of five to
ten business days, depending upon the significance of the waiver and the manner
of disclosure to the registered holders of the Old Notes, if the Exchange Offer
would otherwise expire during such period. Holders of Old Notes will have
certain rights against the Company under the Registration Rights Agreement
should the Company fail to consummate the Exchange Offer.
EXCHANGE AGENT
Texas Commerce Bank National Association, the trustee under the Indenture,
has been appointed as Exchange Agent for the Exchange Offer. Questions and
requests for assistance and requests for additional copies of this Prospectus or
of the Letter of Transmittal should be directed to the Exchange Agent addressed
as follows:
<TABLE>
<S> <C>
By Mail: By Hand or Overnight Courier:
Texas Commerce Bank National Association Texas Commerce Bank National Association
Corporate Trust Services Corporate Trust Services
P.O. Box 2320 1201 Main Street, 18th Floor
Dallas, Texas 75221-2320 Dallas, Texas 75202
Attention: Mr. Frank Ivins Attention: Mr. Frank Ivins
Facsimile Transmission: (214) 672-5746
Confirm by Telephone: (214) 672-5125
(800) 275-2048
</TABLE>
FEES AND EXPENSES
The expenses of soliciting tenders pursuant to the Exchange Offer will be
borne by the Company. The principal solicitation for tenders pursuant to the
Exchange Offer is being made by mail. Additional solicitations may be made by
officers and regular employees of the Company and its affiliates in person, by
telegraph or telephone. The Company will not make any payments to brokers,
dealers or other persons soliciting acceptances of the Exchange Offer. The
Company, however, will pay the Exchange Agent reasonable and customary fees for
its services and will reimburse the Exchange Agent for its reasonable
out-of-pocket expenses in connection therewith. The Company may also pay
brokerage houses and other custodians, nominees and fiduciaries the reasonable
out-of-pocket expenses incurred by them in forwarding copies of this Prospectus,
Letters of Transmittal and related documents to the beneficial owners of the Old
Notes and in handling or forwarding tenders for exchange.
The other expenses incurred in connection with the Exchange Offer,
including fees and expenses of the Exchange Agent and Trustee and accounting and
legal fees, will be paid by the Company. The Company will pay all transfer
taxes, if any, applicable to the exchange of Old Notes pursuant to the Exchange
Offer. If, however, Exchange Notes or Old Notes not tendered or accepted for
exchange are to be delivered to, or are to be registered or issued in the name
of, any person other than the registered holder of the Old Notes tendered, or if
tendered Old Notes are registered in the name of any person other than the
person signing the Letter of Transmittal, or if a transfer tax is imposed for
any reason other than the exchange of Old Notes pursuant to the Exchange Offer,
then the amount of any such transfer taxes (whether imposed on the registered
holder or any other persons) will be payable by the tendering holder.
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<PAGE> 55
If satisfactory evidence of payment of such taxes or exemption therefrom is not
submitted with the Letter of Transmittal, the amount of such transfer taxes will
be billed directly to such tendering holder.
ACCOUNTING TREATMENT
No gain or loss for accounting purposes will be recognized by the Company
upon the consummation of the Exchange Offer. The expenses of the Exchange Offer
will be amortized by the Company over the term of the Exchange Notes under
generally accepted accounting principles.
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<PAGE> 56
DESCRIPTION OF THE NOTES
The Exchange Notes will be issued and the Old Notes were issued under an
indenture (the "Indenture") to be entered into among the Company and Texas
Commerce Bank National Association, as trustee (the "Trustee").
The terms of the Notes will include those stated in the Indenture and those
made part of the Indenture by reference to the Trust Indenture Act of 1939 (the
"1939 Act"). The following summary of certain terms and provisions of the Notes
and the Indenture does not purport to be complete and is qualified in its
entirety by reference to the 1939 Act, the Notes and the Indenture. A copy of
the Indenture and the form of Notes are available upon request to the Company at
the address set forth below under "Available Information."
The Indenture provides for the issuance of up to $100.0 million of Old
Notes and additional Notes (as part of the same or an additional series) in an
aggregate principal amount of not more than $50.0 million. All the Notes will be
identical in all respects other than issue price and issuance date.
The definitions of certain capitalized terms used in the following summary
are set forth below under "Certain Definitions." Capitalized terms used in this
summary and not otherwise defined below have the meanings assigned to them in
the Indenture. For purposes of this "Description of the Notes," references to
the "Company" shall mean Stone Energy Corporation, excluding its subsidiaries.
GENERAL
The Notes will mature on September 15, 2007, and will be limited to an
aggregate principal amount of $150.0 million. The Old Notes were issued in an
aggregate principal amount of $100.0 million. The Old Notes bear interest at
8 3/4% per annum from September 19, 1997, or from the most recent interest
payment date to which interest has been paid, payable semiannually on March 15
and September 15 of each year, beginning on March 15, 1998, to the Person in
whose name the Note (or any predecessor Note) is registered at the close of
business on the immediately preceding March 1 or September 1, as the case may
be. Interest will be computed on the basis of a 360-day year comprised of twelve
30-day months.
Principal of, premium, if any, on and interest on the Notes will be
payable, and the Notes will be exchangeable and transferable, at an office or
agency of the Company, one of which will be maintained for such purpose in The
City of New York (which initially will be an office of the Trustee) or such
other office or agency permitted under the Indenture. At the option of the
Company, payment of interest may be made by check mailed to the person entitled
thereto as shown on the Security Register. The Notes will be issued in
denominations of $1,000 and integral multiples thereof.
The interest rate on the Notes is subject to increase in certain
circumstances (such additional interest being referred to as "Special Interest")
if the Company does not file a registration statement relating to the Exchange
Offer on a timely basis, if such registration statement is not declared
effective on a timely basis or if certain other conditions are not satisfied,
all as further described under "Exchange Offer; Registration Rights." All
references herein to interest shall include such Special Interest, if
appropriate.
Under the circumstances described below, the obligations of the Company
under the Notes will in the future be unconditionally guaranteed on an unsecured
senior subordinated basis by Restricted Subsidiaries of the Company. See
"-- Subsidiary Guaranties."
SUBORDINATION
The Notes are unsecured senior subordinated obligations of the Company. The
payment of the principal of, premium, if any, on and interest on the Notes will
be subordinated in right of payment, as set forth in the Indenture, to the
payment when due of all Senior Indebtedness of the Company. The Notes rank
subordinate in right of payment to all existing and future Senior Indebtedness
of the Company, pari passu with any future Pari Passu Indebtedness of the
Company and senior to any future Subordinated
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<PAGE> 57
Indebtedness of the Company. The Subsidiary Guaranty of any Subsidiary Guarantor
will rank subordinate in right of payment to all existing and future Senior
Indebtedness of such Subsidiary Guarantor, pari passu with any future Pari Passu
Indebtedness of such Subsidiary Guarantor and senior to any future Subordinated
Indebtedness of such Subsidiary Guarantor.
In connection with the Offering, the Company repaid all except $10 million
of the revolving credit loan outstanding under the Bank Credit Facility. The
borrowing base was reduced to $55 million after the Offering and will be
redetermined at year-end based on a revaluation of the Company's oil and gas
properties. An additional $3.0 million of other Senior Indebtedness is
outstanding. Borrowings under the Bank Credit Facility constitute Senior
Indebtedness. As of such date, the Company would have had no outstanding Pari
Passu Indebtedness or Subordinated Indebtedness (other than the Old Notes).
Although the Indenture contains limitations on the amount of additional
Indebtedness that the Company and its Restricted Subsidiaries may incur, the
amounts of such Indebtedness could be substantial and such Indebtedness may be
Senior Indebtedness or Pari Passu Indebtedness. In addition, the Subsidiary
Guaranties could be effectively subordinated to all the obligations of any
Subsidiary Guarantors under certain circumstances. The Notes and any Subsidiary
Guaranties will also be effectively subordinated to any secured debt of the
Company and the Subsidiary Guarantors that is not otherwise Senior Indebtedness.
See "-- Certain Covenants -- Limitation on Indebtedness," "Risk
Factors -- Subordination of Notes" and "-- Fraudulent Conveyance Considerations
Relating to Future Subsidiary Guaranties" and "Description of Bank Credit
Facility."
The Company may not pay principal of, premium, if any, on or interest on,
the Notes or make any deposit pursuant to the provisions of the Indenture
described under "-- Defeasance and Covenant Defeasance" and may not repurchase,
redeem or otherwise retire any Notes (collectively, "pay the Notes") if (i) any
principal, premium, interest or other amounts due in respect of any Senior
Indebtedness of the Company is not paid within any applicable grace period
(including at maturity) or (ii) any other default on Senior Indebtedness of the
Company occurs and the maturity of such Senior Indebtedness is accelerated in
accordance with its terms unless, in either case, the default has been cured or
waived and any such acceleration has been rescinded or such Senior Indebtedness
has been paid in full; provided, however, that the Company may pay the Notes
without regard to the foregoing if the Company and the Trustee receive written
notice approving such payment from the Representative of each issue of
Designated Senior Indebtedness. During the continuance of any default (other
than a default described in clause (i) or clause (ii) of the preceding sentence)
with respect to any Designated Senior Indebtedness pursuant to which the
maturity thereof may be accelerated immediately without further notice (except
such notice as may be required to effect such acceleration), the Company may not
pay the Notes for a period (a "Payment Blockage Period") commencing upon the
receipt by the Company and the Trustee of written notice of such default from
the Representative of the holders of such Designated Senior Indebtedness
specifying an election to effect a Payment Blockage Period (a "Payment Blockage
Notice") and ending 179 days after receipt of such notice by the Company and the
Trustee unless earlier terminated (a) by written notice to the Company and the
Trustee from the Representative which gave such Payment Blockage Notice, (b)
because such default is no longer continuing or (c) because such Designated
Senior Indebtedness has been repaid in full. Notwithstanding the provisions
described in the immediately preceding sentence, unless the holders of such
Designated Senior Indebtedness or the Representative of such holders have
accelerated the maturity of such Designated Senior Indebtedness and not
rescinded such acceleration, the Company may (unless otherwise prohibited as
described in the first sentence of this paragraph) resume payments on the Notes
after the end of such Payment Blockage Period. No more than one Payment Blockage
Notice may be given in any consecutive 360-day period regardless of the number
of defaults with respect to one or more issues of Senior Indebtedness.
Upon any payment or distribution of the assets of the Company upon a total
or partial liquidation, dissolution or winding up of the Company or in a
bankruptcy, reorganization, insolvency, receivership, or similar proceeding
relating to the Company or its property, the holders of Senior Indebtedness of
the Company will be entitled to receive payment in full in cash before the
Holders of the Notes are entitled to receive any payment of principal of, or
premium, if any, or interest on, the Notes. In addition, until the
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<PAGE> 58
Senior Indebtedness of the Company is paid in full, any distribution made by or
on behalf of the Company to which Holders of Notes would be entitled but for the
subordination provisions of the Indenture will be made to holders of the Senior
Indebtedness of the Company, except that Holders of Notes may receive and retain
shares of stock and any debt securities that are subordinated to all Senior
Indebtedness of the Company to at least the same extent as the Notes.
The Subsidiary Guaranty of any Subsidiary Guarantor will be subordinated to
Senior Indebtedness of such Subsidiary Guarantor to the same extent and in the
same manner as the Notes are subordinated to Senior Indebtedness of the Company.
The Indenture provides that the subordination provisions of the Indenture
applicable to the Notes and any Subsidiary Guaranties may not be amended, waived
or modified in a manner that would adversely affect the rights of the holders of
any Designated Senior Indebtedness unless the holders of such Indebtedness
consent in writing (in accordance with the provisions of such Indebtedness) to
such amendment, waiver or modification.
SUBSIDIARY GUARANTIES
Under the circumstances described below under "-- Certain
Covenants -- Future Subsidiary Guarantors," the Company's payment obligations
under the Notes will in the future be jointly and severally guaranteed by one or
more Subsidiary Guarantors. The Subsidiary Guaranty of any Subsidiary Guarantor
will be an unsecured senior subordinated obligation of such Subsidiary
Guarantor. See "-- Subordination."
Certain mergers, consolidations and dispositions of Property may result in
the addition of additional Subsidiary Guarantors or the release of Subsidiary
Guarantors. See "-- Certain Covenants -- Limitation on Issuance and Sale of
Capital Stock of Restricted Subsidiaries" and "-- Merger, Consolidation and Sale
of Substantially All Assets." In addition, any Subsidiary Guarantor that is
designated an Unrestricted Subsidiary in accordance with the terms of the
Indenture shall be released from and relieved of its obligations under its
Subsidiary Guaranty upon execution and delivery of a supplemental indenture
satisfactory to the Trustee.
Each of the Company and any Subsidiary Guarantors will agree to contribute
to any other Subsidiary Guarantor which makes payments pursuant to its
Subsidiary Guaranty an amount equal to the Company's or such Subsidiary
Guarantor's proportionate share of such payment, based on the net worth of the
Company or such Subsidiary Guarantor relative to the aggregate net worth of the
Company and the Subsidiary Guarantors.
OPTIONAL REDEMPTION
Except as provided in the next succeeding paragraph, the Notes are not
redeemable prior to September 15, 2002. At any time on or after September 15,
2002, the Notes are redeemable at the option of the Company, in whole or in part
(equal to $1,000 in principal amount or an integral multiple thereof), on not
less than 30 nor more than 60 days' prior notice, at the following redemption
prices (expressed as percentages of principal amount), plus accrued and unpaid
interest, if any, to the date of redemption (subject to the right of Holders of
record on the relevant record date to receive interest due on the relevant
interest payment date), if redeemed during the 12-month period commencing on
September 15 of the years indicated below:
<TABLE>
<CAPTION>
REDEMPTION
YEAR PRICE
- ----------------------------------------------- ----------
<S> <C>
2002........................................... 104.375%
2003........................................... 102.917%
2004........................................... 101.458%
2005 and thereafter............................ 100.000%
</TABLE>
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<PAGE> 59
Notwithstanding the foregoing, prior to September 15, 2000 the Company may,
at any time or from time to time, redeem up to 33 1/3% of the aggregate
principal amount of the Notes originally issued at a redemption price of
108.750% of the principal amount thereof, plus accrued and unpaid interest, if
any, to the date of redemption (subject to the right of Holders of record on the
relevant record date to receive interest due on the relevant interest payment
date), with the net proceeds of one or more Equity Offerings of the Company,
provided that at least 66 2/3% of the aggregate principal amount of the Notes
originally issued remains outstanding after the occurrence of such redemption
and provided, further, that such redemption shall occur not later than 90 days
after the date of the closing of any such Equity Offering. The redemption shall
be made in accordance with procedures set forth in the Indenture.
If less than all the Notes are to be redeemed at any time, selection of
Notes for redemption will be made by the Trustee in compliance with the
requirements of the principal national securities exchange, if any, on which the
Notes are listed, or, if the Notes are not so listed, on a pro rata basis, by
lot or by such method as the Trustee shall deem fair and appropriate.
SINKING FUND
There will be no mandatory sinking fund payments for the Notes.
REPURCHASE AT THE OPTION OF HOLDERS UPON A CHANGE OF CONTROL
Upon the occurrence of a Change of Control, each Holder of Notes shall have
the right to require the Company to repurchase all or any part (equal to $1,000
in principal amount or an integral multiple thereof) of such Holder's Notes
pursuant to the offer described below (the "Change of Control Offer") at a
purchase price in cash equal to 101% of the principal amount thereof, plus
accrued and unpaid interest, if any, to the date of purchase, subject to the
right of Holders of record on the relevant record date to receive interest due
on the relevant interest payment date (the "Change of Control Payment").
Within 30 days following any Change of Control, the Company shall mail a
notice to each Holder stating, among other things: (i) that a Change of Control
has occurred and a Change of Control Offer is being made pursuant to the
Indenture and that all Notes (or portions thereof) properly tendered will be
accepted for payment; (ii) the purchase price and the purchase date, which shall
be, subject to any contrary requirements of applicable law, no fewer than 30
days nor more than 60 days from the date the Company mails such notice (the
"Change of Control Payment Date"); (iii) that any Note (or portion thereof)
accepted for payment (and duly paid on the Change of Control Payment Date)
pursuant to the Change of Control Offer shall cease to accrue interest on the
Change of Control Payment Date; (iv) that any Notes (or portions thereof) not
properly tendered will continue to accrue interest; (v) a description of the
transaction or transactions constituting the Change of Control; (vi) the
procedures that Holders of Notes must follow in order to tender their Notes (or
portions thereof) for payment and the procedures that Holders of Notes must
follow in order to withdraw an election to tender Notes (or portions thereof)
for payment; and (vii) all other instructions and materials necessary to enable
Holders to tender Notes pursuant to the Change of Control Offer.
The Company will comply, to the extent applicable, with the requirements of
Rule 14e-1 under the Exchange Act and any other securities laws and regulations
thereunder to the extent such laws and regulations are applicable in connection
with the purchase of Notes in connection with a Change of Control. To the extent
that the provisions of any securities laws or regulations conflict with the
provisions relating to the Change of Control Offer, the Company will comply with
the applicable securities laws and regulations and will not be deemed to have
breached its obligations described above by virtue thereof.
If a Change of Control were to occur, there can be no assurance that the
Company and any Subsidiary Guarantors would have sufficient financial resources,
or would be able to arrange financing, to pay the purchase price for all Notes
tendered by the Holders thereof. In addition, as of the Issue Date the existing
Bank Credit Facility will, and any future Bank Credit Facilities or other
agreements relating to indebtedness (including Senior Indebtedness or Pari Passu
Indebtedness) to which the Company or any Subsidiary Guarantor becomes a party
may, contain restrictions on the purchase of Notes. If a Change of
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<PAGE> 60
Control occurs at a time when the Company and any Subsidiary Guarantors are
unable to purchase the Notes (due to insufficient financial resources,
contractual prohibition or otherwise), such failure to purchase tendered Notes
would constitute an Event of Default under the Indenture, which would, in turn,
constitute a default under the existing Bank Credit Facility and may constitute
a default under the terms of any other Indebtedness of the Company or any
Subsidiary Guarantors then outstanding. In such circumstances, the subordination
provisions in the Indenture would likely prohibit payments to Holders of Notes.
The provisions under the Indenture related to the Company's obligation to make
an offer to repurchase the Notes as a result of a Change of Control may be
waived or modified (at any time prior to the occurrence of such Change of
Control) with the written consent of the Holders of a majority in principal
amount of the Notes. See "-- Subordination."
The Company will not be required to make a Change of Control Offer upon a
Change of Control if a third party makes the Change of Control Offer in the
manner, at the times and otherwise in compliance with the requirements set forth
in the Indenture applicable to a Change of Control Offer made by the Company and
purchases all Notes validly tendered and not withdrawn under such Change of
Control Offer.
A "Change of Control" shall be deemed to occur if (i) any "person" or
"group" (within the meaning of Sections 13(d)(3) and 14(d)(2) of the Exchange
Act or any successor provision to either of the foregoing, including any group
acting for the purpose of acquiring, holding or disposing of securities within
the meaning of Rule 13d-5(b)(1) under the Exchange Act), other than one or more
Permitted Holders, becomes the "beneficial owner" (as defined in Rules 13d-3 and
13d-5 under the Exchange Act, except that a Person will be deemed to have
"beneficial ownership" of all shares that any such Person has the right to
acquire, whether such right is exercisable immediately or only after the passage
of time) of 50 percent or more of the total voting power of all classes of the
Voting Stock of the Company or currently exercisable warrants or options to
acquire such Voting Stock, (ii) the sale, lease, conveyance or transfer of all
or substantially all the assets of the Company and the Restricted Subsidiaries
taken as a whole (other than to any Wholly Owned Subsidiary) shall have
occurred, (iii) the shareholders of the Company shall have approved any plan of
liquidation or dissolution of the Company, (iv) the Company consolidates with or
merges into another Person (other than one or more Permitted Holders) or any
Person (other than one or more Permitted Holders) consolidates with or merges
into the Company in any such event pursuant to a transaction in which the
outstanding Voting Stock of the Company is reclassified into or exchanged for
cash, securities or other property, other than any such transaction where (a)
the outstanding Voting Stock of the Company is reclassified into or exchanged
for Voting Stock of the surviving corporation that is Capital Stock and (b)
either (x) the holders of the Voting Stock of the Company immediately prior to
such transaction own, directly or indirectly, not less than a majority of the
Voting Stock of the surviving corporation immediately after such transaction in
substantially the same proportion as before the transaction or (y) within 25
days after the closing of any such transaction both Moody's and S&P shall have
expressly affirmed credit ratings for the Notes (after giving effect to such
transaction) that are as high or higher than the highest such ratings for the
Notes given by such services, respectively, at any time during the 90 days
immediately prior to the public announcement of such transaction and such
expressly affirmed ratings are at least "Ba3" from Moody's and "BB" from S&P or
(v) during any period of two consecutive years, individuals who at the beginning
of such period constituted the Company's Board of Directors (together with any
new directors whose election or appointment by such Board or whose nomination
for election by the shareholders of the Company was approved by a vote of a
majority of the directors then still in office who were either directors at the
beginning of such period or whose election or nomination for election was
previously so approved) cease for any reason to constitute a majority of the
Company's Board of Directors then in office. "Permitted Holders" means James H.
Stone, D. Peter Canty, Michael L. Finch and Joe R. Klutts and their respective
estates, spouses, ancestors, and lineal descendants, the legal representatives
of any of the foregoing and the trustees of any bona fide trusts of which the
foregoing are the sole beneficiaries or the grantors, or any Person of which the
foregoing "beneficially owns" (as defined in Rules 13d-3 and 13d-5 under the
Exchange Act) voting securities representing at least 66 2/3% of the total
voting power of all classes of Voting Stock of such Person (exclusive of any
matters as to which class voting rights exist).
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The definition of Change of Control includes a phrase relating to the sale,
lease, conveyance or transfer of "all or substantially all" the Company's
assets. The Indenture will be governed by New York law, and there is no
established quantitative definition under New York law of "substantially all"
the assets of a corporation. Accordingly, if the Company and any Subsidiary
Guarantors were to engage in a transaction in which they disposed of less than
all the assets of the Company and any Subsidiary Guarantors taken as a whole, a
question of interpretation could arise as to whether such disposition was of
"substantially all" their assets and whether the Company was required to make a
Change of Control Offer.
Except as described above with respect to a Change of Control, the
Indenture does not contain any other provisions that permit the Holders of the
Notes to require that the Company repurchase or redeem the Notes in the event of
a takeover, recapitalization or similar restructuring.
BOOK-ENTRY SYSTEM
The Notes will initially be issued in the form of one or more Global
Securities held in book-entry form. The Notes will be deposited with the Trustee
as custodian for The Depository Trust Company (the "Depository"), and the
Depository or its nominee will initially be the sole registered holder of the
Notes for all purposes under the Indenture. Except as set forth below, a Global
Security may not be transferred except as a whole by the Depository to a nominee
of the Depository or by a nominee of the Depository to the Depository.
Upon the issuance of a Global Security, the Depository or its nominee will
credit, on its internal system, the accounts of persons holding through it with
the respective principal amounts of the individual beneficial interests
represented by such Global Security purchased by such persons in the Offering.
Such accounts shall initially be designated by the Initial Purchasers with
respect to Notes placed by the Initial Purchasers for the Company. Ownership of
beneficial interests in a Global Security will be limited to persons that have
accounts with the Depository ("participants") or persons that may hold interests
through participants. Any Person acquiring an interest in a Global Security
through an offshore transaction in reliance on Regulation S of the Securities
Act may hold such interest through Cedel or Euroclear. Ownership of beneficial
interests by participants in a Global Security will be shown on, and the
transfer of that ownership interest will be effected only through, records
maintained by the Depository or its nominee for such Global Security. Ownership
of beneficial interests in such Global Security by persons that hold through
participants will be shown on, and the transfer of that ownership interest
within such participant will be effected only through, records maintained by
such participant. The laws of some jurisdictions require that certain purchasers
of securities take physical delivery of such securities in definitive form. Such
limits and such laws may impair the ability to transfer beneficial interests in
a Global Security.
Payment of principal of, premium, if any, on and interest on Notes
represented by any such Global Security will be made to the Depository or its
nominee, as the case may be, as the sole registered owner and the sole Holder of
the Notes represented thereby for all purposes under the Indenture. None of the
Company, the Trustee, any agent of the Company or the Initial Purchasers will
have any responsibility or liability for any aspect of the Depository's reports
relating to or payments made on account of beneficial ownership interests in a
Global Security representing any Notes or for maintaining, supervising or
reviewing any of the Depository's records relating to such beneficial ownership
interests.
The Company has been advised by the Depository that upon receipt of any
payment of principal of, premium, if any, on or interest on any Global Security,
the Depository will immediately credit, on its book-entry registration and
transfer system, the accounts of participants with payments in amounts
proportionate to their respective beneficial interests in the principal or face
amount of such Global Security, as shown on the records of the Depository. The
Company expects that payments by participants to owners of beneficial interests
in a Global Security held through such participants will be governed by standing
instructions and customary practices as is now the case with securities held for
customer accounts registered in "street name" and will be the sole
responsibility of such participants.
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So long as the Depository or its nominee is the registered owner or holder
of such Global Security, the Depository or such nominee, as the case may be,
will be considered the sole owner or holder of the Notes represented by such
Global Security for the purposes of receiving payment on the Notes, receiving
notices and for all other purposes under the Indenture and the Notes. Beneficial
interests in Notes will be evidenced only by, and transfers thereof will be
effected only through, records maintained by the Depository and its
participants. Except as provided above, owners of beneficial interests in a
Global Security will not be entitled to and will not be considered the holders
of such Global Security for any purposes under the Indenture. Accordingly, each
person owning a beneficial interest in a Global Security must rely on the
procedures of the Depository and, if such person is not a participant, on the
procedures of the participant through which such person owns its interest, to
exercise any rights of a holder under the Indenture. The Company understands
that under existing industry practices, if the Company requests any action of
holders or that an owner of a beneficial interest in a Global Security desires
to give or take any action that a Holder is entitled to give or take under the
Indenture, the Depository would authorize the participants holding the relevant
beneficial interest to give or take such action, and such participants would
authorize beneficial owners owning through such participants to give or take
such action or would otherwise act upon the instructions of beneficial owners
owning through them.
The Depository has advised the Company that it will take any action
permitted to be taken by a Holder of Notes (including the presentation of Notes
for exchange as described below) only at the direction of one or more
participants to whose account with the Depository interests in a Global Security
are credited and only in respect of such portion of the aggregate principal
amount of the Notes as to which such participant or participants has or have
given such direction.
The Depository has advised the Company that the Depository is a
limited-purpose trust company organized under the Banking Law of the State of
New York, a "banking organization" within the meaning of New York Banking Law, a
member of the Federal Reserve System, a "clearing corporation" within the
meaning of the New York Uniform Commercial Code and a "clearing agency"
registered under the Exchange Act. The Depository was created to hold the
securities of its participants and to facilitate the clearance and settlement of
securities transactions among its participants in such securities through
electronic book-entry changes in accounts of the participants, thereby
eliminating the need for physical movement of securities certificates. The
Depository's participants include securities brokers and dealers (including the
Initial Purchasers), banks, trust companies, clearing corporations and certain
other organizations some of whom (or their representatives) own the Depository.
Access to the Depository's book-entry system is also available to others, such
as banks, brokers, dealers and trust companies that clear through or maintain a
custodial relationship with a participant, either directly or indirectly.
CERTIFICATED NOTES
The Notes represented by a Global Security are exchangeable for
certificated Notes only if (i) the Depository notifies the Company that it is
unwilling or unable to continue as a depository for such Global Security or if
at any time the Depository ceases to be a clearing agency registered under the
Exchange Act, and a successor depository is not appointed by the Company within
90 days, (ii) the Company executes and delivers to the Trustee a notice that
such Global Security shall be so transferable, registrable and exchangeable, and
such transfer shall be registrable, or (iii) there shall have occurred and be
continuing a Default or Event of Default with respect to the Notes represented
by such Global Security. Any Global Security that is exchangeable for
certificated Notes pursuant to the preceding sentence will be transferred to,
and registered and exchanged for, certificated Notes in authorized denominations
and registered in such names as the Depository or its nominee holding such
Global Security may direct. Subject to the foregoing, a Global Security is not
exchangeable, except for a Global Security of like denomination to be registered
in the name of the Depository or its nominee. If a Global Security becomes
exchangeable for certificated Notes, (i) certificated Notes will be issued only
in fully registered form in denominations of $1,000 or an integral multiple
thereof, (ii) payment of principal of, and premium, any repurchase price and
interest on, the certificated Notes will be payable, and the transfer of the
certificated Notes will be registrable, at the office or agency of the Company
maintained for
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such purposes and (iii) no service charge will be made for any issuance of the
certificated Notes, although the Company may require payment of a sum sufficient
to cover any transfer tax, assessment or similar governmental charge imposed in
connection therewith. In addition, such certificates will bear the legend
referred to under "Notice to Investors" (unless the Company determines otherwise
in accordance with applicable law) subject, with respect to such Notes, to the
provisions of such legend.
