<PAGE> 1
Filed Pursuant to Rule 424(b)(5)
Registration No. 033-54809 and
No. 333-27363
<TABLE>
<S> <C>
PROSPECTUS SUPPLEMENT [SOCO LOGO]
(To Prospectus Dated May 21, 1997)
</TABLE>
$175,000,000
SNYDER OIL CORPORATION
8 3/4% SENIOR SUBORDINATED NOTES DUE 2007
---------------------
The 8 3/4% Senior Subordinated Notes due 2007 (the "Notes") are being
offered (the "Offering") by Snyder Oil Corporation, a Delaware corporation (the
"Company"). The net proceeds of this Offering will be used to repay certain
existing indebtedness and for general corporate purposes. See "Use of Proceeds."
The Notes mature on June 15, 2007, unless previously redeemed. Interest on
the Notes is payable semiannually on June 15 and December 15, commencing
December 15, 1997. The Notes will be redeemable at the option of the Company, in
whole or in part, on or after June 15, 2002, at the redemption prices set forth
herein, plus accrued and unpaid interest, if any, to the redemption date.
Notwithstanding the foregoing, at any time on or before June 15, 2000, the
Company may redeem up to 30% of the original aggregate principal amount of the
Notes with the net cash proceeds of a Public Equity Offering (as defined herein)
at a redemption price equal to 108.750% of the principal amount thereof, plus
accrued and unpaid interest, if any, to the redemption date; provided, that at
least $122,500,000 of the aggregate principal amount of the Notes originally
issued remain outstanding immediately after such redemption. Upon a Change of
Control (as defined herein), the Company will be required to make an offer to
purchase all outstanding Notes at 101% of the aggregate principal amount thereof
plus accrued and unpaid interest, if any, to the date of repurchase. See
"Description of Notes."
The Notes will be general unsecured obligations of the Company, subordinated
in right of payment to all existing and future Senior Indebtedness (as defined
herein) of the Company, which will include borrowings under the Credit Facility
(as defined herein). As of March 31, 1997, on a pro forma basis after giving
effect to the Offering and the application of the proceeds therefrom as
described under "Use of Proceeds," the Company, excluding its Unrestricted
Subsidiaries (as defined herein), would have had no Senior Indebtedness
outstanding. Following the redemption of the Company's 7% convertible
subordinated notes due 2001 (the "Convertible Subordinated Notes") as described
under "Use of Proceeds," no Indebtedness (as defined herein) of the Company will
be expressly subordinated to the Notes. The Notes will be unconditionally
guaranteed on a senior subordinated basis by certain of the Company's
subsidiaries (the "Subsidiary Guarantors"), provided that such guarantees will
terminate under certain circumstances. See "Risk Factors," "Capitalization" and
"Description of Notes."
The Notes will be represented by a Global Certificate registered in the name
of the nominee of The Depository Trust Company, which will act as the Depositary
(the "Depositary"). Beneficial interests in the Global Certificate will be shown
on, and transfers thereof will be effected only through, records maintained by
the Depositary and its participants. Except as described herein, Notes in
definitive form will not be issued. See "Description of Notes -- Book-Entry,
Delivery and Form."
The Company does not intend to list the Notes on any national securities
exchange. See "Risk Factors -- Absence of Public Market."
SEE "RISK FACTORS" BEGINNING ON PAGE S-12 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 SUPPLEMENT OR THE ACCOMPANYING
PROSPECTUS TO WHICH IT RELATES. ANY REPRESENTATION TO THE CONTRARY IS A CRIMINAL
OFFENSE.
<TABLE>
<CAPTION>
- ---------------------------------------------------------------------------------------------------------------------------------
PRICE TO DISCOUNTS AND PROCEEDS TO
PUBLIC(1) COMMISSIONS(2) COMPANY(3)
- ---------------------------------------------------------------------------------------------------------------------------------
<S> <C> <C> <C>
Per Note........................................... 99.179% 2.727% 96.452%
Total.............................................. $173,563,250 $4,772,989 $168,790,261
- ------------------------------------------------------------------------------------------------------------------------------
</TABLE>
(1) Plus accrued interest, if any, from June 10, 1997.
(2) The Company and the Subsidiary Guarantors have agreed, jointly and
severally, to indemnify the Underwriters (as defined herein) against certain
liabilities, including liabilities under the Securities Act of 1933, as
amended. See "Underwriting."
(3) Before deducting expenses payable by the Company, estimated at $500,000.
The Notes are being offered, subject to prior sale, by the Underwriters
when, as and if issued to and accepted by the Underwriters, and subject to
various prior conditions. The Underwriters reserve the right to withdraw, cancel
or modify such offer and to reject orders in whole or in part. It is expected
that delivery of the Global Certificate will be made on or about June 10, 1997
in book-entry form through the facilities of the Depositary, against payment
therefor.
NATIONSBANC CAPITAL MARKETS, INC.
CHASE SECURITIES INC.
SMITH BARNEY INC.
PETRIE PARKMAN & CO.
The date of this Prospectus Supplement is June 5, 1997
<PAGE> 2
[OPERATING AREA MAP]
CERTAIN PERSONS PARTICIPATING IN THE OFFERING MAY ENGAGE IN TRANSACTIONS THAT
STABILIZE, MAINTAIN OR OTHERWISE AFFECT THE PRICE OF THE NOTES. SPECIFICALLY,
THE UNDERWRITERS MAY OVER-ALLOT IN CONNECTION WITH THE OFFERING AND MAY BID FOR,
AND PURCHASE, NOTES IN THE OPEN MARKET. FOR A DESCRIPTION OF THESE ACTIVITIES,
SEE "UNDERWRITING."
<PAGE> 3
PROSPECTUS SUPPLEMENT SUMMARY
The following Summary is qualified in its entirety by, and should be read
in conjunction with, the more detailed information and Consolidated Financial
Statements and the notes thereto appearing elsewhere or incorporated by
reference herein or in the Prospectus. References to the "Company" refer to
Snyder Oil Corporation and its predecessors and subsidiaries unless the context
otherwise requires. References to the "Restricted Group" refer to the Company
and its Restricted Subsidiaries (as defined herein). Unless otherwise stated,
information herein relates to the Company and its Restricted Subsidiaries and
Unrestricted Subsidiaries (as defined herein). See "Glossary" for definitions of
certain oil and gas terms used in this Prospectus Supplement. Investors should
carefully consider the information set forth under the heading "Risk Factors."
THE COMPANY
GENERAL
Snyder Oil Corporation is an independent energy company engaged in oil and
gas development, acquisition, exploration and production activities primarily in
the Gulf of Mexico, western Rocky Mountains and North Louisiana. The Company
also gathers, transports and markets natural gas near its principal producing
properties. In addition, through its affiliates, the Company participates in
international exploration and production. From 1991 through 1996, the Company
pursued a balanced strategy of acquisitions and development drilling. During
this period, the Company's revenues increased from $86.6 million to $292.4
million and Adjusted EBITDA (as defined herein) increased from $43.7 million to
$126.8 million. At December 31, 1996, the Company's proved reserves totaled
141.4 million BOE having a Present Value of $1.2 billion. Approximately 71% of
these reserves are natural gas. The Company operates more than 3,500 wells that
account for almost 90% of its developed reserves.
The Company's domestic operations are focused on three core areas, each
with the potential to contribute significantly to future growth:
- Gulf of Mexico. The Company had proved reserves in the Gulf of Mexico of
17.4 million BOE at December 31, 1996, concentrated in the Pabst, Busch
and Ingrid Fields of the Main Pass area offshore Mississippi. The
production from the Pabst and Busch Fields typically has been restricted
to 100 MMcf (42 MMcf net) of gas per day but is expected to increase to
more than 150 MMcf (62 MMcf net) per day following the expansion of
pipeline capacity serving these fields in early 1998. During 1997 the
Company intends to begin installation of a platform and production
facilities with total initial capacity of 100 MMcf per day on its
50%-owned Ingrid Field, with production commencing in early 1998. The
Company plans to expand its activities in the Gulf of Mexico
significantly and has budgeted approximately $59 million for development
and exploration in this area in 1997.
- Western Rocky Mountains. The Company had proved reserves in Wyoming,
western Colorado and Utah of 50.3 million BOE at December 31, 1996. These
reserves are concentrated in gas development programs in the Washakie,
Green River and Piceance Basins, and in two large, mature non-operated
oil fields in northern Wyoming. The Company has also initiated gas
projects in the Wind River and Big Horn Basins and an oil project in
Utah. The Company recently formed a gas marketing joint venture with
Coastal Corporation, one of the largest gas marketers in North America.
This joint venture is expected further to enhance efficiencies and
downstream marketing opportunities for the Company's western Rocky
Mountain gas operations. The Company has budgeted approximately $43
million for continued development and exploration in the western Rocky
Mountains during 1997.
- North Louisiana. The Company owns over 300,000 net mineral acres, with
leases and lease options covering more than 225,000 additional net acres,
in North Louisiana. The Company has identified a number of exploration
prospects as a result of an initial 48 square mile 3-D seismic survey,
and is in the process of performing an additional 110 square mile 3-D
survey. Based on these surveys, the Company expects to begin drilling
activities in North Louisiana by the end of 1997. The Company expects
expenditures in North Louisiana to total approximately $4 million in
1997.
S-3
<PAGE> 4
BUSINESS STRATEGY
In early 1995, the Company began a strategic repositioning program to
improve operating performance and enhance reserve and production growth
opportunities by (i) reducing its dependence on the Rocky Mountains through the
acquisition of significant properties in the Gulf of Mexico and the addition of
partners to its major Rocky Mountain projects, (ii) disposing of selected
non-core properties, (iii) reducing operating costs and (iv) increasing
financial flexibility. Through the implementation of this repositioning program,
over the last two years the Company has sold over 300 non-core properties with
limited upside potential, leaving it with 30 projects of which two-thirds are
believed to provide significant opportunities for growth. During the same
period, the Company has reduced employment by over 20% while increasing proved
reserves by 18%.
Key elements of the Company's business strategy are summarized below:
Geographic Focus. The Company's domestic operations are concentrated in the
Gulf of Mexico, the western Rocky Mountains and North Louisiana. By focusing on
a select number of core geographic areas, the Company believes that it can
maximize operating and administrative cost efficiencies and leverage the
technical expertise gained in these areas to its competitive advantage.
Development and Exploitation. The Company initiates development drilling,
recompletions and other production enhancement techniques to maximize production
and reserves. During 1996, the Company spent $36.7 million to drill or
recomplete 75 wells in its core areas and has budgeted approximately $94 million
for such activities in 1997. The Company has identified over 700 development and
exploitation locations on its existing core properties, representing a 10-year
inventory at 1996 drilling levels.
Exploration. The Company selectively pursues higher risk, higher potential
return projects and manages its exploration risks through the use of 3-D seismic
and other advanced technologies as well as through joint venture partners. Also,
the geographic and geological diversity of the Company's exploration
opportunities in its core areas mitigates its economic risk. The Company
expended $4.6 million on exploration activities in 1996 and intends to expend
approximately $12 million on such activities in the Gulf of Mexico, the western
Rocky Mountains and North Louisiana during 1997.
Acquisitions. The Company continually evaluates opportunities to acquire
oil and gas properties that complement its existing reserve base or that may
allow it to develop new core areas. The Company evaluates potential acquisitions
based on various factors, including development potential, profit enhancement
opportunity, geographic concentration and reserve and production attributes. In
1996, the Company spent $72.1 million to increase its core holdings in the Gulf
of Mexico.
Cost-Effective Operations. The Company is committed to maintaining a
cost-effective operating structure. During 1996, the Company streamlined its
organizational structure and enhanced its operations by concentrating on core
geographic areas pursuant to its repositioning program. Further, the Company
operates properties collectively representing almost 90% of the Present Value of
its proved reserves, which provides it with significant control over the timing
and the extent of operating and drilling costs.
Financial Flexibility. The Company believes that maintaining financial
flexibility will enable it to respond quickly to acquisition opportunities and
changing market conditions. As of March 31, 1997, on a pro forma basis to
reflect completion of the Offering and application of the proceeds therefrom as
described under "Use of Proceeds," the Company, excluding its Unrestricted
Subsidiaries, would have had no Senior Indebtedness outstanding, and its
borrowing base under the Credit Facility would have been $120.0 million. The
Company anticipates that it will be able to fund its capital expenditures
largely through operating cash flow. In addition, the Company has significant
investments in Patina Oil & Gas Corporation ("Patina") and SOCO International,
Inc. ("SOCO International"), as described below.
S-4
<PAGE> 5
During 1996, the Company consolidated its Wattenberg Field properties in
Colorado with those of Gerrity to create Patina, a New York Stock Exchange
listed company of which the Company owns approximately 74% (14.0 million
shares). Through the formation of Patina, the Company converted its working
interest in the field into a controlling interest in the field's largest
producer. At December 31, 1996, Patina held interests in over 3,600 wells with
proved reserves of approximately 71.9 million BOE, approximately 70% of which
were attributable to natural gas.
The Company's international operations are conducted through its wholly
owned subsidiary, SOCO International. SOCO International operates through a
holding company that owns 11.7 million shares (approximately 7%) of Cairn Energy
plc ("Cairn"), a publicly-traded Scotland-based exploration and production
company. Until May 1997, SOCO International also operated through a 90%-owned
operating subsidiary that had investments in Mongolia, Russia and Thailand.
Recently, however, the Company completed a public offering of the international
operating company, whose common stock is now listed on the London Stock
Exchange. See "-- Recent Developments." The Company's investments in Patina and
Cairn had market values of $124.3 million and $98.4 million, respectively, at
June 3, 1997.
RESTRICTED GROUP
Patina and SOCO International (and their respective subsidiaries) will be
Unrestricted Subsidiaries and, as a result, they will be neither part of the
Restricted Group nor Subsidiary Guarantors. In addition, the Indenture (as
defined herein) will not restrict the Company's ability to dispose of all or
part of its interests in such Unrestricted Subsidiaries and to use the proceeds
of any such disposition for corporate or other purposes. In 1996, the Restricted
Group would have had pro forma revenues and Adjusted EBITDA of $198.3 million
and $85.5 million, respectively. At December 31, 1996, the Restricted Group's
proved reserves totaled 69.5 million BOE having a Present Value of $578.2
million. See "Risk Factors -- Unrestricted Subsidiaries."
The following summary diagram illustrates the corporate structure of the
Company and its subsidiaries:
[CORPORATE STRUCTURE]
S-5
<PAGE> 6
RECENT DEVELOPMENTS
SOCO International. In May 1997, SOCO International transferred its 90%
interest in SOCO International Operations, Inc. ("Operations"), which held the
Company's investments in Mongolia, Russia and Thailand, to SOCO International
plc ("SOCO plc"), a recently formed United Kingdom company, in exchange for
shares of SOCO plc stock. SOCO plc also acquired the interests of a number of
minority investors in Operations' ventures and assets in Yemen, Tunisia and
onshore England from Cairn. At the time of the acquisitions, SOCO plc, which is
listed on the London Stock Exchange, completed a public offering of its common
shares that raised approximately $75 million of new equity capital to fund its
continuing exploration and development expenditures. The 7.8 million shares of
SOCO plc acquired by the Company represent approximately 15.9% of SOCO plc and
had a market value of $30.2 million at June 3, 1997. Under London Stock Exchange
rules, the Company will not be permitted to sell these shares for two years.
Edward T. Story, a director and former Vice President -- International of the
Company, is the chief executive officer of SOCO plc.
Significant Drilling Results. In the Gulf of Mexico, the Company has
completed one successful exploration well and two development wells during 1997.
In High Island 208, an exploratory well in which the Company holds a 60% working
interest logged two separate productive intervals which were tested at a
combined rate of 18.6 MMcf of gas and 160 barrels of condensate per day.
Production began from the lower interval in late May 1997. This interval, which
had tested at 6 MMcf per day, is producing at a daily rate of approximately 11
MMcf of gas and 60 barrels of condensate. The Company will evaluate the timing
of completing the upper zone, which tested at a daily rate of 16 MMcf per day,
after further observation of the lower level.
In the Pabst Field in Main Pass 259, where the Company has a 60% working
interest, two development wells have been completed since the end of the first
quarter. One well is producing at a daily rate of approximately 16.5 MMcf of gas
and 2,900 barrels of condensate. The other well is producing at a daily rate of
20 MMcf of gas and 250 barrels of condensate.
S-6
<PAGE> 7
THE OFFERING
Securities Offered......... $175,000,000 aggregate principal amount of 8 3/4%
Senior Subordinated Notes due 2007 of the Company
(the "Notes").
Maturity Date.............. June 15, 2007.
Interest Payment Dates..... June 15 and December 15, commencing December 15,
1997.
Optional Redemption........ The Notes will be redeemable at the option of the
Company, in whole or in part, at any time on or
after June 15, 2002, at the redemption prices set
forth herein, together with accrued and unpaid
interest, if any, to the date of redemption.
Notwithstanding the foregoing, at any time on or
before June 15, 2000, the Company may redeem up to
30% of the original aggregate principal amount of
the Notes with the net proceeds of a Public Equity
Offering (as defined herein) at a redemption price
equal to 108.75% of the principal amount thereof,
plus accrued and unpaid interest, if any, to the
redemption date; provided, that at least
$122,500,000 of the aggregate principal amount of
the Notes originally issued remain outstanding
immediately after such redemption. See "Description
of Notes -- Optional Redemption."
Mandatory Redemption....... None, except at maturity on June 15, 2007.
Ranking.................... The Notes will be general unsecured obligations of
the Company, subordinated in right of payment to
all existing and future Senior Indebtedness of the
Company, which will include borrowings under the
Credit Facility. As of March 31, 1997, on a pro
forma basis, the Company, excluding its
Unrestricted Subsidiaries, would have had no
outstanding Senior Indebtedness. See "Risk
Factors -- Subordination of Notes,"
"Capitalization" and "Description of
Notes -- Subordination."
Subsidiary Guarantees...... The Notes will be unconditionally guaranteed (the
"Subsidiary Guarantees") by certain of the
Company's subsidiaries (the "Subsidiary
Guarantors"). The Subsidiary Guarantees will be
general unsecured senior subordinated obligations
of the Subsidiary Guarantors and will be
subordinated in right of payment to all existing or
future senior indebtedness of the Subsidiary
Guarantors. The Subsidiary Guarantees may be
released under certain circumstances. See
"Description of Notes -- Senior Subordinated
Guarantees of Notes."
Change of Control.......... Upon a Change of Control (as defined herein), the
Company will be required to make an offer to
repurchase all outstanding Notes at 101% of the
principal amount thereof plus accrued and unpaid
interest to the date of redemption. See
"Description of Notes -- Repurchase at the Option
of Holders -- Change of Control."
Covenants.................. The Indenture (as defined herein) pursuant to which
the Notes will be issued will contain certain
covenants, including, but not limited to, covenants
with respect to the following matters: (i)
limitation on disposition of proceeds of asset
sales; (ii) limitation on the ownership of capital
stock of restricted subsidiaries; (iii) limitation
on restricted payments; (iv) limitation on the
incurrence of indebtedness; (v) limitation on
liens; (vi) limitation on guarantees of
indebtedness by restricted subsidiaries; (vii)
limitation on dividends and other payment
restrictions affecting restricted subsidiaries;
(viii) limitation on layering debt; (ix) limitation
on mergers, consolidations or sales of assets; and
S-7
<PAGE> 8
(x) limitation on transactions with affiliates. See
"Description of Notes -- Repurchase at the Option
of Holders" and "-- Certain Covenants."
Use of Proceeds............ The Company intends to use approximately $85
million of the net proceeds of the Offering to
redeem its Convertible Subordinated Notes,
approximately $57 million to repay indebtedness
under the Credit Facility and the balance for
general corporate purposes. See "Use of Proceeds."
RISK FACTORS
See "Risk Factors" for a discussion of certain matters that should be
considered in evaluating an investment in the Notes.
S-8
<PAGE> 9
SUMMARY FINANCIAL DATA
The following tables present summary consolidated historical Company and
Pro Forma Restricted Group financial, reserve and operating data and should be
read in conjunction with the Consolidated Financial Statements and the notes
thereto presented elsewhere herein. Pro Forma Restricted Group data reflect
Patina and SOCO International as investments accounted for in accordance with
the equity method of accounting and give effect to the Offering and application
of proceeds therefrom as described under "Use of Proceeds" and significant 1996
and 1997 transactions as if they had occurred on January 1, 1996 and 1997,
respectively, for statement of operations data, and on March 31, 1997 for
balance sheet data. See "Unaudited Pro Forma Condensed Consolidated Restricted
Group Financial Information."
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31, THREE MONTHS ENDED MARCH 31,
-------------------------------------------- --------------------------------
PRO FORMA PRO FORMA
RESTRICTED RESTRICTED
HISTORICAL GROUP(A) HISTORICAL GROUP(A)
------------------------------- ---------- ------------------- ----------
1994 1995 1996 1996 1996 1997 1997
--------- -------- -------- ---------- -------- -------- ----------
(IN THOUSANDS, EXCEPT RATIOS)
<S> <C> <C> <C> <C> <C> <C> <C>
STATEMENT OF OPERATIONS DATA
Revenues
Oil and gas sales....................... $ 137,858 $144,608 $189,327 $122,643 $ 36,122 $ 67,848 $38,408
Gas transportation, processing and
marketing............................. 107,247 38,256 17,655 17,477 4,451 4,209 4,209
Gains on sales of equity interests in
investees............................. 9,747 2,183 69,343 439 407 13,000 --
Gains (losses) on sales of properties... 1,969 12,254 8,786 8,786 (20) 2,607 2,607
Equity in earnings (losses) of
investees............................. 1,355 (1,319) 421 39,440 (88) 222 10,932
Other................................... 4,152 6,178 6,882 9,562 847 869 1,856
--------- -------- -------- -------- -------- -------- -------
262,328 202,160 292,414 198,347 41,719 88,755 58,012
Expenses
Direct operating........................ 46,267 52,486 49,638 33,038 10,759 14,021 9,046
Cost of gas and transportation.......... 94,177 29,374 15,020 14,951 3,696 4,191 4,191
Exploration............................. 6,505 8,033 4,232 3,397 514 1,700 1,641
General and administrative.............. 12,853 17,680 17,143 10,795 3,868 5,492 3,934
Interest................................ 10,337 21,679 23,587 15,695 3,614 6,787 3,932
Other................................... 2,126 5,322 5,312 5,440 679 1,756 1,791
Depletion, depreciation and
amortization.......................... 70,770 76,378 84,547 42,491 16,771 23,208 10,780
Property impairments.................... 5,783 27,412 2,753 2,753 -- -- --
Litigation settlement................... -- 4,400 -- -- -- -- --
Loss on sale of subsidiary interest..... -- -- 15,481 15,481 -- -- --
--------- -------- -------- -------- -------- -------- -------
Income (loss) before taxes and minority
interest................................ 13,510 (40,604) 74,701 54,306 1,818 31,600 22,697
Net income (loss)......................... 12,372 (39,831) 62,950 68,782 1,777 19,926 19,100
STATEMENT OF CASH FLOWS DATA
Net cash provided by operations........... $ 86,397 $ 69,121 $101,730 $ 26,709 $ 51,775
Net cash realized (used) by investing..... (245,503) 32,421 (62,356) (13,542) (7,380)
Net cash realized (used) by financing..... 169,926 (96,012) (38,715) 2,905 (34,425)
OTHER FINANCIAL DATA
Adjusted EBITDA(b)........................ $93,834... $ 84,180 $126,751 $ 85,458 $ 22,418 $ 47,466 $25,511
Capital expenditures(c)................... 279,288 99,741 348,952 (d) 12,907 23,806 (d)
Ratio of Adjusted EBITDA to interest
expense................................. 9.1x 3.9x 5.4x 5.4x 6.2x 7.0x 6.5x
Ratio of Adjusted EBITDA to interest
expense and preferred stock dividends
(tax effected)(e)....................... 4.3x 3.0x 4.2x 3.9x 4.3x 5.3x 4.4x
Ratio of total debt to Adjusted EBITDA.... 3.4x 2.8x 2.9x 2.2x
Ratio of earnings to fixed charges(f)..... 2.3x -- 3.9x 4.5x 1.5x 5.3x 6.8x
</TABLE>
<TABLE>
<CAPTION>
AT MARCH 31, 1997
---------------------------------------
AS ADJUSTED
RESTRICTED RESTRICTED
HISTORICAL GROUP(G) GROUP(G)
---------- ---------- -----------
(IN THOUSANDS)
<S> <C> <C> <C>
BALANCE SHEET DATA
Cash and equivalents...................................... $ 37,892 $ 29,033 $ 57,067
Investments............................................... 124,015 171,415 171,415
Oil and gas properties, net............................... 635,633 242,331 242,331
Total assets.............................................. 862,531 485,562 518,869
Total debt................................................ 320,988 133,625 173,563
Stockholders' equity...................................... 311,329 287,054 284,148
</TABLE>
(see notes on the following page)
S-9
<PAGE> 10
- ---------------
(a) Pro Forma Restricted Group reflects Patina and SOCO International as
investments accounted for in accordance with the equity method of accounting
and gives effect to the Offering and the application of net proceeds
therefrom as described under "Use of Proceeds" and significant acquisitions
and dispositions as if they had occurred at the beginning of the period
indicated.
(b) Adjusted EBITDA is defined as income (loss) before taxes, minority interest,
interest expense, depletion, depreciation and amortization, exploration
expense and certain other unusual or non-operating items and is calculated
as follows:
<TABLE>
<CAPTION>
THREE MONTHS
YEAR ENDED DECEMBER 31, ENDED MARCH 31,
-------------------------------------------- -------------------------------
PRO PRO
FORMA FORMA
RESTRICTED RESTRICTED
HISTORICAL GROUP HISTORICAL GROUP
------------------------------- ---------- ------------------ ----------
1994 1995 1996 1996 1996 1997 1997
------- ---------- -------- ---------- ------- -------- ----------
<S> <C> <C> <C> <C> <C> <C> <C>
Income (loss) before taxes and minority
interest............................. $13,510 $(40,604) $ 74,701 $ 54,306 $ 1,818 $ 31,600 $ 22,697
Interest expense....................... 10,337 21,679 23,587 15,695 3,614 6,787 3,932
Depletion, depreciation and
amortization......................... 70,770 76,378 84,547 42,491 16,771 23,208 10,780
Exploration expense.................... 6,505 8,033 4,232 3,397 514 1,700 1,641
Gains on sales of equity interests in
investees............................ (9,747) (2,183) (69,343) (439) (407) (13,000) --
(Gains) losses on sales of
properties........................... (1,969) (12,254) (8,786) (8,786) 20 (2,607) (2,607)
Equity in (earnings) losses of
investees............................ (1,355) 1,319 (421) (39,440) 88 (222) (10,932)
Property impairments................... 5,783 27,412 2,753 2,753 -- -- --
Litigation settlement.................. -- 4,400 -- -- -- -- --
Loss on sale of subsidiary interest.... -- -- 15,481 15,481 -- -- --
------- -------- -------- -------- ------- -------- --------
Adjusted EBITDA........................ $93,834 $ 84,180 $126,751 $ 85,458 $22,418 $ 47,466 $ 25,511
======= ======== ======== ======== ======= ======== ========
</TABLE>
Adjusted EBITDA is presented because it is a widely accepted financial
indicator of a company's ability to service debt. Adjusted EBITDA is not
intended to represent net income or cash flow in accordance with generally
accepted accounting principles and should not be considered a measure of a
company's profitability or liquidity.
(c) 1996 capital expenditures include $218.4 million related to the formation of
Patina and the subsequent May 1996 acquisition of Gerrity.
(d) Capital expenditures for the Restricted Group for the year ended December
31, 1996 and for the three months ended March 31, 1997 were $120.1 million
and $18.0 million, respectively.
(e) The ratio of Adjusted EBITDA to interest expense and preferred stock
dividends (tax effected) is calculated as Adjusted EBITDA divided by
interest expense plus dividends on the Company's 6% convertible preferred
stock divided by one minus the effective consolidated income tax rate for
the Company, and is equivalent to the Consolidated Fixed Charge Coverage
Ratio as defined in the Indenture. See "Description of Notes."
(f) For purposes of calculating the ratio of earnings to fixed charges,
"earnings" are net income (loss) before income taxes, minority interest and
interest expense. Fixed charges consist of interest expense and preferred
stock dividends of consolidated subsidiaries. Earnings were inadequate to
cover fixed charges by $40.6 million for the year ended December 31, 1995.