CERTAIN COVENANTS
Limitation on Indebtedness. The Indenture provides that the Company will
not, and it will not permit any of its Restricted Subsidiaries to, directly or
indirectly, Incur any Indebtedness unless, after giving pro forma effect to the
Incurrence of such Indebtedness and the receipt and application of the proceeds
thereof, no Default or Event of Default would occur as a consequence of, or be
continuing following, such Incurrence and application and either (a) after
giving pro forma effect to such Incurrence and application, the Consolidated
Interest Coverage Ratio would exceed 2.5 to 1.0 or (b) such Indebtedness is
Permitted Indebtedness.
"Permitted Indebtedness" means any and all of the following: (i)
Indebtedness arising under the Indenture with respect to the Offered Notes and
any Subsidiary Guaranties relating thereto; (ii) Indebtedness under the Bank
Credit Facilities, provided that the aggregate principal amount of all
Indebtedness under the Bank Credit Facilities, together with all Indebtedness
Incurred pursuant to clause (x) of this paragraph in respect of Indebtedness
previously Incurred pursuant to this clause (ii), at any one time outstanding
does not exceed the greater of (a) $100.0 million, which amount shall be
permanently reduced by the amount of Net Available Cash from Asset Sales used to
permanently repay Indebtedness under the Bank Credit Facilities and not
subsequently reinvested in Additional Assets or used to permanently reduce other
Indebtedness to the extent permitted pursuant to the provisions of the Indenture
described under "-- Limitation on Asset Sales," and (b) an amount equal to the
sum of (1) $25.0 million and (2) 20.0% of Adjusted Consolidated Net Tangible
Assets determined as of the date of the Incurrence of such Indebtedness; (iii)
Indebtedness to the Company or any Wholly Owned Subsidiary by any of its
Restricted Subsidiaries or Indebtedness of the Company to any of its Wholly
Owned Subsidiaries (but only so long as such Indebtedness is held by the Company
or a Wholly Owned Subsidiary); (iv) Indebtedness in respect of bid, performance,
reimbursement or surety obligations issued by or for the account of the Company
or any Restricted Subsidiary in the ordinary course of business, including
guaranties and letters of credit functioning as or supporting such bid,
performance, reimbursement or surety obligations (in each case other than for an
obligation for money borrowed); (v) Indebtedness under Permitted Hedging
Agreements; (vi) in-kind obligations relating to oil or gas balancing positions
arising in the ordinary course of business; (vii) Indebtedness outstanding on
the Issue Date not otherwise permitted in clauses (i) through (vi) above; (viii)
Non-recourse Purchase Money Indebtedness; (ix) Indebtedness not otherwise
permitted to be Incurred pursuant to this paragraph (excluding any Indebtedness
Incurred pursuant to clause (a) of the immediately preceding paragraph),
provided that the aggregate principal amount of all Indebtedness Incurred
pursuant to this clause (ix), together with all Indebtedness Incurred pursuant
to clause (x) of this paragraph in respect of Indebtedness previously Incurred
pursuant to this clause (ix), at any one time outstanding does not exceed $30.0
million, (x) Indebtedness Incurred in exchange for, or the proceeds of which are
used to refinance, (a) Indebtedness referred to in clauses (i), (ii), (vii),
(viii) and (ix) of this paragraph (including Indebtedness previously Incurred
pursuant to this clause (x)) and (b) Indebtedness Incurred pursuant to clause
(a) of the immediately preceding paragraph, provided that, in the case of each
of the foregoing clauses (a) and (b), such Indebtedness is Permitted Refinancing
Indebtedness; and (xi) Indebtedness consisting of obligations in respect of
purchase price adjustments, indemnities or Guarantees of the same or similar
matters in connection with the acquisition or disposition of Property.
Limitation on Liens. The Indenture provides that the Company will not, and
will not permit any Restricted Subsidiary to, directly or indirectly, enter
into, create, Incur, assume or suffer to exist any Lien on or with respect to
any Property of the Company or such Restricted Subsidiary, whether owned on the
Issue Date or acquired after the Issue Date, or any interest therein or any
income or profits therefrom, unless the Notes or any Subsidiary Guaranty of such
Restricted Subsidiary are secured equally and
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ratably with (or prior to) any and all other obligations secured by such Lien,
except that the Company and its Restricted Subsidiaries may enter into, create,
Incur, assume or suffer to exist Liens securing Senior Indebtedness and
Permitted Liens.
Limitation on Restricted Payments.
(a) The Indenture provides that the Company will not, and will not permit
any of its Restricted Subsidiaries to, directly or indirectly, make any
Restricted Payment if, at the time of and after giving effect to the proposed
Restricted Payment, (i) any Default or Event of Default would have occurred and
be continuing, (ii) the Company could not Incur at least $1.00 of additional
Indebtedness pursuant to clause (a) of the first paragraph under "-- Limitation
on Indebtedness" or (iii) the aggregate amount expended or declared for all
Restricted Payments from the Issue Date would exceed the sum (without
duplication) of the following:
(A) 50% of the aggregate Consolidated Net Income of the Company
accrued on a cumulative basis commencing on the last day of the fiscal
quarter immediately preceding the Issue Date, and ending on the last day of
the fiscal quarter ending on or immediately preceding the date of such
proposed Restricted Payment (or, if such aggregate Consolidated Net Income
shall be a loss, minus 100% of such loss), plus
(B) the aggregate net cash proceeds, or the Fair Market Value of
Property other than cash, received by the Company on or after the Issue
Date from the issuance or sale (other than to a Subsidiary of the Company)
of Capital Stock of the Company or any options, warrants or rights to
purchase Capital Stock of the Company, plus
(C) the aggregate net cash proceeds, or the Fair Market Value of
Property other than cash, received by the Company as capital contributions
to the Company (other than from a Subsidiary of the Company) on or after
the Issue Date, plus
(D) the aggregate net cash proceeds received by the Company from the
issuance or sale (other than to any Subsidiary of the Company) on or after
the Issue Date of convertible Indebtedness that has been converted into or
exchanged for Capital Stock of the Company, together with the aggregate
cash received by the Company at the time of such conversion or exchange or
received by the Company from any conversion or exchange of convertible
Senior Indebtedness or convertible Pari Passu Indebtedness issued or sold
(other than to any Subsidiary of the Company) prior to the Issue Date, plus
(E) to the extent not otherwise included in the Company's Consolidated
Net Income, an amount equal to the net reduction in Investments made by the
Company and its Restricted Subsidiaries subsequent to the Issue Date in any
Person resulting from (1) payments of interest on debt, dividends,
repayments of loans or advances or other transfers or distributions of
Property, in each case to the Company or any Restricted Subsidiary from any
Person other than the Company or a Restricted Subsidiary, and in an amount
not to exceed the book value of such Investments previously made in such
Person that were treated as Restricted Payments, or (2) the designation of
any Unrestricted Subsidiary as a Restricted Subsidiary, and in an amount
not to exceed the lesser of (x) the book value of all Investments
previously made in such Unrestricted Subsidiary that were treated as
Restricted Payments and (y) the Fair Market Value of such Unrestricted
Subsidiary, plus
(F) $15.0 million.
(b) The limitations set forth in paragraph (a) above will not prevent the
Company or any Restricted Subsidiary from making the following Restricted
Payments so long as, at the time thereof, no Default or
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Event of Default shall have occurred and be continuing (except in the case of
clause (i) below under which the payment of a dividend is permitted):
(i) the payment of any dividend on Capital Stock or Redeemable Stock
of the Company or any Restricted Subsidiary within 60 days after the
declaration thereof, if at such declaration date such dividend could have
been paid in compliance with paragraph (a) above;
(ii) the repurchase, redemption or other acquisition or retirement for
value of any Capital Stock of the Company or any of its Subsidiaries held
by any current or former officers, directors or employees of the Company or
any of its Subsidiaries pursuant to the terms of agreements (including
employment agreements) or plans approved by the Company's Board of
Directors, including any such repurchase, redemption, acquisition or
retirement of shares of such Capital Stock that is deemed to occur upon the
exercise of stock options or similar rights if such shares represent all or
a portion of the exercise price or are surrendered in connection with
satisfying Federal income tax obligations; provided, however, that the
aggregate amount of such repurchases, redemptions, acquisitions and
retirements shall not exceed the sum of (a) $1.0 million in any
twelve-month period and (b) the aggregate net proceeds, if any, received by
the Company during such twelve-month period from any issuance of such
Capital Stock pursuant to such agreements or plans;
(iii) the purchase, redemption or other acquisition or retirement for
value of any Capital Stock or Redeemable Stock of the Company or any
Restricted Subsidiary, in exchange for, or out of the aggregate net cash
proceeds of, a substantially concurrent issuance and sale (other than to a
Subsidiary of the Company or an employee stock ownership plan or trust
established by the Company or any of its Subsidiaries, for the benefit of
their employees) of Capital Stock of the Company;
(iv) the making of any principal payment on or the repurchase,
redemption, legal defeasance or other acquisition or retirement for value,
prior to any scheduled principal payment, scheduled sinking fund payment or
maturity, of any Subordinated Indebtedness (other than Redeemable Stock) in
exchange for, or out of the aggregate net cash proceeds of, a substantially
concurrent issuance and sale (other than to a Subsidiary of the Company or
an employee stock ownership plan or trust established by the Company or any
of its Subsidiaries, for the benefit of their employees) of Capital Stock
of the Company;
(v) the making of any principal payment on or the repurchase,
redemption, legal defeasance or other acquisition or retirement for value
of Subordinated Indebtedness in exchange for, or out of the aggregate net
cash proceeds of a substantially concurrent Incurrence (other than a sale
to a Subsidiary of the Company) of Subordinated Indebtedness so long as
such new Indebtedness is Permitted Refinancing Indebtedness and (A) has an
Average Life that is longer than the Average Life of the Notes and (B) has
a Stated Maturity for its final scheduled principal payment that is more
than one year after the Stated Maturity of the final scheduled principal
payment of the Notes; and
(vi) loans made to officers, directors or employees of the Company or
any Restricted Subsidiary approved by the Board of Directors (or a duly
authorized officer), the net cash proceeds of which are used solely (A) to
purchase common stock of the Company in connection with a restricted stock
or employee stock purchase plan, or to exercise stock options received
pursuant to an employee or director stock option plan or other incentive
plan, in a principal amount not to exceed the exercise price of such stock
options or (B) to refinance loans, together with accrued interest thereon,
made pursuant to item (A) of this clause (vi).
The actions described in clauses (i) and (ii) of this paragraph (b) shall be
included in the calculation of the amount of Restricted Payments. The actions
described in clauses (iii), (iv), (v) and (vi) of this paragraph (b) shall be
excluded in the calculation of the amount of Restricted Payments, provided that
the net cash proceeds from any issuance or sale of Capital Stock of the Company
pursuant to such clause (iii), (iv) or (vi) shall be excluded from any
calculations pursuant to clause (B) or (C) under the immediately preceding
paragraph (a).
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Limitation on Issuance and Sale of Capital Stock of Restricted
Subsidiaries. The Indenture provides that the Company will not (i) permit any
Restricted Subsidiary to sell or otherwise issue any Capital Stock other than to
the Company or one of its Wholly Owned Subsidiaries or (ii) permit any Person
other than the Company or a Wholly Owned Subsidiary to own any Capital Stock or
of any other Restricted Subsidiary, except, in each case, for (a) directors'
qualifying shares, (b) the Capital Stock of a Restricted Subsidiary owned by a
Person at the time such Restricted Subsidiary became a Restricted Subsidiary or
acquired by such Person in connection with the formation of such Restricted
Subsidiary, or transfers thereof, or (c) a sale of all the Capital Stock of a
Restricted Subsidiary owned by the Company or its Subsidiaries effected in
accordance with the provisions of the Indenture described under "-- Limitation
on Asset Sales." In the event of the consummation of a sale of all the Capital
Stock of a Restricted Subsidiary pursuant to the foregoing clause (c) and the
execution and delivery of a supplemental indenture in form satisfactory to the
Trustee, any such Restricted Subsidiary that is also a Subsidiary Guarantor
shall be released from all its obligations under its Subsidiary Guaranty.
Limitation on Asset Sales. The Indenture provides that the Company will
not, and will not permit any Restricted Subsidiary to, consummate any Asset Sale
unless (i) the Company or such Restricted Subsidiary, as the case may be,
receives consideration at the time of such Asset Sale at least equal to the Fair
Market Value of the Property subject to such Asset Sale and (ii) all of the
consideration paid to the Company or such Restricted Subsidiary in connection
with such Asset Sale is in the form of cash, cash equivalents, Liquid
Securities, Exchanged Properties or the assumption by the purchaser of
liabilities of the Company (other than liabilities of the Company that are by
their terms subordinated to the Notes) or liabilities of any Subsidiary
Guarantor that made such Asset Sale (other than liabilities of a Subsidiary
Guarantor that are by their terms subordinated to such Subsidiary Guarantor's
Subsidiary Guaranty), in each case as a result of which the Company and its
remaining Restricted Subsidiaries are no longer liable for such liabilities
("Permitted Consideration"); provided, however, that the Company and its
Restricted Subsidiaries shall be permitted to receive Property other than
Permitted Consideration, so long as the aggregate Fair Market Value of all such
Property other than Permitted Consideration received from Asset Sales and held
by the Company or any Restricted Subsidiary at any one time shall not exceed
10.0% of Adjusted Consolidated Net Tangible Assets.
The Net Available Cash from Asset Sales by the Company or a Restricted
Subsidiary may be applied by the Company or such Restricted Subsidiary, to the
extent the Company or such Restricted Subsidiary elects (or is required by the
terms of any Senior Indebtedness of the Company or a Subsidiary Guarantor), to
(i) prepay, repay or purchase Senior Indebtedness of the Company or a Subsidiary
Guarantor (in each case excluding Indebtedness owed to the Company or an
Affiliate of the Company), (ii) to reinvest in Additional Assets (including by
means of an Investment in Additional Assets by a Restricted Subsidiary with Net
Available Cash received by the Company or another Restricted Subsidiary) or
(iii) purchase Notes or purchase both Notes and one or more series or issues of
other Pari Passu Indebtedness on a pro rata basis (excluding Notes and Pari
Passu Indebtedness owned by the Company or an Affiliate of the Company).
Any Net Available Cash from an Asset Sale not applied in accordance with
the preceding paragraph within 365 days from the date of such Asset Sale shall
constitute "Excess Proceeds." When the aggregate amount of Excess Proceeds
exceeds $10.0 million, the Company will be required to make an offer to purchase
Notes having an aggregate principal amount equal to the aggregate amount of
Excess Proceeds (the "Prepayment Offer") at a purchase price equal to 100% of
the principal amount of such Notes plus accrued and unpaid interest, if any, to
the Purchase Date (as defined) in accordance with the procedures (including
prorating in the event of oversubscription) set forth in the Indenture, but, if
the terms of any Pari Passu Indebtedness require that a Pari Passu Offer be made
contemporaneously with the Prepayment Offer, then the Excess Proceeds shall be
prorated between the Prepayment Offer and such Pari Passu Offer in accordance
with the aggregate outstanding principal amounts of the Notes and such Pari
Passu Indebtedness, and the aggregate principal amount of Notes for which the
Prepayment Offer is made shall be reduced accordingly. If the aggregate
principal amount of Notes tendered by Holders thereof exceeds the amount of
available Excess Proceeds, then such Excess Proceeds will be allocated pro rata
according to the principal amount of the Notes tendered and the
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Trustee will select the Notes to be purchased in accordance with the Indenture.
To the extent that any portion of the amount of Excess Proceeds remains after
compliance with the second sentence of this paragraph and provided that all
Holders of Notes have been given the opportunity to tender their Notes for
purchase as described in the following paragraph in accordance with the
Indenture, the Company and its Restricted Subsidiaries may use such remaining
amount for purposes permitted by the Indenture and the amount of Excess Proceeds
will be reset to zero.
Within 30 days after the 365th day following the date of an Asset Sale, the
Company shall, if it is obligated to make an offer to purchase the Notes
pursuant to the preceding paragraph, send a written Prepayment Offer notice, by
first-class mail, to the Holders of the Notes (the "Prepayment Offer Notice"),
accompanied by such information regarding the Company and its Subsidiaries as
the Company believes will enable such Holders of the Notes to make an informed
decision with respect to the Prepayment Offer. The Prepayment Offer Notice will
state, among other things, (i) that the Company is offering to purchase Notes
pursuant to the provisions of the Indenture, (ii) that any Note (or any portion
thereof) accepted for payment (and duly paid on the Purchase Date) pursuant to
the Prepayment Offer shall cease to accrue interest on the Purchase Date, (iii)
that any Notes (or portions thereof) not properly tendered will continue to
accrue interest, (iv) the purchase price and purchase date, which shall be,
subject to any contrary requirements of applicable law, no less than 30 days nor
more than 60 days after the date the Prepayment Offer Notice is mailed (the
"Purchase Date"), (v) the aggregate principal amount of Notes to be purchased,
(vi) a description of the procedure which Holders of Notes must follow in order
to tender their Notes and the procedures that Holders of Notes must follow in
order to withdraw an election to tender their Notes for payment and (vii) all
other instructions and materials necessary to enable Holders to tender Notes
pursuant to the Prepayment Offer.
The Company will comply, to the extent applicable, with the requirements of
Rule 14e-1 under the Exchange Act and any other securities laws or regulations
thereunder to the extent such laws and regulations are applicable in connection
with the purchase of Notes as described above. To the extent that the provisions
of any securities laws or regulations conflict with the provisions relating to
the Prepayment Offer, the Company will comply with the applicable securities
laws and regulations and will not be deemed to have breached its obligations
described above by virtue thereof.
Incurrence of Layered Indebtedness. The Indenture provides that (i) the
Company will not Incur any Indebtedness which is subordinated or junior in right
of payment to any Senior Indebtedness of the Company unless such Indebtedness
constitutes Indebtedness which is junior to, or pari passu with, the Notes in
right of payment and (ii) no Subsidiary Guarantor will Incur any Indebtedness
that is subordinated or junior in right of payment to any Senior Indebtedness of
such Subsidiary Guarantor unless such Indebtedness constitutes Indebtedness
which is junior to, or pari passu with, such Subsidiary Guarantor's Subsidiary
Guaranty in right of payment.
Limitation on Transactions with Affiliates. The Indenture provides that the
Company will not, and will not permit any of its Restricted Subsidiaries to,
directly or indirectly, conduct any business or enter into any transaction or
series of transactions (including the sale, transfer, disposition, purchase,
exchange or lease of Property, the making of any Investment, the giving of any
Guarantee or the rendering of any service) with or for the benefit of any
Affiliate of the Company (other than the Company or a Wholly Owned Subsidiary),
unless (i) such transaction or series of transactions is on terms no less
favorable to the Company or such Restricted Subsidiary than those that could be
obtained in a comparable arm's-length transaction with a Person that is not an
Affiliate of the Company or such Restricted Subsidiary, and (ii) with respect to
a transaction or series of transactions involving aggregate payments by or to
the Company or such Restricted Subsidiary having a Fair Market Value equal to or
in excess of (a) $1.0 million but less than $5.0 million, an officer of the
Company certifies that such transaction or series of transactions complies with
clause (i) of this paragraph, as evidenced by an Officer's Certificate delivered
to the Trustee, (b) $5.0 million but less than $20.0 million, the Board of
Directors of the Company (including a majority of the disinterested members of
such Board of Directors) approves such transaction or series of transactions and
certifies that such transaction or series of transactions complies with clause
(i) of this paragraph, as evidenced by a certified resolution delivered to the
Trustee, or
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(c) $20.0 million, (1) the Company receives from an independent, nationally
recognized investment banking firm or appraisal firm, in either case
specializing or having a specialty in the type and subject matter of the
transaction (or series of transactions) at issue, a written opinion that such
transaction (or series of transactions) is fair, from a financial point of view,
to the Company or such Restricted Subsidiary and (2) such Board of Directors
(including a majority of the disinterested members of the Board of Directors of
the Company) approves such transaction or series of transactions and certifies
that such transaction or series of transactions complies with clause (i) of this
paragraph, as evidenced by a certified resolution delivered to the Trustee.
The limitations of the preceding paragraph do not apply to (i) the payment
of reasonable and customary regular fees to directors of the Company or any of
its Restricted Subsidiaries who are not employees of the Company or any of its
Restricted Subsidiaries, (ii) indemnities of officers and directors of the
Company or any Subsidiary consistent with such Person's charter, bylaws and
applicable statutory provisions, (iii) any issuance of securities, or other
payments, awards or grants in cash, securities or otherwise pursuant to, or the
funding of, employment arrangements, stock options and stock ownership plans
approved by the Board of Directors of the Company, (iv) loans made (a) to
officers, directors or employees of the Company or any Restricted Subsidiary
approved by the Board of Directors (or by a duly authorized officer) of the
Company, the proceeds of which are used solely to purchase common stock of the
Company in connection with a restricted stock or employee stock purchase plan,
or to exercise stock options received pursuant to an employee or director stock
option plan or other incentive plan, in a principal amount not to exceed the
exercise price of such stock options, or (b) to refinance loans, together with
accrued interest thereon, made pursuant to this clause (iv), (v) advances and
loans to officers, directors and employees of the Company or any Subsidiary in
the ordinary course of business, provided such loans and advances (excluding
loans or advances made pursuant to the preceding clause (iv)) do not exceed $2.0
million at any one time outstanding, (vi) any Restricted Payment permitted to be
paid pursuant to the provisions of the Indenture described under "-- Limitations
on Restricted Payments," (vii) any transaction or series of transactions between
the Company and one or more Restricted Subsidiaries or between two or more
Restricted Subsidiaries in the ordinary course of business, provided that no
more than 10% of the total voting power of the Voting Stock of any such
Restricted Subsidiary is owned by an Affiliate of the Company (other than a
Restricted Subsidiary) and (viii) any transaction or series of transactions
pursuant to any agreement or obligation of the Company or any of its Restricted
Subsidiaries in effect on the Issue Date.
Limitation on Restrictions on Distributions from Restricted
Subsidiaries. The Indenture provides that the Company will not, and will not
permit any of its Restricted Subsidiaries to, directly or indirectly, create or
otherwise cause or permit to exist or become effective any consensual
encumbrance or restriction on the legal right of any Restricted Subsidiary to
(i) pay dividends, in cash or otherwise, or make any other distributions on or
in respect of its Capital Stock or Redeemable Stock, or pay any Indebtedness or
other obligation owed, to the Company or any other Restricted Subsidiary, (ii)
make loans or advances to the Company or any other Restricted Subsidiary or
(iii) transfer any of its Property to the Company or any other Restricted
Subsidiary. Such limitation will not apply (a) with respect to clauses (i), (ii)
and (iii), to encumbrances and restrictions (1) in the Bank Credit Facilities
and other agreements and instruments, in each case as in effect on the Issue
Date, (2) relating to Indebtedness of a Restricted Subsidiary and existing at
the time it became a Restricted Subsidiary if such encumbrance or restriction
was not created in anticipation of or in connection with the transactions
pursuant to which such Restricted Subsidiary became a Restricted Subsidiary or
(3) which result from the renewal, refinancing, extension or amendment of an
agreement that is the subject of clause (a)(1) or (2) above or clause (b)(1) or
(2) below, provided that such encumbrance or restriction is not materially less
favorable to the Holders of Notes than those under or pursuant to the agreement
so renewed, refinanced, extended or amended, and (b) with respect to clause
(iii) only, to (1) any restriction on the sale, transfer or other disposition of
Property relating to Indebtedness that is permitted to be Incurred and secured
under the provisions of the Indenture described under "-- Limitation on
Indebtedness" and "-- Limitation on Liens," (2) any encumbrance or restriction
applicable to Property at the time it is acquired by the Company or a Restricted
Subsidiary, so long as such encumbrance or restriction relates solely to the
Property so
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acquired and was not created in anticipation of or in connection with such
acquisition, (3) customary provisions restricting subletting or assignment of
leases and customary provisions in other agreements that restrict assignment of
such agreements or rights thereunder and (4) customary restrictions contained in
asset sale agreements limiting the transfer of such assets pending the closing
of such sale.
Future Subsidiary Guarantors. The Company shall cause each Restricted
Subsidiary that (i) Incurs Indebtedness following the Issue Date or (ii) has
Indebtedness or Preferred Stock outstanding on the date on which such Restricted
Subsidiary becomes a Restricted Subsidiary, to execute and deliver to the
Trustee a Subsidiary Guaranty at the time such Restricted Subsidiary Incurs such
Indebtedness or becomes a Restricted Subsidiary; provided, however, that such
Restricted Subsidiary shall not be required to deliver a Subsidiary Guaranty if
the aggregate amount of such Indebtedness or Preferred Stock, together with all
other Indebtedness and Preferred Stock then outstanding among Restricted
Subsidiaries that are not Subsidiary Guarantors, is less than $10.0 million.
Restricted and Unrestricted Subsidiaries. Unless defined or designated as
an Unrestricted Subsidiary, any Person that becomes a Subsidiary of the Company
or any of its Restricted Subsidiaries shall be classified as a Restricted
Subsidiary subject to the provisions of the next paragraph. The Company may
designate a Subsidiary (including a newly formed or newly acquired Subsidiary)
of the Company or any of its Restricted Subsidiaries as an Unrestricted
Subsidiary if (i) such Subsidiary does not at such time own any Capital Stock or
Indebtedness of, or own or hold any Lien on any Property of, the Company or any
other Restricted Subsidiary, (ii) such Subsidiary does not at such time have any
Indebtedness or other obligations which, if in default, would result (with the
passage of time or notice or otherwise) in a default on any Indebtedness of the
Company or any Restricted Subsidiary and (iii)(a) such designation is effective
immediately upon such Subsidiary becoming a Subsidiary of the Company or of a
Restricted Subsidiary, (b) the Subsidiary to be so designated has total assets
of $1,000 or less or (c) if such Subsidiary has assets greater than $1,000, then
such redesignation as an Unrestricted Subsidiary is deemed to constitute a
Restricted Payment in an amount equal to the Fair Market Value of the Company's
direct and indirect ownership interest in such Subsidiary, and such Restricted
Payment would be permitted to be made at the time of such designation under
"-- Limitation on Restricted Payments." Except as provided in the immediately
preceding sentence, no Restricted Subsidiary may be redesignated as an
Unrestricted Subsidiary. The designation of an Unrestricted Subsidiary or
removal of such designation shall be made by the Board of Directors of the
Company or a committee thereof pursuant to a certified resolution delivered to
the Trustee and shall be effective as of the date specified in the applicable
certified resolution, which shall not be prior to the date such certified
resolution is delivered to the Trustee.
The Company will not, and will not permit any of its Restricted
Subsidiaries to, take any action or enter into any transaction or series of
transactions that would result in a Person becoming a Restricted Subsidiary
(whether through an acquisition or otherwise) unless, after giving effect to
such action, transaction or series of transactions, on a pro forma basis, (i)
the Company could Incur at least $1.00 of additional Indebtedness pursuant to
clause (a) of the first paragraph under "-- Limitation on Indebtedness" and (ii)
no Default or Event of Default would occur or be continuing.