(g) Restricted Group reflects Patina and SOCO International as investments
accounted for in accordance with the equity method of accounting. As
Adjusted Restricted Group reflects the Restricted Group adjusted for the
Offering and the application of net proceeds therefrom as described under
"Use of Proceeds."
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<PAGE> 11
SUMMARY RESERVE DATA
<TABLE>
<CAPTION>
AS OF OR FOR THE YEAR ENDED DECEMBER 31,
---------------------------------------------------
RESTRICTED
HISTORICAL GROUP
------------------------------------ ----------
1994 1995 1996(A) 1996
-------- -------- ---------- ----------
<S> <C> <C> <C> <C>
ESTIMATED PROVED RESERVES
Oil (MBbl)................................................ 34,977 24,247 40,497 18,022
Gas (MMcf)................................................ 511,251 395,718 605,636 308,977
Equivalent barrels (MBOE)................................. 120,186 90,200 141,436 69,518
Percent of proved developed reserves...................... 71% 85% 75% 71%
Present Value (in thousands).............................. $414,367 $372,811 $1,227,004(b) $578,207(b)
Reserve life index (in years)(c).......................... 10.3 6.9 10.7 8.2
RESERVE ADDITIONS (MBOE)
Purchases................................................. 19,421 4,243 54,280 7,825
Extensions, discoveries and revisions..................... 9,304 (12,287) 22,368 21,449
-------- -------- ---------- --------
Total reserve additions (reductions)...................... 28,725 (8,044) 76,648 29,274
-------- -------- ---------- --------
COSTS INCURRED (IN THOUSANDS)
Acquisitions of proved reserves........................... $ 44,684 $ 13,675 $ 273,088 $ 52,094
Development............................................... 156,912 62,578 43,075 36,697
Exploration............................................... 5,514 8,214 4,588 4,008
-------- -------- ---------- --------
Total costs incurred...................................... $207,110 $ 84,467 $ 320,751 $ 92,799
-------- -------- ---------- --------
RESERVE REPLACEMENT DATA
Finding costs per BOE(d).................................. $ 7.21 (f) $ 4.18 $ 3.17
Production replacement(e)................................. 246% (f) 581% 390%
</TABLE>
- ---------------
(a) Proved reserves of 8.6 million BOE (with a Present Value of $25.8 million)
assigned to SOCO International projects in Russia at December 31, 1996 are
not included in the table.
(b) Based on benchmark prices of $20.00 per barrel of oil and $2.25 per Mcf of
gas, the Present Value as of December 31, 1996 would have been $690.9
million for the total Company and $326.4 million for the Restricted Group.
See "Risk Factors -- Price Fluctuations and Markets."
(c) Year end proved reserves divided by annual production for the respective
year.
(d) Total costs incurred divided by total reserve additions for the respective
year.
(e) Total reserve additions during the respective year divided by production for
such year.
(f) In 1995 price declines resulted in downward reserve revisions which led to a
net reduction in proved reserves. Accordingly, 1995 finding costs per BOE
and production replacement are not meaningful.
SUMMARY OPERATING DATA
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
----------------------------------------
PRO FORMA
RESTRICTED
HISTORICAL GROUP(A)
--------------------------- ----------
1994 1995 1996 1996
------- ------- ------- ----------
<S> <C> <C> <C> <C>
PRODUCTION DATA
Oil (MBbl)............................ 4,366 4,278 3,884 2,149
Gas (MMcf)............................ 43,809 53,227 55,840 37,772
Equivalent barrels (MBOE)............. 11,668 13,149 13,191 8,444
AVERAGE PRICES
Oil (per Bbl)......................... $ 14.80 $ 16.96 $ 20.39 $ 20.10
Gas (per Mcf)......................... 1.67 1.35 1.97 2.10
Equivalent barrels (per BOE).......... 11.82 11.00 14.35 14.52
AVERAGE COSTS (PER BOE)
Direct operating...................... $ 3.97 $ 3.99 $ 3.76 $ 3.91
General and administrative............ 1.10 1.34 1.30 1.28
Depletion, depreciation and
amortization........................ 6.07 5.80 6.41 5.03
<CAPTION>
THREE MONTHS ENDED MARCH 31,
--------------------------------
PRO FORMA
RESTRICTED
HISTORICAL GROUP(A)
------------------ ----------
1996 1997 1997
------- ------- ----------
<S> <C> <C> <C>
PRODUCTION DATA
Oil (MBbl)............................ 823 1,002 523
Gas (MMcf)............................ 11,994 16,472 9,801
Equivalent barrels (MBOE)............. 2,822 3,748 2,157
AVERAGE PRICES
Oil (per Bbl)......................... $ 17.95 $ 21.18 $ 20.84
Gas (per Mcf)......................... 1.78 2.83 2.81
Equivalent barrels (per BOE).......... 12.80 18.10 17.81
AVERAGE COSTS (PER BOE)
Direct operating...................... $ 3.81 $ 3.74 $ 4.19
General and administrative............ 1.37 1.47 1.82
Depletion, depreciation and
amortization........................ 5.94 6.19 5.00
</TABLE>
- ---------------
(a) Pro Forma Restricted Group reflects Patina and SOCO International as
investments accounted for in accordance with the equity method of accounting
and gives effect to significant acquisitions and dispositions as if they had
occurred at the beginning of the period indicated.
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<PAGE> 12
RISK FACTORS
Prospective purchasers of the Notes should carefully review the information
contained elsewhere in this Prospectus Supplement and in the accompanying
Prospectus and should particularly consider the following matters:
PRICE FLUCTUATIONS AND MARKETS
The Company's results of operations are highly dependent upon the prices
received for the Company's oil and natural gas production. 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. Accordingly, the prices received by the Company for its
oil and natural gas production are dependent upon numerous factors beyond the
control of the Company. These factors include, but are not limited to, the level
of consumer product demand, governmental regulations and taxes, the price and
availability of alternative fuels, the level of foreign imports of oil and
natural gas, and the overall economic environment. Significant declines in
prices for oil and natural gas could have a material adverse effect on the
Company's financial condition, results of operations and quantities of reserves
recoverable on an economic basis. Should the industry experience significant
price declines from current levels or other adverse market conditions, the
Company may not be able to generate sufficient cash flow from operations to meet
its obligations and make planned capital expenditures. See "Management's
Discussion and Analysis of Financial Condition and Results of
Operations -- Financial Condition and Capital Resources."
Prices in effect at December 31, 1996 averaged $24.47 per barrel of oil and
$3.59 per Mcf of gas. Year end gas prices, although typically higher than prices
prevailing through most of a calendar year, were at or near all time highs and
significantly higher than prices prevailing throughout most of 1996. Prices for
both oil and gas have fallen since year end, partially as the result of
decreased demand associated with warm weather. Price reductions decrease reserve
values by lowering the future net revenues attributable to the reserves and also
by reducing the quantities of reserves that are recoverable on an economic
basis. Price increases have the opposite effect. Any significant decline in
prices of oil or gas could have a material adverse effect on the Company's
financial condition and results of operations.
The availability of a ready market for the Company's oil and natural gas
production also depends on a number of factors, including the demand for and
supply of oil and natural gas and the proximity of reserves to, and the capacity
of, oil and gas gathering systems, pipelines or trucking and terminal
facilities. Wells may be shut-in or constrained for lack of a market or due to
inadequacy or unavailability of pipeline or gathering system capacity.
REPLACEMENT OF RESERVES
In general, the volume of production from oil and natural gas properties
declines as reserves are depleted. Except to the extent the Company acquires
properties containing proved reserves or conducts successful development and
exploration activities, or both, the proved reserves of the Company will decline
as reserves are produced. The Company's future oil and gas production is,
therefore, highly dependent upon its level of success in finding or acquiring
additional reserves at attractive rates of return. In order to increase reserves
and production, the Company must continue its development drilling and
recompletion programs, pursue its exploration drilling programs or undertake
other replacement activities. The Company's current strategy includes increasing
its reserve base by continuing to exploit its existing properties, by acquiring
producing properties and, to a lesser extent, by pursuing exploration
opportunities. There can be no assurance, however, that the Company's planned
development and exploration projects and acquisition activities will result in
significant additional reserves or that the Company will have continuing success
drilling productive wells at favorable finding costs.
POTENTIAL ADDITIONAL INDEBTEDNESS
As of March 31, 1997, on a pro forma basis giving effect to the Offering
and the application of the proceeds therefrom as described under "Use of
Proceeds," the Restricted Group would have had no
S-12
<PAGE> 13
indebtedness outstanding other than the Notes. See "Use of Proceeds" and
"Capitalization." The Indenture and the Credit Facility restrict, but do not
prohibit, the Company's ability to incur additional indebtedness under the
Credit Facility and otherwise. See "Description of Notes -- Certain
Covenants -- Incurrence of Indebtedness" and "Management's Discussion and
Analysis of Financial Condition and Results of Operations -- Financial Condition
and Capital Resources" and "Description of the Credit Facility."
The Company's level of future indebtedness will have several important
effects on its future operations, including (i) a substantial portion of the
Company's cash flow from operations must be dedicated to the payment of interest
on its indebtedness and will not be available for other purposes, (ii) covenants
contained in the Credit Facility and the Indenture governing the Notes will
require the Company to meet certain financial tests, and other restrictions may
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
its business, including possible acquisition activities and (iii) the Company's
ability to obtain additional financing in the future for working capital,
capital expenditures, acquisitions, general corporate purposes or other purposes
may be impaired. See "Management's Discussion and Analysis of Financial
Condition and Results of Operations -- Financial Condition and Capital
Resources."
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. Based upon the current and anticipated level of operations,
the Company believes that its cash flow from operations, together with amounts
available under its Credit Facility and its other sources of liquidity, will be
adequate to meet its anticipated requirements in the foreseeable future for
working capital, capital expenditures, interest payments and scheduled principal
payments. There can be no assurance, however, that the Company's business will
continue to generate cash flow at or above current levels. If the Company is
unable to generate sufficient cash flow from operations in the future to service
its debt, it may be required to refinance all or a portion of its existing debt,
including the Notes, or to obtain additional financing. There can be no
assurance that any such refinancing would be possible or that any additional
financing could be obtained. The inability to obtain additional financing could
have a material adverse effect on the Company. For example, a default by the
Company under the terms of the Indenture could result in a default under the
terms of the Credit Facility.
SUBSTANTIAL CAPITAL REQUIREMENTS
The Company makes, and will continue to make, substantial capital
expenditures for the acquisition, development, exploration, production and
abandonment of oil and natural gas reserves. The Company intends to finance such
capital expenditures primarily with funds provided by operations and borrowings
under the Credit Facility. During 1996, the Company's capital expenditures
totalled $130.6 million, including $79.3 million for acquisitions (excluding the
Gerrity acquisition) and $51.3 million for development, exploration and gas
transportation facilities. During 1997, the Company expects to increase its
capital expenditures, excluding acquisitions, to $125.0 million.
The Company believes that, after debt service, it will have sufficient cash
provided by operating activities and availability under the Credit Facility to
fund planned capital expenditures for exploration and development activities for
the foreseeable future. However, if revenues decrease as a result of lower oil
or gas prices or otherwise or if the Company incurs substantial additional
indebtedness to finance acquisitions or for other purposes, the Company may have
limited ability to expend the capital necessary to replace its reserves or to
maintain production at current levels, resulting in a decrease in production
over time. If the Company's cash flow from operations is not sufficient to
satisfy its capital expenditure requirements, there can be no assurance that
additional debt or equity financing will be available to meet these
requirements. See "Management's Discussion and Analysis of Financial Condition
and Results of Operations -- Financial Condition and Capital Resources."
S-13
<PAGE> 14
ACQUISITION RISKS
The Company constantly evaluates acquisition opportunities and frequently
engages in bidding and negotiation for acquisitions, many of which are
substantial. If successful in this process, the Company may be required to alter
or increase substantially its capitalization to finance these acquisitions
through the issuance of additional debt or equity securities, the sale of
production payments or otherwise; however, the Credit Facility includes, and the
Indenture will include, covenants that limit the Company's ability to incur
additional indebtedness. See "-- Potential Additional Indebtedness." These
changes in capitalization may significantly affect the risk profile of the
Company. Significant acquisitions can change the nature of the operations and
business of the Company depending upon the character of the acquired properties,
which may be substantially different in operating or geologic characteristics or
geographic location from existing properties. While the Company intends to
concentrate on acquiring producing properties with development and exploration
potential located in its current areas of operation, the Company may decide to
pursue acquisitions of properties located in other geographic regions. There can
be no assurance that the Company will be successful in the acquisition of any
material property interests. See "Management's Discussion and Analysis of
Financial Condition and Results of Operations -- Financial Condition and Capital
Resources."
DRILLING RISKS
Drilling activities are subject to many risks, including the risk that no
commercially productive reservoirs will be encountered. There can be no
assurance that new wells drilled by the Company will be productive or that the
Company will recover all or any portion of its investment. Drilling for oil and
natural gas may involve unprofitable efforts, not only from dry wells, but from
wells that are productive but that do not produce sufficient net revenues to
return a profit after drilling, operating and other costs. The cost of drilling,
completing and operating wells is often uncertain. The Company's drilling
operations may be curtailed, delayed or canceled as a result of numerous
factors, many of which are beyond the Company's control, including title
problems, weather conditions, compliance with environmental and other
governmental requirements and shortages or delays in the delivery of equipment
and services.
OPERATING HAZARDS AND UNINSURED RISKS
The Company's operations are subject to hazards and risks inherent in
drilling for, producing and transporting oil and natural gas, such as fires,
natural disasters, explosions, formations with abnormal pressures, blowouts,
cratering, pipeline ruptures and spills, any of which can result in loss of
hydrocarbons, environmental pollution, personal injury claims and other damage
to properties of the Company and others. As protection against operating
hazards, the Company maintains insurance coverage against some, but not all,
potential losses. The Company's coverages include, but are not limited to,
operator's extra expense, physical damage on certain assets, comprehensive
general liability, automobile and workers' compensation insurance. The Company
believes that its insurance is adequate and customary for companies of a similar
size engaged in operations similar to those of the Company, but losses could
occur for uninsurable or uninsured risks or in amounts in excess of existing
insurance coverage. The occurrence of an event that is not fully covered by
insurance could have a material and adverse impact on the Company's financial
condition and results of operations.