MERGER, CONSOLIDATION AND SALE OF SUBSTANTIALLY ALL ASSETS
The Company shall not consolidate with or merge with or into any Person, or
convey, transfer or lease, in one transaction or a series of transactions, all
or substantially all its Property, unless: (i) the resulting, surviving or
transferee person (the "Successor Company") shall be a Person organized or
existing under the laws of the United States of America, any State thereof or
the District of Columbia and the Successor Company (if not the Company) shall
expressly assume, by an indenture supplemental thereto, executed and delivered
to the Trustee, in form satisfactory to the Trustee, all the obligations of the
Company under the Notes and the Indenture; (ii) in the case of a conveyance,
transfer or lease of all or substantially all the Company's Property, such
Property shall have been so conveyed, transferred or leased as an entirety or
virtually as an entirety to one Person; (iii) immediately after giving effect to
such transaction (and treating, for purposes of this clause (iii) and clauses
(iv) and (v) below, any
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Indebtedness which becomes or is anticipated to become an obligation of the
Successor Company or any Restricted Subsidiary as a result of such transaction
as having been Incurred by such Successor Company or such Restricted Subsidiary
at the time of such transaction), no Default or Event of Default shall have
occurred and be continuing; (iv) immediately after giving effect to such
transaction, the Successor Company would be able to Incur an additional $1.00 of
Indebtedness pursuant to clause (a) of the first paragraph under "-- Limitation
on Indebtedness;" (v) immediately after giving effect to such transaction, the
Successor Company shall have Consolidated Net Worth in an amount that is not
less than the Consolidated Net Worth of the Company immediately prior to such
transaction; and (vi) the Company shall have delivered to the Trustee an
Officer's Certificate, stating that such consolidation, merger or transfer and
such supplemental indenture (if any) comply with the Indenture.
The Company shall not permit any Subsidiary Guarantor to consolidate with
or merge with or into, or convey, transfer or lease, in one transaction or a
series of transactions, all or substantially all its Property to, any Person
(other than the Company or any other Subsidiary Guarantor), unless: (a) the
Successor Company (if not such Subsidiary) shall be a person organized and
existing under the laws of the United States of America, any State thereof or
the District of Columbia and the Successor Company (if not such Subsidiary)
shall expressly assume, by a supplemental indenture, in form satisfactory to the
Trustee, all the obligations of such Subsidiary under its Subsidiary Guaranty;
(b) in the case of a conveyance, transfer or lease of all or substantially all
the Property of such Subsidiary Guarantor, such Property shall have been so
conveyed, transferred or leased as an entirety or virtually as an entirety to
one Person; (c) immediately after giving effect to such transaction (and
treating, for purposes of this clause (c) and clauses (d) and (e) below, any
Indebtedness which becomes or is anticipated to become an obligation of the
Successor Company or the Company or any other Restricted Subsidiary as a result
of such transaction as having been Incurred by such Person at the time of such
transaction), no Default or Event of Default shall have occurred and be
continuing; (d) immediately after giving effect to such transaction, the Company
would be able to Incur an additional $1.00 of Indebtedness pursuant to clause
(a) of the first paragraph under "-- Limitation on Indebtedness;" (e)
immediately after giving effect to such transaction, the Company shall have
Consolidated Net Worth in an amount that is not less than the Consolidated Net
Worth of the Company immediately prior to such transaction; and (f) the Company
shall have delivered to the Trustee an Officers' Certificate, stating that such
consolidation, merger or transfer and such supplemental indenture (if any)
comply with the Indenture. The provisions of clauses (a), (b), (d), (e) and (f)
above shall not apply to any transactions which constitute an Asset Sale if the
Company has complied with the provisions of the Indenture described under
"-- Limitation on Asset Sales."
The Successor Company shall be the successor to the Company (or the
applicable Subsidiary Guarantor, as the case may be) and shall succeed to, and
be substituted for, and may exercise every right and power of the Company under
the Indenture (or of such Subsidiary Guarantor under its Subsidiary Guaranty),
but the predecessor Company in the case of a conveyance, transfer or lease shall
not be released from the obligation to pay the principal of and interest on the
Notes.
REPORTS
The Indenture provides that, whether or not required by the rules and
regulations of the Commission, so long as any Notes are outstanding, the Company
will file with the Commission and furnish to the Holders of Notes all quarterly
and annual financial information required to be contained in a filing with the
Commission on Forms 10-Q and 10-K, including a "Management's Discussion and
Analysis of Financial Condition and Results of Operations" and, with respect to
the annual consolidated financial statements only, a report thereon by the
Company's independent auditors.
CERTAIN DEFINITIONS
Set forth below is a summary of certain of the defined terms used in the
Indenture. Reference is made to the Indenture for the full definition of all
such terms, as well as any other capitalized terms used herein for which no
definition is provided.
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"Additional Assets" means (i) any Property (other than cash, Permitted
Short-Term Investments or securities) used in the Oil and Gas Business or any
business ancillary thereto, (ii) Investments in any other Person engaged in the
Oil and Gas Business or any business ancillary thereto (including the
acquisition from third parties of Capital Stock of such Person) as a result of
which such other Person becomes a Restricted Subsidiary in compliance with the
provisions of the Indenture described under "-- Certain Covenants -- Restricted
and Unrestricted Subsidiaries," (iii) the acquisition from third parties of
Capital Stock of a Restricted Subsidiary or (iv) Permitted Business Investments.
"Adjusted Consolidated Net Tangible Assets" means (without duplication), as
of the date of determination, the remainder of:
(i) the sum of (a) discounted future net revenues from proved oil and
gas reserves of the Company and its Restricted Subsidiaries calculated in
accordance with Commission guidelines before any state, federal or foreign
income taxes, as estimated by the Company and confirmed by a nationally
recognized firm of independent petroleum engineers in a reserve report
prepared as of the end of the Company's most recently completed fiscal year
for which audited financial statements are available, as increased by, as
of the date of determination, the estimated discounted future net revenues
from (1) estimated proved oil and gas reserves acquired since such
year-end, which reserves were not reflected in such year-end reserve
report, and (2) estimated oil and gas reserves attributable to upward
revisions of estimates of proved oil and gas reserves since such year-end
due to exploration, development or exploitation activities, in each case
calculated in accordance with Commission guidelines (utilizing the prices
utilized in such year-end reserve report), and decreased by, as of the date
of determination, the estimated discounted future net revenues from (3)
estimated proved oil and gas reserves produced or disposed of since such
year-end and (4) estimated oil and gas reserves attributable to downward
revisions of estimates of proved oil and gas reserves since such year-end
due to changes in geological conditions or other factors which would, in
accordance with standard industry practice, cause such revisions, in each
case calculated in accordance with Commission guidelines (utilizing the
prices utilized in such year-end reserve report); provided that, in the
case of each of the determinations made pursuant to clauses (1) through
(4), such increases and decreases shall be as estimated by the Company's
petroleum engineers, unless there is a Material Change as a result of such
acquisitions, dispositions or revisions, in which event the discounted
future net revenues utilized for purposes of this clause (i)(a) shall be
confirmed in writing by a nationally recognized firm of independent
petroleum engineers, (b) the capitalized costs that are attributable to oil
and gas properties of the Company and its Restricted Subsidiaries to which
no proved oil and gas reserves are attributable, based on the Company's
books and records as of a date no earlier than the date of the Company's
latest annual or quarterly financial statements, (c) the Net Working
Capital on a date no earlier than the date of the Company's latest annual
or quarterly financial statements and (d) the greater of (1) the net book
value on a date no earlier than the date of the Company's latest annual or
quarterly financial statements and (2) the appraised value, as estimated by
independent appraisers, of other tangible assets (including, without
duplication, Investments in unconsolidated Restricted Subsidiaries) of the
Company and its Restricted Subsidiaries, as of the date no earlier than the
date of the Company's latest audited financial statements, minus
(ii) the sum of (a) minority interests, (b) any net gas balancing
liabilities of the Company and its Restricted Subsidiaries reflected in the
Company's latest audited financial statements, (c) to the extent included
in (i)(a) above, the discounted future net revenues, calculated in
accordance with Commission guidelines (utilizing the prices utilized in the
Company's year-end reserve report), attributable to reserves which are
required to be delivered to third parties to fully satisfy the obligations
of the Company and its Restricted Subsidiaries with respect to Volumetric
Production Payments (determined, if applicable, using the schedules
specified with respect thereto) and (d) the discounted future net revenues,
calculated in accordance with Commission guidelines, attributable to
reserves subject to Dollar-Denominated Production Payments which, based on
the estimates of production and price assumptions included in determining
the discounted future net
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revenues specified in (i)(a) above, would be necessary to fully satisfy the
payment obligations of the Company and its Restricted Subsidiaries with
respect to Dollar-Denominated Production Payments (determined, if
applicable, using the schedules specified with respect thereto). If the
Company changes its method of accounting from the full cost method to the
successful efforts method or a similar method of accounting, "Adjusted
Consolidated Net Tangible Assets" will continue to be calculated as if the
Company were still using the full cost method of accounting.
"Affiliate" of any specified Person means any other Person (i) which
directly or indirectly through one or more intermediaries controls, or is
controlled by, or is under common control with, such specified Person or (ii)
which beneficially owns or holds directly or indirectly 10% or more of any class
of the Voting Stock of such specified Person or of any Subsidiary of such
specified Person. For the purposes of this definition, "control," when used with
respect to any specified Person, means the power to direct the management and
policies of such Person directly or indirectly, whether through the ownership of
Voting Stock, by contract or otherwise; and the terms "controlling" and
"controlled" have meanings correlative to the foregoing.
"Asset Sale" means, with respect to any Person, any transfer, conveyance,
sale, lease or other disposition (collectively, "dispositions," and including
dispositions pursuant to any consolidation or merger) by such Person or any of
its Restricted Subsidiaries in any single transaction or series of transactions
of (i) shares of Capital Stock or other ownership interests of another Person
(including Capital Stock of Restricted Subsidiaries and Unrestricted
Subsidiaries) or (ii) any other Property of such Person or any of its Restricted
Subsidiaries; provided, however, that the term "Asset Sale" shall not include:
(a) the disposition of Permitted Short-Term Investments, inventory, accounts
receivable, surplus or obsolete equipment or other Property (excluding the
disposition of oil and gas in place and other interests in real property unless
made in connection with a Permitted Business Investment) in the ordinary course
of business; (b) the abandonment, assignment, lease, sublease or farmout of oil
and gas properties, or the forfeiture or other disposition of such properties
pursuant to standard form operating agreements, in each case in the ordinary
course of business in a manner that is customary in the Oil and Gas Business;
(c) the disposition of Property received in settlement of debts owing to the
Company or any Restricted Subsidiary as a result of foreclosure, perfection or
enforcement of any Lien or debt, which debts were owing to the Company or any
Restricted Subsidiary in the ordinary course of business of the Company or such
Restricted Subsidiary; (d) any disposition that constitutes a Restricted Payment
made in compliance with the provisions of the Indenture described under
"-- Certain Covenants -- Limitation on Restricted Payments;" (e) when used with
respect to the Company, any disposition of all or substantially all of the
Property of the Company permitted pursuant to the provisions of the Indenture
described under "-- Merger, Consolidation and Sale of Substantially All Assets;"
(f) the disposition of any Property by the Company or a Restricted Subsidiary to
the Company or a Wholly Owned Subsidiary; (g) the disposition of any asset with
a Fair Market Value of less than $2.0 million; or (h) any Production Payments
and Reserve Sales, provided that any such Production Payments and Reserve Sales,
other than incentive compensation programs on terms that are reasonably
customary in the Oil and Gas Business for geologists, geophysicists and other
providers of technical services to the Company or a Restricted Subsidiary, shall
have been created, Incurred, issued, assumed or Guaranteed in connection with
the financing of, and within 60 days after the acquisition of, the Property that
is subject thereto.
"Average Life" means, with respect to any Indebtedness, at any date of
determination, the quotient obtained by dividing (i) the sum of the products of
(a) the number of years (and any portion thereof) from the date of determination
to the date or dates of each successive scheduled principal payment (including
any sinking fund or mandatory redemption payment requirements) of such
Indebtedness multiplied by (b) the amount of each such principal payment by (ii)
the sum of all such principal payments.
"Bank Credit Facilities" means, with respect to any Person, one or more
debt facilities or commercial paper facilities with banks or other institutional
lenders (including pursuant to the Third Amended and Restated Credit Agreement,
dated as of July 31, 1997, among the Company, NationsBank of Texas, N.A.,
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as agent, and the lenders referred to therein and the Term Loan Agreement dated
as of November 30, 1995, between the Company and First National Bank of
Commerce) providing for revolving credit loans, term loans, receivables
financing (including through the sale of receivables to such lenders or to
special purpose entities formed to borrow from such lenders against such
receivables) or trade letters of credit.
"Capital Lease Obligation" means any obligation which is required to be
classified and accounted for as a capital lease obligation in accordance with
GAAP, and the amount of Indebtedness represented by such obligation shall be the
capitalized amount of such obligation determined in accordance with GAAP, and
the Stated Maturity thereof shall be the date of the last payment date of rent
or any other amount due in respect of such obligation.
"Capital Stock" in any Person means any and all shares, interests,
participations or other equivalents in the equity interest (however designated)
in such Person and any rights (other than debt securities convertible into an
equity interest), warrants or options to subscribe for or to acquire an equity
interest in such Person; provided, however, that "Capital Stock" shall not
include Redeemable Stock.
"Consolidated Interest Coverage Ratio" means, as of the date of the
transaction giving rise to the need to calculate the Consolidated Interest
Coverage Ratio (the "Transaction Date"), the ratio of (i) the aggregate amount
of EBITDA of the Company and its consolidated Restricted Subsidiaries for the
four full fiscal quarters immediately prior to the Transaction Date for which
financial statements are available to (ii) the aggregate Consolidated Interest
Expense of the Company and its Restricted Subsidiaries that is anticipated to
accrue during a period consisting of the fiscal quarter in which the Transaction
Date occurs and the three fiscal quarters immediately subsequent thereto (based
upon the pro forma amount and maturity of, and interest payments in respect of,
Indebtedness of the Company and its Restricted Subsidiaries expected by the
Company to be outstanding on the Transaction Date), assuming for the purposes of
this measurement the continuation of market interest rates prevailing on the
Transaction Date and base interest rates in respect of floating interest rate
obligations equal to the base interest rates on such obligations in effect as of
the Transaction Date; provided, that if the Company or any of its Restricted
Subsidiaries is a party to any Interest Rate Protection Agreement which would
have the effect of changing the interest rate on any Indebtedness of the Company
or any of its Restricted Subsidiaries for such four quarter period (or a portion
thereof), the resulting rate shall be used for such four quarter period or
portion thereof; provided further that any Consolidated Interest Expense with
respect to Indebtedness Incurred or retired by the Company or any of its
Restricted Subsidiaries during the fiscal quarter in which the Transaction Date
occurs shall be calculated as if such Indebtedness was so Incurred or retired on
the first day of the fiscal quarter in which the Transaction Date occurs. In
addition, if since the beginning of the four full fiscal quarter period
preceding the Transaction Date, (a) the Company or any of its Restricted
Subsidiaries shall have engaged in any Asset Sale, EBITDA for such period shall
be reduced by an amount equal to the EBITDA (if positive), or increased by an
amount equal to the EBITDA (if negative), directly attributable to the assets
which are the subject of such Asset Sale for such period calculated on a pro
forma basis as if such Asset Sale and any related retirement of Indebtedness had
occurred on the first day of such period or (b) the Company or any of its
Restricted Subsidiaries shall have acquired any material assets, EBITDA shall be
calculated on a pro forma basis as if such asset acquisitions had occurred on
the first day of such four fiscal quarter period.
"Consolidated Interest Expense" means, with respect to any Person for any
period, without duplication, (i) the sum of (a) the aggregate amount of cash and
noncash interest expense (including capitalized interest) of such Person and its
Restricted Subsidiaries for such period as determined on a consolidated basis in
accordance with GAAP in respect of Indebtedness (including (1) any amortization
of debt discount, (2) net costs associated with Interest Rate Protection
Agreements (including any amortization of discounts), (3) the interest portion
of any deferred payment obligation, (4) all accrued interest and (5) all
commissions, discounts, commitment fees, origination fees and other fees and
charges owed with respect to the Bank Credit Facilities and other Indebtedness)
paid, accrued or scheduled to be paid or accrued during such period; (b)
Redeemable Stock dividends of such Person (and of its Restricted Subsidiaries if
paid to a Person other than such Person or its Restricted Subsidiaries) and
Preferred Stock dividends of such Person's Restricted Subsidiaries if paid to a
Person
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other than such Person or its other Restricted Subsidiaries; (c) the portion of
any rental obligation of such Person or its Restricted Subsidiaries in respect
of any Capital Lease Obligation allocable to interest expense in accordance with
GAAP; (d) the portion of any rental obligation of such Person or its Restricted
Subsidiaries in respect of any Sale and Leaseback Transaction that is
Indebtedness allocable to interest expense (determined as if such obligation
were treated as a Capital Lease Obligation); and (e) to the extent any
Indebtedness of any other Person (other than Restricted Subsidiaries) is
Guaranteed by such Person or any of its Restricted Subsidiaries, the aggregate
amount of interest paid, accrued or scheduled to be paid or accrued by such
other Person during such period attributable to any such Indebtedness; less (ii)
to the extent included in (i) above, amortization or write-off of deferred
financing costs of such Person and its Restricted Subsidiaries during such
period; in the case of both (i) and (ii) above, after elimination of
intercompany accounts among such Person and its Restricted Subsidiaries and as
determined in accordance with GAAP.
"Consolidated Net Income" of any Person means, for any period, the
aggregate net income (or net loss, as the case may be) of such Person and its
Restricted Subsidiaries for such period on a consolidated basis, determined in
accordance with GAAP; provided that there shall be excluded therefrom, without
duplication: (i) items classified as extraordinary gains or losses net of tax
(less all fees and expenses relating thereto); (ii) any gain or loss net of
taxes (less all fees and expenses relating thereto) realized on the sale or
other disposition of Property, including the Capital Stock of any other Person
(but in no event shall this clause (ii) apply to any gains or losses on the sale
in the ordinary course of business of oil, gas or other hydrocarbons produced or
manufactured); (iii) the net income of any Restricted Subsidiary of such
specified Person to the extent the transfer to that Person of that income is
restricted by contract or otherwise, except for any cash dividends or cash
distributions actually paid by such Restricted Subsidiary to such Person during
such period; (iv) the net income (or loss) of any other Person in which such
specified Person or any of its Restricted Subsidiaries has an interest (which
interest does not cause the net income of such other Person to be consolidated
with the net income of such specified Person in accordance with GAAP or is an
interest in a consolidated Unrestricted Subsidiary), except to the extent of the
amount of cash dividends or other cash distributions actually paid to such
Person or its consolidated Restricted Subsidiaries by such other Person during
such period; (v) for the purposes of "-- Certain Covenants -- Limitation on
Restricted Payments" only, the net income of any Person acquired by such
specified Person or any of its Restricted Subsidiaries in a pooling-of-interests
transaction for any period prior to the date of such acquisition; (vi) any gain
or loss, net of taxes, realized on the termination of any employee pension
benefit plan; (vii) any adjustments of a deferred tax liability or asset
pursuant to Statement of Financial Accounting Standards No. 109 which result
from changes in enacted tax laws or rates; (viii) the cumulative effect of a
change in accounting principles; (ix) any write-downs of non-current assets,
provided that any ceiling limitation write-downs under Commission guidelines
shall be treated as capitalized costs, as if such write-downs had not occurred;
and (x) any non-cash compensation expense realized for grants of performance
shares, stock options or stock awards to officers, directors and employees of
the Company or any of its Restricted Subsidiaries.
"Consolidated Net Worth" of any Person means the stockholders' equity of
such Person and its Restricted Subsidiaries, as determined on a consolidated
basis in accordance with GAAP, less (to the extent included in stockholders'
equity) amounts attributable to Redeemable Stock of such Person or its
Restricted Subsidiaries.
"Default" means any event, act or condition the occurrence of which is, or
after notice or the passage of time or both would be, an Event of Default.
"Designated Senior Indebtedness" means (i) the Bank Credit Facilities and
(ii) any other Senior Indebtedness of the Company which has, at the time of
determination, an aggregate principal amount outstanding of at least $10.0
million that is specifically designated in the instrument evidencing such Senior
Indebtedness and is designated in a notice delivered by the Company to the
holders or a Representative of the holders of such Senior Indebtedness and the
Trustee as "Designated Senior Indebtedness" of the Company.
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"Dollar-Denominated Production Payments" means production payment
obligations recorded as liabilities in accordance with GAAP, together with all
undertakings and obligations in connection therewith.
"EBITDA" means with respect to any Person for any period, the Consolidated
Net Income of such Person for such period, plus (i) the sum of, to the extent
reflected in the consolidated income statement of such Person and its Restricted
Subsidiaries for such period from which Consolidated Net Income is determined
and deducted in the determination of such Consolidated Net Income, without
duplication: (a) income tax expense (but excluding income tax expense relating
to sales or other dispositions of Property, including the Capital Stock of any
other Person, the gains from which are excluded in the determination of such
Consolidated Net Income), (b) Consolidated Interest Expense, (c) depreciation
and depletion expense, (d) amortization expense, (e) exploration expense (if
applicable to the Company after the Issue Date) and (f) any other noncash
charges including unrealized foreign exchange (excluding, however, any such
other noncash charge which requires an accrual of or reserve for cash charges
for any future period) less (ii) the sum of, to the extent reflected in the
consolidated income statement of such Person and its Restricted Subsidiaries for
such period from which Consolidated Net Income is determined and added in the
determination of such Consolidated Net Income, without duplication (a) income
tax recovery (excluding, however, income tax recovery relating to sales or other
dispositions of Property, including the Capital Stock of any other Person, the
losses from which are excluded in the determination of such Consolidated Net
Income) and (b) unrealized foreign exchange gains.
"Equity Offering" means a bona fide underwritten sale to the public of
common stock of the Company pursuant to a registration statement (other than a
Form S-8 or any other form relating to securities issuable under any employee
benefit plan of the Company) that is declared effective by the Commission
following the Issue Date.
"Exchanged Properties" means properties or assets used or useful in the Oil
and Gas Business received by the Company or a Restricted Subsidiary in trade or
as a portion of the total consideration for other such properties or assets.
"Exchange Rate Contract" means, with respect to any Person, any currency
swap agreements, forward exchange rate agreements, foreign currency futures or
options, exchange rate collar agreements, exchange rate insurance and other
agreements or arrangements, or any combination thereof, entered into by such
Person in the ordinary course of its business for the purpose of limiting or
managing exchange rate risks to which such Person is subject.
"Fair Market Value" means, with respect to any assets to be transferred
pursuant to any Asset Sale or Sale and Leaseback Transaction or any noncash
consideration or property transferred or received by any Person, the fair market
value of such consideration or other property as determined by (i) any officer
of the Company if such fair market value is less than $5.0 million and (ii) the
Board of Directors of the Company as evidenced by a certified resolution
delivered to the Trustee if such fair market value is equal to or in excess of
$5.0 million.
"GAAP" means United States generally accepted accounting principles as in
effect on the date of the Indenture, unless stated otherwise.
"Guarantee" by any Person means any obligation, contingent or otherwise, of
such Person guaranteeing or having the economic effect of guaranteeing any
Indebtedness of any other Person (the "primary obligor") in any manner, whether
directly or indirectly, and including any Lien on the assets of such Person
securing obligations to pay Indebtedness of the primary obligor and any
obligation of such Person (i) to purchase or pay (or advance or supply funds for
the purchase or payment of) such Indebtedness or to purchase (or to advance or
supply funds for the purchase or payment of) any security for the payment of
such Indebtedness, (ii) to purchase Property, securities or services for the
purpose of assuring the holder of such Indebtedness of the payment of such
Indebtedness or (iii) to maintain working capital, equity capital or other
financial statement condition or liquidity of the primary
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obligor so as to enable the primary obligor to pay such Indebtedness (and
"Guaranteed", "Guaranteeing" and "Guarantor" shall have meanings correlative to
the foregoing); provided, however, that a Guarantee by any Person shall not
include (a) endorsements by such Person for collection or deposit, in either
case, in the ordinary course of business or (b) a contractual commitment by one
Person to invest in another Person for so long as such Investment is reasonably
expected to constitute a Permitted Investment under clause (ii) of the
definition of Permitted Investments.
"Holder" means the Person in whose name a Note is registered on the
Securities Register.
"Incur" means, with respect to any Indebtedness or other obligation of any
Person, to create, issue, incur (by conversion, exchange or otherwise), assume,
Guarantee or become liable in respect of such Indebtedness or other obligation
or the recording, as required pursuant to GAAP or otherwise, of any such
Indebtedness or obligation on the balance sheet of such Person (and
"Incurrence", "Incurred", "Incurrable" and "Incurring" shall have meanings
correlative to the foregoing); provided, however, that a change in GAAP that
results in an obligation of such Person that exists at such time, and is not
theretofore classified as Indebtedness, becoming Indebtedness shall not be
deemed an Incurrence of such Indebtedness. For purposes of this definition,
Indebtedness of the Company or a Restricted Subsidiary held by a Wholly Owned
Subsidiary shall be deemed to be Incurred by the Company or such Restricted
Subsidiary in the event such Wholly Owned Subsidiary ceases to be a Wholly Owned
Subsidiary or in the event such Indebtedness is transferred to a Person other
than the Company or a Wholly Owned Subsidiary. For purposes of this definition,
any non-interest bearing or other discount Indebtedness shall be deemed to have
been Incurred (in an amount equal to its aggregate principal amount at its
Stated Maturity) only on the date of original issue thereof.
"Indebtedness" means at any time (without duplication), with respect to any
Person, whether recourse is to all or a portion of the assets of such Person,
and whether or not contingent, (i) any obligation of such Person for borrowed
money, (ii) any obligation of such Person evidenced by bonds, debentures, notes,
Guarantees or other similar instruments, including any such obligations Incurred
in connection with the acquisition of Property, assets or businesses, (iii) any
reimbursement obligation of such Person with respect to letters of credit,
bankers' acceptances or similar facilities issued for the account of such
Person, (iv) any obligation of such Person issued or assumed as the deferred
purchase price of Property or services (other than Trade Accounts Payable), (v)
any Capital Lease Obligation of such Person, (vi) the maximum fixed redemption
or repurchase price of Redeemable Stock of such Person at the time of
determination, (vii) any payment obligation of such Person under Exchange Rate
Contracts, Interest Rate Protection Agreements, Oil and Gas Hedging Contracts or
under any similar agreements or instruments, (viii) any obligation to pay rent
or other payment amounts of such Person with respect to any Sale and Leaseback
Transaction to which such Person is a party and (ix) any obligation of the type
referred to in clauses (i) through (viii) of this paragraph of another Person
and all dividends of another Person the payment of which, in either case, such
Person has Guaranteed or is responsible or liable, directly or indirectly, as
obligor, Guarantor or otherwise; provided, however, that Indebtedness shall not
include Production Payments and Reserve Sales. For purposes of this definition,
the maximum fixed repurchase price of any Redeemable Stock that does not have a
fixed repurchase price shall be calculated in accordance with the terms of such
Redeemable Stock as if such Redeemable Stock were repurchased on any date on
which Indebtedness shall be required to be determined pursuant to the Indenture;
provided, however, that if such Redeemable Stock is not then permitted to be
repurchased, the repurchase price shall be the book value of such Redeemable
Stock. The amount of Indebtedness of any Person at any date shall be the
outstanding balance at such date of all unconditional obligations as described
above and the maximum liability at such date in respect of any contingent
obligations described above.
"Interest Rate Protection Agreement" means, with respect to any Person, any
interest rate swap agreement, forward rate agreement, interest rate cap or
collar agreement or other financial agreement or arrangement entered into by
such Person in the ordinary course of its business for the purpose of limiting
or managing interest rate risks to which such Person is subject.
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"Investment" means, with respect to any Person (i) any amount paid by such
Person, directly or indirectly, to any other Person for Capital Stock or other
Property of, or as a capital contribution to, any other Person or (ii) any
direct or indirect loan or advance to any other Person (other than accounts
receivable of such Person arising in the ordinary course of business); provided,
however, that Investments shall not include (a) in the case of clause (i) as
used in the definition of "Restricted Payments" only, any such amount paid
through the issuance of Capital Stock of the Company and (b) in the case of
clause (i) or (ii), extensions of trade credit on commercially reasonable terms
in accordance with normal trade practices and any increase in the equity
ownership in any Person resulting from retained earnings of such Person.
"Issue Date" means the date on which the Offered Notes first were issued
under the Indenture.