UNCERTAINTY OF ESTIMATES OF RESERVES AND FUTURE NET REVENUES
There are numerous uncertainties inherent in estimating quantities of
proved reserves, including many factors beyond the control of the Company. The
reserve information set forth and incorporated by reference in this Prospectus
Supplement represents estimates based on reports prepared by the Company's
independent petroleum engineers, as well as on internally generated reports.
Petroleum engineering is not an exact science. Estimates of economically
recoverable oil and natural gas reserves and of future net cash flows
necessarily depend upon a number of variable factors and assumptions, such as
historical production from the area compared with production from other
producing areas, the assumed effects of regulation by governmental agencies and
assumptions concerning future oil and natural gas prices, future operating
costs, severance and excise taxes, capital expenditures and workover and
remedial costs, all of which may in fact vary considerably
S-14
<PAGE> 15
from actual results. With respect to certain properties that historically have
experienced seasonal curtailment, the reserve estimates assume that the seasonal
pattern of such curtailment will continue in the future. For these reasons,
estimates of classifications of such reserves based on risk of recovery and
estimates of expected future net cash flows prepared by different engineers or
by the same engineers at different times may vary substantially. Actual
production, revenues and expenditures with respect to the Company's reserves
will likely vary from estimates, and the variances may be material.
The Present Values referred to in this Prospectus Supplement 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 Securities and Exchange Commission (the "Commission"), the
estimated discounted 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 factors such as the amount and timing of actual production,
supply and demand for oil and gas, curtailments or increases in consumption by
gas 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 to calculate 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.
UNRESTRICTED SUBSIDIARIES
Patina and SOCO International (and their respective subsidiaries) will be
Unrestricted Subsidiaries and, as a result, they will not be Subsidiary
Guarantors of the Company's obligations under the Indenture and the Notes. The
Indenture will not restrict the activities, including the incurrence of
indebtedness, of these Unrestricted Subsidiaries, nor will it restrict the
ability of the Company or its Restricted Subsidiaries to dispose of all or part
of their respective interests in such Unrestricted Subsidiaries and to use the
proceeds of any such disposition for corporate or other purposes. The Indenture
will, however, limit the ability of the Company and its Restricted Subsidiaries
to make additional investments in such Unrestricted Subsidiaries. All material
Company subsidiaries other than Patina and SOCO International (and their
respective subsidiaries) will be Restricted Subsidiaries and Subsidiary
Guarantors. See "Description of Notes."
As with all its investments and properties, the Company continuously
evaluates its positions in the Unrestricted Subsidiaries and assesses
alternatives to increase value to the Company and its shareholders. Such
alternatives include maintaining its investments, selling all or part of its
investments, either in one transaction or incrementally, distributing all or
part of its investments to its shareholders or acquiring an increased interest
in one or more of its Unrestricted Subsidiaries. Any decisions will be made in
light of strategic, financial and other factors deemed appropriate by management
at the time.
SUBORDINATION OF NOTES
The Indenture governing the Notes will limit, but will not prohibit, the
incurrence by the Company of additional indebtedness that is senior in right of
payment to the Notes (including by reason of structural subordination of the
Notes to the indebtedness and other liabilities of the Company's subsidiaries
that are not Subsidiary Guarantors). In the event of bankruptcy, liquidation,
reorganization or other winding up of the Company, the assets of the Company
will be available to pay the Company's obligations on the Notes only after all
Senior Indebtedness has been paid in full, and there may not be sufficient
assets remaining to pay principal of, premium, if any, or interest due on the
Notes. In addition, under certain circumstances, no payments may be made with
respect to the Notes if a default exists with respect to any Senior
Indebtedness. See "Description of Notes -- Subordination."
As of March 31, 1997, on a pro forma basis after giving effect to the
Offering and the application of the proceeds therefrom as described in "Use of
Proceeds," the Restricted Group would have had no Senior Indebtedness
outstanding.
S-15
<PAGE> 16
The Indenture imposes limits on the ability of the Company and its
Restricted Subsidiaries to incur additional indebtedness and liens and to enter
into agreements that would restrict the ability of such Restricted Subsidiaries
to make distributions, loans or other payments to the Company. The Indenture
also imposes limits on the ability of the Company to transfer assets to
Unrestricted Subsidiaries or acquire Unrestricted Subsidiaries. However, these
limitations are subject to various qualifications. For additional details of
these provisions and the applicable qualifications, see "Description of
Notes -- Certain Covenants."
SUBSIDIARY GUARANTEES MAY TERMINATE; FRAUDULENT CONVEYANCE CONSIDERATIONS
RELATING TO SUBSIDIARY GUARANTEES
The Company's obligations under the Notes will be guaranteed on a senior
subordinated basis by the Subsidiary Guarantors. The Subsidiary Guarantors are
the Company's existing material Restricted Subsidiaries, including its existing
principal subsidiaries other than Patina and SOCO International, which are
Unrestricted Subsidiaries. The Indenture does not require any future Restricted
Subsidiary of the Company to guarantee the Notes unless such subsidiary
guarantees other indebtedness of the Company. Various fraudulent conveyance laws
have been enacted for the protection of creditors and might be utilized by a
court of competent jurisdiction to subordinate or avoid any Subsidiary Guarantee
issued by a Subsidiary Guarantor. To the extent that a court were to find that
(x) a Subsidiary Guarantee was incurred by a Subsidiary Guarantor with the
intent to hinder, delay or defraud any present or future creditor or that such
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) a Subsidiary
Guarantor did not receive fair consideration or reasonably equivalent value for
issuing its Subsidiary Guarantee and, at the time it issued the Subsidiary
Guarantee, such Subsidiary Guarantor (i) was insolvent or rendered insolvent by
reason of the issuance of the Subsidiary Guarantee, (ii) was engaged or about to
engage in a business or transaction for which the remaining assets of such
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
Guarantee in favor of the Subsidiary Guarantor's other creditors. Among other
things, a legal challenge to the Subsidiary Guarantee issued by any such
Subsidiary Guarantor on fraudulent conveyance grounds might 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 the Subsidiary Guarantee
issued by a Subsidiary Guarantor were voided 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 the Subsidiary Guarantor and would be creditors solely
of the Company and any other Subsidiary Guarantors.
On the basis of financial information and other information currently
available to it, the Company believes the Notes and the Subsidiary Guarantees
issued concurrently with the issuance of the Notes are being incurred for proper
purposes and in good faith and that, after giving effect to indebtedness
incurred in connection with the issuance of the Notes and the issuance of the
Subsidiary Guarantees, the Company and the Subsidiary Guarantors are solvent and
will continue to be solvent, will have sufficient capital for carrying on their
respective business and will be able to pay their debts as such debts become
absolute and mature. There can be no assurance, however, that a court passing on
such questions would reach the same conclusions. Furthermore, there can be no
assurance that such standards would be satisfied in the case of any person that
becomes a Subsidiary Guarantor after the date the Notes are first issued,
because a determination as to whether such standards would be satisfied will
depend upon, among other circumstances, the financial condition of any such
Subsidiary Guarantor at the time of the incurrence of its obligations in respect
of its Subsidiary Guarantee.
REPURCHASE OF NOTES UPON A CHANGE OF CONTROL
The Company must offer to repurchase the Notes upon the occurrence of
certain events. In the event of a Change of Control, the Company must offer to
repurchase all Notes then outstanding at a purchase price equal to 101% of the
principal amount thereof, plus accrued and unpaid interest to the date of
purchase. See "Description of Notes -- Repurchase at the Option of
Holders -- Change of Control."
S-16
<PAGE> 17
Prior to repurchasing the Notes, the Company might be required to (i) repay
all or a portion of indebtedness under the Credit Facility or (ii) obtain any
requisite consent to permit the repurchase. If the Company were unable to repay
all of such indebtedness or were unable to obtain the necessary consents, then
the Company would be unable to offer to repurchase the Notes and such failure
would constitute an Event of Default under the Indenture. There can be no
assurance that the Company would have sufficient funds available at the time of
a Change of Control, if any, to make any debt payment (including repurchases of
Notes) as described above.
The events that constitute a Change of Control under the Indenture might
also be events of default under the Credit Facility or other Senior Indebtedness
of the Company and its Restricted Subsidiaries. Such events might permit the
lenders under such debt instruments to reduce the borrowing base thereunder or
accelerate the debt and, if the debt were not paid, to enforce security
interests on, or commence 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 and receive the special benefit of
the offer-to-purchase provisions to the Holders of the Notes. See "Description
of the Credit Facility."
ENVIRONMENTAL AND OTHER GOVERNMENTAL REGULATION
The Company's operations are affected by extensive regulation pursuant to
various federal, state and local laws and regulations relating to the
exploration for, and the development, production, transportation and marketing
of, oil and natural gas and the release of materials into the environment or
otherwise relating to protection of the environment. In particular, the
Company's oil and natural gas exploration, development and production, and its
activities in connection with the storage and transportation of liquid
hydrocarbons, are subject to stringent environmental regulations by governmental
authorities. Such regulations have increased the costs of planning, designing,
drilling, installing, operating and abandoning oil and natural gas wells and
other related facilities.
The Company may be required to expend significant resources, both financial
and managerial, to comply with environmental regulations and permitting
requirements. Although the Company believes that its operations are in general
compliance with all such laws and regulations, including applicable
environmental laws and regulations, risks of substantial costs and liabilities
are inherent in oil and natural gas operations, and there can be no assurance
that significant costs and liabilities will not be incurred in the future.
Moreover, it is possible that other developments, such as increasingly strict
environmental laws and regulations and enforcement policies thereunder, and
claims for damages to property, employees, other persons and the environment
resulting from the Company's operations, could result in substantial costs and
liabilities in the future.
The Company expects to maintain customary insurance coverage for its
operations, including coverage for sudden environmental damages, but does not
believe that insurance coverage that explicitly covers environmental damages
that occur over time will be available at a reasonable cost. Moreover, the
Company does not believe that insurance coverage against the full potential
liability that could be caused by environmental damages is available at a
reasonable cost. Accordingly, the Company might be subject to uninsured or only
partially insured liability because of the prohibitive premium costs of insuring
against certain hazards.
COMPETITION
The oil and gas industry is highly competitive. The Company will compete in
the acquisition, development, production and marketing of oil and natural gas
with major oil companies, other independent oil and natural gas concerns and
individual producers and operators. Many of these competitors have substantially
greater financial and other resources than the Company. Furthermore, the oil and
natural gas industry competes with other industries in supplying the energy and
fuel needs of industrial, commercial and other consumers.
S-17
<PAGE> 18
ABSENCE OF PUBLIC MARKET
There is no existing market for the Notes and, although certain of the
Underwriters have advised the Company that they currently intend to make a
market in the Notes, the Underwriters are not obligated to do so and may
discontinue such market making at any time. Accordingly, there can be no
assurance that an active market will develop upon completion of the Offering or,
if developed, that such market will be sustained. The initial offering price of
the Notes will be determined through negotiations between the Company and the
Underwriters, and may bear no relationship to the market price of the Notes
after the Offering. Factors such as quarterly or cyclical variations in the
Company's financial results, variations in interest rates, future announcements
concerning the Company or its competitors, government regulation, general
economic and other conditions and developments affecting the oil and gas
industry could cause the market price of the Notes to fluctuate substantially.
FORWARD-LOOKING INFORMATION
All statements other than statements of historical fact contained in this
Prospectus Supplement or the accompanying Prospectus, including statements in
"Prospectus Supplement Summary," "Unaudited Pro Forma Condensed Consolidated
Restricted Group Financial Information," "Management's Discussion and Analysis
of Financial Condition and Results of Operations" and "Business and Properties,"
are forward-looking statements within the meaning of the Private Securities
Litigation Reform Act of 1995. Forward-looking statements in this Prospectus
Supplement or the Prospectus generally are accompanied by words such as
"anticipate," "believe," "estimate," "expect," "intend," "plan," "project,"
"potential" or similar statements. Although the Company believes that the
expectations reflected in such forward-looking statements are reasonable, no
assurance can be given that such expectations will prove correct. Factors that
could cause the Company's results to differ materially from the results
discussed in such forward-looking statements include the risks described under
"Risk Factors," such as the fluctuations of the prices received or demand for
the Company's oil and gas, the ability to replace depleting reserves, potential
additional indebtedness, the requirements for capital, drilling risks, operating
hazards, acquisition risks, the uncertainty of reserve estimates, competition
and the effects of governmental and environmental regulation. All
forward-looking statements in this Prospectus Supplement and the accompanying
Prospectus are expressly qualified in their entirety by the cautionary
statements in this paragraph.
S-18
<PAGE> 19
USE OF PROCEEDS
The net proceeds from the Offering are estimated at $168.3 million. Of this
amount, the Company intends to use approximately $85 million to redeem the
Convertible Subordinated Notes and approximately $57 million to repay its
indebtedness under the Credit Facility. Remaining proceeds will initially be
invested in short-term interest-bearing securities. Thereafter, the Company
intends to use any remaining proceeds, together with cash flow from operations
and borrowings under the Credit Facility, to fund its development and
exploration activities, possible acquisitions and for other corporate purposes.
The long-term portion of the Credit Facility terminates on December 31,
2000, and the short-term portion of the Credit Facility terminates October 30,
1997. The short-term facility termination date generally is extended every six
months prior to maturity for an additional one-year period. At May 31, 1997, the
average interest rate on borrowings under the Credit Facility was approximately
6.5% per annum. Borrowings under the Credit Facility during the past year were
used for working capital and general corporate purposes. The Convertible
Subordinated Notes mature on May 15, 2001 and bear interest at the rate of 7%
per annum. See Consolidated Financial Statements and the notes thereto and
"Description of the Credit Facility."
S-19
<PAGE> 20
CAPITALIZATION
The following table sets forth the cash and equivalents and capitalization
of (i) the Company as of March 31, 1997 and (ii) the Restricted Group as of
March 31, 1997 and as adjusted to give effect to the Offering and the
application of the net proceeds therefrom as described under "Use of Proceeds."
This table should be read in conjunction with the Consolidated Financial
Statements and the notes thereto presented elsewhere herein, "Unaudited Pro
Forma Condensed Consolidated Restricted Group Financial Information" and
"Management's Discussion and Analysis of Financial Condition and Results of
Operations."