"Lien" means, with respect to any Property, any mortgage or deed of trust,
pledge, hypothecation, assignment, deposit arrangement, security interest, lien
(statutory or other), charge, easement, encumbrance, preference, priority or
other security or similar agreement or preferential arrangement of any kind or
nature whatsoever on or with respect to such Property (including any conditional
sale or other title retention agreement having substantially the same economic
effect as any of the foregoing). For purposes of the provisions of the Indenture
described under "-- Certain Covenants -- Limitation on Liens," a Capital Lease
Obligation shall be deemed to be secured by a Lien on the property being leased.
"Liquid Securities" means securities (i) of an issuer that is not an
Affiliate of the Company, (ii) that are publicly traded on the New York Stock
Exchange, the American Stock Exchange or the Nasdaq National Market and (iii) as
to which the Company is not subject to any restrictions on sale or transfer
(including any volume restrictions under Rule 144 under the Securities Act or
any other restrictions imposed by the Securities Act) or as to which a
registration statement under the Securities Act covering the resale thereof is
in effect for as long as the securities are held; provided that securities
meeting the requirements of clauses (i), (ii) and (iii) above shall be treated
as Liquid Securities from the date of receipt thereof until and only until the
earlier of (x) the date on which such securities are sold or exchanged for cash
or Permitted Short-Term Investments and (y) 150 days following the date of
receipt of such securities. If such securities are not sold or exchanged for
cash or Permitted Short-Term Investments within 120 days of receipt thereof, for
purposes of determining whether the transaction pursuant to which the Company or
a Restricted Subsidiary received the securities was in compliance with the
provisions of the Indenture described under "-- Certain Covenants -- Limitation
on Asset Sales," such securities shall be deemed not to have been Liquid
Securities at any time.
"Material Change" means an increase or decrease (except to the extent
resulting from changes in prices) of more than 30% during a fiscal quarter in
the estimated discounted future net revenues from proved oil and gas reserves of
the Company and its Restricted Subsidiaries, calculated in accordance with
clause (i)(a) of the definition of Adjusted Consolidated Net Tangible Assets;
provided, however, that the following will be excluded from the calculation of
Material Change: (i) any acquisitions during the quarter of oil and gas reserves
with respect to which the Company's estimate of the discounted future net
revenues from proved oil and gas reserves has been confirmed by independent
petroleum engineers; and (ii) any dispositions of Properties during such quarter
that were disposed of in compliance with the provisions of the Indenture
described under "-- Certain Covenants -- Limitation on Asset Sales."
"Moody's" means Moody's Investors Service, Inc. and its successors.
"Net Available Cash" from an Asset Sale means cash proceeds received
therefrom (including (i) any cash proceeds received by way of deferred payment
of principal pursuant to a note or installment receivable or otherwise, but only
as and when received and (ii) the Fair Market Value of Liquid Securities and
Permitted Short-Term Investments, and excluding (a) any other consideration
received in the form of assumption by the acquiring Person of Indebtedness or
other obligations relating to the Property that is the subject of such Asset
Sale and (b) except to the extent subsequently converted to cash, Liquid
Securities or Permitted Short-Term Investments within 240 days after such Asset
Sale, consideration constituting Exchanged Properties or consideration other
than as identified in the immediately preceding clauses (i) and (ii)), in each
case net of (a) all legal, title and recording expenses, commissions and
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other fees and expenses incurred, and all federal, state, foreign and local
taxes required to be paid or accrued as a liability under GAAP as a consequence
of such Asset Sale, (b) all payments made on any Indebtedness (but specifically
excluding Indebtedness of the Company and its Restricted Subsidiaries assumed in
connection with or in anticipation of such Asset Sale) which is secured by any
assets subject to such Asset Sale, in accordance with the terms of any Lien upon
such assets, or which must by its terms, or in order to obtain a necessary
consent to such Asset Sale or by applicable law, be repaid out of the proceeds
from such Asset Sale, provided that such payments are made in a manner that
results in the permanent reduction in the balance of such Indebtedness and, if
applicable, a permanent reduction in any outstanding commitment for future
incurrences of Indebtedness thereunder, (c) all distributions and other payments
required to be made to minority interest holders in Subsidiaries or joint
ventures as a result of such Asset Sale and (d) the deduction of appropriate
amounts to be provided by the seller as a reserve, in accordance with GAAP,
against any liabilities associated with the assets disposed of in such Asset
Sale and retained by the Company or any Restricted Subsidiary after such Asset
Sale; provided, however, that if any consideration for an Asset Sale (which
would otherwise constitute Net Available Cash) is required to be held in escrow
pending determination of whether a purchase price adjustment will be made, such
consideration (or any portion thereof) shall become Net Available Cash only at
such time as it is released to such Person or its Restricted Subsidiaries from
escrow.
"Net Working Capital" means (i) all current assets of the Company and its
Restricted Subsidiaries, less (ii) all current liabilities of the Company and
its Restricted Subsidiaries, except current liabilities included in
Indebtedness, in each case as set forth in consolidated financial statements of
the Company prepared in accordance with GAAP.
"Non-recourse Purchase Money Indebtedness" means Indebtedness (other than
Capital Lease Obligations) of the Company or any Subsidiary Guarantor incurred
in connection with the acquisition by the Company or such Subsidiary Guarantor
in the ordinary course of business of fixed assets used in the Oil and Gas
Business (including office buildings and other real property used by the Company
or such Subsidiary Guarantor in conducting its operations) with respect to which
(i) the holders of such Indebtedness agree that they will look solely to the
fixed assets so acquired which secure such Indebtedness, and neither the Company
nor any Restricted Subsidiary (a) is directly or indirectly liable for such
Indebtedness or (b) provides credit support, including any undertaking,
Guarantee, agreement or instrument that would constitute Indebtedness (other
than the grant of a Lien on such acquired fixed assets), and (ii) no default or
event of default with respect to such Indebtedness would cause, or permit (after
notice or passage of time or otherwise), any holder of any other Indebtedness of
the Company or a Subsidiary Guarantor to declare a default or event of default
on such other Indebtedness or cause the payment, repurchase, redemption,
defeasance or other acquisition or retirement for value thereof to be
accelerated or payable prior to any scheduled principal payment, scheduled
sinking fund payment or maturity.
"Oil and Gas Business" means the business of exploiting, exploring for,
developing, acquiring, operating, producing, processing, gathering, marketing,
storing, selling, hedging, treating, swapping, refining and transporting
hydrocarbons and other related energy businesses.
"Oil and Gas Hedging Contract" means, with respect to any Person, any
agreement or arrangement, or any combination thereof, relating to oil and gas or
other hydrocarbon prices, transportation or basis costs or differentials or
other similar financial factors, that is customary in the Oil and Gas Business
and is entered into by such Person in the ordinary course of its business for
the purpose of limiting or managing risks associated with fluctuations in such
prices, costs, differentials or similar factors.
"Oil and Gas Liens" means (i) Liens on any specific property or any
interest therein, construction thereon or improvement thereto to secure all or
any part of the costs incurred for surveying, exploration, drilling, extraction,
development, operation, production, construction, alteration, repair or
improvement of, in, under or on such property and the plugging and abandonment
of wells located thereon (it being understood that, in the case of oil and gas
producing properties, or any interest therein, costs incurred for "development"
shall include costs incurred for all facilities relating to such properties or
to projects,
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ventures or other arrangements of which such properties form a part or which
relate to such properties or interests); (ii) Liens on an oil or gas producing
property to secure obligations incurred or guarantees of obligations incurred in
connection with or necessarily incidental to commitments for the purchase or
sale of, or the transportation or distribution of, the products derived from
such property; (iii) Liens arising under partnership agreements, oil and gas
leases, overriding royalty agreements, net profits agreements, production
payment agreements, royalty trust agreements, incentive compensation programs
for geologists, geophysicists and other providers of technical services to the
Company or a Restricted Subsidiary, master limited partnership agreements,
farmout agreements, farmin agreements, division orders, contracts for the sale,
purchase, exchange, transportation, gathering or processing of oil, gas or other
hydrocarbons, unitizations and pooling designations, declarations, orders and
agreements, development agreements, operating agreements, production sales
contracts, area of mutual interest agreements, gas balancing or deferred
production agreements, injection, repressuring and recycling agreements, salt
water or other disposal agreements, seismic or geophysical permits or
agreements, and other agreements which are customary in the Oil and Gas
Business; provided, however, in all instances that such Liens are limited to the
assets that are the subject of the relevant agreement, program, order or
contract; (iv) Liens arising in connection with Production Payments and Reserve
Sales; and (v) Liens on pipelines or pipeline facilities that arise by operation
of law.
"Pari Passu Indebtedness" means any Indebtedness of the Company (or a
Subsidiary Guarantor) that is pari passu in right of payment to the Notes (or a
Subsidiary Guaranty, as appropriate).
"Pari Passu Offer" means an offer by the Company or a Subsidiary Guarantor
to purchase all or a portion of Pari Passu Indebtedness to the extent required
by the indenture or other agreement or instrument pursuant to which such Pari
Passu Indebtedness was issued.
"Permitted Business Investments" means Investments and expenditures made in
the ordinary course of, and of a nature that is or shall have become customary
in, the Oil and Gas Business as a means of actively engaging therein through
agreements, transactions, interests or arrangements which permit one to share
risks or costs, comply with regulatory requirements regarding local ownership or
satisfy other objectives customarily achieved through the conduct of Oil and Gas
Business jointly with third parties, including (i) ownership interests in oil
and gas properties or gathering, transportation, processing, storage or related
systems and (ii) Investments and expenditures in the form of or pursuant to
operating agreements, processing agreements, farmin agreements, farmout
agreements, development agreements, area of mutual interest agreements,
unitization agreements, pooling arrangements, joint bidding agreements, service
contracts, joint venture agreements, partnership agreements (whether general or
limited) and other similar agreements (including for limited liability
companies) with third parties, excluding, however, Investments in corporations
other than Restricted Subsidiaries.
"Permitted Hedging Agreements" means (i) Exchange Rate Contracts and Oil
and Gas Hedging Contracts and (ii) Interest Rate Protection Agreements but only
to the extent that the stated aggregate notional amount thereunder does not
exceed 100% of the aggregate principal amount of the Indebtedness of the Company
or a Restricted Subsidiary covered by such Interest Rate Protection Agreements
at the time such agreements were entered into.
"Permitted Investments" means any and all of the following: (i) Permitted
Short-Term Investments; (ii) Investments in property, plant and equipment used
in the ordinary course of business and Permitted Business Investments; (iii)
Investments by any Restricted Subsidiary in the Company; (iv) Investments by the
Company or any Restricted Subsidiary in any Restricted Subsidiary; (v)
Investments by the Company or any Restricted Subsidiary in (a) any Person that
will, upon the making of such Investment, become a Restricted Subsidiary or (b)
any Person if as a result of such Investment such Person is merged or
consolidated with or into, or transfers or conveys all or substantially all its
Property to, the Company or a Restricted Subsidiary; (vi) Investments in the
form of securities received from Asset Sales, provided that such Asset Sales are
made in compliance with the provisions of the Indenture described under
"-- Certain Covenants -- Limitation on Asset Sales;" (vii) Investments in
negotiable instruments held for collection; lease, utility and other similar
deposits; and stock, obligations or other securities
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received in settlement of debts (including under any bankruptcy or other similar
proceeding) owing to the Company or any of its Restricted Subsidiaries as a
result of foreclosure, perfection or enforcement of any Liens or Indebtedness,
in each of the foregoing cases in the ordinary course of business of the Company
or such Restricted Subsidiary; (viii) relocation allowances for, and advances
and loans to, officers, directors and employees of the Company or any of its
Restricted Subsidiaries made in the ordinary course of business; provided such
items do not exceed in the aggregate $2.0 million at any one time outstanding;
(ix) Investments intended to promote the Company's strategic objectives in the
Oil and Gas Business in an amount not to exceed 5% of Adjusted Consolidated Net
Tangible Assets (determined as of the date of the making of any such Investment)
at any one time outstanding (which Investments shall be deemed to be no longer
outstanding only upon the return of capital thereof); (x) Investments made
pursuant to Permitted Hedging Agreements of the Company and its Restricted
Subsidiaries; and (xi) Investments pursuant to any agreement or obligation of
the Company or any of its Restricted Subsidiaries as in effect on the Issue Date
(other than Investments described in clauses (i) through (x) above).
"Permitted Liens" means any and all of the following: (i) Liens existing as
of the Issue Date; (ii) Liens securing the Notes, any Subsidiary Guaranties and
other obligations arising under the Indenture; (iii) any Lien existing on any
Property of a Person at the time such Person is merged or consolidated with or
into the Company or a Restricted Subsidiary or becomes a Restricted Subsidiary
(and not incurred in anticipation of or in connection with such transaction),
provided that such Liens are not extended to other Property of the Company or
the Restricted Subsidiaries; (iv) any Lien existing on any Property at the time
of the acquisition thereof (and not incurred in anticipation of or in connection
with such transaction), provided that such Liens are not extended to other
Property of the Company or the Restricted Subsidiaries; (v) any Lien incurred in
the ordinary course of business incidental to the conduct of the business of the
Company or the Restricted Subsidiaries or the ownership of their Property
(including (a) easements, rights of way and similar encumbrances, (b) rights or
title of lessors under leases (other than Capital Lease Obligations), (c) rights
of collecting banks having rights of setoff, revocation, refund or chargeback
with respect to money or instruments of the Company or the Restricted
Subsidiaries on deposit with or in the possession of such banks, (d) Liens
imposed by law, including Liens under workers' compensation or similar
legislation and mechanics', carriers', warehousemen's, materialmen's, suppliers'
and vendors' Liens, (e) Liens incurred to secure performance of obligations with
respect to statutory or regulatory requirements, performance or return-of-money
bonds, surety bonds or other obligations of a like nature and incurred in a
manner consistent with industry practice and (f) Oil and Gas Liens), in each
case which are not incurred in connection with the borrowing of money, the
obtaining of advances or credit or the payment of the deferred purchase price of
Property (other than Trade Accounts Payable); (vi) Liens for taxes, assessments
and governmental charges not yet due or the validity of which are being
contested in good faith by appropriate proceedings, promptly instituted and
diligently conducted, and for which adequate reserves have been established to
the extent required by GAAP as in effect at such time; (vii) Liens incurred to
secure appeal bonds and judgment and attachment Liens, in each case in
connection with litigation or legal proceedings that are being contested in good
faith by appropriate proceedings so long as reserves have been established to
the extent required by GAAP as in effect at such time and so long as such Liens
do not encumber assets by an aggregate amount (together with the amount of any
unstayed judgments against the Company or any Restricted Subsidiary but
excluding any such Liens to the extent securing insured or indemnified judgments
or orders) in excess of $20.0 million; (viii) Liens securing Permitted Hedging
Agreements of the Company and its Restricted Subsidiaries so long as such
Permitted Hedging Agreements are permitted under the provisions of the Indenture
described under "-- Limitation on Indebtedness;" (ix) Liens securing Purchase
Money Indebtedness or Capital Lease Obligations, provided that such Liens attach
only to the Property acquired with the proceeds of such Purchase Money
Indebtedness or Capital Lease Obligations; (x) Liens securing Non-recourse
Purchase Money Indebtedness granted in connection with the acquisition by the
Company or any Subsidiary Guarantor in the ordinary course of business of fixed
assets used in the Oil and Gas Business (including office buildings and other
real property used by the Company or such Subsidiary Guarantor in conducting its
operations), provided that
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(a) such Liens attach only to the fixed assets acquired with the proceeds of
such Non-recourse Purchase Money Indebtedness and (b) such Non-recourse Purchase
Money Indebtedness is not in excess of the purchase price of such fixed assets;
(xi) Liens resulting from the deposit of funds or evidences of Indebtedness in
trust for the purpose of decreasing or legally defeasing Indebtedness of the
Company or any of its Subsidiaries so long as such deposit of funds is permitted
by the provisions of the Indenture described under "-- Limitation on Restricted
Payments;" (xii) Liens resulting from a pledge of Capital Stock of a Person that
is not a Restricted Subsidiary to secure obligations of such Person and any
refinancings thereof; (xiii) Liens to secure any permitted extension, renewal,
refinancing, refunding or exchange (or successive extensions, renewals,
refinancings, refundings or exchanges), in whole or in part, of or for any
Indebtedness secured by Liens referred to in clauses (i), (ii), (iii), (iv),
(ix) and (x) above; provided, however, that (a) such new Lien shall be limited
to all or part of the same Property (including future improvements thereon and
accessions thereto) subject to the original Lien and (b) the Indebtedness
secured by such Lien at such time is not increased to any amount greater than
the sum of (1) the outstanding principal amount or, if greater, the committed
amount of the Indebtedness secured by such original Lien immediately prior to
such extension, renewal, refinancing, refunding or exchange and (2) an amount
necessary to pay any fees and expenses, including premiums, related to such
refinancing, refunding, extension, renewal or replacement; (xiv) Liens in favor
of the Company or a Restricted Subsidiary; and (xv) Liens not otherwise
permitted by clauses (i) through (xiv) above incurred in the ordinary course of
business of the Company and its Restricted Subsidiaries and encumbering Property
having an aggregate Fair Market Value not in excess of $5.0 million at any one
time. Notwithstanding anything in this paragraph to the contrary, the term
"Permitted Liens" does not include Liens resulting from the creation,
incurrence, issuance, assumption or Guarantee of any Production Payments and
Reserve Sales other than (a) any such Liens existing as of the Issue Date, (b)
Production Payments and Reserve Sales in connection with the acquisition of any
Property after the Issue Date, provided that any such Lien created in connection
therewith is created, incurred, issued, assumed or guaranteed in connection with
the financing of, and within 60 days after the acquisition of, such Property,
(c) Production Payments and Reserve Sales, other than those described in clauses
(a) and (b) of this sentence, to the extent such Production Payments and Reserve
Sales constitute Asset Sales made pursuant to and in compliance with the
provisions of the Indenture described under "-- Limitation on Asset Sales" and
(d) incentive compensation programs for geologists, geophysicists and other
providers of technical services to the Company or a Restricted Subsidiary;
provided, however, that, in the case of the immediately foregoing clauses (a),
(b), (c) and (d), any Lien created in connection with any such Production
Payments and Reserve Sales shall be limited to the Property that is the subject
of such Product Payments and Reserve Sales.
"Permitted Refinancing Indebtedness" means Indebtedness ("new
Indebtedness") Incurred in exchange for, or proceeds of which are used to
refinance, other Indebtedness ("old Indebtedness"); provided, however, that (i)
such new Indebtedness is in an aggregate principal amount not in excess of the
sum of (a) the aggregate principal amount then outstanding of the old
Indebtedness (or, if such old Indebtedness provides for an amount less than the
principal amount thereof to be due and payable upon a declaration of
acceleration thereof, such lesser amount as of the date of determination), and
(b) an amount necessary to pay any fees and expenses, including premiums,
related to such exchange or refinancing, (ii) such new Indebtedness has a Stated
Maturity no earlier than the Stated Maturity of the old Indebtedness, (iii) such
new Indebtedness has an Average Life at the time such new Indebtedness is
Incurred that is equal to or greater than the Average Life of the old
Indebtedness at such time, (iv) such new Indebtedness is subordinated in right
of payment to the Notes (or, if applicable, the Subsidiary Guaranties) to at
least the same extent, if any, as the old Indebtedness and (v) if such old
Indebtedness is Non-recourse Purchase Money Indebtedness or Indebtedness that
refinanced Non-recourse Purchase Money Indebtedness, such new Indebtedness
satisfies clauses (i) and (ii) of the definition of "Non-recourse Purchase Money
Indebtedness."
"Permitted Short-Term Investments" means (i) Investments in U.S. Government
Obligations maturing within one year of the date of acquisition thereof, (ii)
Investments in demand accounts, time deposit accounts, certificates of deposit,
bankers' acceptances and money market deposits maturing within one
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year of the date of acquisition thereof issued by a bank or trust company which
is organized under the laws of the United States of America or any State thereof
or the District of Columbia that is a member of the Federal Reserve System
having capital, surplus and undivided profits aggregating in excess of $500.0
million and whose long-term Indebtedness is rated "A" (or higher) according to
Moody's, (iii) Investments in deposits available for withdrawal on demand with
any commercial bank that is organized under the laws of any country in which the
Company or any Restricted Subsidiary maintains an office or is engaged in the
Oil and Gas Business, provided that (a) all such deposits have been made in such
accounts in the ordinary course of business and (b) such deposits do not at any
one time exceed $15.0 million in the aggregate, (iv) repurchase and reverse
repurchase obligations with a term of not more than seven days for underlying
securities of the types described in clause (i) entered into with a bank meeting
the qualifications described in clause (ii), (v) Investments in commercial paper
or notes, maturing not more than one year after the date of acquisition, issued
by a corporation (other than an Affiliate of the Company) organized and in
existence under the laws of the United States of America or any State thereof or
the District of Columbia with a short-term rating at the time as of which any
Investment therein is made of "P-1" (or higher) according to Moody's or "A-1"
(or higher) according to S&P or a long-term rating at the time as of which any
Investment is made of "A3" (or higher) according to Moody's or "A-" (or higher)
according to S&P, (vi) Investments in any money market mutual fund having assets
in excess of $250.0 million all of which consist of other obligations of the
types described in clauses (i), (ii), (iv) and (v) hereof and (vii) Investments
in asset-backed securities maturing within one year of the date of acquisition
thereof with a long-term rating at the time as of which any Investment therein
is made of "A3" (or higher) according to Moody's or "A-" (or higher) according
to S&P.
"Person" means any individual, corporation, partnership, joint venture,
limited liability company, unlimited liability company, trust, estate,
unincorporated organization or government or any agency or political subdivision
thereof.
"Preferred Stock" of any Person means Capital Stock of such Person of any
class or classes (however designated) that ranks prior, as to the payment of
dividends or as to the distribution of assets upon any voluntary or involuntary
liquidation, dissolution or winding up of such Person, to shares of Capital
Stock of any other class of such Person; provided, however, that "Preferred
Stock" shall not include Redeemable Stock.
"Principal" of any Indebtedness (including the Notes) means the principal
amount of such Indebtedness plus the premium, if any, on such Indebtedness.
"Production Payments and Reserve Sales" means the grant or transfer by the
Company or a Restricted Subsidiary to any Person of a royalty, overriding
royalty, net profits interest, production payment (whether volumetric or dollar
denominated), partnership or other interest in oil and gas properties, reserves
or the right to receive all or a portion of the production or the proceeds from
the sale of production attributable to such properties where the holder of such
interest has recourse solely to such production or proceeds of production,
subject to the obligation of the grantor or transferor to operate and maintain,
or cause the subject interests to be operated and maintained, in a reasonably
prudent manner or other customary standard or subject to the obligation of the
grantor or transferor to indemnify for environmental, title or other matters
customary in the Oil and Gas Business, including any such grants or transfers
pursuant to incentive compensation programs on terms that are reasonably
customary in the Oil and Gas Business for geologists, geophysicists and other
providers of technical services to the Company or a Restricted Subsidiary.
"Property" means, with respect to any Person, any interest of such Person
in any kind of property or asset, whether real, personal or mixed, or tangible
or intangible, including Capital Stock and other securities issued by any other
Person (but excluding Capital Stock or other securities issued by such first
mentioned Person).
"Redeemable Stock" of any Person means any equity security of such Person
that by its terms (or by the terms of any security into which it is convertible
or for which it is exchangeable), or otherwise (including on the happening of an
event), is or could become required to be redeemed for cash or other
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Property or is or could become redeemable for cash or other Property at the
option of the holder thereof, in whole or in part, on or prior to the first
anniversary of the Stated Maturity of the Notes; or is or could become
exchangeable at the option of the holder thereof for Indebtedness at any time in
whole or in part, on or prior to the first anniversary of the Stated Maturity of
the Notes; provided, however, that Redeemable Stock shall not include any
security by virtue of the fact that it may be exchanged or converted at the
option of the holder for Capital Stock of the Company having no preference as to
dividends or liquidation over any other Capital Stock of the Company.
"Representative" means the trustee, agent or representative expressly
authorized to act in such capacity, if any, for an issue of Senior Indebtedness.
"Restricted Payment" means (i) a dividend or other distribution declared or
paid on the Capital Stock or Redeemable Stock of the Company or to the Company's
shareholders (other than dividends, distributions or payments made solely in
Capital Stock of the Company or in options, warrants or other rights to purchase
or acquire Capital Stock), or declared and paid to any Person other than the
Company or any of its Restricted Subsidiaries (and, if such Restricted
Subsidiary is not a Wholly Owned Subsidiary, to the other shareholders of such
Restricted Subsidiary on a pro rata basis) on the Capital Stock or Redeemable
Stock of any Restricted Subsidiary, (ii) a payment made by the Company or any of
its Restricted Subsidiaries (other than to the Company or any Restricted
Subsidiary) to purchase, redeem, acquire or retire any Capital Stock or
Redeemable Stock, or any options, warrants or other rights to acquire Capital
Stock or Redeemable Stock, of the Company or of a Restricted Subsidiary, (iii) a
payment made by the Company or any of its Restricted Subsidiaries to redeem,
repurchase, legally defease or otherwise acquire or retire for value (including
pursuant to mandatory repurchase covenants), prior to any scheduled maturity,
scheduled sinking fund or scheduled mandatory redemption, any Indebtedness of
the Company or a Restricted Subsidiary which is subordinate (whether pursuant to
its terms or by operation of law) in right of payment to the Notes or the
relevant Subsidiary Guaranty, as the case may be, provided that this clause
(iii) shall not include any such payment with respect to (a) any such
subordinated Indebtedness to the extent of Excess Proceeds remaining after
compliance with the provisions of the Indenture described under "-- Certain
Covenants -- Limitation on Asset Sales" and to the extent required by the
indenture or other agreement or instrument pursuant to which such subordinated
Indebtedness was issued or (b) the purchase, repurchase or other acquisition of
any such subordinated Indebtedness purchased in anticipation of satisfying a
scheduled maturity, scheduled sinking fund or scheduled mandatory redemption, in
each case due within one year of the date of acquisition, or (iv) an Investment
(other than a Permitted Investment) by the Company or a Restricted Subsidiary in
any Person.
"Restricted Subsidiary" means any Subsidiary of the Company that has not
been designated an Unrestricted Subsidiary pursuant to the provision of the
Indenture described under "-- Certain Covenants -- Restricted and Unrestricted
Subsidiaries."
"S&P" means Standard & Poor's Ratings Service, a division of The
McGraw-Hill Companies, Inc., and its successors.
"Sale and Leaseback Transaction" means, with respect to any Person, any
direct or indirect arrangement (excluding, however, any such arrangement between
such Person and a Wholly Owned Subsidiary of such Person or between one or more
Wholly Owned Subsidiaries of such Person) pursuant to which Property is sold or
transferred by such Person or a Restricted Subsidiary of such Person and is
thereafter leased back from the purchaser or transferee thereof by such Person
or one of its Restricted Subsidiaries.
"Senior Indebtedness" when used with respect to the Company means the
obligations of the Company with respect to Indebtedness of the Company, whether
outstanding on the date of the Indenture or thereafter created, Incurred or
assumed, and any renewal, refunding, refinancing, replacement or extension
thereof, unless, in the case of any particular Indebtedness, the instrument
creating or evidencing the same or pursuant to which the same is outstanding
expressly provides that such Indebtedness shall not be senior in right of
payment to the Notes; provided, however, that Senior
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Indebtedness of the Company shall not include (i) Indebtedness of the Company to
a Subsidiary of the Company, (ii) amounts owed for goods, materials or services
purchased in the ordinary course of business, (iii) Indebtedness Incurred in
violation of the Indenture, (iv) amounts payable or any other Indebtedness to
employees of the Company or any Subsidiary of the Company, (v) any liability for
federal, state, local or other taxes owed or owing by the Company, (vi) any
Indebtedness of the Company that, when Incurred and without regard to any
election under Section 1111(b) of the United States Bankruptcy Code, was without
recourse to the Company, (vii) Pari Passu or Subordinated Indebtedness of the
Company, (viii) Indebtedness of the Company that is represented by Redeemable
Stock, (ix) Indebtedness evidenced by the Notes and (x) in-kind obligations
relating to net oil and gas balancing positions. "Senior Indebtedness" of any
Subsidiary Guarantor has a correlative meaning.
"Significant Subsidiary" means, at any date of determination, any
Restricted Subsidiary that would be a "Significant Subsidiary" of the Company
within the meaning of Rule 1-02 under Regulation S-X promulgated by the
Commission.