<TABLE>
<CAPTION>
MARCH 31, 1997
---------------------------------------
RESTRICTED GROUP
-------------------------
HISTORICAL HISTORICAL AS ADJUSTED
---------- ---------- -----------
(IN THOUSANDS)
<S> <C> <C> <C>
Cash and equivalents.................... $ 37,892 $ 29,033 $ 57,067
======== ======== ========
Long-term debt (including current
portion)
Credit Facility....................... $ 53,301 $ 53,301 $ --
8 3/4% Senior Subordinated Notes due
2007............................... -- -- 173,563
Convertible Subordinated Notes........ 80,324 80,324 --
-------- -------- --------
Subtotal...................... 133,625 133,625 173,563
Patina credit facility................ 87,450 -- --
Patina subordinated notes............. 99,913 -- --
-------- -------- --------
Total long-term debt.......... 320,988 133,625 173,563
-------- -------- --------
Minority interest....................... 86,289 -- --
Stockholders' equity
Preferred stock, $.01 par, 10,000,000
shares authorized, 6% convertible
preferred stock, 1,033,500 shares
issued and outstanding(a).......... 10 10 10
Common stock, $.01 par, 75,000,000
shares authorized, 31,543,665
shares issued...................... 315 315 315
Capital in excess of par value........ 260,411 260,411 260,411
Retained earnings..................... 42,030 42,030 39,124
Common stock held in treasury, 989,800
shares at cost..................... (15,712) (15,712) (15,712)
Unrealized gain on investments........ 24,275 -- --
-------- -------- --------
Total stockholders' equity.... 311,329 287,054 284,148
-------- -------- --------
Total capitalization.......... $718,606 $420,679 $457,711
======== ======== ========
</TABLE>
- ---------------
(a) Each share of preferred stock is exchangeable, at the Company's option, for
$100 principal amount of 6% convertible subordinated debentures on any
dividend payment date. However, the Indenture will restrict the Company's
ability to exchange the preferred stock. See "Description of
Notes -- Certain Covenants -- Restricted Payments" and "-- Incurrence of
Indebtedness."
S-20
<PAGE> 21
UNAUDITED PRO FORMA CONDENSED CONSOLIDATED RESTRICTED GROUP
FINANCIAL INFORMATION
The unaudited pro forma condensed consolidated Restricted Group financial
statements set forth the financial position of the Company as of March 31, 1997,
and its results of operations for the three months then ended and the year ended
December 31, 1996, adjusted to reflect the deconsolidation of the Unrestricted
Subsidiaries and to give effect to certain acquisitions and dispositions during
the period, and to the Offering and the application of the proceeds therefrom as
described under "Use of Proceeds." The unaudited pro forma condensed
consolidated Restricted Group financial statements are based upon the
assumptions set forth in the accompanying notes to such statements. The pro
forma adjustments are based upon available information and assumptions that
management believes are reasonable under the circumstances.
The unaudited pro forma condensed consolidated Restricted Group balance
sheet at March 31, 1997, and the related pro forma condensed consolidated
statements of operations for the three months then ended and the year ended
December 31, 1996 were prepared as if the transactions had been consummated on
March 31, 1997, January 1, 1997 and January 1, 1996, respectively. The pro forma
financial statements should be read in conjunction with the Consolidated
Financial Statements and the notes thereto and are not necessarily indicative of
the results that would have actually occurred had the transactions been
consummated on the dates or for the periods indicated or of the results that may
occur in the future.
UNRESTRICTED SUBSIDIARIES ADJUSTMENTS
The historical consolidated financial statements of the Company reflect
Patina as a consolidated subsidiary. SOCO International is also reflected as a
consolidated subsidiary, but each of SOCO International's significant holdings
is reflected in the consolidated financial statements as an investment in
accordance with the equity or cost methods of accounting. The adjustments
necessary to present Patina and SOCO International as investments accounted for
in accordance with the equity method of accounting have been reflected in the
accompanying unaudited pro forma condensed consolidated Restricted Group
financial statements as "Unrestricted Subsidiaries Adjustments."
PRO FORMA DIVESTITURES
During 1996, the Company consummated three significant transactions
pursuant to which oil and gas properties were divested, including the sale of a
45% interest in its Piceance Basin holdings for $22.4 million, the sale of a 50%
interest in its Green River Basin gas project for $16.9 million and the sale of
its interests in the Giddings Field of southeast Texas for $11.8 million. These
transactions have been reflected in the accompanying unaudited pro forma
condensed consolidated Restricted Group financial statements as "Pro Forma
Divestitures."
PRO FORMA ACQUISITIONS
During 1996, the Company consummated three significant transactions
pursuant to which incremental interests in certain properties located in the
Gulf of Mexico were acquired for a net purchase price of $72.1 million. These
transactions have been reflected in the accompanying unaudited pro forma
condensed consolidated Restricted Group financial statements as "Pro Forma
Acquisitions."
OFFERING ADJUSTMENTS
"Offering Adjustments" reflects consummation of the Offering and the
application of the net proceeds therefrom as described under "Use of Proceeds."
S-21
<PAGE> 22
UNAUDITED PRO FORMA CONDENSED CONSOLIDATED RESTRICTED GROUP
BALANCE SHEET
MARCH 31, 1997
(IN THOUSANDS)
<TABLE>
<CAPTION>
UNRESTRICTED
SUBSIDIARIES
ADJUSTMENTS(A)
------------------------ PRO FORMA
SOCO RESTRICTED OFFERING RESTRICTED
HISTORICAL PATINA INTERNATIONAL GROUP ADJUSTMENTS(B) GROUP
---------- -------- ------------- ---------- -------------- ----------
<S> <C> <C> <C> <C> <C> <C>
ASSETS
Current assets................. $ 89,953 (25,049) (3,074) $ 61,830 28,034 $ 89,864
Investments.................... 124,015 119,520 (72,120) 171,415 171,415
Oil and gas properties, net.... 635,633 (392,721) (581) 242,331 242,331
Gas facilities and other,
net.......................... 12,930 (2,944) 9,986 5,273 15,259
-------- -------- --------
$862,531 $485,562 $518,869
======== ======== ========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities............ $ 89,865 (23,788) $ 66,077 (2,160) $ 63,917
Credit Facility................ 53,301 53,301 (53,301) --
8 3/4% Senior Subordinated
Notes due 2007............... -- -- 173,563 173,563
Convertible Subordinated
Notes........................ 80,324 80,324 (80,324) --
Patina credit facility......... 87,450 (87,450) -- --
Patina subordinated notes...... 99,913 (99,913) -- --
Deferred taxes payable......... 25,294 (43,036) (17,742) (1,565) (19,307)
Other noncurrent liabilities... 28,766 (12,218) 16,548 16,548
Minority interest.............. 86,289 (77,825) (8,464) -- --
Stockholders' equity
Preferred stock.............. 10 10 10
Common stock................. 315 315 315
Capital in excess of par
value..................... 260,411 260,411 260,411
Retained earnings............ 42,030 42,030 (2,906) 39,124
Common stock held in
treasury.................. (15,712) (15,712) (15,712)
Unrealized gain on
investments............... 24,275 (24,275) -- --
-------- -------- --------
311,329 287,054 284,148
-------- -------- --------
$862,531 $485,562 $518,869
======== ======== ========
</TABLE>
The accompanying notes are an integral part of these statements.
S-22
<PAGE> 23
UNAUDITED PRO FORMA CONDENSED CONSOLIDATED RESTRICTED GROUP
STATEMENT OF OPERATIONS
THREE MONTHS ENDED MARCH 31, 1997
(IN THOUSANDS)
<TABLE>
<CAPTION>
UNRESTRICTED
SUBSIDIARIES
ADJUSTMENTS(A)
------------------------ PRO FORMA
SOCO RESTRICTED OFFERING RESTRICTED
HISTORICAL PATINA INTERNATIONAL GROUP ADJUSTMENTS GROUP
---------- -------- ------------- ---------- ----------- ----------
<S> <C> <C> <C> <C> <C> <C>
Revenues
Oil and gas sales..................... $67,848 (29,440) $38,408 $38,408
Gas transportation, processing and
marketing.......................... 4,209 4,209 4,209
Gains on sales of equity interests in
investees.......................... 13,000 (13,000) -- --
Gains on sales of properties.......... 2,607 2,607 2,607
Equity in earnings of investees....... 222 4,141 6,569 10,932 10,932
Other................................. 869 (46) 683 1,506 350(c) 1,856
------- ------- -------
88,755 57,662 58,012
------- ------- -------
Expenses
Direct operating...................... 14,021 (4,975) 9,046 9,046
Cost of gas and transportation........ 4,191 4,191 4,191
Exploration........................... 1,700 (59) 1,641 1,641
General and administrative............ 5,492 (1,327) (231) 3,934 3,934
Interest.............................. 6,787 (4,441) 2,346 1,586(c) 3,932
Other................................. 1,756 1,756 35(c) 1,791
Depletion, depreciation and
amortization....................... 23,208 (12,428) 10,780 10,780
------- ------- -------
Income before taxes and minority
interest.............................. 31,600 23,968 22,697
Provision for income taxes
Current............................... -- -- --
Deferred.............................. 8,871 (4,829) 4,042 (445)(d) 3,597
------- ------- -------
8,871 4,042 3,597
------- ------- -------
Minority interest in subsidiaries....... 2,803 (2,115) (688) -- --
------- ------- -------
Net income.............................. $19,926 $19,926 $19,100
======= ======= =======
</TABLE>
The accompanying notes are an integral part of these statements.
S-23
<PAGE> 24
UNAUDITED PRO FORMA CONDENSED CONSOLIDATED RESTRICTED GROUP
STATEMENT OF OPERATIONS
YEAR ENDED DECEMBER 31, 1996
(IN THOUSANDS)
<TABLE>
<CAPTION>
UNRESTRICTED
SUBSIDIARIES
ADJUSTMENTS(A)
------------------------ PRO FORMA(E)
SOCO RESTRICTED --------------------------- OFFERING
HISTORICAL PATINA INTERNATIONAL GROUP DIVESTITURES ACQUISITIONS ADJUSTMENTS
---------- -------- ------------- ---------- ------------ ------------ -----------
<S> <C> <C> <C> <C> <C> <C> <C>
Revenues
Oil and gas sales............ $189,327 (82,184) $107,143 (14,182) 29,682
Gas transportation,
processing and marketing... 17,655 17,655 (178)
Gains on sales of equity
interests in investees..... 69,343 (68,904) 439
Gains on sales of
properties................. 8,786 8,786
Equity in earnings of
investees.................. 421 1,022 37,997 39,440
Other........................ 6,882 (1,003) 3,283 9,162 400
-------- --------
292,414 182,625
-------- --------
Expenses
Direct operating............. 49,638 (14,520) 35,118 (4,172) 2,092
Cost of gas and
transportation............. 15,020 15,020 (69)
Exploration.................. 4,232 (224) 4,008 (611)
General and administrative... 17,143 (6,150) (401) 10,592 203
Interest..................... 23,587 (14,304) 9,283 (1,221) 3,232 4,401(c)
Other........................ 5,312 5,312 128(c)
Depletion, depreciation and
amortization............... 84,547 (44,822) 39,725 (8,801) 11,567
Property impairments......... 2,753 2,753
Loss on sale of subsidiary
interest................... 15,481 15,481
-------- --------
Income before taxes and
minority interest............ 74,701 45,333
-------- --------
Provision (benefit) for income
taxes
Current...................... 33 33
Deferred..................... 4,313 394 (22,996) (18,289) 249(d) 4,477(d) (1,585)(d)
-------- --------
4,346 (18,256)
-------- --------
Minority interest in
subsidiaries................. 7,405 (2,539) (4,227) 639
-------- --------
Net income..................... $ 62,950 $ 62,950
======== ========
<CAPTION>
PRO FORMA
RESTRICTED
GROUP
----------
<S> <C>
Revenues
Oil and gas sales............ $122,643
Gas transportation,
processing and marketing... 17,477
Gains on sales of equity
interests in investees..... 439
Gains on sales of
properties................. 8,786
Equity in earnings of
investees.................. 39,440
Other........................ 9,562
--------
198,347
--------
Expenses
Direct operating............. 33,038
Cost of gas and
transportation............. 14,951
Exploration.................. 3,397
General and administrative... 10,795
Interest..................... 15,695
Other........................ 5,440
Depletion, depreciation and
amortization............... 42,491
Property impairments......... 2,753
Loss on sale of subsidiary
interest................... 15,481
--------
Income before taxes and
minority interest............ 54,306
--------
Provision (benefit) for income
taxes
Current...................... 33
Deferred..................... (15,148)
--------
(15,115)
--------
Minority interest in
subsidiaries................. 639
--------
Net income..................... $ 68,782
========
</TABLE>
The accompanying notes are an integral part of these statements.
S-24
<PAGE> 25
NOTES TO UNAUDITED PRO FORMA CONDENSED CONSOLIDATED RESTRICTED
GROUP FINANCIAL STATEMENTS
The unaudited pro forma condensed consolidated Restricted Group financial
statements reflect the adjustments described below:
(a) To reflect the adjustments necessary to present Patina and SOCO
International as investments accounted for in accordance with the equity
method of accounting.
(b) To reflect the Offering assuming issuance of $175.0 million principal amount
of Notes with debt issuance costs of approximately $5.3 million. The
proceeds from the Offering are reflected to be used to redeem and pay
accrued interest on the Company's Convertible Subordinated Notes and to
repay its indebtedness under the Credit Facility. Remaining proceeds are
reflected to be invested in short-term interest-bearing securities. An
extraordinary loss of approximately $2.9 million (net of deferred tax
expense of approximately $1.6 million) is expected to be recorded which
includes the write off of unamortized debt issuance costs related to and the
estimated premium paid for, the redemption of the Convertible Subordinated
Notes.
(c) To adjust interest expense to reflect (i) the retirement of the Company's
Convertible Subordinated Notes, (ii) the retirement of amounts payable under
the Credit Facility and (iii) the issuance of the Notes with an assumed
interest rate of 8.75%; to adjust other expense to reflect the difference in
amortization of debt issuance costs; and to adjust other revenues for
interest income earned on the remaining proceeds invested in short-term
interest-bearing securities.
(d) To record the estimated deferred income tax provision which would have been
provided had the acquisitions and divestitures and offering adjustments
occurred at the beginning of the period.
(e) To adjust revenue and expense items to the amounts which would have been
recorded had the acquisitions and divestitures occurred at the beginning of
the period.
S-25
<PAGE> 26
SELECTED FINANCIAL DATA
The following table presents selected historical financial data for each of
the years in the five year period ended December 31, 1996 and for each of the
three months ended March 31, 1996 and 1997. The following information should be
read in conjunction with the Consolidated Financial Statements and the notes
thereto presented elsewhere herein.