"Stated Maturity," when used with respect to any security or any
installment of principal thereof or interest thereon, means the date specified
in such security as the fixed date on which the principal of such security or
such installment of principal or interest is due and payable, including pursuant
to any mandatory redemption provision (but excluding any provision providing for
the repurchase of such security at the option of the holder thereof upon the
happening of any contingency unless such contingency has occurred).
"Subordinated Indebtedness" means Indebtedness of the Company (or a
Subsidiary Guarantor) that is subordinated or junior in right of payment to the
Notes (or a Subsidiary Guaranty, as appropriate) pursuant to a written agreement
to that effect.
"Subsidiary" of a Person means (i) another Person which is a corporation a
majority of whose Voting Stock is at the time, directly or indirectly, owned or
controlled by (a) the first Person, (b) the first Person and one or more of its
Subsidiaries or (c) one or more of the first Person's Subsidiaries or (ii)
another Person which is not a corporation (x) at least 50% of the ownership
interest of which and (y) the power to elect or direct the election of a
majority of the directors or other governing body of which are controlled by
Persons referred to in clause (a), (b) or (c) above.
"Subsidiary Guarantors" means, unless released from their Subsidiary
Guaranties as permitted by the Indenture, any Restricted Subsidiary that becomes
a guarantor of the Notes in compliance with the provisions of the Indenture and
executes a supplemental indenture agreeing to be bound by the terms of the
Indenture.
"Subsidiary Guaranty" means an unconditional, unsecured senior subordinated
guaranty of the Notes given by any Restricted Subsidiary pursuant to the terms
of the Indenture.
"Trade Accounts Payable" means accounts payable or other obligations of the
Company or any Restricted Subsidiary to trade creditors created or assumed by
the Company or such Restricted Subsidiary in the ordinary course of business in
connection with the obtaining of goods or services.
"Unrestricted Subsidiary" means (i) each Subsidiary of the Company that the
Company has designated pursuant to the provision of the Indenture described
under "-- Certain Covenants -- Restricted and Unrestricted Subsidiaries" as an
Unrestricted Subsidiary and (ii) any Subsidiary of an Unrestricted Subsidiary.
"U.S. Government Obligations" means securities that are (i) direct
obligations of the United States of America for the timely payment of which its
full faith and credit is pledged or (ii) obligations of a Person controlled or
supervised by and acting as an agency or instrumentality of the United States of
America, the timely payment of which is unconditionally guaranteed as a full
faith and credit obligation by the United States of America which, in either
case, are not callable or redeemable at the option of the issuer thereof, and
shall also include a depository receipt issued by a bank (as defined in Section
3(a)(2) of the Securities Act), as custodian, with respect to any such U.S.
Government Obligation
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or a specific payment of principal of or interest on any such U.S. Government
Obligation held by such custodian for the account of the holder of such
depository receipt; provided, however, that (except as required by law) such
custodian is not authorized to make any deduction from the amount payable to the
holder of such depository receipt from any amount received by the custodian in
respect of the U.S. Government Obligation or the specific payment of principal
of or interest on the U.S. Government Obligation evidenced by such depository
receipt.
"Volumetric Production Payments" means production payment obligations
recorded as deferred revenue in accordance with GAAP, together with all
undertakings and obligations in connection therewith.
"Voting Stock" of any Person means Capital Stock of such Person which
ordinarily has voting power for the election of directors (or persons performing
similar functions) of such Person whether at all times or only so long as no
senior class of securities has such voting power by reason of any contingency.
"Wholly Owned Subsidiary" means, at any time, a Restricted Subsidiary of
the Company all the Voting Stock of which (other than directors' qualifying
shares) is at such time owned, directly or indirectly, by the Company and its
other Wholly Owned Subsidiaries.
DEFEASANCE AND COVENANT DEFEASANCE
The Indenture provides that the Company will be discharged from its
obligations with respect to the Notes (except for certain obligations to
exchange or register the transfer of Notes, to replace stolen, lost or mutilated
Notes, to maintain paying agencies and to hold moneys for payment in trust) upon
the deposit in trust for the benefit of the Holders of the Notes of money or
U.S. Government Obligations, or a combination thereof, which, through the
payment of principal, premium, if any, and interest in respect thereof in
accordance with their terms, will provide money in an amount sufficient to pay
the principal of and any premium and interest on the Notes at Stated Maturity
thereof or on earlier redemption in accordance with the terms of the Indenture
and the Notes. Such defeasance or discharge may occur only if, among other
things, the Company has delivered to the Trustee an Opinion of Counsel to the
effect that (i) the Company has received from, or there has been published by,
the United States Internal Revenue Service a ruling or (ii) since the date of
the Indenture there has been a change in the applicable federal income tax law,
in either case to the effect that Holders of the Notes will not recognize gain
or loss for federal income tax purposes as a result of such deposit, defeasance
and discharge and will be subject to federal income tax on the same amount, in
the same manner and at the same times as would have been the case if such
deposit, defeasance and discharge were not to occur; and that the resulting
trust will not be an "Investment Company" within the meaning of the Investment
Company Act of 1940 unless such trust is qualified thereunder or exempt from
regulation thereunder.
The Indenture provides that if the Company takes the actions described
below, it may omit to comply with certain covenants, including those described
under "-- Repurchase at the Option of Holders Upon a Change of Control,"
"-- Certain Covenants" and in clauses (iv) and (v) under the first paragraph and
in the second paragraph of "-- Merger, Consolidation and Sale of Substantially
All Assets," and the occurrence of the Events of Default described below in
clauses (iii) and (iv) (with respect to such covenants) and clauses (v), (vi),
(vii) (with respect to Significant Subsidiaries) and (viii) under "-- Events of
Default and Notice" will be deemed not to be or result in an Event of Default.
The Company, in order to exercise such option, will be required to deposit, in
trust for the benefit of the Holders of the Notes, money or U.S. Government
Obligations, or a combination thereof, which, through the payment of principal,
premium, if any, and interest in respect thereof in accordance with their terms,
will provide money in an amount sufficient to pay the principal of and any
premium and interest on the Notes at Stated Maturity thereof or on earlier
redemption in accordance with the terms of the Indenture and the Notes. The
Company will also be required, among other things, to deliver to the Trustee an
Opinion of Counsel to the effect that Holders of the Notes will not recognize
gain or loss for federal income tax purposes as a result of such deposit and
defeasance of certain obligations and will be subject to federal income tax on
the same amount, in the same manner and at the same times as would have been the
case if such deposit and defeasance were not to occur; and that the resulting
trust will not be an "Investment Company" within the meaning of the Investment
Company Act of 1940 unless such trust is
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qualified thereunder or exempt from regulation thereunder. If the Company were
to exercise this option and the Notes were declared due and payable because of
the occurrence of any Event of Default, the amount of money and U.S. Government
Obligations so deposited in trust would be sufficient to pay amounts due on the
Notes at the time of their Stated Maturity but may not be sufficient to pay
amounts due on the Notes upon any acceleration resulting from such Event of
Default. In such case, the Company would remain liable for such payments.
If the Company exercises either of the options described above, each
Subsidiary Guarantor, if any, will be released from all its obligations under
its Subsidiary Guaranty.
EVENTS OF DEFAULT AND NOTICE
The following are summaries of Events of Default under the Indenture with
respect to the Notes: (i) failure to pay any interest on the Notes when due,
continued for 30 days; (ii) failure to pay principal of (or premium, if any, on)
the Notes when due; (iii) failure to comply with the provisions of the Indenture
described under "Merger, Consolidation and Sale of Substantially All Assets;"
(iv) failure to perform any other covenant of the Company or any Subsidiary
Guarantor in the Indenture, continued for 60 days after written notice to the
Company from the Trustee or the Holders of at least 25% in aggregate principal
amount of the outstanding Notes; (v) a default by the Company or any Restricted
Subsidiary under any Indebtedness for borrowed money (other than Non-recourse
Purchase Money Indebtedness) which results in acceleration of the maturity of
such Indebtedness, or failure to pay any such Indebtedness at maturity, in an
amount greater than $5.0 million if such Indebtedness is not discharged or such
acceleration is not rescinded or annulled within 10 days after written notice as
provided in the Indenture; (vi) one or more final judgments or orders by a court
of competent jurisdiction are entered against the Company or any Restricted
Subsidiary in an uninsured or unindemnified aggregate amount outstanding at any
time in excess of $5.0 million and such judgments or orders are not discharged,
waived, stayed, satisfied or bonded for a period of 60 consecutive days; (vii)
certain events of bankruptcy, insolvency or reorganization with respect to the
Company or any Significant Subsidiary; or (viii) a Subsidiary Guaranty ceases to
be in full force and effect (other than in accordance with the terms of the
Indenture and such Subsidiary Guaranty) or a Subsidiary Guarantor denies or
disaffirms its obligations under its Subsidiary Guaranty.
The Indenture provides that if an Event of Default (other than an Event of
Default described in clause (vii) above) with respect to the Notes at the time
outstanding shall occur and be continuing, either the Trustee or the Holders of
at least 25% in aggregate principal amount of the outstanding Notes by notice as
provided in the Indenture may declare the principal amount of the Notes to be
due and payable immediately. If an Event of Default described in clause (vii)
above with respect to the Notes at the time outstanding shall occur, the
principal amount of all the Notes will automatically, and without any action by
the Trustee or any Holder, become immediately due and payable. After any such
acceleration, but before a judgment or decree based on acceleration, the Holders
of at least a majority in aggregate principal amount of the outstanding Notes
may, under certain circumstances, rescind and annul such acceleration if all
Events of Default, other than the nonpayment of accelerated principal (or other
specified amount), have been cured or waived as provided in the Indenture.
Subject to the provisions of the Indenture relating to the duties of the
Trustee, in case an Event of Default shall occur and be continuing, the Trustee
will be under no obligation to exercise any of its rights or powers under the
Indenture at the request or direction of any of the Holders of the Notes, unless
such Holders shall have offered to the Trustee reasonable indemnity. Subject to
such provisions for the indemnification of the Trustee, the Holders of at least
a majority in aggregate principal amount of the outstanding Notes will have the
right to direct the time, method and place of conducting any proceeding for any
remedy available to the Trustee or exercising any trust or power conferred on
the Trustee with respect to the Notes.
No Holder of Notes will have any right to institute any proceeding with
respect to the Indenture, or for the appointment of a receiver or a trustee, or
for any other remedy thereunder, unless (i) such Holder has previously given to
the Trustee written notice of a continuing Event of Default with respect to the
Notes,
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(ii) the Holders of at least 25% in aggregate principal amount of the
outstanding Notes have made written request, and such Holder or Holders have
offered reasonable indemnity, to the Trustee to institute such proceeding as
trustee and (iii) the Trustee has failed to institute such proceeding and has
not received from the Holders of at least a majority in aggregate principal
amount of the outstanding Notes a direction inconsistent with such request,
within 60 days after such notice, request and offer. However, such limitations
do not apply to a suit instituted by a Holder of Notes for the enforcement of
payment of the principal of or any premium or interest on such Notes on or after
the applicable due date specified in such Notes.
MODIFICATION OF THE INDENTURE; WAIVER
The Indenture provides that modifications and amendments of the Indenture
may be made by the Company, any Subsidiary Guarantors and the Trustee without
the consent of any Holders of Notes in certain limited circumstances, including
(i) to cure any ambiguity, omission, defect or inconsistency, (ii) to provide
for the assumption of the obligations of the Company under the Indenture upon
the merger, consolidation or sale or other disposition of all or substantially
all the assets of the Company and the Restricted Subsidiaries taken as a whole
and certain other events specified in the provisions of the Indenture described
under "Merger, Consolidation and Sale of Substantially All Assets," (iii) to
provide for uncertificated Notes in addition to or in place of certificated
Notes, (iv) to comply with any requirement of the Commission in order to effect
or maintain the qualification of the Indenture under the 1939 Act, (v) to make
any change that does not adversely affect the rights of any Holder of Notes in
any material respect, (vi) to add or remove Subsidiary Guarantors pursuant to
the procedure set forth in the Indenture and (vii) certain other modifications
and amendments as set forth in the Indenture.
The Indenture contains provisions permitting the Company, any Subsidiary
Guarantors and the Trustee, with the written consent of the Holders of not less
than a majority in aggregate principal amount of the outstanding Notes, to
execute supplemental indentures or amendments adding any provisions to or
changing or eliminating any of the provisions of the Indenture or modifying the
rights of the Holders of the Notes, except that no such supplemental indenture,
amendment or waiver may, without the consent of all the Holders of outstanding
Notes, among other things, (i) reduce the principal amount of Notes whose
Holders must consent to an amendment or waiver, (ii) reduce the rate of or
change the time for payment of interest on any Notes, (iii) change the currency
in which any amount due in respect of the Notes is payable, (iv) reduce the
principal of or any premium on or change the Stated Maturity of any Notes or
alter the redemption or repurchase provisions with respect thereto, (v) reduce
the relative ranking of any Notes, (vi) release any security that may have been
granted to the Trustee in respect of the Notes, (vii) at any time after a Change
of Control has occurred, change the time at which the Change of Control Offer
relating thereto must be made or at which the Notes must be repurchased pursuant
to such Change of Control Offer or (viii) make certain other significant
amendments or modifications as specified in the Indenture.
The Holders of at least a majority in principal amount of the outstanding
Notes may waive compliance by the Company with certain restrictive provisions of
the Indenture. The Holders of at least a majority in principal amount of the
outstanding Notes may waive any past default under the Indenture, except a
default in the payment of principal, premium or interest and certain covenants
and provisions of the Indenture which cannot be amended without the consent of
the Holders of each outstanding Note.
NOTICES
Notices to Holders of the Notes will be given by mail to the addresses of
such Holders as they may appear in the Security Register.
GOVERNING LAW
The Indenture and the Notes are governed by and construed in accordance
with the internal laws of the State of New York without reference to principles
of conflicts of law.
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TRUSTEE
Texas Commerce Bank National Association is the Trustee under the
Indenture. The Trustee maintains normal banking relationships with the Company
and its Subsidiaries and may perform certain services for and transact other
business with the Company and its Subsidiaries from time to time in the ordinary
course of business.
EXCHANGE OFFER; REGISTRATION RIGHTS
The Company agreed pursuant to a registration agreement (the "Registration
Agreement") with the Initial Purchasers, for the benefit of the Holders, that
the Company will, at its cost, use its reasonable best efforts to (i) not later
than 60 days after the date of original issuance of the Old Notes, file a
registration statement (the "Exchange Offer Registration Statement") with the
Commission with respect to a registered offer (the "Exchange Offer") to exchange
the Old Notes for new notes of the Company (the "Exchange Notes") having terms
substantially identical in all material respects to the Old Notes (except that
the Exchange Notes will not contain terms with respect to transfer restrictions)
and (ii) cause the Exchange Offer Registration Statement to be declared
effective under the Securities Act not later than 120 days after the date of
original issuance of the Old Notes. Upon the effectiveness of the Exchange Offer
Registration Statement, the Company will offer the Exchange Notes in exchange
for surrender of the Old Notes. The Company will use its reasonable best efforts
to keep the Exchange Offer open for not less than 30 days (or longer if required
by applicable law) after the date notice of the Exchange Offer is mailed to the
Holders. For each Note surrendered to the Company pursuant to the Exchange
Offer, the Holder of such Note will receive an Exchange Note having a principal
amount equal to that of the surrendered Note. Interest on each Exchange Note
will accrue from the last interest payment date on which interest was paid on
the Note surrendered in exchange therefor or, if no interest has been paid on
such Note, from the date of its original issue. Under existing Commission
interpretations, the Exchange Notes would be freely transferable by Holders
other than affiliates of the Company after the Exchange Offer without further
registration under the Securities Act if the holder of the Exchange Notes
represents that it is acquiring the Exchange Notes in the ordinary course of its
business, that it has no arrangement or understanding with any person to
participate in the distribution of the Exchange Notes and that it is not an
affiliate of the Company, as such terms are interpreted by the Commission,
provided that broker-dealers ("Participating Broker-Dealers") receiving Exchange
Notes in the Exchange Offer will have a prospectus delivery requirement with
respect to resales of such Exchange Notes. The Commission has taken the position
that Participating Broker-Dealers may fulfill their prospectus delivery
requirements with respect to Exchange Notes (other than a resale of an unsold
allotment from the original sale of the Offered Notes) with the prospectus
contained in the Exchange Offer Registration Statement. Under the Registration
Agreement, the Company is required to allow Participating Broker-Dealers and
other persons, if any, with similar prospectus delivery requirements to use the
prospectus contained in the Exchange Offer Registration Statement in connection
with the resale of such Exchange Notes.
A Holder of Old Notes (other than certain specified Holders) who wishes to
exchange such Notes for Exchange Notes in the Exchange Offer will be required to
represent that any Exchange Notes to be received by it will be acquired in the
ordinary course of its business and that at the time of the commencement of the
Exchange Offer it has no arrangement or understanding with any person to
participate in the distribution (within the meaning of the Securities Act) of
the Exchange Notes and that it is not an "affiliate" of the Company, as defined
in Rule 405 under the Securities Act, or if it is an affiliate, that it will
comply with the registration and prospectus delivery requirements of the
Securities Act to the extent applicable.
If (i) changes in law or applicable interpretations of the Commission staff
do not permit the Company to effect such an Exchange Offer, (ii) for any other
reason the Exchange Registration Statement is not declared effective within 120
days after the date of original issuance of the Old Notes or the Exchange Offer
is not consummated within 150 days after the date of original issuance of the
Old Notes, (iii) the Initial Purchasers so request with respect to Old Notes not
eligible to be exchanged for Exchange Notes
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in the Exchange Offer or (iv) any Holder (other than an Initial Purchaser) is
not eligible to participate in the Exchange Offer or does not receive freely
tradeable Exchange Notes in the Exchange Offer other than by reason of such
Holder being an affiliate of the Company (it being understood that the
requirement that a Participating Broker-Dealer deliver the prospectus contained
in the Exchange Offer Registration Statement in connection with sales of
Exchange Notes shall not result in such Exchange Notes being not "freely
tradeable"), the Company will, at its cost, use its reasonable best efforts to
(i) as promptly as practicable, file a resale shelf registration statement (the
"Shelf Registration Statement") covering resales of the Old Notes or the
Exchange Notes, as the case may be, (ii) cause the Shelf Registration Statement
to be declared effective under the Securities Act and (iii) keep the Shelf
Registration Statement effective until two years after its effective date (or
until one year after such effective date if such Shelf Registration Statement is
filed at the request of an Initial Purchaser). The Company will, in the event a
Shelf Registration Statement is filed, among other things, provide to each
Holder for whom such Shelf Registration Statement was filed copies of the
prospectus that is a part of the Shelf Registration Statement, notify each such
Holder when the Shelf Registration Statement has become effective and take
certain other actions as are required to permit unrestricted resales of the Old
Notes or the Exchange Notes, as the case may be. A Holder who sells such Old
Notes or Exchange Notes pursuant to the Shelf Registration Statement generally
will be required to be named as a selling security holder in the related
prospectus and to deliver a prospectus to purchasers, will be subject to certain
of the civil liability provisions of the Securities Act in connection with such
sales and will be bound by the provisions of the Registration Agreement which
are applicable to such Holder (including certain indemnification obligations).
If (i) on or prior to the 60th day following the date of original issuance
of the Old Notes, neither the Exchange Offer Registration Statement nor the
Shelf Registration Statement has been filed with the Commission, (ii) on or
prior to the 120th day following the date of original issuance of the Old Notes,
neither the Exchange Offer Registration Statement nor the Shelf Registration
Statement has been declared effective, (iii) on or prior to the 150th day
following the date of original issuance of the Old Notes, neither the Exchange
Offer has been consummated nor the Shelf Registration Statement has been
declared effective or (iv) after either the Exchange Offer Registration
Statement or the Shelf Registration Statement has been declared effective, such
Registration Statement thereafter ceases to be effective or usable (subject to
certain exceptions) in connection with resales of Old Notes or Exchange Notes in
accordance with and during the periods specified in the Registration Agreement
(each such event referred to in clauses (i) through (iv), a "Registration
Default"), interest ("Special Interest") will accrue on the Old Notes and the
Exchange Notes (in addition to the stated interest on the Offered Notes and the
Exchange Notes) from and including the date on which the first such Registration
Default shall occur to but excluding the date on which all Registration Defaults
have been cured. Special Interest will accrue at a rate of 0.5% per annum during
the 90-day period immediately following the occurrence of the first such
Registration Default and shall increase by 0.25% per annum at the end of each
subsequent 90-day period, but in no event shall such rate exceed 1.50% per
annum.
All accrued Special Interest shall be paid to Holders in the same manner in
which payments of other interest are made pursuant to the Indenture. See
"Description of the Notes -- General."
The summary herein of certain provisions of the Registration Agreement does
not purport to be complete and is subject to, and is qualified in its entirety
by reference to, all the provisions of the Registration Agreement, a copy of
which is available upon request to the Company.
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CERTAIN FEDERAL INCOME TAX CONSEQUENCES
The following discussion of the material United Stated Federal income tax
consequences of the Exchange Offer is for general information only. It is based
on the Internal Revenue Code of 1986, as amended to the date hereof (the
"Code"), existing and proposed Treasury regulations, and judicial and
administrative determinations, all of which are subject to change at any time,
possibly on a retroactive basis. The following relates only to the Old Notes,
and the Exchange Notes received therefor, that are held as "capital assets"
within the meaning of Section 1221 of the Code. It does not discuss state, local
or foreign tax consequences, nor, except as otherwise noted, does it discuss tax
consequences to categories of holders that are subject to special rules, such as
foreign persons, tax-exempt organizations, insurance companies, banks and
dealers in stocks and securities. Tax consequences may vary depending on the
particular status of an investor. No rulings will be sought from the Internal
Revenue Service ("IRS") with respect to the Federal income tax consequences of
the Exchange Offer.
THIS SECTION DOES NOT PURPORT TO DEAL WITH ALL ASPECTS OF FEDERAL INCOME
TAXATION THAT MAY BE RELEVANT TO AN INVESTOR'S DECISION TO PURCHASE THE NOTES.
EACH INVESTOR SHOULD CONSULT WITH ITS OWN TAX ADVISOR CONCERNING THE APPLICATION
OF THE FEDERAL INCOME TAX LAWS AND OTHER TAX LAWS TO ITS PARTICULAR SITUATION
BEFORE DETERMINING WHETHER TO PURCHASE THE NOTES.
PAYMENT OF INTEREST AND SPECIAL INTEREST
Interest on an Old Note, including Special Interest payable to U.S. Holders
of Old Notes under the circumstances described under "Exchange Offer;
Registration Rights," and interest on an Exchange Note generally will be
includable in the income of a U.S. Holder as ordinary income at the time such
interest is received or accrued, in accordance with such U.S. Holder's method of
accounting for United States federal income tax purposes. The Old Notes were not
issued with original issue discount ("OID") within the meaning of the Code.
Because there is only a remote possibility that a Registration Default will
occur, the Company believes that any Special Interest payable to U.S. Holders as
a result of a Registration Default will not cause the Old Notes to be considered
issued with OID and that any Special Interest will be taken into account by each
U.S. Holder as ordinary income only to the extent and at such time that the
interest becomes fixed or is actually paid.
SALE, EXCHANGE OR REDEMPTION
Subject to the discussion of the Exchange Offer below and the market
discount rules, upon the sale, exchange or redemption of an Old Note or Exchange
Note, a U.S. Holder generally will recognize capital gain or loss equal to the
difference between (i) the amount of cash proceeds and the fair market value of
any property received on the sale, exchange or redemption (except to the extent
such amount is attributable to accrued interest income or market discount not
previously included in income which is taxable as ordinary income) and (ii) such
U.S. Holder's adjusted tax basis in the Old Note or Exchange Offered Note. A
U.S. Holder's adjusted tax basis in an Old Note or Exchange Note generally will
equal the cost of the Old Note or Exchange Note to such U.S. Holder increased by
the amount of any market discount previously taken into income by the U.S.
Holder, and reduced by the amount of any bond premium amortized by the U.S.
Holder with respect to the Old Notes or Exchange Notes. Capital gain recognized
by an individual generally will be subject to a maximum United States federal
income tax rate of (i) 39.6% if the U.S. Holder held the asset for not more than
one year, (ii) 28% if the U.S. Holder held the asset for more than one year but
not more than eighteen months and (iii) 20% if the U.S. Holder held the asset
for more than eighteen months.
AMORTIZABLE BOND PREMIUM
Generally, the excess of a U.S. Holder's tax basis in an Old Note or
Exchange Note over the amount payable at maturity is bond premium that the U.S.
Holder may elect to amortize under Section 171 of the Code on a yield to
maturity basis over the period from the U.S. Holder's acquisition date to the
maturity
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date of the Old Note or Exchange Note. The amortizable bond premium is treated
as an offset to interest income on the Old Note or Exchange Note for United
States federal income tax purposes. A U.S. Holder who elects to amortize bond
premium must reduce its tax basis in the Old Note or Exchange Note by the
deductions allowable for amortizable bond premium. An election to amortize bond
premium is revocable only with the consent of the IRS and applies to all
obligations owned or acquired by the U.S. Holder on or after the first day of
the taxable year to which the election applies.
An Old Note or Exchange Note may be called or submitted for redemption at a
premium prior to maturity. See "Description of the Notes -- Optional
Redemption." An earlier call date is treated as the maturity date of the Old
Note or Exchange Note and the amount of bond premium is determined by treating
the amount payable on such call date as the amount payable at maturity, if such
a calculation produces a smaller bond premium than the method described in the
preceding paragraph. If a U.S. Holder is required to amortize and deduct the
bond premium by reference to a certain call date, the Old Note or Exchange Note
will be treated as maturing on that date for the amount then payable. If the Old
Note or Exchange Note is not redeemed on that call date, the Old Note or
Exchange Note will be treated as reissued on that date for the amount of the
call price on that date. If an Old Note or Exchange Note purchased at a premium
is redeemed prior to its maturity, a U.S. Holder who has elected to deduct the
bond premium may be permitted to deduct any remaining unamortized bond premium
as an ordinary loss in the taxable year of the redemption.
MARKET DISCOUNT
The resale of Old Notes or Exchange Notes may be affected by the market
discount provisions of the Code. A U.S. Holder has market discount if an Old
Note or Exchange Note is purchased (other than at original issue) at an amount
below the stated redemption price at maturity of the Old Note or Exchange Note.
A de minimis amount of market discount is ignored. A U.S. Holder of an Old Note
or Exchange Note with market discount must either elect to include market
discount in income as it accrues or treat a portion of the gain recognized on
the disposition or retirement of the Old Note or Exchange Note as ordinary
income. The amount of gain treated as ordinary income would equal the lesser of
(i) the gain recognized (or the appreciation, in the case of a nontaxable
transaction such as a gift) or (ii) the portion of the market discount that
accrued on a ratable basis (or, if elected, on a constant interest rate basis)
while the Old Note or Exchange Note was held by the U.S. Holder.
A U.S. Holder who acquires an Old Note or Exchange Note at a market
discount also may be required to defer a portion of any interest expense that
otherwise may be deductible on any indebtedness incurred or maintained to
purchase or carry such Old Note or Exchange Note until the U.S. Holder disposes
of the Old Note or Exchange Note in a taxable transaction. Moreover, to the
extent of any accrued market discount on such Old Note or Exchange Note, any
partial principal payment with respect to an Old Note or Exchange Note will be
includible as ordinary income upon receipt, as will the fair market value of the
Old Note or Exchange Note on certain otherwise non-taxable transfers (such as
gifts).
A U.S. Holder of Old Notes or Exchange Notes acquired at a market discount
may elect for United States federal income tax purposes to include market
discount in gross income as the discount accrues, either on a straight-line
basis or on a constant interest rate basis. This current inclusion election,
once made, applies to all market discount obligations acquired by the U.S.
Holder on or after the first day of the first taxable year to which the election
applies, and may not be revoked without the consent of the IRS. If a U.S. Holder
of Old Notes or Exchange Notes makes such an election, the foregoing rules with
respect to the recognition of ordinary income on sales and other dispositions of
such debt instruments and on any partial principal payment with respect to the
Old Notes or Exchange Notes, and the deferral of interest deductions on
indebtedness incurred or maintained to purchase or carry such debt instruments,
would not apply.