<TABLE>
<CAPTION>
AS OF OR FOR THE
AS OF OR FOR THE THREE MONTHS
YEAR ENDED DECEMBER 31, ENDED MARCH 31,
------------------------------------------------------ -------------------
1992 1993 1994 1995 1996 1996 1997
-------- --------- --------- -------- -------- -------- --------
(IN THOUSANDS, EXCEPT RATIOS)
<S> <C> <C> <C> <C> <C> <C> <C>
STATEMENT OF OPERATIONS DATA
Revenues
Oil and gas sales........................ $ 77,363 $ 124,641 $ 137,858 $144,608 $189,327 $ 36,122 $ 67,848
Gas transportation, processing and
marketing.............................. 38,611 94,839 107,247 38,256 17,655 4,451 4,209
Gains on sales of equity interests in
investees.............................. 766 2,283 9,747 2,183 69,343 407 13,000
Gains (losses) on sales of properties.... (1,202) (1,033) 1,969 12,254 8,786 (20) 2,607
Equity in earnings (losses) of
investees.............................. -- 189 1,355 (1,319) 421 (88) 222
Other.................................... 3,432 7,933 4,152 6,178 6,882 847..... 869
-------- --------- --------- -------- -------- -------- --------
118,970 228,852 262,328 202,160 292,414 41,719 88,755
Expenses
Direct operating......................... 28,057 41,401 46,267 52,486 49,638 10,759 14,021
Cost of gas and transportation........... 30,469 85,640 94,177 29,374 15,020 3,696 4,191
Exploration.............................. 1,515 2,960 6,505 8,033 4,232 514 1,700
General and administrative............... 6,704 10,280 12,853 17,680 17,143 3,868 5,492
Interest................................. 4,997 5,315 10,337 21,679 23,587 3,614 6,787
Other.................................... 696 1,956 2,126 5,322 5,312 679 1,756
Depletion, depreciation and
amortization........................... 28,090 54,393 70,770 76,378 84,547 16,771 23,208
Property impairments..................... 3,415 4,369 5,783 27,412 2,753 -- --
Litigation settlement.................... -- -- -- 4,400 -- -- --
Loss on sale of subsidiary interest...... -- -- -- -- 15,481 -- --
-------- --------- --------- -------- -------- -------- --------
Income (loss) before taxes, minority
interest and extraordinary items......... 15,027 22,538 13,510 (40,604) 74,701 1,818 31,600
Net income (loss).......................... 14,597 19,545 12,372 (39,831) 62,950 1,777 19,926
STATEMENT OF CASH FLOWS DATA
Net cash provided by operations............ $ 48,339 $ 68,728 $ 86,397 $ 69,121 $101,730 $ 26,709 $ 51,775
Net cash realized (used) by investing...... (73,645) (207,933) (245,503) 32,421 (62,356) (13,542) (7,380)
Net cash realized (used) by financing...... 21,079 129,633 169,926 (96,012) (38,715) 2,905 (34,425)
OTHER FINANCIAL DATA
Adjusted EBITDA(a)......................... $ 53,480 $ 88,136 $ 93,834 $ 84,180 $126,751 $ 22,418 $ 47,466
Capital expenditures(b).................... 130,803 167,161 297,288 99,741 348,952 12,907 23,806
Ratio of Adjusted EBITDA to interest
expense.................................. 10.7x 16.6x 9.1x 3.9x 5.4x 6.2x 7.0x
Ratio of total debt to Adjusted EBITDA..... 2.2x 1.3x 3.4x 2.8x 2.9x
Ratio of earnings to fixed charges(c)...... 4.0x 5.2x 2.3x -- 3.9x 1.5x 5.3x
BALANCE SHEET DATA
Working capital............................ $ 7,619 $ 491 $ 708 $ 5,842 $ 9,168 $ 9,217 $ 88
Oil and gas properties, net................ 241,804 316,406 472,239 435,217 635,387 431,285 635,633
Total assets............................... 331,638 453,301 673,259 555,493 879,459 571,690 862,531
Total debt................................. 115,318 114,952 318,507 234,059 372,073 240,161 320,988
Minority interest.......................... -- -- 5,724 3,601 86,710 3,951 86,289
Stockholders' equity....................... 168,866 274,734 274,086 235,368 294,668 234,924 311,329
</TABLE>
- ---------------
(a) Adjusted EBITDA is calculated as income (loss) before taxes, minority
interest and extraordinary items, interest expense, depletion, depreciation
and amortization, exploration expense, gains on sales of equity interests in
investees, gains (losses) on sales of properties, equity in earnings
(losses) of investees, property impairments, litigation settlement and loss
on sale of subsidiary interest. Adjusted EBITDA is presented because it is a
widely accepted financial indicator of a company's ability to service debt.
Adjusted EBITDA is not intended to represent net income or cash flow in
accordance with generally accepted accounting principles and should not be
considered a measure of a company's profitability or liquidity.
(b) 1996 capital expenditures include $218.4 million related to the formation of
Patina and the subsequent May 1996 acquisition of Gerrity.
(c) For purposes of calculating the ratio of earnings to fixed charges,
"earnings" are net income (loss) before income taxes, minority interest,
extraordinary items and interest expense. Fixed charges consist of interest
expense and preferred stock dividends of consolidated subsidiaries. Earnings
were inadequate to cover fixed charges by $40.6 million for the year ended
December 31, 1995.
S-26
<PAGE> 27
MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
OVERVIEW
Snyder Oil Corporation is an independent energy company engaged in oil and
gas development, acquisition, exploration and production activities primarily in
the Gulf of Mexico, western Rocky Mountains and North Louisiana. The Company
also gathers, transports and markets natural gas near its principal producing
properties. In addition, through its affiliates, the Company participates in
international exploration and production.
The Company's results of operations have been significantly affected by its
success in acquiring oil and gas properties and its ability to maintain or
increase production through its exploitation activities. Fluctuations in oil and
gas prices have also significantly affected the Company's results. Through 1995,
the Company achieved significant increases in its oil and gas production
primarily through acquisitions and exploitation. During 1996, oil and gas
production remained relatively constant overall with decreases from divestitures
of nonstrategic properties in late 1995 and during 1996 offset by acquisitions
and successful exploitation activities. These acquisitions and exploitation
successes resulted in increased production in the first quarter of 1997. The
following table reflects the Company's oil and gas production and its average
oil and gas prices (including hedging activities) for the periods indicated:
<TABLE>
<CAPTION>
THREE MONTHS
YEAR ENDED DECEMBER 31, ENDED MARCH 31,
--------------------------- -----------------
1994 1995 1996 1996 1997
------- ------- ------- ------- -------
<S> <C> <C> <C> <C> <C>
Production data
Oil (MBbls)........................... 4,366 4,278 3,884 823 1,002
Gas (MMcf)............................ 43,809 53,227 55,840 11,994 16,472
Equivalent barrels (MBOE)............. 11,668 13,149 13,191 2,822 3,748
Average prices
Oil (per Bbl)......................... $ 14.80 $ 16.96 $ 20.39 $ 17.95 $ 21.18
Gas (per Mcf)......................... 1.67 1.35 1.97 1.78 2.83
Equivalent barrels (per BOE).......... 11.82 11.00 14.35 12.80 18.10
Average costs (per BOE)
Direct operating...................... $ 3.97 $ 3.99 $ 3.76 $ 3.81 $ 3.74
General and administrative............ 1.10 1.34 1.30 1.37 1.47
Depletion, depreciation and
amortization....................... 6.07 5.80 6.41 5.94 6.19
</TABLE>
The Company uses the successful efforts method of accounting for its oil
and gas properties. Consequently, leasehold costs are capitalized when incurred.
Unproved properties are assessed periodically within specific geographic areas
and impairments in value are charged to expense. Exploratory expenses, including
geological and geophysical expenses and delay rentals, are charged to expense as
incurred. Exploratory drilling costs are initially capitalized, but charged to
expense if and when the well is determined to be unsuccessful. Costs of
productive wells, unsuccessful developmental wells and productive leases are
capitalized and amortized on a unit-of-production basis over the life of the
remaining proved or proved developed reserves, as applicable. Gas is converted
to equivalent barrels at the rate of 6 Mcf to 1 barrel. Amortization of
capitalized costs is generally provided on a property-by-property basis. The
Company also assesses the need for an impairment of capitalized costs of oil and
gas properties on a property-by-property basis. If an impairment is indicated
based on undiscounted expected future cash flows, then it is recognized to the
extent that net capitalized costs exceed discounted expected future cash flows.
Accordingly, in 1995, the Company provided for $27.4 million of such
impairments. No such impairments were made in 1994, 1996 or the three months
ended March 31, 1997. Estimated future abandonment costs (net of salvage values)
are accrued at unit-of-production rates and taken into account in determining
depletion, depreciation and amortization.
S-27
<PAGE> 28
From time to time, the Company enters into commodity contracts to hedge the
price risk of a portion of its production. Settlements of gains and losses on
hedging contracts are generally based upon the difference between the contract
price and an index price, except on the long-term contract discussed below, and
are reported as a component of oil and gas revenues. Gains or losses
attributable to the termination of a hedging contract are deferred and
recognized as revenue when the hedged commodity is sold. In 1994, the Company
entered into a long-term swap arrangement in order to lock in the price
differential between the Rocky Mountain and Henry Hub prices on a portion of its
Rocky Mountain gas production. The contract covers 20,000 MMBtu per day through
2004. In March 1997, that volume represented approximately 36% of the Restricted
Group's Rocky Mountain gas production and 15% of the Company's consolidated
Rocky Mountain gas production.
RESULTS OF OPERATIONS
Comparison of First Quarter 1997 to First Quarter 1996
Total revenues for the three month period ended March 31, 1997 were $88.8
million, a $47.0 million increase from the same period in 1996. The increase was
primarily due to a $31.7 million increase in oil and gas sales and a $12.6
million increase in gains on sales of equity interests in investees. The
increase in oil and gas sales was a combination of a 41% rise in the price
received per BOE and a 33% increase in BOE production. Natural gas prices
rebounded toward the end of 1996 resulting in an average price for the first
quarter of 1997 of $2.83 per Mcf compared to $1.78 per Mcf during the same
period in 1996. Oil prices improved 18% to average $21.18 per barrel during the
first quarter of 1997. The Restricted Group had total revenues of $57.7 million
for the period ended March 31, 1997.
Net income for the three month period ended March 31, 1997 was $19.9
million, an increase from the $1.8 million experienced in the same period in
1996. Net income was positively impacted by the aforementioned price increases,
which resulted in approximately $10 million in additional net income. The
quarter also benefitted from the sales of Cairn stock, which contributed
approximately $8 million to net income. Production increases also contributed,
but these increases were offset somewhat by higher operating and depletion,
depreciation and amortization expenses. Net income for the Restricted Group was
$9.2 million, excluding equity in earnings of the Unrestricted Subsidiaries.
Revenues from production operations, less direct operating expenses, for
the quarter ended March 31, 1997 were $53.8 million, an increase of 112% from
the same period in 1996. Average daily production during the first quarter of
1997 was 41,641 BOE, an increase of 34% over the same period in 1996 (an 8%
increase over fourth quarter 1996 production). In addition, the average product
price received increased by 41% to $18.10 per BOE. The increase in oil and gas
production can be attributed primarily to Patina's acquisition of Gerrity. The
increased production resulting from three acquisitions in the Gulf of Mexico
during 1996 was offset by decreased production due to the sale of nonstrategic
properties throughout 1996. The Company expects to increase development
activities during 1997 which, along with two acquisitions in the Gulf of Mexico
in the fourth quarter of 1996, should result in increased production through
1997. Total operating expenses for the first quarter of 1997 increased by $3.3
million ($3.0 million attributable to the Unrestricted Subsidiaries) from the
same period in 1996 in line with increased production. Operating costs per BOE
were $3.74 compared to $3.81 in the same period in 1996.
Gains on sales of equity interests in investees were $13.0 million during
the three month period ended March 31, 1997. The 1997 gains resulted from sales
of Cairn stock totaling 4.5 million shares at an average of $8.81 per share,
realizing $39.2 million in aggregate proceeds.
Gains on sales of properties were $2.6 million during the three months
ended March 31, 1997, compared to losses on sales of properties of $20,000
during the same period in 1996. The most significant gain during the first
quarter of 1997 was $2.1 million on the sale of a nonstrategic offshore block in
the Gulf of Mexico.
General and administrative expenses, net of reimbursements, for the three
month period ended March 31, 1997 increased $1.6 million from the same period in
1996 but decreased $342,000 from the fourth quarter of
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<PAGE> 29
1996. The increase was primarily due to the Company's having a larger number of
properties in the DJ Basin of Colorado as a result of the Gerrity acquisition.
Interest expense was $6.8 million during the first quarter of 1997, $4.4
million of which was incurred by Patina, compared to $3.6 million during the
same period in 1996. The majority of the increase was the result of a higher
average interest rate primarily due to Patina's subordinated notes, which have
an effective interest rate of 11.1%.
Depletion, depreciation and amortization expense during the first quarter
of 1997 increased to $23.2 million from $16.8 million in the same period in
1996. The increase was primarily attributable to the 33% increase in production
volumes and, to a lesser extent, a higher total depletion, depreciation and
amortization rate per BOE of $6.19 compared to $5.94 during the same period in
1996. The increase in rates was primarily due to the amortization of a
noncompetition agreement by Patina. Excluding the Unrestricted Subsidiaries,
total depletion, depreciation and amortization expense was $10.8 million ($5.00
per BOE).
Comparison of 1996 results to 1995. Total revenues for 1996 were $292.4
million, a $90.3 million increase from 1995. The increase was in large part due
to a $67.2 million increase in gains on sales of investments, of which a $65.5
million gain was attributable to the fourth quarter exchange of the Company's
stock held in Command Petroleum Limited ("Command"), an Australian affiliate,
for stock in Cairn. An increase in oil and gas sales of $44.7 million was also
experienced in 1996 as a result of a 31% rise in the price received per BOE
while production remained relatively stable compared to 1995. Natural gas prices
rebounded in 1996 to $1.97 per Mcf from $1.35 per Mcf in 1995, a 46% increase.
Oil prices improved 20% to average $20.39 per barrel during 1996. Partially
offsetting these increases was a decrease in gas transportation, processing and
marketing revenues of $20.6 million primarily as a result of the sale of the
Company's Wattenberg gas facilities in 1995.
Net income for 1996 was $63.0 million, compared to a net loss in 1995 of
$39.8 million. The 1996 income was boosted by the net effect of the Command
transaction ($57.2 million after minority interest expense and deferred tax
expense). However, the Company also recorded a noncash charge of $15.5 million
in the second quarter related to the contribution of the Company's Wattenberg
oil and gas properties to Patina, in return for a 70% (currently 74%) stake in
Patina. The 1995 loss was primarily due to $27.4 million in noncash property
impairment charges and almost $11 million in combined losses resulting from a
litigation settlement, losses on marketable securities, as well as severance and
restructuring costs. Absent these special non-recurring items, there was an
increase in net income from 1995 to 1996 of approximately $23 million. This
increase can be attributed primarily to the 31% increase in average price
received per BOE, which increased revenues $44.7 million, offset partially by a
decrease in gas management margin of $6.2 million and an increase in
depreciation, depletion and amortization expense of $8.2 million.
Revenues from production operations, less direct operating expenses, for
1996 were $139.7 million, an increase of 52% from 1995 production margin.
Average daily production during 1996 was 36,040 BOE, almost exactly what it was
in 1995 (36,024 BOE). However, the average product price received increased by
31% to $14.35 per BOE. During 1996, oil and gas production remained relatively
constant overall with decreases from divestitures of nonstrategic properties in
late 1995 and during 1996 offset by acquisitions, primarily in the Gulf of
Mexico and the DJ Basin of Colorado, and by exploitation efforts. This process
is substantially complete. The Company expects to increase its development
schedule in 1997 which, along with two acquisitions in the Gulf of Mexico in the
fourth quarter 1996, should result in an increase in production during 1997.
Total operating expenses for 1996 decreased by $2.8 million in line with the
Company's efforts of divesting of marginal properties with high operating costs
and acquiring incremental interests in offshore properties which have
historically had lower operating costs per BOE. Operating costs per BOE were
$3.76 compared to $3.99 in 1995.
Direct operating margin from gas transportation, processing and marketing
for 1996 was $2.6 million compared to $8.9 million in 1995. The decrease
resulted primarily from a reduction in processing margins due to the sale of the
Company's Wattenberg gas processing facilities which was completed in the third
quarter of 1995. The Company realized almost $80 million in sales proceeds
during 1995 on these facilities and recognized a total of $8.7 million in gains.
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<PAGE> 30
Gains on sales of investments were $69.3 million in 1996, compared to $2.2
million in 1995. The $65.5 million gain on the Command exchange accounted for
the bulk of the increase. The remaining gains are primarily due to sales of a
portion of the Company's interests in the Permtex venture in Russia and the
Tamtsag venture in Mongolia. In January 1997, the Company's interest in the
Tamtsag venture was further reduced.
Gains on sales of properties were $8.8 million in 1996, compared to $12.3
million in 1995. The most significant gain during 1996 was a $7.4 million gain
on the sale of a 50% interest in the Green River Basin holdings for $16.9
million. The most significant gain during 1995 was the $8.7 million gain
recognized as part of the sale of the Company's Wattenberg gas processing
facilities for almost $80 million.
Other income increased 50% or $2.4 million from 1995. The increase can be
primarily attributed to equity in earnings of Command increasing $1.9 million
from the equity in losses recorded in 1995.
Exploration expenses for 1996 were $4.2 million, down $3.8 million from
1995. The decrease was due primarily to a writeoff of $4.1 million of acreage
costs in 1995 that was not incurred in 1996. Included in the 1996 expenditures
of $4.2 million was a $1.2 million dry hole drilled in the Gulf of Mexico in the
third quarter on an unexplored block adjacent to one of the Company's current
producing blocks.
General and administrative expenses, net of reimbursements, for 1996 were
$17.1 million as compared to $17.7 million in 1995. The slight decrease is the
result of ongoing expense reduction efforts and reductions in personnel due to
the property divestitures that have taken place over the past two years offset
somewhat by increased expenses related to the acquisition of Gerrity.
Interest and other expense was $28.9 million compared to $27.0 million in
1995. The majority of the increase is the result of a higher average interest
rate primarily due to Patina's subordinated notes, which have an effective
interest rate of 11.1%.
Depletion, depreciation and amortization expense in 1996 increased to $84.5
million from $76.4 million in 1995. The increase reflects an increase in the
overall depletion, depreciation and amortization rate per equivalent barrel from
$5.80 to $6.41. This increase can be attributed to downward revisions in reserve
quantities at year end 1995 primarily in proved undeveloped reserves which
became uneconomic at year end 1995 prices and the growing impact of the Gulf of
Mexico operations which are typically more capital intensive thus having a
higher depletion rate.
The Restricted Group realized net income of $63.0 million for 1996. Net
income for the Restricted Group was $20.7 million, excluding equity in earnings
of the Unrestricted Subsidiaries, deferred tax benefit and other nonrecurring
charges. The equity in earnings of the Unrestricted Subsidiaries of $39.4
million was primarily due to the gain recognized as a result of the
Command/Cairn exchange transaction, and the deferred tax benefit recognized of
$18.3 million was also related to this transaction. In addition, a nonrecurring
charge of $15.5 million was recorded related to the formation of Patina, whereby
the Company recognized a loss on contributing all its Wattenberg properties to
Patina in return for 14 million shares of Patina common stock. The Restricted
Group had oil and gas sales of $107.1 million on production averaging 20,525 BOE
per day, direct operating expenses of $4.67 per BOE produced, interest expense
of $9.3 million and depletion, depreciation and amortization expense of $5.29
per BOE produced.
Comparison of 1995 results to 1994. Total revenues for 1995 were $202.2
million, a $60.2 million decline from 1994. The revenue decrease included $56
million as a result of the suspension of low margin third party gas marketing
activities late in 1994 and a $13 million decrease due to the sale of the
Company's Wattenberg gas facilities in 1995. Oil and gas sales, on the other
hand, rose by 5% to $144.6 million as a result of a 13% growth in production of
barrels of oil equivalent. The production increase was partially offset by a 7%
decrease in the average price received per BOE. Natural gas prices dropped
sharply by 19% in 1995 to an average of $1.35 per Mcf, the lowest average price
received in the Company's history. Oil prices improved 15% to average $16.96 per
barrel during 1995.
The net loss for 1995 was $39.8 million, compared to net income in 1994 of
$12.4 million. The 1995 loss was primarily due to $27.4 million in noncash
property impairment charges and almost $11 million in losses as
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<PAGE> 31
a result of a litigation settlement, losses on marketable securities, as well as
severance and restructuring costs. The property impairment charges resulted from
the fourth quarter adoption of Statement of Financial Accounting Standards No.
121 ("SFAS 121"), "Accounting for the Impairment of Long-Lived Assets and for
Long-Lived Assets to Be Disposed Of." Prior to the fourth quarter of 1995, the
Company provided impairments for significant proved and unproved oil and gas
property groups to the extent that net capitalized costs exceeded the
undiscounted future cash flows. SFAS 121 requires the Company to assess the need
for an impairment of capitalized costs of oil and gas properties on a
property-by-property basis. If an impairment is indicated based on undiscounted
expected future cash flows, then an impairment is recognized to the extent that
net capitalized costs exceed discounted expected future cash flows. The decline
from the 1994 net income also resulted from the decrease in natural gas prices
and sharply increased financing costs, incurred prior to the reduction in
outstanding debt accomplished during the latter half of 1995.
Revenues from production operations, less direct operating expenses, for
1995 were $92.1 million, slightly greater than the 1994 production margin.
Average daily production during 1995 was 36,024 BOE, up 13% from 1994 levels,
although the average product price received decreased by 7% to $11.00 per BOE.
The production increase resulted primarily from newly drilled wells completed
late in 1994 and during early 1995. In 1995, the Company completed 223 wells,
including 88 in the DJ Basin of Colorado, 24 in the Austin Chalk area of Texas,
16 in the Green River Basin of Wyoming and six in the Piceance Basin of western
Colorado. Additionally, late in 1995, the Company sold its minor interest in a
south Texas field where 70 nonoperated wells had been completed earlier in the
year. In the DJ Basin, the Company completed 360 wells in 1994, but reduced its
drilling in 1995 in response to the dramatic decrease in natural gas prices in
the region. Total operating expenses for 1995 increased by 13%, in line with the
production growth. Operating costs per BOE were $3.99, essentially even with
those of the prior year.
Revenues from gas processing, transportation, and marketing, less direct
expenses, for 1995 were $8.9 million, compared to $13.1 million in 1994. The
decrease resulted primarily from a reduction in processing margins due to the
sale of the Company's Wattenberg processing facilities. During 1995, the Company
realized almost $80 million in sales proceeds and recorded $8.7 million in
gains. In conjunction with the sales, the Company completed an agreement with
the primary purchaser, which, at current gas prices, is not expected to have a
material adverse effect on the wellhead net prices compared to the Company's
processing arrangements prior to the sale. Gas transportation and gathering
margins from facilities retained by the Company climbed 47% during 1995 to $3.4
million, associated with rising production and system expansions in southern
Wyoming and western Colorado. Gas marketing net revenues declined by $797,000
between years, after the suspension of third party marketing activities in late
1994.
Gains on sales of properties were $12.3 million in 1995, compared to $2.0
million in 1994. The $8.7 million gain from the DJ Basin facility sales
accounted for the bulk of the increase. The remaining gains were part of the
Company's ongoing program to dispose of nonstrategic assets at favorable prices.
Other income in 1995 was $7.0 million, which was reduced from $15.3 million
in 1994, as the prior year included $6.6 million in gains on the sale of a
portion of the Company's interest in the Permtex venture in Russia and the sale
of equity securities by Command. The remaining decrease was primarily due to
losses on the sale of marketable securities in 1995. The Company realized $13.1
million in proceeds from the securities sales, which was applied to further
reduce the outstanding debt.
Exploration expenses for 1995 were $8.0 million, up $1.5 million from 1994.
The increase resulted primarily from the writeoff of $4.1 million of certain
acreage costs.
General and administrative expenses, net of reimbursements, were $17.7
million as compared to $12.9 million in 1994. The increase consists of $2.3
million associated with an increase of activities related to the Company's newer
development projects, $1.5 million in severance and restructuring costs
primarily related to the Wattenberg area activities and $1.0 million related to
the expanding offshore operations.
Interest and other expense was $27.0 million in 1995, up from $12.5 million
in 1994. The majority of the increase was due to larger outstanding debt levels
at higher average interest rates, and to a lesser extent, the writedown of
certain notes receivable to their realizable value. Senior debt was
significantly reduced during the
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<PAGE> 32
last half of the year with the proceeds from the sale of the Wattenberg
facilities and the west Texas oil and gas properties.
Depletion, depreciation and amortization expense increased 8% during 1995.
The increase resulted from the 13% growth in oil and gas production, offset
somewhat by a reduction in the production depletion, depreciation and
amortization rate per BOE to $5.00 in 1995 from $5.37 in 1994.
The effective income tax rate for 1995 was a benefit of three percent. This
benefit was limited to the extent of the net deferred tax liability at December
31, 1994 of $591,000 and the realization of a $779,000 deferred tax asset that
was previously recorded to stockholders' equity as required by SFAS No. 115.
DEVELOPMENT, ACQUISITION AND EXPLORATION
During the three months ended March 31, 1997, the Company incurred $23.8
million in capital expenditures, including $20.3 million for development, $1.8
million for exploration, $1.0 million for property acquisitions and $753,000 for
fixed assets.
Of the $20.3 million of development expenditures, $8.7 million was
concentrated in the Gulf of Mexico, $2.1 million in the Washakie Basin of
southern Wyoming, $1.7 million in the Green River Basin of southern Wyoming,
$1.1 million in the Piceance Basin of western Colorado and $1.1 million in other
areas. In addition, Patina incurred $5.6 million of the total development
expenditures of the Company. During the three months ended March 31, 1997, the
Company completed 30 wells, drilled one developmental dry hole and had 22 wells
in progress at quarter end.
Exploration costs in the first quarter of 1997 were $1.8 million, primarily
for seismic work performed in and around the Company's major drilling projects.
Patina incurred $58,000 of exploration costs in the first quarter of 1997.
During 1996, the Company incurred $349.0 million in capital expenditures,
including $297.7 million for property acquisitions, $43.1 million for
development, $4.6 million for exploration, $2.0 million for field and office
equipment and $1.6 million for gas facility expansion.
The Company expended $297.7 million relating to property acquisitions
during 1996. Of this amount, $273.1 million was for producing properties and
$24.6 million was for unevaluated properties. Of the $273.1 million expended for
producing properties, $218.4 million related to the formation of Patina and the
subsequent May 1996 acquisition of Gerrity. In 1996, the Company acquired, via
three acquisitions, incremental interests in certain properties located in the
Gulf of Mexico for a net purchase price of $72.1 million ($22.4 million was
classified as unevaluated properties).
Of the total 1996 development expenditures, $12.8 million was concentrated
in the Gulf of Mexico where four wells were completed (with three in progress at
year end), $8.6 million was spent in the Piceance Basin of western Colorado to
complete 22 wells, (with one in progress at year end) and $5.7 million was spent
in the East Washakie Basin of southern Wyoming to complete twelve wells (with
three in progress at year end). In addition, $2.9 million was incurred to
complete five wells in the Green River Basin (with two in progress at year end)
and $4.8 million was spent in other areas. Also, Patina incurred $8.3 million of
the total development expenditures of the Company.
Exploration costs in 1996 were $4.6 million primarily for seismic work
performed in and around the Company's major drilling projects and a dry hole
drilled in the Gulf of Mexico.
In Russia, ten additional wells were drilled and completed in 1996
increasing production to over 3,500 barrels per day. Drilling activity has been
slower than anticipated due to difficulties in securing drilling contracts on
commercially reasonable terms. During 1997, SOCO Perm Russia, Inc. expects to
drill 11 wells. In Mongolia, the Mongolian Parliament ratified the grant of two
additional concessions in the area to SOCO Tamtsag Mongolia, Inc. bringing the
total acreage position to approximately 10 million acres. During 1996, two
exploratory wells were drilled, one of which resulted in a second discovery.