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THE EXCHANGE OFFER
Pursuant to recently issued Treasury regulations, the exchange of Old Notes
for Exchange Notes pursuant to the Exchange Offer should not constitute a
significant modification of the terms of the Old Notes and, accordingly, such
exchange should not be treated as a taxable event for federal income tax
purposes. Therefore, such exchange should have no federal income tax
consequences to U.S. Holders of Old Notes, and each U.S. Holder of Exchange
Notes would continue to be required to include interest on the Exchange Notes in
its gross income in accordance with its method of accounting for federal income
tax purposes.
NON-U.S. HOLDERS
Under present United States federal income and estate tax law and subject
to the discussion of backup withholding below:
(a) Payments of interest on the Old Notes or the Exchange Notes by the
Company or any agent of the Company to any holder of an Old Note or an
Exchange Note that is not a U.S. Holder (a "Non-U.S. Holder") will not be
subject to United States federal withholding tax, provided that such
interest income is not effectively connected with a United States trade or
business of the Non-U.S. Holder and provided that (i) the Non-U.S. Holder
does not actually or constructively own 10% or more of the total combined
voting power of all classes of stock of the Company entitled to vote; (ii)
the Non-U.S. Holder is not a controlled foreign corporation that is related
to the Company through stock ownership; and (iii) either (A) the beneficial
owner of the Old Notes or the Exchange Notes certifies (by submitting to
the Company or its agent a Form W-8 (or a suitable substitute form)) in
compliance with applicable laws and regulations to the Company or its
agent, under penalties of perjury, that it is not a "United States person"
as defined in the Code and provides its name and address or (B) a
securities clearing organization, bank or other financial institution that
holds customers' securities in the ordinary course of its trade or business
(a "financial institution"), and holds the Old Notes or the Exchange Notes
on behalf of the beneficial owner, provides a statement to the Company or
its agent in which it certifies that a Form W-8 (or a suitable substitute
form) has been received from the beneficial owner by it or by a financial
institution between it and the beneficial owner and furnishes the payor
with a copy thereof. A Non-U.S. Holder that is not exempt from tax under
these rules will be subject to United States federal income tax withholding
at a rate of 30% unless the interest is effectively connected with the
conduct of a United States trade or business, in which case the interest
will be subject to the United States federal income tax on net income that
applies to United States persons generally. Non-U.S. Holders should consult
applicable income tax treaties, which may include different rules.
(b) A Non-U.S. Holder will generally not be subject to United States
federal income or withholding tax on gain realized on the sale, exchange or
redemption of an Old Note or an Exchange Note unless (i) the gain is
effectively connected with a United States trade or business of the Non-
U.S. Holder, (ii) in the case of a Non-U.S. Holder who is an individual,
such Holder is present in the United States for a period or periods
aggregating 183 days or more during the taxable year of the disposition and
certain other conditions are met or (iii) the Holder is subject to tax
pursuant to the provisions of the Code applicable to certain United States
expatriates. The amount withheld in accordance with these rules will be
creditable against the Non-U.S. Holder's United States federal income tax
liability and may entitle the Non-U.S. Holder to a refund upon furnishing
the required information to the IRS. Non-U.S. Holders should consult
applicable income tax treaties, which may provide different rules.
(c) An Old Note or an Exchange Note held by an individual who at the
time of death is not a citizen or resident of the United States for United
States federal estate tax purposes will not be subject to United States
federal estate tax as a result of such individual's death if, at the time
of such death, the individual did not actually or constructively own 10% or
more of the total combined voting power of all classes of stock of the
Company entitled to vote and the income on the Old Notes or the
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Exchange Notes would not have been effectively connected with the conduct
of a trade or business by the individual in the United States.
Recently proposed Treasury regulations that would be effective January 1,
1998, provide for several alternative methods for Non-U.S. Holders or "qualified
intermediaries" who hold the Old Notes or the Exchange Notes on behalf of
Non-U.S. Holders to obtain an exemption from withholding on interest payments.
The proposed Treasury regulations also would require, in the case of Old Notes
or Exchange Notes held by a foreign partnership, that (i) the certification
described in clause (a) (iii) of the preceding paragraph be provided by the
partners rather than by the foreign partnership and (ii) the partnership provide
certain information to the payor, including a United States taxpayer
identification number. A look-through rule would apply in the case of tiered
partnerships. There can be no assurance as to whether the proposed Treasury
regulations will be adopted or as to the provisions that they will include if
and when adopted in temporary or final form.
Except to the extent that an applicable treaty otherwise provides, a
Non-U.S. Holder generally will be taxed in the same manner as a U.S. Holder with
respect to interest if the interest income is effectively connected with a
United States trade or business of the Non-U.S. Holder. Effectively connected
interest received by a corporate Non-U.S. Holder may also, under certain
circumstances, be subject to an additional "branch profits tax" at a 30% rate
(or, if applicable, a lower treaty rate). Even though such effectively connected
interest is subject to income tax, and may be subject to the branch profits tax,
it is not subject to withholding tax if the Non-U.S. Holder delivers a properly
executed IRS Form 4224 to the payor.
INFORMATION REPORTING AND BACKUP WITHHOLDING TAX
In general, information reporting requirements may apply to principal and
interest payments on an Old Note or Exchange Note and to payments of the
proceeds of the sale of an Old Note or Exchange Note. A 31% backup withholding
tax may apply to such payments unless the Holder (i) is a corporation, Non-U.S.
Holder or comes within certain other exempt categories and, when required,
demonstrates its exemption, or (ii) provides a correct taxpayer identification
number, certifies as to no loss of exemption from backup withholding and
otherwise complies with applicable requirements of the backup withholding rules.
A Holder of an Old Note or Exchange Note who does not provide the Company with
the Holder's correct taxpayer identification number may be subject to penalties
imposed by the IRS. Any amounts withheld under the backup withholding rules from
a payment to a Holder will be allowed as a credit against such Holder's United
States federal income tax, provided that the required information is furnished
to the IRS.
PLAN OF DISTRIBUTION
Each broker-dealer that receives Exchange Notes for its own account
pursuant to the Exchange Offer must acknowledge that it will deliver a
prospectus in connection with any resale of such Exchange Notes. This
Prospectus, as it may be amended or supplemented from time to time, may be used
by a broker-dealer in connection with resales of Exchange Notes received in
exchange for Old Notes where such Old Notes were acquired as a result of
market-making activities or other trading activities. The Company has agreed
that, starting on the Expiration Date and ending on the close of business 180
days after the Expiration Date, it will make this Prospectus, as amended or
supplemented, available to any broker-dealer for use in connection with any such
resale. A broker-dealer that delivers such a prospectus to purchasers in
connection with such resales will be subject to certain of the civil liability
provisions under the Securities Act and will be bound by the provisions of the
Registration Agreement (including certain indemnification rights and
obligations).
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The Company will not receive any proceeds from any sale of Exchange Notes
by broker-dealers. Exchange Notes received by broker-dealers for their own
account pursuant to the Exchange Offer may be sold from time to time in one or
more transactions in the over-the-counter market, in negotiated transactions,
through the writing of options on the Exchange Notes or a combination of such
methods of resale, at market prices prevailing at the time of resale, at prices
related to such prevailing market prices or negotiated prices. Any such resale
may be made directly to purchasers or to or through brokers or dealers who may
receive compensation in the form of commissions or concessions from any such
broker-dealer and/or the purchasers of any such Exchange Notes. Any
broker-dealer that resells Exchange Notes that were received by it for its own
account pursuant to the Exchange Offer and any broker or dealer that
participates in a distribution of such Exchange Notes may be deemed to be an
"underwriter" within the meaning of the Securities Act and any profit on any
such resale of Exchange Notes and any commissions or concessions received by any
such persons may be deemed to be underwriting compensation under the Securities
Act. The Letter of Transmittal states that by acknowledging that it will deliver
and by delivering a prospectus, a broker-dealer will not be deemed to admit that
it is an "underwriter" within the meaning of the Securities Act.
For a period of 180 days after the Expiration Date, the Company will
promptly send additional copies of this Prospectus and any amendment or
supplement to this Prospectus to any broker-dealer that requests such documents
in the Letter of Transmittal. The Company has agreed in the Registration
Agreement to pay all expenses incident to the Exchange Offer other than
commissions or concessions of any brokers or dealers and to indemnify the
holders of the Old Notes (including any broker-dealers) against certain
liabilities, including liabilities under the Securities Act.
TRANSFER RESTRICTIONS ON OLD NOTES
OFFERING AND SALES BY THE INITIAL PURCHASERS
The Old Notes were not registered under the Securities Act and may not be
offered or sold in the United States or to, or for the account or benefit of,
U.S. persons except in accordance with an applicable exemption from the
registration requirements thereof. Accordingly, the Old Notes were offered and
sold only (i) in the United States to QIBs under Rule 144A under the Securities
Act and (ii) outside the United States to non-U.S. persons ("foreign
purchasers") in reliance upon Regulation S under the Securities Act. Each
foreign purchaser that is a purchaser of Old Notes from the Initial Purchasers
(an "Initial Foreign Purchaser") was required to sign a certificate in the form
provided by the Initial Purchasers.
INVESTOR REPRESENTATIONS AND RESTRICTIONS ON RESALE
Each purchaser of the Old Notes was deemed to have represented and agreed
as follows:
(1) it is acquiring the Old Notes for its own account or for an
account with respect to which it exercises sole investment discretion, and
that it or such account is a QIB or a foreign purchaser outside the United
States;
(2) it acknowledges that the Old Notes have not been registered under
the Securities Act and may not be sold except as permitted below;
(3) it understands and agrees (x) that such Old Notes are being
offered only in a transaction not involving any public offering within the
meaning of the Securities Act, and (y) that (A) if within two years after
the date of original issuance of the Old Notes or if within three months
after it ceases to be an affiliate (within the meaning of Rule 144 under
the Securities Act) of the Company, it decides to resell, pledge or
otherwise transfer such Old Notes on which the legend set forth below
appears, such Old Notes may be resold, pledged or transferred only (i) to
the Company, (ii) so long as such security is eligible for resale pursuant
to Rule 144A, to a person whom the seller reasonably believes is a QIB that
purchases for its own account or for the account of a QIB to whom notice is
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given that the resale, pledge or transfer is being made in reliance on Rule
144A (as indicated by the box checked by the transferor on the Certificate
of Transfer on the reverse of the Old Note if such Old Note is not in
book-entry form), (iii) in an offshore transaction in accordance with
Regulation S (as indicated by the box checked by the transferor on the
Certificate of Transfer on the reverse of the Old Note if such Old Note is
not in book-entry form), (iv) to an Institutional Accredited Investor, as
defined in Rule 501(a)(1), (2), (3) or (7) under the Securities Act (as
indicated by the box checked by the transferor on the Certificate of
Transfer on the reverse of the Old Note if such Old Note is not in
book-entry form), that is acquiring the Old Notes for investment purposes
and not for distribution, and a certificate which may be obtained from the
Company or the Trustee is delivered by the transferee to the Company and
the Trustee, (v) pursuant to an exemption from the registration
requirements of the Securities Act provided by Rule 144 (if applicable)
under the Securities Act or (vi) pursuant to an effective registration
statement under the Securities Act, in each case in accordance with any
applicable securities laws of any state of the United States, (B) the
purchaser will, and each subsequent holder is required to, notify any
purchaser of Old Notes from it of the resale restrictions referred to in
(A) above, if then applicable, and (C) with respect to any transfer of Old
Notes by an Institutional Accredited Investor, such holder will deliver to
the Company and the Trustee such certificates and other information as they
may reasonably require to confirm that the transfer by it complies with the
foregoing restrictions.
(4) it understands that the notification requirement referred to in
(3) above will be satisfied, in the case only of transfers by physical
delivery of certificated Old Notes other than a Global Security, by virtue
of the fact that the following legend will be placed on the Old Notes
unless otherwise agreed to by the Company:
"THIS SECURITY HAS NOT BEEN REGISTERED UNDER THE SECURITIES ACT OF 1933,
AS AMENDED (THE "SECURITIES ACT"). THE HOLDER HEREOF, BY PURCHASING THIS
SECURITY, AGREES FOR THE BENEFIT OF THE COMPANY THAT THIS SECURITY MAY
NOT BE RESOLD, PLEDGED OR OTHERWISE TRANSFERRED (X) PRIOR TO THE SECOND
ANNIVERSARY OF THE ISSUANCE HEREOF (OR A PREDECESSOR SECURITY HERETO) OR
(Y) BY ANY HOLDER THAT WAS AN AFFILIATE OF THE COMPANY AT ANY TIME
DURING THE THREE MONTHS PRECEDING THE DATE OF SUCH TRANSFER, IN EITHER
CASE OTHER THAN (1) TO THE COMPANY, (2) SO LONG AS THIS SECURITY IS
ELIGIBLE FOR RESALE PURSUANT TO RULE 144A UNDER THE SECURITIES ACT
("RULE 144A"), TO A PERSON WHOM THE SELLER REASONABLY BELIEVES IS A
QUALIFIED INSTITUTIONAL BUYER WITHIN THE MEANING OF RULE 144A PURCHASING
FOR ITS OWN ACCOUNT OR FOR THE ACCOUNT OF A QUALIFIED INSTITUTIONAL
BUYER TO WHOM NOTICE IS GIVEN THAT THE RESALE, PLEDGE OR OTHER TRANSFER
IS BEING MADE IN RELIANCE ON RULE 144A (AS INDICATED BY THE BOX CHECKED
BY THE TRANSFEROR ON THE CERTIFICATE OF TRANSFER ON THE REVERSE OF THIS
SECURITY), (3) IN AN OFFSHORE TRANSACTION IN ACCORDANCE WITH REGULATION
S UNDER THE SECURITIES ACT (AS INDICATED BY THE BOX CHECKED BY THE
TRANSFEROR ON THE CERTIFICATE OF TRANSFER ON THE REVERSE OF THIS
SECURITY), (4) TO AN INSTITUTION THAT IS AN "ACCREDITED INVESTOR" AS
DEFINED IN RULE 501(a)(1), (2), (3) OR (7) UNDER THE SECURITIES ACT (AS
INDICATED BY THE BOX CHECKED BY THE TRANSFEROR ON THE CERTIFICATE OF
TRANSFER ON THE REVERSE OF THIS SECURITY) THAT IS ACQUIRING THIS
SECURITY FOR INVESTMENT PURPOSES AND NOT FOR DISTRIBUTION, AND A
CERTIFICATE WHICH MAY BE OBTAINED FROM THE COMPANY OR THE TRUSTEE IS
DELIVERED BY THE TRANSFEREE TO THE COMPANY AND THE TRUSTEE, (5) PURSUANT
TO AN EXEMPTION FROM REGISTRATION UNDER THE SECURITIES ACT PROVIDED BY
RULE 144 (IF APPLICABLE) UNDER THE SECURITIES ACT, OR (6) PURSUANT TO AN
EFFECTIVE REGISTRATION STATEMENT UNDER THE SECURITIES ACT, IN EACH CASE
IN ACCORDANCE WITH ANY APPLICABLE SECURITIES LAWS OF ANY STATE OF THE
UNITED STATES. AN INSTITUTIONAL ACCREDITED INVESTOR HOLDING THIS
SECURITY AGREES IT WILL FURNISH TO THE COMPANY AND THE TRUSTEE SUCH
CERTIFICATES AND OTHER INFORMATION AS THEY MAY REASONA-
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BLY REQUIRE TO CONFIRM THAT ANY TRANSFER BY IT OF THIS SECURITY COMPLIES
WITH THE FOREGOING RESTRICTIONS. THE HOLDER HEREOF, BY PURCHASING THIS
SECURITY, REPRESENTS AND AGREES FOR THE BENEFIT OF THE COMPANY THAT IT
IS (1) A QUALIFIED INSTITUTIONAL BUYER WITHIN THE MEANING OF RULE 144A
OR (2) AN INSTITUTION THAT IS AN "ACCREDITED INVESTOR" AS DEFINED IN
RULE 501(a)(1), (2), (3) OR (7) UNDER THE SECURITIES ACT AND THAT IT IS
HOLDING THIS SECURITY FOR INVESTMENT PURPOSES AND NOT FOR DISTRIBUTION
OR (3) A NON-U.S. PERSON OUTSIDE THE UNITED STATES WITHIN THE MEANING OF
(OR AN ACCOUNT SATISFYING THE REQUIREMENTS OF PARAGRAPH (o)(2) OF RULE
902 UNDER) REGULATION S UNDER THE SECURITIES ACT."
(5) it (i) is able to fend for itself in the transactions contemplated
by the Offering Memorandum; (ii) has such knowledge and experience in
financial and business matters as to be capable of evaluating the merits
and risks of its prospective investment in the Old Notes; and (iii) has the
ability to bear the economic risks of its prospective investment and can
afford the complete loss of such investment;
(6) it has received a copy of the Offering Memorandum and acknowledges
that it has had access to such financial and other information and has been
afforded the opportunity to ask questions of the Company and receive
answers thereto, as it deemed necessary in connection with its decision to
purchase the Old Notes; and
(7) it understands that the Company, the Initial Purchasers and others
will rely upon the truth and accuracy of the foregoing acknowledgments,
representations and agreements and agrees that if any of the
acknowledgments, representations and agreements deemed to have been made by
its purchase of the Old Notes are no longer accurate, it shall promptly
notify the Company and the Initial Purchasers; and if it is acquiring the
Old Notes as a fiduciary or agent for one or more investor accounts, it
represents that it has sole investment discretion with respect to each such
account and it has full power to make the foregoing acknowledgments,
representations and agreements on behalf of such account.
LEGAL MATTERS
The validity of the issuance of the Exchange Notes offered hereby will be
passed upon for the Company by Vinson & Elkins L.L.P., Houston, Texas.
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EXPERTS
Information appearing in this Prospectus regarding the gross quantities of
reserves of the oil and gas properties owned by the Company and the future cash
flows and the present values thereof from such reserves, other than all such
information as of August 1, 1997 and the reserves attributed to Eugene Island
Block 243 Field at December 31, 1994, which information is based on estimates
prepared by the Company, is based on estimates of such reserves and present
values prepared by Atwater Consultants, Ltd. and Cawley, Gillespie & Associates,
Inc., both independent petroleum engineers.
The consolidated financial statements of the Company as of December 31,
1996 and 1995, and for the three years in the period ended December 31, 1996,
included elsewhere in this registration statement have been audited by Arthur
Andersen LLP, independent public accountants, as indicated in their report with
respect thereto, and are included herein in reliance upon the authority of said
firm as experts in accounting and auditing in giving said reports. With respect
to the unaudited interim financial information as of and for the three and six
months ended June 30, 1997 and 1996, Arthur Andersen LLP has applied limited
procedures in accordance with professional standards for review of that
information. However, their separate reports thereon state that they did not
audit and they do not express an opinion on that interim financial information.
Accordingly, the degree of reliance on their report on that information should
be restricted in light of the limited nature of the review procedures applied.
In addition, the accountants are not subject to the liability provisions of
Section 11 of the Securities Act for their report on the unaudited interim
financial information because that report is not a "report" or a "part" of the
registration statement prepared or certified by the accountants within the
meaning of Sections 7 and 11 of the Securities Act.
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GLOSSARY OF OIL AND GAS TERMS
The definitions set forth below shall apply to the indicated terms as used
in this Offering Memorandum. All volumes of natural gas referred to herein are
stated at the legal pressure base of the state or area where the reserves exist
and at 60 degrees Fahrenheit and in most instances are rounded to the nearest
major multiple.
Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume, used herein
in reference to crude oil or other liquid hydrocarbons.
Bbls/d. Barrels of crude oil or other liquid hydrocarbons per day.
Bcf. Billion cubic feet.
BOE. Barrels of oil equivalent, determined using the ratio of six Mcf of
natural gas to one Bbl of crude oil, condensate or natural gas liquids.
Btu. British thermal unit, which is the heat required to raise the
temperature of a one-pound mass of water from 58.5 to 59.5 degrees Fahrenheit.
Completion. The installation of permanent equipment for the production of
oil or natural gas, or in the case of a dry hole, the reporting of abandonment
to the appropriate agency.
Developed acreage. The number of acres that 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.
Dry hole or well. A well found to be incapable of producing hydrocarbons in
sufficient quantities such that proceeds from the sale of such production exceed
production expenses and taxes.
Exploratory well. A well drilled to find and produce oil or natural gas
reserves not classified as proved, to find a new reservoir in a field previously
found to be productive of oil or natural gas in another reservoir or to extend a
known reservoir.
Farmin or farmout agreement. An agreement whereunder the owner of a working
interest in an oil and gas lease assigns the working interest or a portion
thereof to another party who desires to drill on the leased acreage. Generally,
the assignee is required to drill one or more wells in order to earn its
interest in the acreage. The assignor usually retains a royalty or reversionary
interest in the lease. The interest received by an assignee is a "farmin" while
the interest transferred by the assignor is a "farmout."
Field. An area consisting of a single reservoir or multiple reservoirs all
grouped on or related to the same individual geological structural feature
and/or stratigraphic condition.
Finding costs. Costs associated with acquiring and developing proved oil
and gas reserves which are capitalized by the Company pursuant to generally
accepted accounting principles, excluding any capitalized general and
administrative expenses.
Gross acreage or gross wells. The total acres or wells, as the case may be,
in which a working interest is owned.
Liquids. Crude oil, condensate and natural gas liquids.
MBbls. One thousand barrels of crude oil or other liquid hydrocarbons.
MBbls/d. One thousand barrels of crude oil or other liquid hydrocarbons per
day.
MBOE. One thousand barrels of oil equivalent.
MBOE/d. One thousand barrels of oil equivalent per day.
Mcf. One thousand cubic feet.
97
<PAGE> 99
Mcf/d. One thousand cubic feet per day.
MMBbls. One million barrels of crude oil or other liquid hydrocarbons.
MMBOE. One million barrels of oil equivalent.
MMBtu. One million Btus.
MMcf. One million cubic feet.
MMcf/d. One million cubic feet per day.
MMS. Mineral Management Service of the United States Department of the
Interior.
Net acres or net wells. The sum of the fractional working interests owned
in gross acres or gross wells, as the case may be.
Oil. Crude oil and condensate.
Present value. When used with respect to oil and natural gas reserves, the
estimated future gross revenue to be generated from the production of proved
reserves, net of estimated production and future development costs, using prices
and costs in effect as of the date indicated, without giving effect to non-
property related expenses such as general and administrative expenses, debt
service and future income tax expenses or to depreciation, depletion and
amortization, discounted using an annual discount rate of 10%.
Productive well. A well that is found to be capable of producing
hydrocarbons in sufficient quantities such that proceeds from the sale of such
production exceed production expenses and taxes.
Proved developed nonproducing reserves. Proved developed reserves expected
to be recovered from zones behind casing in existing wells.
Proved developed producing reserves. Proved developed reserves that are
expected to be recovered from completion intervals currently open in existing
wells and capable of production to market.
Proved reserves. The estimated quantities of oil, natural gas and natural
gas liquids that geological and engineering data demonstrate with reasonable
certainty to be recoverable in future years from known reservoirs under existing
economic and operating conditions.
Proved undeveloped reserves. Reserves that are expected to be recovered
from new wells on developed acreage where the subject reserves cannot be
recovered without drilling additional wells.
Recompletion. The completion for production of an existing well bore in
another formation from that in which the well has been previously completed.
Reservoir. A porous and permeable underground formation containing a
natural accumulation of producible oil and/or natural gas that is confined by
impermeable rock or water barriers and is individual and separate from other
reservoirs.
Royalty interest. An interest in an oil and natural gas property entitling
the owner to a share of oil or natural gas production free of costs of
production.
Undeveloped acreage. Lease acreage on which wells have not been drilled or
completed to a point that would permit the production of commercial quantities
of oil and natural gas regardless of whether such acreage contains proved
reserves.
Working interest. The operating interest that gives the owner the right to
drill, produce and conduct operating activities on the property and a share of
production.
Workover. Operations on a producing well to restore or increase production.
98
<PAGE> 100
INDEX TO FINANCIAL STATEMENTS
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
Report of Independent Public Accountants.................... F-2
Consolidated Balance Sheet of Stone Energy Corporation as of
June 30, 1997 and December 31, 1996 and 1995.............. F-3
Consolidated Statements of Operations of Stone Energy
Corporation for six months ended June 30, 1997 and 1996
and the years ended December 31, 1996, 1995 and 1994...... F-4
Consolidated Statements of Cash Flows of Stone Energy
Corporation for the six months ended June 30, 1997 and
1996 and the years ended December 31, 1996, 1995 and
1994...................................................... F-5
Consolidated Statement of Changes in Equity of Stone Energy
Corporation for the six months ended June 30, 1997 and the
years ended December 31, 1996, 1995 and 1994.............. F-6
Notes to Consolidated Financial Statements.................. F-7
</TABLE>
F-1
<PAGE> 101
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Stockholders of
Stone Energy Corporation:
We have audited the accompanying consolidated balance sheets of Stone
Energy Corporation (a Delaware corporation) and subsidiary as of December 31,
1996 and 1995, and the related consolidated statements of operations, changes in
equity and cash flows for each of the three years in the period ended December
31, 1996. These financial statements are the responsibility of the Company's
management. Our responsibility is to express an opinion on these financial
statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly,
in all material respects, the financial position of Stone Energy Corporation and
subsidiary as of December 31, 1996 and 1995, and the results of their operations
and their cash flows for each of the three years in the period ended December
31, 1996, in conformity with generally accepted accounting principles.
ARTHUR ANDERSEN LLP
New Orleans, Louisiana
February 28, 1997
F-2
<PAGE> 102
STONE ENERGY CORPORATION
CONSOLIDATED BALANCE SHEET
<TABLE>
<CAPTION>
DECEMBER 31,
JUNE 30, --------------------
1997 1996 1995
----------- -------- --------
(UNAUDITED)
(DOLLAR AMOUNTS IN THOUSANDS,
EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C>
ASSETS
Current assets:
Cash and cash equivalents............................ $ 10,396 $ 9,864 $ 6,286
Marketable securities, at market..................... 16,003 10,331 10,232
Accounts receivable.................................. 11,247 12,466 7,247
Unbilled accounts receivable......................... 196 470 89
Other current assets................................. 432 94 612
-------- -------- --------
Total current assets......................... 38,274 33,225 24,466
Oil and gas properties -- full cost method of
accounting:
Proved, net of accumulated depreciation, depletion
and amortization of $137,192, $125,533 and
$106,277, respectively............................ 207,013 167,562 108,820
Unevaluated.......................................... 3,146 3,834 2,428
Building and land, net of accumulated depreciation of
$122, $79 and $0, respectively....................... 3,606 3,390 3,284
Other assets, net of accumulated depreciation and
amortization of $2,268, $2,058 and $4,177,
respectively......................................... 1,517 1,395 462
-------- -------- --------
Total assets................................. $253,556 $209,406 $139,460
======== ======== ========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Current portion of long-term loans................... $ 78 $ 76 $ 69
Advance payments..................................... 279 354 373
Accounts payable to vendors.......................... 27,620 17,651 10,980
Undistributed oil and gas proceeds................... 6,057 4,567 5,228
Other accrued liabilities............................ 1,512 3,894 2,437
-------- -------- --------
Total current liabilities.................... 35,546 26,542 19,087
Long-term loans........................................ 51,137 26,172 47,754
Deferred tax liability................................. 15,264 12,112 5,413
Other long-term liabilities............................ 2,079 139 279
-------- -------- --------
Total liabilities............................ 104,026 64,965 72,533
-------- -------- --------
Commitments and Contingencies (see Note 9)
Common Stock, $.01 par value; authorized 25,000,000
shares; issued and outstanding 15,015,408, 15,015,408
and 11,792,349 shares, respectively.................. 150 150 118
Paid-in capital........................................ 118,502 118,606 52,157
Retained earnings...................................... 30,878 25,685 14,652
-------- -------- --------
Total equity................................. 149,530 144,441 66,927
-------- -------- --------
Total liabilities and equity................. $253,556 $209,406 $139,460
======== ======== ========
</TABLE>
The accompanying notes are an integral part of this consolidated balance sheet.
F-3
<PAGE> 103
STONE ENERGY CORPORATION
CONSOLIDATED STATEMENT OF OPERATIONS
<TABLE>
<CAPTION>
SIX MONTHS
ENDED JUNE 30, YEAR ENDED DECEMBER 31,
----------------- ---------------------------
1997 1996 1996 1995 1994
------- ------- ------- ------- -------
(UNAUDITED)
(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
<S> <C> <C> <C> <C> <C>
Revenues:
Oil and gas production............... $29,005 $28,391 $55,839 $38,693 $31,179
Overhead reimbursements and
management fees................... 255 365 814 522 444
Other income......................... 639 740 1,312 1,336 1,264
------- ------- ------- ------- -------
Total revenues............... 29,899 29,496 57,965 40,551 32,887
------- ------- ------- ------- -------
Expenses:
Normal lease operating expenses...... 4,362 3,968 8,625 6,294 5,312
Major maintenance expenses........... 486 260 427 446 1,834
Production taxes..................... 1,499 1,511 3,399 3,057 2,303
Depreciation, depletion and
amortization...................... 11,929 10,334 19,564 15,719 11,569
Interest............................. 1,103 1,537 3,574 2,191 982
Salaries and other employee costs
.................................. 1,047 951 2,062 1,663 1,566
Incentive compensation plan.......... 316 278 928 85 1,358
General and administrative costs .... 712 711 1,447 1,635 1,533
------- ------- ------- ------- -------
Total expenses............... 21,454 19,550 40,026 31,090 26,457
------- ------- ------- ------- -------
Net income before income taxes......... 8,445 9,946 17,939 9,461 6,430
------- ------- ------- ------- -------
Provision for income taxes:
Current.............................. 100 122 208 131 --
Deferred............................. 3,152 3,707 6,698 3,514 2,410
------- ------- ------- ------- -------
Total income taxes........... 3,252 3,829 6,906 3,645 2,410
------- ------- ------- ------- -------
Net income............................. $ 5,193 $ 6,117 $11,033 $ 5,816 $ 4,020
======= ======= ======= ======= =======
Earnings per common share (see Note 1):
Net income per share................. $ 0.33 $ 0.51 $ 0.89 $ 0.49 $ 0.34
======= ======= ======= ======= =======
Net income per share assuming full
dilution.......................... $ 0.33 $ 0.51 $ 0.88 $ 0.49 $ 0.34
======= ======= ======= ======= =======
Average shares outstanding........... 15,312 11,954 12,356 11,818 11,801
======= ======= ======= ======= =======
Average shares outstanding assuming
full dilution..................... 15,327 11,954 12,486 11,847 11,870
======= ======= ======= ======= =======
</TABLE>
The accompanying notes are an integral part of this consolidated statement.
F-4
<PAGE> 104
STONE ENERGY CORPORATION
CONSOLIDATED STATEMENT OF CASH FLOWS
<TABLE>
<CAPTION>
SIX MONTHS
ENDED JUNE YEAR ENDED DECEMBER 31,
-------------------- --------------------------------
1997 1996 1996 1995 1994
-------- -------- -------- -------- --------
(UNAUDITED)
<S> <C> <C> <C> <C> <C>
) (DOLLAR AMOUNTS IN THOUSANDS
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income.......................................... $ 5,193 $ 6,117 $ 11,033 $ 5,816 $ 4,020
Adjustments to reconcile net income to net cash
provided by operating activities:
Depreciation, depletion and amortization ......... 11,929 10,334 19,564 15,719 11,569
Provision for deferred income taxes............... 3,152 3,707 6,698 3,514 2,410
Gain on sale of other assets...................... -- -- -- -- (88)
-------- -------- -------- -------- --------
20,274 20,158 37,295 25,049 17,911
(Increase) decrease in marketable securities........ (5,672) (5,760) (99) 4,964 (15,196)
(Increase) decrease in accounts receivable ......... 1,493 (1,835) (5,600) 426 850
(Increase) decrease in other current assets ........ (356) (28) 518 (370) 904
Increase (decrease) in accrued liabilities ......... (967) 300 777 (2,260) 5,586
Deferred financing costs............................ -- -- (418) (151) (128)
Other............................................... 1,942 (16) (140) (159) (318)
-------- -------- -------- -------- --------
Net cash provided by operating activities............. 16,714 12,819 32,333 27,499 9,609
-------- -------- -------- -------- --------
CASH FLOWS FROM INVESTING ACTIVITIES:
Investment in oil and gas properties................ (40,453) (16,321) (72,733) (48,122) (41,174)
Sale of reserves in place........................... -- -- -- -- 2,011
Proceeds from sale of other assets.................. -- -- -- -- 179
Purchase of building and land, building additions
and renovations................................... (260) -- (185) (3,284) --
Other asset additions............................... (332) (191) (743) (101) (148)
-------- -------- -------- -------- --------
Net cash used in investing activities................. (41,045) (16,512) (73,661) (51,507) (39,132)
-------- -------- -------- -------- --------
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings............................ 25,000 9,000 49,000 30,098 22,725
Repayment of debt................................... (33) (4,034) (70,575) (5,000) (16,223)
Sale of common stock................................ (104) -- 66,446 -- --
Exercise of stock options........................... -- 34 35 66 28
-------- -------- -------- -------- --------
Net cash provided by financing activities............. 24,863 5,000 44,906 25,164 6,530
-------- -------- -------- -------- --------
Net increase (decrease) in cash and cash
equivalents......................................... 532 1,307 3,578 1,156 (22,993)
Cash and cash equivalents, beginning of year.......... 9,864 6,286 6,286 5,130 28,123
-------- -------- -------- -------- --------
Cash and cash equivalents, end of year................ $ 10,396 $ 7,593 $ 9,864 $ 6,286 $ 5,130
======== ======== ======== ======== ========
Supplemental disclosures of cash flow information:
Cash paid during the year for:
Interest (net of amount capitalized).............. $ 1,003 $ 1,496 $ 3,672 $ 1,927 $ 1,053
Income taxes...................................... 100 44 145 216 --
-------- -------- -------- -------- --------
$ 1,103 $ 1,540 $ 3,817 $ 2,143 $ 1,053
======== ======== ======== ======== ========
</TABLE>
The accompanying notes are an integral part of this consolidated statement.
F-5
<PAGE> 105
STONE ENERGY CORPORATION
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
<TABLE>
<CAPTION>
COMMON PAID-IN RETAINED
STOCK CAPITAL EARNINGS
------ -------- --------
(DOLLAR AMOUNTS IN THOUSANDS)
<S> <C> <C> <C>
Balance, December 31, 1993................................. $118 $ 52,063 $ 4,816
Net income............................................... -- -- 4,020
Exercise of stock options................................ 28 --
---- -------- -------
Balance, December 31, 1994................................. 118 52,091 8,836
Net income............................................... -- -- 5,816
Exercise of stock options................................ 66 --
---- -------- -------
Balance, December 31, 1995................................. 118 52,157 14,652
Net income............................................... -- -- 11,033
Sale of common stock..................................... 32 66,414 --
Exercise of stock options................................ 35 --
---- -------- -------
Balance, December 31, 1996................................. 150 118,606 25,685
Net income............................................... -- -- 5,193
Expenses for sale of common stock........................ -- (104) --
---- -------- -------
Balance, June 30, 1997 (unaudited)......................... $150 $118,502 $30,878
==== ======== =======
</TABLE>
The accompanying notes are an integral part of this consolidated statement.
F-6
<PAGE> 106
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
NOTE 1 -- ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES:
Stone Energy Corporation (the "Company" or "Stone Energy") is an
independent oil and gas company primarily engaged in the acquisition,
exploitation and operation of producing oil and gas properties located in the
Gulf Coast Basin. The Company's business strategy is focused on the acquisition
of mature properties with established production history that have significant
exploitation and development potential. Since implementing its present business
strategy in 1989, Stone Energy has acquired 14 properties, net of dispositions,
that comprise its asset base -- eight offshore and six onshore Louisiana. The
Company is headquartered in Lafayette, Louisiana, with additional offices in New
Orleans and Houston.
The Company was organized under the laws of the State of Delaware in March
1993 to become a holding company for The Stone Petroleum Corporation ("TSPC")
and its subsidiaries and interests in certain partnerships (the "Acquisition
Partnerships").
A summary of significant accounting policies followed in the preparation of
the accompanying consolidated financial statements is set forth below:
Consolidation:
The consolidated financial statements include the accounts of the Company
and its proportionate share of the Acquisition Partnerships; TSPC, a
wholly-owned subsidiary organized in June 1981 and TSPC's proportionate share of
managed limited partnerships. In December 1996, TSPC adopted a plan of
dissolution whereby a majority of its assets are to be transferred to the
Company. Any assets necessary to satisfy any known liabilities will remain in
TSPC. In December 1994, Cut Off Corporation ("Cut Off"), a wholly-owned
subsidiary of TSPC organized in May 1991, was merged into TSPC. The accounts of
Cut Off were included in the consolidated financial statements prior to the
merger. In December 1993, The Stone Programs Corporation ("Programs"), a
wholly-owned subsidiary of TSPC organized in March 1976 as a broker dealer, was
liquidated and The Stone Properties Corporation ("Properties"), a wholly-owned
subsidiary of TSPC organized in August 1990, was merged into TSPC. Prior to such
liquidation and merger, the accounts of both Programs and Properties were
included in the consolidated financial statements. Both Properties and Cut Off
were organized for the purpose of purchasing certain oil and gas properties and
conducting related development and operational activities. All intercompany
balances and transactions are eliminated.
Use of Estimates:
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of the financial
statements and the reported amounts of revenues and expenses during the
reporting period. Actual results could differ from those estimates. Estimates
are used primarily when accounting for depreciation, depletion and amortization,
taxes and contingencies.
Fair Value of Financial Instruments:
Fair value of cash, cash equivalents, net accounts receivable, accounts
payable and debt approximates book value at December 31, 1996.
F-7
<PAGE> 107
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
Oil and Gas Properties:
The Company follows the full cost method of accounting for oil and gas
properties. Under this method, all acquisition, exploration and development
costs, including certain related employee costs and general and administrative
costs (less any reimbursements for such costs), incurred for the purpose of
finding oil and gas are capitalized. Such amounts include the cost of drilling
and equipping productive wells, dry hole costs, lease acquisition costs, delay
rentals and other costs related to such activities. Employee, general and
administrative costs that are capitalized include salaries and all related
fringe benefits paid to employees directly engaged in the acquisition,
exploration and development of oil and gas properties, as well as all other
directly identifiable general and administrative costs associated with such
activities, such as rentals, utilities and insurance. Fees received from managed
partnerships for providing such services are accounted for as a reduction of
capitalized costs. Employee, general and administrative costs associated with
production operations and general corporate activities are expensed in the
period incurred.
The Company amortizes its investment in oil and gas properties using the
future gross revenue method, a unit of production method, whereby the annual
provision for depreciation, depletion and amortization is computed by dividing
revenue produced during the period by future gross revenues at the beginning of
the period, and applying the resulting rate to the cost of oil and gas
properties, including estimated future development, restoration, dismantlement
and abandonment costs. Additionally, the capitalized costs of oil and gas
properties cannot exceed the present value of the estimated net cash flow from
its proved reserves, together with the lower of cost or estimated fair value of
its unevaluated properties (the full cost ceiling). Transactions involving sales
of reserves in place, unless extraordinarily large portions of reserves are
involved, are recorded as adjustments to the reserves for accumulated
depreciation, depletion and amortization.
Oil and gas properties include $3,834 and $2,428 of unevaluated properties
and related costs that are not being amortized at December 31, 1996 and 1995,
respectively. These costs are associated with the acquisition and evaluation of
unproved properties and major development projects expected to entail
significant costs to ascertain quantities of proved reserves. The unevaluated
costs at December 31, 1996 relate to acquisition and development costs incurred
during 1996, and at December 31, 1995 relate to acquisition costs incurred in
1994. The Company currently believes that the unevaluated properties at December
31, 1996 will be evaluated within one to 24 months. The excluded costs and
related proved reserves will be included in the amortization base as the
properties are evaluated and proved reserves are established or impairment is
determined. Interest capitalized on unevaluated properties during the years
ended December 31, 1996 and 1995 was $90 and $246, respectively.
In March 1995, the Financial Accounting Standards Board ("FASB") issued
Statement of Financial Accounting Standards No. 121 ("SFAS No. 121"),
"Accounting for the Impairment of Long-Lived Assets and For Long-Lived Assets to
be Disposed of." The Company adopted SFAS No. 121 in 1996. The effect of
adopting SFAS No. 121 was not material.
Cash and Cash Equivalents:
The Company considers all highly liquid investments in overnight securities
through its commercial bank accounts, which result in available funds on the
next business day, to be cash and cash equivalents.
F-8
<PAGE> 108
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
Marketable Securities:
The Company has retained a third-party investment firm to manage its
portfolio of short-term marketable securities, which are actively and frequently
bought and sold with the primary objective of generating profits on the
short-term differences in prices. Thus, the related security investments are
classified as trading securities, which are marked to market in accordance with
SFAS No. 115. All realized and unrealized gains and losses are included in
current operating results. The securities included in the portfolio are
primarily U.S. Treasury obligations and mortgage-backed securities with an
average maturity of not more than 180 days.
Income Taxes:
The Company accounts for income taxes in accordance with SFAS No. 109.
Provisions for income taxes include deferred taxes resulting primarily from
temporary differences due to different reporting methods for oil and gas
properties for financial reporting purposes and income tax purposes. For
financial reporting purposes, all exploratory and development expenditures are
capitalized and depreciated, depleted and amortized on the future gross revenue
method. For income tax purposes, only the equipment and leasehold costs relative
to successful wells are capitalized and recovered through depreciation or
depletion. Generally, most other exploratory and development costs are charged
to expense as incurred; however, the Company uses certain provisions of the
Internal Revenue Code which allow capitalization of intangible drilling costs
where management deems appropriate. Other financial and income tax reporting
differences occur as a result of statutory depletion, different reporting
methods for sales of oil and gas reserves in place, and different reporting
periods used in accounting for income and costs arising from oil and gas
operations conducted through tax partnerships.
Gas Production Revenues:
The Company records as revenue only that portion of gas production sold and
allocable to its ownership interest in the related well. Any gas production
proceeds received in excess of its ownership interest are reflected as a
liability in the accompanying consolidated financial statements. Revenues
relating to gas production to which the Company is entitled but for which the
Company has not received payment are not recorded in the consolidated financial
statements until compensation is received.
Net under-balanced production positions at December 31, 1996 and 1995 are
immaterial.
Earnings Per Common Share:
Earnings per share for each of the six months ended June 30, 1997 and 1996
and the years ended December 31, 1996, 1995 and 1994, was computed by dividing
net earnings by the sum of the outstanding shares of Common Stock of the
Company, plus Common Stock Equivalents, thereby reflecting the dilutive effect
of stock options granted to outside directors and certain employees on various
dates through December 31, 1996 (see Note 10).
In February 1997, the FASB issued Statement of Financial Accounting
Standards No. 128 ("SFAS No. 128"), "Earnings Per Share," which simplifies the
computation of earnings per share (EPS). SFAS No. 128 is effective for financial
statements issued for periods ending after December 15, 1997, and requires
restatement for all prior period EPS data presented. Pro forma EPS and EPS
assuming dilution calculated in accordance with SFAS No. 128 totaled $0.35 and
$0.34 per share, respectively, for the six months ended June 30, 1997, and $0.52
and $0.51 per share, respectively, for the six months ended June 30, 1996.
F-9
<PAGE> 109
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
Building and Land:
The Company records building and land at cost. The Company's office
building is being depreciated for financial statement purposes on the
straight-line method over its estimated useful life.
Hedging Activities:
From time to time, the Company has utilized futures and hedging activities
in order to reduce the effect of product price volatility. The resulting gains
or losses on hedging contracts are accounted for as revenues from oil and gas
production in the financial statements.
NOTE 2 -- ACCOUNTS RECEIVABLE AND ADVANCE PAYMENTS:
In its capacity as operator, manager and/or sponsor for its partners and
other co-venturers, the Company incurs drilling and other costs and receives
payment for advance billings for drilling, all of which are billed to the
respective parties. Accounts receivable and advance payments were comprised of
the following amounts:
<TABLE>
<CAPTION>
DECEMBER 31,
------------------
1996 1995
------- -------
<S> <C> <C>
Accounts Receivable --
Managed partnerships...................................... $ 1,687 $ 447
Other co-venturers........................................ 1,136 1,364
Trade..................................................... 9,637 5,432
Officers and employees.................................... 6 4
------- -------
$12,466 $ 7,247
======= =======
Advance Payments --
Managed partnerships...................................... $ -- $ 216
Other co-venturers........................................ 256 56
Trade..................................................... 98 101
------- -------
$ 354 $ 373
======= =======
</TABLE>
Costs incurred but not yet billed to the managed partnerships and other
co-venturers at December 31, 1996 and 1995 amounted to $470 and $89,
respectively.
F-10
<PAGE> 110
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
NOTE 3 -- INVESTMENT IN OIL AND GAS PROPERTIES:
The following table discloses certain financial data relative to the
Company's oil and gas producing activities, which are located onshore and
offshore the continental United States:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
----------------------------------
1996 1995 1994
--------- --------- --------
<S> <C> <C> <C>
Costs incurred during year:
Capitalized --
Acquisition costs:
Proved......................................... $ 24,522 $ 8,104 $ 6,711
Unevaluated.................................... 2,065 -- 5,080
Investments posted as performance bonds.......... 63 (30) (326)
Exploratory drilling............................. 26,339 8,261 4,719
Development drilling:
Proved......................................... 22,321 27,383 18,345
Unevaluated.................................... 1,769 -- 3,896
General and administrative costs................. 3,238 2,743 3,708
Less: overhead reimbursements, management fees
and repromotion income......................... (913) (953) (959)
--------- --------- --------
$ 79,404 $ 45,508 $ 41,174
========= ========= ========
Charged to expenses --
Operating costs:
Normal lease operating expenses................ $ 8,625 $ 6,294 $ 5,312
Major maintenance expenses..................... 427 446 1,834
--------- --------- --------
Total operating costs............................ 9,052 6,740 7,146
Production taxes................................. 3,399 3,057 2,303
--------- --------- --------
$ 12,451 $ 9,797 $ 9,449
========= ========= ========
Depreciation, depletion and amortization.............. $ 19,256 $ 15,551 $ 11,420
========= ========= ========
Oil and gas properties --
Balance, beginning of year.......................... $ 217,525 $ 172,017 $130,843
Additions........................................... 79,404 45,508 41,174
--------- --------- --------
Balance, end of year................................ 296,929 217,525 172,017
--------- --------- --------
Accumulated depreciation, depletion and amortization--
Balance, beginning of year.......................... (106,277) (90,726) (70,746)
Provision for depreciation, depletion and
amortization..................................... (19,256) (15,551) (11,420)
Sale of reserves.................................... -- -- (2,011)
Cancellation of loan................................ -- -- (1,126)
Cancellation of production payment loan............. -- -- (5,423)
--------- --------- --------
Balance, end of year................................ (125,533) (106,277) (90,726)
--------- --------- --------
Net capitalized costs (proved and unevaluated)........ $ 171,396 $ 111,248 $ 81,291
========= ========= ========
</TABLE>
In November 1994, the Company sold to Nuevo Energy Company ("Nuevo") all of
the interests in 11 oil and gas fields located in Louisiana, Mississippi and
Oklahoma owned by the Company and certain of its affiliates. The Company
received $2,011 of the total of $9,480 of sales proceeds, the balance of
F-11
<PAGE> 111
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
which was attributable to the interests of other participants in limited
partnerships and joint ventures formed during the period of 1980 through 1985.
The proved reserves of the properties sold comprised approximately 3% of the
Company's total estimated proved reserves as of December 31, 1994. Therefore,
the sale was recorded as an adjustment to the reserve for accumulated
depreciation, depletion and amortization.
In addition to the cash received, the Company's obligation of $5,423 with
respect to a production payment owed to Energy Assets International Corporation
("EAI"), an affiliate of Nuevo, was terminated. The transaction was recorded as
an adjustment to the reserve for accumulated depreciation, depletion and
amortization.
NOTE 4 -- INCOME TAXES:
The Company follows the provisions of SFAS No. 109, "Accounting For Income
Taxes," which provides for recognition of a deferred tax asset for deductible
temporary timing differences, operating loss carryforwards, statutory depletion
carryforwards and tax credit carryforwards net of a "valuation allowance." An
analysis of the Company's deferred tax liability follows:
<TABLE>
<CAPTION>
DECEMBER 31,
--------------------
1996 1995
-------- --------
<S> <C> <C>
Net operating loss carryforwards............................ $ 1,224 $ 5,335
Statutory depletion carryforward............................ 4,463 3,857
Investment tax credit carryforward.......................... 887 1,967
Alternative minimum tax credit.............................. 447 239
Temporary differences:
Oil and gas properties -- full cost....................... (18,794) (15,223)
Other..................................................... (339) (487)
-------- --------
(12,112) (4,312)
Valuation allowance......................................... 0 (1,101)
-------- --------
$(12,112) $ (5,413)
======== ========
</TABLE>
For tax reporting purposes, the Company had operating loss carryforwards of
$3,180 and investment tax credit carryforwards of $887 at December 31, 1996. If
not utilized, such carryforwards would begin expiring in 1997 and would
completely expire by the year 2007. Because of tax rules relating to changes in
corporate ownership and computations required to be made on a separate entity
basis, the utilization by the Company of these benefit carryforwards in reducing
its tax liability is restricted. Additionally, the Company had available for tax
reporting purposes $11,592 in statutory depletion deductions that may be carried
forward indefinitely. Recognition of a deferred tax asset associated with these
carryforwards is dependent upon the Company's evaluation that it is more likely
than not that the asset will ultimately be realized. As of December 31, 1995,
the valuation allowance was increased due to revised estimates of investment tax
credits that the Company believed more likely than not would expire prior to
their utilization. The valuation allowance was eliminated at December 31, 1996
as the corresponding investment tax credits expired unutilized.
F-12
<PAGE> 112
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
Reconciliations between the statutory federal income tax expense (benefit)
rate and the Company's effective income tax expense rate as a percentage of
income before income taxes were as follows:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
--------------------------
1996 1995 1994
---- ---- ----
<S> <C> <C> <C>
Income taxes computed at the statutory federal income
tax rate.............................................. 35% 35% 35%
Changes in valuation allowance.......................... -- -- 9
State tax and other..................................... 4 4 (7)
--- --- ---
Effective income tax rate............................... 39% 39% 37%
=== === ===
</TABLE>
NOTE 5 -- LONG-TERM LOANS:
Long-term loans consisted of the following at:
<TABLE>
<CAPTION>
DECEMBER 31,
JUNE 30, ------------------
1997 1996 1995
-------- ------- -------
<S> <C> <C> <C>
Unsecured revolving credit facility with NationsBank
of Texas, N.A. ("NationsBank") (described
below)............................................ $48,073 $23,073 $44,573
Term Loan Agreement with First National Bank of
Commerce ("FNBC") with interest at 7.45%.......... 3,142 3,175 3,250
Less: portion due within one year................... (78) (76) (69)
------- ------- -------
Total long-term loans..................... $51,137 $26,172 $47,754
======= ======= =======
</TABLE>
Aggregate minimum principal payments at December 31, 1996 for the next five
years are as follows: 1997 -- $76, 1998 -- $81, 1999 -- $23,161, 2000 -- $94 and
2001 -- $2,843.
On July 30, 1997, the Company executed its Third Amended and Restated
Credit Agreement with NationsBank, as agent for a group of banks. The total
facility amount of $150,000 is comprised of a three-year revolving credit loan
and a term loan due on January 1, 1999. Current availability of the facility is
$130,000, and the current weighted average interest rate of the facility is 7.3%
per annum. As of August 1, 1997, the total outstanding principal balance was
$79,073 and letters of credit totaling $6,522 have been issued pursuant to the
facility.
The revolver provides for total availability of $100,000, with a limitation
on total outstanding borrowings based on a borrowing base amount established by
the banks for the Company's oil and gas properties, which currently is $80,000.
The term loan of $50,000 was established to finance the acquisition of the
Vermilion Block 255 Field and certain development costs. If the term loan is
outstanding on March 1, 1998, the banks have the right to redetermine the
borrowing base of the facility which could result in an acceleration of the
payments due under the term loan.
On November 30, 1995, the Company executed a term loan agreement with FNBC
in the original principal amount of $3,250 to finance the purchase of the
Company's office building (see Note 6). The loan has a five-year term bearing
interest at the rate of 7.45% over the entire term of the loan. Payments of $26
are due monthly and are based upon a 20-year amortization period. The
indebtedness under the agreement is collateralized by the building.
F-13
<PAGE> 113
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
The terms of the NationsBank and FNBC agreements contain, among other
provisions, requirements for maintaining defined levels of working capital and
tangible net worth.
NOTE 6 -- TRANSACTIONS WITH RELATED PARTIES:
The Company receives certain fees as a result of its function as managing
partner of certain partnerships. For the years ended December 31, 1996, 1995 and
1994, the Company generated management fees and overhead reimbursements from
partnerships amounting to $744, $851 and $637, respectively, the majority of
which was treated as a reduction of the investment in oil and gas properties.
The Company collects and distributes production revenues as managing
partner for the partnerships' interests in oil and gas properties. At December
31, 1995, $858 was included in undistributed oil and gas proceeds that was
identified as distributable to partners in the partnerships.
TSPC leased office space in a building owned by RiverStone Associates, an
affiliate, from 1982 through November 30, 1995, on which date the building and
related land were purchased by the Company. The entire purchase price of $3,250
was paid to the holder of the first mortgage on the property. RiverStone
Associates and its partners did not receive any of the sales proceeds, nor were
any such parties relieved of any personal liability as a result of the sale.
James H. Stone and Joe R. Klutts, each an officer and director of the Company,
are partners in RiverStone Associates. The sale was approved by the
disinterested members of the Board of Directors. The Company and TSPC incurred
net rent expense of $633 and $702, respectively, during the years ended December
31, 1995 and 1994.
In December 1994, the Company sold a residential townhouse located in
Houston, Texas to Frantzen/Voelker Investments, L.L.C. ("Frantzen/Voelker") for
$77. David Voelker, a director of the Company, is a principal of
Frantzen/Voelker. The sales price was based upon an appraisal of the property by
an independent third party and the sale was approved by the disinterested
members of the Board of Directors.
The Company's interests in certain oil and gas properties are burdened by
various net profit interests granted at the time of acquisition to certain
officers and other employees of the Company. Such net profit interest owners do
not receive any cash distributions until the Company has recovered all of its
acquisition, development, financing and operating costs. Management believes the
estimated value of such interests at the time of acquisition is not material to
the Company's financial position or results of operations.
Certain officers and directors are working interest owners in properties
operated by the Company and are billed and pay their proportionate share of
drilling and operating costs in the normal course of business.
NOTE 7 -- HEDGING ACTIVITIES:
In order to reduce its exposure to the possibility of declining oil and gas
prices, the Company hedges with third parties certain of its crude oil and
natural gas production in various swap agreement contracts. The crude oil
contracts are tied to the price of NYMEX light sweet crude oil futures and are
settled monthly based on the differences between contract prices and the average
NYMEX prices for that month applied to the related contract volumes. Settlement
for gas swap contracts is based on the average of the last three days of trade
on the NYMEX for each month of the swap.
F-14
<PAGE> 114
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
As of February 28, 1997, the Company's forward position was as follows:
<TABLE>
<CAPTION>
OIL GAS
---------------- -------------------
AVERAGE AVERAGE
PRICE PRICE
MBBLS ($/BBL) BBTU ($/MMBTU)
----- ------- ------ ---------
<S> <C> <C> <C> <C>
1997........................................ 165 $20.76 2,865 $ 2.556
</TABLE>
The fair market value of the hedging contracts was ($434) at December 31,
1996. For the six months ended June 30, 1997 and the years ended December 31,
1996 and 1995, net oil and gas hedging losses of $726, $3,801 and $11,
respectively, were treated as a reduction of revenues from oil and gas
production. As of August 15, 1997, the Company had no forward positions.
NOTE 8 -- COMMON STOCK:
On November 19, 1996, the Company completed an underwritten public offering
of 3,680,000 shares of Common Stock at a price to the public of $21.75 per
share. The shares offered included 3,221,159 shares sold by the Company (480,000
shares of which represented the exercise of the underwriters' over-allotment
option) and 458,841 shares sold by certain selling stockholders. This offering
resulted in the receipt by the Company of cash proceeds (net of $217 of offering
costs) totaling approximately $66,446. The Company used a portion of the
proceeds to retire a term loan incurred to finance the cost of acquisitions and
certain development projects performed in the third quarter of 1996 (see Note
5), and the remainder was used to repay a portion of the outstanding
indebtedness under its revolving bank credit facility.
NOTE 9 -- COMMITMENTS AND CONTINGENCIES:
The Company leases office facilities in New Orleans, Louisiana under the
terms of a long-term non-cancelable lease expiring on March 15, 1998. Office
facilities in Lafayette, Louisiana were leased through November 30, 1995, on
which date the Company purchased the building (see Note 6). Additionally, the
Company leases automobiles under terms of non-cancelable leases expiring at
various dates through 1999. The minimum net annual commitments under all leases,
subleases and contracts noted above at December 31, 1996 are as follows:
<TABLE>
<S> <C>
1997........................................................ $100
1998........................................................ 40
1999........................................................ 14
</TABLE>
Rent expense for the years ended December 31, 1996, 1995 and 1994 was
approximately $114, $727 and $793, respectively.
The Company is the managing general partner of eight partnerships and is
contingently liable for any recourse debts and other liabilities that result
from their operations. Management currently is not aware of the existence of any
such liabilities that would have a material impact on the future operations of
the Company.
In August 1989, the Company was advised by the EPA that it believed the
Company to be a potentially responsible party (a "PRP") for the cleanup of an
oil field waste disposal facility located near Abbeville, Louisiana, which was
included on CERCLA's National Priority List (the "Superfund List") by the EPA in
March 1989. In addition to the Company, approximately 370 other companies have
been named as being potentially responsible for the cleanup of the site. While
the Company's records do not
F-15
<PAGE> 115
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
indicate that any drilling wastes generated by the Company were disposed of at
this site, it is possible that one or more waste haulers contracted by the
Company may have disposed of wastes at this site. Given the extremely large
number of PRPs at this site, management does not believe that any liability for
this site would materially adversely affect the financial condition of the
Company.
In August 1989, the Company was advised by the EPA that it believed the
Company to be a PRP for the cleanup of an oil field waste disposal facility
located adjacent to the site described above. This site is presently owned by a
subsidiary of Dow Chemical Corporation that performed remediation activities at
this site in 1987 before it was placed on the Superfund List by the EPA in
October 1989. The Company entered into a settlement agreement with Dow Chemical
Corporation on September 16, 1996, releasing the Company from any anticipated
claims at this site. The Company paid Dow $50 in connection with such
settlement.
In December 1995, Goodrich Leasehold L.L.C. and Goodrich Drillers L.L.C.
filed a civil action in the 333rd Judicial District Court, Harris County, Texas,
against the Company in an attempt to set aside a Farmout Agreement affecting
portions of the West Flank of the Weeks Island field in Iberia Parish,
Louisiana. Management believes that this claim is without merit and intends to
vigorously defend this action.
The Company is contingently liable to a surety insurance company in the
aggregate amount of $12,174 relative to bonds issued on its behalf to the U.S.
Minerals Management Service ("MMS") and certain third parties from which it
purchased oil and gas working interests. The bonds represent guarantees by the
surety insurance company that the Company will operate offshore in accordance
with MMS rules and regulations and perform certain plugging and abandonment
obligations as specified by the applicable working interest purchase and sale
contracts.
The Company is also named as a defendant in certain lawsuits and is a party
to certain regulatory proceedings arising in the ordinary course of business.
Management does not expect these matters, individually or in the aggregate, to
have a material adverse effect on the financial condition of the Company.
OPA imposes ongoing requirements on a responsible party, including the
preparation of oil spill response plans and proof of financial responsibility to
cover environmental cleanup and restoration costs that could be incurred in
connection with an oil spill. As amended by the Coast Guard Authorization Act of
1996, OPA requires responsible parties for offshore facilities to provide
financial assurance in the amount of $35,000 cover potential OPA liabilities.
This amount can be increased up to $150,000 if a formal risk assessment
indicates that an amount higher than $35,000 should be required. The Company
does not anticipate that it will experience any difficulty in satisfying the
MMS's requirements for demonstrative financial responsibility under OPA.
In 1996, the American Institute of Certified Public Accountants issued its
Statement of Position 96-1 ("SOP 96-1"), which provides guidance on accounting
for environmental remediation liabilities. SOP 96-1 interprets existing
Financial Accounting Standards Board standards applicable to public companies.
The Company will apply SOP 96-1 starting in 1997. The Company believes adoption
of SOP 96-1 will not have a material effect on its results of operations or
financial position.
NOTE 10 -- EMPLOYEE BENEFIT PLANS:
The Company entered into deferred compensation and disability agreements
with certain of its employees whereby the Company has purchased split-dollar
life insurance policies to provide certain
F-16
<PAGE> 116
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
retirement and death benefits for the employees and death benefits payable to
the Company. The aggregate death benefit of the policies is $3,473 at December
31, 1996, of which $2,400 is payable to employees or their beneficiaries and
$1,073 is payable to the Company. Total cash surrender value of the policies,
net of related surrender charges at December 31, 1996, was approximately $748.
Additionally, the benefits under the deferred compensation agreements vest after
certain periods of employment, and at December 31, 1996, the liability for such
vested benefits was approximately $710. The difference between the actuarial
determined liability for retirement benefits or the vested amounts, where
applicable, and the net cash surrender value has been recorded as an other
long-term liability and is being amortized over the remaining term of the
various deferred compensation agreements.
The Company has adopted a series of incentive compensation plans designed
to align the interests of the executives and employees with those of its
stockholders. The following is a brief description of each of the plans.
i. The Annual Incentive Compensation Program provides for an annual
incentive bonus that ties incentives to the annual return on the
Company's Common Stock and also a comparison of the price performance
of the Common Stock to the average annual return on the shares of
stock of a peer group of companies with which the Company competes and
to the growth in net earnings, net cash flow and net asset value of
the Company. Incentive bonuses are awarded to participants based upon
individual performance factors.
ii. The Nonemployee Directors' Stock Option Plan provides for the
issuance of up to 250,000 shares of Common Stock upon the exercise of
such options granted pursuant to such plan. Generally, options
outstanding under the Nonemployee Directors' Stock Option Plan: (a)
are granted at prices that equate to the fair market value of the
Common Stock on date of grant, (b) vest ratably over a three year
service vesting period, and (c) expire five years subsequent to
award.
iii. The Company's Stock Option Plan provides for 850,000 shares of Common
Stock to be reserved for issuance pursuant to such plan. Under this
plan, the Company may grant both incentive stock options qualifying
under Section 422 of the Internal Revenue Code and options that are
not qualified as incentive stock options. All such options: (a) must
have an exercise price of not less than the fair market value of the
Common Stock on the date of grant, (b) vest ratably over a five year
service vesting period, and (c) expire ten years subsequent to award.
iv. The 401(k) Profit Sharing Plan provides eligible employees with the
option to defer receipt of a portion of their compensation and the
Company may, at its discretion, match a portion or all of the
employee's deferral. The amounts held under the plan are invested in
various investment funds maintained by a third party in accordance
with the directions of each employee. An employee is 20% vested in the
Company's matching contributions (if any) for each year of service and
is fully vested upon five years of service with the Company. For the
years ended December 1996, 1995 and 1994, the Company contributed
$169, $168 and $134, respectively, to the plan.
In October 1995, the FASB issued SFAS No. 123, "Accounting for Stock-Based
Compensation," which became effective with respect to the Company in 1996. Under
SFAS No. 123, companies can either record expense based on the fair value of
stock-based compensation upon issuance or elect to remain under the current
Accounting Principles Board Opinion No. 25 ("APB 25") method whereby no
compensation cost is recognized upon grant if certain requirements are met. The
Company is continuing
F-17
<PAGE> 117
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
to account for its stock-based compensation under APB 25. However, pro forma
disclosures as if the Company adopted the cost recognition requirements under
SFAS No. 123 are presented below.
If the compensation cost for the Company's 1996 and 1995 grants for
stock-based compensation plans had been determined consistent with SFAS No. 123,
the Company's net income and earnings per common share for the years ended
December 31, 1996 and 1995 would have approximated the pro forma amounts below:
<TABLE>
<CAPTION>
DECEMBER 31,
----------------------------------------------
1996 1995
--------------------- ---------------------
AS AS
REPORTED PRO FORMA REPORTED PRO FORMA
-------- --------- -------- ---------
<S> <C> <C> <C> <C>
Net income.............................. $11,033 $10,639 $5,816 $5,749
Earnings per common share:
Primary............................... $ 0.89 $ 0.86 $ 0.49 $ 0.49
Fully-diluted......................... $ 0.88 $ 0.85 $ 0.49 $ 0.49
</TABLE>
The effects of applying SFAS No. 123 in this pro forma disclosure are not
indicative of future amounts. SFAS No. 123 does not apply to grants prior to
1995, and additional awards in the future are anticipated.
A summary of the Company's stock options as of December 31, 1996 and 1995
and changes during the years ended on those dates is presented below:
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------------------------------------------
1996 1995 1994
------------------ ------------------ ------------------
WEIGHTED WEIGHTED WEIGHTED
NUMBER AVERAGE NUMBER AVERAGE NUMBER AVERAGE
OF EXERCISE OF EXERCISE OF EXERCISE
OPTIONS PRICE OPTIONS PRICE OPTIONS PRICE
------- -------- ------- -------- ------- --------
<S> <C> <C> <C> <C> <C> <C>
Outstanding at beginning of
year......................... 420,000 $12.33 248,000 $12.24 195,000 $12.37
Granted........................ 317,000 20.27 195,000 12.45 55,000 11.80
Expired........................ -- -- (18,000) 12.38 -- --
Exercised...................... (2,000) 12.38 (5,000) 12.38 (2,000) 12.38
------- ------- -------
Outstanding at end of year..... 735,000 $15.76 420,000 $12.33 248,000 $12.24
Options exercisable at
year-end..................... 180,667 $12.29 86,997 $12.23 37,665 $12.36
Options available for future
grant........................ 338,000 655,000 850,000
Weighted average fair value of
options granted during the
year......................... $ 12.95 $ 7.83
</TABLE>
The fair value of each option granted during the periods presented is
estimated on the date of grant using the Black-Scholes option-pricing model with
the following assumptions: (a) dividend yield of 0%, (b) expected volatility of
42.83% and 46.86% in the years 1996 and 1995, respectively, (c) risk-free
interest rate of 6.41% and 5.55% in the years 1996 and 1995, respectively, and
(d) expected life of 10 years for employee options and five years for director
options.
F-18
<PAGE> 118
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
The following table summarizes information about stock options outstanding
at December 31, 1996:
<TABLE>
<CAPTION>
OPTIONS OUTSTANDING
------------------------------------------------- OPTIONS EXERCISABLE
WEIGHTED ------------------------------
RANGE OF NUMBER AVERAGE NUMBER
EXERCISE OUTSTANDING REMAINING WEIGHTED AVERAGE EXERCISABLE WEIGHTED AVERAGE
PRICES AT 12/31/96 CONTRACTUAL LIFE EXERCISE PRICE AT 12/31/96 EXERCISE PRICE
-------- ----------- ---------------- ---------------- ----------- ----------------
<S> <C> <C> <C> <C> <C>
$11 -- $15........... 418,000 9.0 $12.33 180,667 $12.29
15 -- 19........... 25,000 5.0 17.81 -- --
19 -- 24........... 292,000 10.0 20.48 -- --
------- -------
735,000 9.3 15.76 180,667 12.29
======= =======
</TABLE>
NOTE 11 -- OIL AND GAS RESERVE INFORMATION -- UNAUDITED:
A majority of the Company's net proved oil and gas reserves at December 31,
1996 has been estimated by independent petroleum consultants in accordance with
guidelines established by the Securities and Exchange Commission ("SEC").
Accordingly, the following reserve estimates are based upon existing economic
and operating conditions at the respective dates.
There are numerous uncertainties inherent in estimating quantities of
proved reserves and in providing the future rates of production and timing of
development expenditures. The following reserve data represents estimates only
and should not be construed as being exact. In addition, the present values
should not be construed as the current market value of the Company's oil and gas
properties or the cost that would be incurred to obtain equivalent reserves.
F-19
<PAGE> 119
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
The following table sets forth an analysis of the Company's estimated
quantities of net proved and proved developed oil (including condensate) and
gas, all located onshore and offshore the continental United States:
<TABLE>
<CAPTION>
NATURAL
OIL IN GAS
MBBLS IN MMCF
------ -------
<S> <C> <C>
Proved reserves as of December 31, 1993..................... 6,080 58,491
Revisions of previous estimates........................... (50) (7,579)
Extensions, discoveries and other additions............... 1,454 14,877
Purchase of producing properties.......................... 235 11,304
Sale of reserves.......................................... (151) (2,179)
Production................................................ (1,113) (6,629)
------ -------
Proved reserves as of December 31, 1994..................... 6,455 68,285
Revisions of previous estimates........................... 476 1,208
Extensions, discoveries and other additions............... 399 13,478
Purchase of producing properties.......................... 2,054 6,607
Production................................................ (1,399) (8,399)
------ -------
Proved reserves as of December 31, 1995..................... 7,985 81,179
Revisions of previous estimates........................... (783) (4,025)
Extensions, discoveries and other additions............... 5,526 37,175
Purchase of producing properties.......................... 1,400 41,318
Production................................................ (1,356) (11,331)
------ -------
Proved reserves as of December 31, 1996..................... 12,772 144,316
====== =======
Proved developed reserves:
as of December 31, 1994................................... 5,840 52,215
====== =======
as of December 31, 1995................................... 7,055 67,797
====== =======
as of December 31, 1996................................... 9,260 109,628
====== =======
</TABLE>
F-20
<PAGE> 120
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
The following tables present the standardized measure of future net cash
flows related to proved oil and gas reserves together with changes therein, as
defined by the FASB. The oil, condensate and gas price structure utilized to
project future net cash flows reflects current prices at each year end and has
been escalated only where known and determinable price changes are provided by
contracts and law. Future production and development costs are based on current
costs with no escalations. Estimated future cash flows net of future income
taxes have been discounted to their present values based on a 10% annual
discount rate.
Crude oil and natural gas prices have declined from year-end 1996 to
February 28, 1997. Accordingly, the discounted future net cash flows would be
reduced if the standardized measure was calculated at the latter date. As a
result of the continued volatility in oil and natural gas markets, future prices
received from oil, condensate and natural gas sales may be higher or lower than
current levels.
<TABLE>
<CAPTION>
STANDARDIZED MEASURE
DECEMBER 31,
---------------------------------
1996 1995 1994
--------- -------- --------
<S> <C> <C> <C>
Future cash flows............................ $ 894,418 $347,796 $225,345
Future production and development costs...... (187,715) (89,739) (80,339)
Future income taxes.......................... (198,637) (56,146) (26,629)
--------- -------- --------
Future net cash flows........................ 508,066 201,911 118,377
10% annual discount.......................... (178,728) (57,121) (35,309)
--------- -------- --------
Standardized measure of discounted future net
cash flows................................ $ 329,338 $144,790 $ 83,068
========= ======== ========
</TABLE>
<TABLE>
<CAPTION>
CHANGES IN STANDARDIZED MEASURE
YEAR ENDED DECEMBER 31,
---------------------------------
1996 1995 1994
--------- -------- --------
<S> <C> <C> <C>
Standardized measure at beginning of year...... $ 144,790 $ 83,068 $ 84,404
Sales and transfers of oil and gas produced,
net of production costs...................... (43,389) (28,897) (21,730)
Changes in price, net of future production
costs........................................ 81,428 39,592 (15,388)
Extensions and discoveries, net of future
production and development costs............. 156,804 25,927 24,318
Changes in estimated future development costs,
net of development costs incurred during the
period....................................... (13,214) 6,717 (95)
Revisions of quantity estimates................ (19,372) 5,867 (7,745)
Accretion of discount.......................... 17,837 9,739 10,471
Net change in income taxes..................... (80,443) (19,257) 5,986
Purchase of reserves in place.................. 105,035 22,039 8,382
Sale of reserves in place...................... -- -- (4,994)
Changes in production rates (timing) and
other........................................ (20,138) (5) (541)
--------- -------- --------
Standardized measure at end of year............ $ 329,338 $144,790 $ 83,068
========= ======== ========
</TABLE>
F-21
<PAGE> 121
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
NOTE 12 -- SUMMARIZED QUARTERLY FINANCIAL INFORMATION -- UNAUDITED:
<TABLE>
<CAPTION>
FULLY
PRIMARY DILUTED
EARNINGS EARNINGS
NET PER PER
REVENUES EXPENSES INCOME SHARE SHARE
-------- -------- ------- -------- --------
<S> <C> <C> <C> <C> <C>
1996
First Quarter................................ $15,093 $11,831 $ 3,262 $0.27 $0.27
Second Quarter............................... 14,403 11,548 2,855 0.24 0.24
Third Quarter................................ 13,251 11,230 2,021 0.17 0.17
Fourth Quarter............................... 15,218 12,323 2,895 0.21 0.20
------- ------- ------- ----- -----
$57,965 $46,932 $11,033 $0.89 $0.88
======= ======= ======= ===== =====
1995
First Quarter................................ $ 8,176 $ 7,340 $ 836 $0.07 $0.07
Second Quarter............................... 10,278 8,693 1,585 0.13 0.13
Third Quarter................................ 10,656 9,060 1,596 0.14 0.14
Fourth Quarter............................... 11,441 9,642 1,799 0.15 0.15
------- ------- ------- ----- -----
$40,551 $34,735 $ 5,816 $0.49 $0.49
======= ======= ======= ===== =====
</TABLE>
NOTE 13 -- NEW ACCOUNTING STANDARDS:
In June 1997, the FASB issued SFAS No. 130, "Reporting Comprehensive
Income" and SFAS No. 131, "Disclosures About Segments of an Enterprise and
Related Information." SFAS No. 130 establishes standards for reporting and
display of comprehensive income in the financial statements. Comprehensive
income is the total of net income and all other nonowner changes in equity. SFAS
No. 131 requires that companies disclose segment data based on how management
makes decisions about allocating resources to segments and measuring their
performance. SFAS Nos. 130 and 131 are effective for 1998. Adoption of these
standards is not expected to have an effect on the Company's financial
statements, financial position or results of operations.
NOTE 14 -- SUBSEQUENT EVENTS:
The Company purchased certain interests in Vermilion Block 255 Field for
$36,600 on August 1, 1997. The field consists of interests in four Vermilion
blocks (255, 256, 267 and 268), and the working interests acquired range from
66.7% to 83.3%. The effective date of the acquisition was April 1, 1997, and net
cash flow from the property from April through July 1997, estimated at $2,400,
will be recorded as a reduction of the investment in the property. In addition
to the purchase price, the Company provided a bond in the amount of $8,800 to
secure abandonment obligations.
On August 8, 1997, the Company purchased for $1,500 the 80% working
interest of Nuevo Energy Company in its South Timbalier Block 8 Field, offshore
Louisiana, giving the Company a 98% working interest in approximately 1,592
acres in this field. The effective date of the transaction was June 1, 1997.
F-22
<PAGE> 122
STONE ENERGY CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(DOLLAR AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
(INFORMATION SUBSEQUENT TO DECEMBER 31, 1996 IS UNAUDITED)
NOTE 15 -- UNAUDITED INTERIM FINANCIAL STATEMENTS:
The unaudited consolidated financial statements have been prepared in
accordance with generally accepted accounting principles for interim financial
information and Rule 10.01 of Regulation S-X. Accordingly, they do not include
all of the information and footnotes required by generally accepted accounting
principles for complete financial statements. In the opinion of management, all
adjustments (consisting of normal recurring adjustments) considered necessary
for a fair presentation have been included. Operation results for the six months
ended June 30, 1997, are not necessarily indicative of results for the full
year.
F-23
<PAGE> 123
PART II
INFORMATION NOT REQUIRED IN THE PROSPECTUS
ITEM 20. INDEMNIFICATION OF DIRECTORS AND OFFICERS
The Registrant has authority under Section 145 of the General Corporation
Law of the State of Delaware to indemnify its officers, directors, employees and
agents to the extent provided in such statute. Article VI of the Registrant's
Bylaws, referenced as Exhibit 3.2 hereto, provides for indemnification of the
Registrant's officers, directors, employees and agents.
Section 102 of the Delaware General Corporation Law permits the limitation
of directors' personal liability to the Registrant or its stockholders for
monetary damages for breach of fiduciary duties as a director except in certain
situations including the breach of a director's duty of loyalty or acts or
omissions not made in good faith. Article Ninth of the Registrant's Certificate
of Incorporation limits directors' personal liability to the extent permitted by
Section 102.
Article VI of the Registrant's Bylaws provides that the Registrant may
maintain insurance, at its expense, to protect itself and any of its directors,
officers, employees or agents or any person serving at the request of the
Registrant as a director, officer, employee or agent of another corporation,
partnership, joint venture, trust or other enterprise, against any expense,
liability or loss, whether or not the Registrant would have the power to
indemnify such person against such expense, liability or loss under the Delaware
General Corporation Law.
Insofar as indemnification for liabilities arising under the Securities Act
of 1933, as amended (the "Securities Act") may be permitted to directors,
officers or persons controlling the Registrant pursuant to the foregoing
provisions, the Registrant has been informed that in the opinion of the
Securities and Exchange Commission such indemnification is against public policy
as expressed in the Securities Act and is therefore unenforceable.
ITEM 21. EXHIBITS AND FINANCIAL SCHEDULES
The following instruments and documents are included as Exhibits to this
Registration Statement. Exhibits incorporated by reference are so indicated by
parenthetical information.
<TABLE>
<CAPTION>
EXHIBIT NO. EXHIBIT
----------- -------
<C> <S> <C>
3.1 -- Certificate of Incorporation of Registration, as amended
(incorporated by reference to Exhibit 3.1 to the
Registrant's Registration Statement on Form S-1
(Registration No. 33-62362))
3.2 -- Restated Bylaws of Registrant (incorporated by reference to
Exhibit 3.2 to the Registrant's Registration Statement on
Form S-1 (Registration No. 33-62362))
*4.1 -- Indenture dated as of September 19, 1997 among the Company,
as issuer, and Texas Commerce Bank National Association, as
trustee
*4.2 -- Registration Agreement dated September 19, 1997 by and among
the Company and Salomon Brothers Inc, Credit Suisse First
Boston Corporation, Howard, Weil, Labouisse, Friedrichs
Incorporated, Morgan Stanley & Co. Incorporated and
NationsBanc Capital Markets, Inc.
*5.1 -- Opinion of Vinson & Elkins L.L.P.
*10.1 -- Third Amended and Restated Credit Agreement by and among the
Company and NationsBank of Texas, N.A. as agent for a group
of banks named therein
*10.2 -- Form of Exchange Agreement between the Company and Texas
Commerce Bank National Association, as Exchange Agent
*23.1 -- Consent of Arthur Andersen LLP
</TABLE>
II-1
<PAGE> 124
<TABLE>
<CAPTION>
EXHIBIT NO. EXHIBIT
----------- -------
<C> <S> <C>
*23.2 -- Consent of Atwater Consultants, Ltd.
*23.3 -- Consent of Cawley Gillespie & Associates
*23.4 -- Consent of Vinson & Elkins L.L.P. (included in Exhibit 5.1)
*25.1 -- Statement of Eligibility of Texas Commerce Bank National
Association
*99.1 -- Form of Letter of Transmittal
</TABLE>
- ---------------
* Previously filed.
ITEM 22. UNDERTAKINGS
The Company hereby undertakes that, for purposes of determining any
liability under the Securities Act, each filing of the Company's annual report
pursuant to section 13(a) or section 15(d) of the Exchange Act (and, where
applicable, each filing of an employee benefit plan's annual report pursuant to
section 15(d) of the Exchange Act) that is incorporated by reference in the
Registration Statement 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.
Insofar as indemnification for liabilities arising under the Securities Act
may be permitted to directors, officers and controlling persons of the Company
pursuant to the provisions described under Item 15 above, or otherwise, the
Company has been advised that, in the opinion of the Securities and Exchange
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 Company in the successful defense of any action, suit or
proceeding) is asserted by such director, officer or controlling person in
connection with the securities being registered, the Company 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.
The undersigned registrant hereby undertakes to respond to requests for
information that is incorporated by reference into the Prospectus pursuant to
Item 4, 10(b), 11, or 13 of this form, within one business day of receipt of
such request, and to send the incorporated documents by first class mail or
other equally prompt means. This includes information contained in documents
filed subsequent to the effective date of the Registration Statement through the
date of responding to the request.
The undersigned registrant hereby undertakes to supply by means of a
post-effective amendment all information concerning a transaction, and the
company being acquired involved therein, that was not the subject of and
included in the Registration Statement when it became effective.
II-2
<PAGE> 125
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 Lafayette, the State of
Louisiana on October 22, 1997.
STONE ENERGY CORPORATION
By: /s/ D. PETER CANTY
------------------------------------
D. Peter Canty
President and
Chief Operating Officer
Pursuant to the requirements of the Securities Act of 1933, this
Registration Statement has been signed by the following persons in the
capacities and on the dates indicated.
<TABLE>
<CAPTION>
NAME TITLE DATE
---- ----- ----
<C> <S> <C>
/s/ JAMES H. STONE Chairman of the Board and Chief October 22, 1997
- ----------------------------------------------------- Executive Officer (Principal
James H. Stone Executive Officer)
/s/ JOE R. KLUTTS Vice Chairman of the Board October 22, 1997
- -----------------------------------------------------
Joe R. Klutts
/s/ D. PETER CANTY President, Chief Operating Officer October 22, 1997
- ----------------------------------------------------- and Director
D. Peter Canty
/s/ MICHAEL L. FINCH Executive Vice President, Chief October 22, 1997
- ----------------------------------------------------- Financial Officer and Director
Michael L. Finch (Principal Financial Officer)
/s/ JAMES H. PRINCE Vice President, Chief October 22, 1997
- ----------------------------------------------------- Accounting Officer and
James H. Prince Controller (Principal Accounting
Officer)
/s/ DAVID R. VOELKER Director October 22, 1997
- -----------------------------------------------------
David R. Voelker
/s/ JOHN P. LABORDE Director October 22, 1997
- -----------------------------------------------------
John P. Laborde
/s/ ROBERT A. BERNHARD Director October 22, 1997
- -----------------------------------------------------
Robert A. Bernhard
/s/ RAYMOND B. GARY Director October 22, 1997
- -----------------------------------------------------
Raymond B. Gary
/s/ B. J. DUPLANTIS Director October 22, 1997
- -----------------------------------------------------
B. J. Duplantis
</TABLE>
II-3
<PAGE> 126
INDEX TO EXHIBITS
<TABLE>
<CAPTION>
EXHIBIT NO. EXHIBIT
----------- -------
<C> <S> <C>
3.1 -- Certificate of Incorporation of Registration, as amended
(incorporated by reference to Exhibit 3.1 to the
Registrant's Registration Statement on Form S-1
(Registration No. 33-62362))
3.2 -- Restated Bylaws of Registrant (incorporated by reference to
Exhibit 3.2 to the Registrant's Registration Statement on
Form S-1 (Registration No. 33-62362))
*4.1 -- Indenture dated as of September 19, 1997 among the Company,
as issuer, and Texas Commerce Bank National Association, as
trustee
*4.2 -- Registration Agreement dated September 19, 1997 by and among
the Company and Salomon Brothers Inc, Credit Suisse First
Boston Corporation, Howard, Weil, Labouisse, Friedrichs
Incorporated, Morgan Stanley & Co. Incorporated and
NationsBanc Capital Markets, Inc.
*5.1 -- Opinion of Vinson & Elkins L.L.P.
*10.1 -- Third Amended and Restated Credit Agreement by and among the
Company and NationsBank of Texas, N.A. as agent for a group
of banks named therein
*10.2 -- Form of Exchange Agreement between the Company and Texas
Commerce Bank National Association, as Exchange Agent
*23.1 -- Consent of Arthur Andersen LLP
*23.2 -- Consent of Atwater Consultants, Ltd.
*23.3 -- Consent of Cawley Gillespie & Associates
*23.4 -- Consent of Vinson & Elkins L.L.P. (included in Exhibit 5.1)
*25.1 -- Statement of Eligibility of Texas Commerce Bank National
Association
*99.1 -- Form of Letter of Transmittal
</TABLE>
- ---------------
* Previously filed.