SOCO Tamtsag Mongolia, Inc. intends to drill four wells during 1997. In
Thailand, the Company was awarded Block B8/38 in the Gulf of Thailand. The
Company has entered into an agreement with an international oil company to fund
the
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<PAGE> 33
drilling of an exploration well in this block. Drilling is expected to begin in
the second quarter of 1997, with a second well possibly being drilled by year
end.
FINANCIAL CONDITION AND CAPITAL RESOURCES
At March 31, 1997, the Company had total assets of $862.5 million. Total
capitalization was $718.6 million, of which 43% was represented by stockholders'
equity, 25% by subordinated debt, 20% by senior debt and 12% by minority
interest. During the three months ended March 31, 1997, net cash provided by
operations was $51.8 million, an increase of 94% compared to the same period in
1996. As of March 31, 1997, commitments for capital expenditures, primarily for
new production facilities in the Gulf of Mexico, totaled $26.8 million. Included
in this amount are Patina's commitments of $579,000. The Company anticipates
that 1997 capital expenditures will approximate $129 million. Approximately $109
million is expected to be spent for development drilling programs, $12 million
for expanded exploratory activity and $8 million for gas facilities and other
activities. Of these amounts, $59 million is targeted for continued development
in the Gulf of Mexico, $43 million for expanded development of its major Rocky
Mountain projects (excluding $15 million for Patina), $4 million for additional
leasing, seismic and drilling costs in North Louisiana and $8 million for other
costs. The level of these and other future expenditures is largely
discretionary, and the amount of funds devoted to any particular activity may
increase or decrease significantly, depending on available opportunities and
market conditions. The Company plans to finance its ongoing acquisition,
exploration and development expenditures using internally generated cash flow
and existing credit facilities. In addition, joint ventures or future offerings
of debt or equity securities may be utilized.
In May 1997, SOCO International transferred its 90% interest in Operations
which held the Company's investments in Mongolia, Russia and Thailand, to SOCO
plc, a recently formed United Kingdom company, in exchange for shares of SOCO
plc stock. SOCO plc also acquired the interests of a number of minority
investors in Operations' ventures and assets in Yemen, Tunisia and onshore
England from Cairn. At the time of the acquisitions, SOCO plc, which is listed
on the London Stock Exchange, completed a public offering of its common shares
that raised approximately $75 million of new equity capital to fund its
continuing exploration and development expenditures. The 7.8 million shares of
SOCO plc acquired by the Company represent approximately 15.9% of SOCO plc and
had a market value of $30.2 million at June 3, 1997. Under London Stock Exchange
rules, the Company will not be permitted to sell these shares for two years.
Edward T. Story, a director and former Vice President -- International of the
Company, is the chief executive officer of SOCO plc.
During the first quarter of 1997, Patina accounted for $24.0 million of the
Company's net cash provided by operations. For the foreseeable future, cash
generated by Patina will, however, be retained by Patina to fund its development
program, reduce debt and pursue acquisitions in the DJ Basin or elsewhere.
Moreover, Patina's credit facility currently prohibits the payment of dividends
on its common stock. Accordingly, Patina's cash flow is intended to be used to
reduce debt levels, fund a limited development program and any future
acquisitions which may be consummated and may not be available to fund the
Company's other operations or to pay dividends to its stockholders. During the
first quarter of 1997, Patina reduced its total debt by $10.2 million. As with
all its investments and properties, the Company continuously evaluates its
position in Patina and assesses alternatives to increase value to the Company
and its shareholders.
The Company maintains a $500.0 million revolving credit facility. The
borrowing base available under the facility at March 31, 1997 was $140.0 million
and, upon completion of the Offering, will be $120.0 million. During the first
quarter of 1997, the average interest rate under the revolver was 6.3%. See
"Description of the Credit Facility."
Patina maintains a $140.0 million revolving credit facility (the "Patina
Facility"). The borrowing base available under the facility was $120.0 million
at March 31, 1997. Effective May 1, 1997, the borrowing base was reduced to
$110.0 million. Patina may elect that all or a portion of the facility bear
interest at a rate per annum equal to (i) the higher of (a) prime rate or (b)
the Federal Funds Effective Rate plus 0.5%, or (ii) the Adjusted Eurodollar Rate
(the rate at which Eurodollar deposits for one, two, three or six months (as
selected by Patina) are offered in the interbank Eurodollar market, as adjusted
for reserves) plus a margin which
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<PAGE> 34
fluctuates from 0.625% to 1.125% determined by a debt to EBITDA ratio. During
the first quarter of 1997, the average interest rate under the facility was
6.9%.
The Patina Facility agreement contains certain financial covenants,
including but not limited to a maximum total debt to capitalization ratio, a
maximum total debt to EBITDA ratio and a minimum current ratio. The bank credit
agreement also contains certain negative covenants, including but not limited to
restrictions on indebtedness; certain liens; guaranties, speculative derivatives
and other similar obligations; asset dispositions; dividends, loans and
advances; creation of subsidiaries; investments; leases; acquisitions; mergers;
changes in fiscal year; transactions with affiliates; changes in business
conducted; sale and leaseback and operating lease transactions; sales of
receivables; prepayment of other indebtedness; amendments to principal
documents; pledges of assets; issuances of securities; and nonspeculative
commodity hedging.
The Company from time to time enters into arrangements, primarily by
Patina, to monetize its Section 29 tax credits. These arrangements result in
revenue increases of approximately $0.40 per Mcf on production volumes from
qualified Section 29 Properties. As a result of such arrangements, the Company
recognized additional gas sales of $2.5 million in 1996. During the three months
ended March 31, 1997, the Company recognized additional gas sales of $801,000.
These arrangements are expected to increase revenues through 2002.
The Company seeks to diversify its exploration and development risks by
seeking partners for its significant development projects and maintains a
program to divest marginal properties and assets which do not fit its long range
plans. During the first quarter of 1997, the Company sold 50% of its working
interest in the Wind River Basin and the Big Horn Basin area for a total of $1.7
million in proceeds. The first well was spudded in January 1997 in the Big Horn
Basin and another well is expected to be drilled in the Wind River Basin during
1997.
In November 1996, the Company accepted an offer from Cairn for its interest
in Command. The Company received 16.2 million shares of freely marketable common
stock of Cairn, and recorded a gain of $65.5 million with no associated current
tax liability. However, a deferred tax provision of $4.0 million was recorded
related to this transaction. Immediately prior to the acceptance of Cairn's
offer, the Company accrued for a transaction in which a director of the Company
exchanged his option to purchase 10% of the outstanding common stock of SOCO
International (through which the investment in Command was held) and issued
promissory notes to the Company totaling $591,000 for 10% of the outstanding
common stock of two SOCO International subsidiaries, SOCO International
Holdings, Inc. ("Holdings") and Operations. As a result of this transaction, the
Company recorded a $260,000 loss. Additionally, minority interest expense of
$4.3 million was recorded related to the director's 10% ownership as a result of
the Command gain. The actual exchange occurred in December 1996 and the
promissory notes remained outstanding at March 31, 1997. During the three months
ended March 31, 1997, the Company sold 4.5 million Cairn shares at an average of
$8.81 per share realizing $39.2 million in proceeds. These transactions resulted
in a pretax gain of $13.0 million.
The Board of the Company has authorized the repurchase of up to $50.0
million of the Company's securities. During 1996 and the first quarter of 1997,
the Company repurchased 1.5 million shares of common stock, par value $0.01 per
share ("Common Stock"), of the Company for $19.2 million, 6,000 preferred
depositary shares for $142,000 and $4.3 million principal amount Convertible
Subordinated Notes for $4.0 million. Subsequent to quarter end, the Company has
repurchased an additional 1.1 million shares of Common Stock for $19.6 million
and $290,000 principal amount Convertible Subordinated Notes for $294,000. The
terms of the Notes will restrict the Company's ability to repurchase its
securities. See "Description of Notes -- Certain Covenants -- Restricted
Payments."
The Company believes that its capital resources are adequate to meet the
requirements of its business. However, future cash flows are subject to a number
of variables including the level of production and oil and gas prices, and there
can be no assurance that operations and other capital resources will provide
cash in sufficient amounts to maintain planned levels of capital expenditures.
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<PAGE> 35
INFLATION AND CHANGES IN PRICES
While certain of its costs are affected by the general level of inflation,
factors unique to the petroleum industry result in independent price
fluctuations. Over the past five years, significant fluctuations have occurred
in oil and gas prices. Although it is difficult to estimate future prices of oil
and gas, price fluctuations have had, and will continue to have, a material
effect on the Company.
The following table indicates the average oil and gas prices received over
the last five years and the first quarter of 1997. Average gas prices for the
three months ended March 31, 1997 and the years ended December 31, 1996 and 1995
were increased by $0.06, $0.08 and $0.06 per Mcf, respectively, by the benefit
of the Company's hedging activities. Average price computations exclude contract
settlements and other nonrecurring items to provide comparability. Average
prices per equivalent barrel indicate the composite impact of changes in oil and
gas prices. Natural gas production is converted to oil equivalents at the rate
of 6 Mcf per barrel.
<TABLE>
<CAPTION>
AVERAGE PRICES
------------------------------------
CRUDE OIL
AND NATURAL EQUIVALENT
LIQUIDS GAS BARRELS
--------- --------- ----------
(PER BBL) (PER MCF) (PER BOE)
<S> <C> <C> <C>
1992............................................. $18.87 $1.74 $13.76
1993............................................. 15.41 1.94 13.41
1994............................................. 14.80 1.67 11.82
1995............................................. 16.96 1.35 11.00
1996............................................. 20.39 1.97 14.35
First Quarter 1997............................... 21.18 2.83 18.10
</TABLE>
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<PAGE> 36
BUSINESS AND PROPERTIES
GENERAL
Snyder Oil Corporation is an independent energy company engaged in oil and
gas development, acquisition, exploration and production activities primarily in
the Gulf of Mexico, western Rocky Mountains and North Louisiana. The Company
also gathers, transports and markets natural gas near its principal producing
properties. In addition, through its affiliates, the Company participates in
international exploration and production. From 1991 through 1996, the Company
pursued a balanced strategy of acquisitions and development drilling. During
this period, the Company's revenues increased from $86.6 million to $292.4
million and Adjusted EBITDA (as defined herein) increased from $43.7 million to
$126.8 million. At December 31, 1996, the Company's proved reserves totaled
141.4 million BOE having a Present Value of $1.2 billion. Approximately 71% of
these reserves are natural gas. The Company operates more than 3,500 wells that
account for almost 90% of its developed reserves.
The Company's domestic operations are focused on three core areas, each
with the potential to contribute significantly to future growth:
- Gulf of Mexico. The Company had proved reserves in the Gulf of Mexico of
17.4 million BOE at December 31, 1996, concentrated in the Pabst, Busch
and Ingrid Fields of the Main Pass area offshore Mississippi. The
production from the Pabst and Busch Fields typically has been restricted
to 100 MMcf (42 MMcf net) of gas per day but is expected to increase to
more than 150 MMcf (62 MMcf net) per day following the expansion of
pipeline capacity serving these fields in early 1998. During 1997 the
Company intends to begin installation of a platform and production
facilities with total initial capacity of 100 MMcf per day on its
50%-owned Ingrid Field, with production commencing in early 1998. The
Company plans to expand its activities in the Gulf of Mexico
significantly and has budgeted approximately $59 million for development
and exploration in this area in 1997.
- Western Rocky Mountains. The Company had proved reserves in Wyoming,
western Colorado and Utah of 50.3 million BOE at December 31, 1996. These
reserves are concentrated in gas development programs in the Washakie,
Green River and Piceance Basins, and in two large, mature non-operated
oil fields in northern Wyoming. The Company has also initiated gas
projects in the Wind River and Big Horn Basins and an oil project in
Utah. The Company recently formed a gas marketing joint venture with
Coastal Corporation, one of the largest gas marketers in North America.
This joint venture is expected further to enhance efficiencies and
downstream marketing opportunities for the Company's western Rocky
Mountain gas operations. The Company has budgeted approximately $43
million for continued development and exploration in the western Rocky
Mountains during 1997.
- North Louisiana. The Company owns over 300,000 net mineral acres, with
leases and lease options covering more than 225,000 additional net acres,
in North Louisiana. The Company has identified a number of exploration
prospects as a result of an initial 48 square mile 3-D seismic survey,
and is in the process of performing an additional 110 square mile 3-D
survey. Based on these surveys, the Company expects to begin drilling
activities in North Louisiana by the end of 1997. The Company expects
expenditures in North Louisiana to total approximately $4 million in
1997.
BUSINESS STRATEGY
In early 1995, the Company began a strategic repositioning program to
improve operating performance and enhance reserve and production growth
opportunities by (i) reducing its dependence on the Rocky Mountains through the
acquisition of significant properties in the Gulf of Mexico and the addition of
partners to its major Rocky Mountain projects, (ii) disposing of selected
non-core properties, (iii) reducing operating costs and (iv) increasing
financial flexibility. Through the implementation of this repositioning program,
over the last two years the Company has sold over 300 non-core properties with
limited upside potential, leaving it with 30 projects of which two-thirds are
believed to provide significant opportunities for growth. During the same
period, the Company has reduced employment by over 20% while increasing proved
reserves by 18%.
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Key elements of the Company's business strategy are summarized below:
Geographic Focus. The Company's domestic operations are concentrated in the
Gulf of Mexico, the western Rocky Mountains and North Louisiana. By focusing on
a select number of core geographic areas, the Company believes that it can
maximize operating and administrative cost efficiencies and leverage the
technical expertise gained in these areas to its competitive advantage.
Development and Exploitation. The Company initiates development drilling,
recompletions and other production enhancement techniques to maximize production
and reserves. During 1996, the Company spent $36.7 million to drill or
recomplete 75 wells in its core areas and has budgeted approximately $94 million
for such activities in 1997. The Company has identified over 700 development and
exploitation locations on its existing core properties, representing a 10-year
inventory at 1996 drilling levels.
Exploration. The Company selectively pursues higher risk, higher potential
return projects and manages its exploration risks through the use of 3-D seismic
and other advanced technologies as well as through joint venture partners. Also,
the geographic and geological diversity of the Company's exploration
opportunities in its core areas mitigates its economic risk. The Company
expended $4.6 million on exploration activities in 1996 and intends to expend
approximately $12 million on such activities in the Gulf of Mexico, the western
Rocky Mountains and North Louisiana during 1997.
Acquisitions. The Company continually evaluates opportunities to acquire
oil and gas properties that complement its existing reserve base or that may
allow it to develop new core areas. The Company evaluates potential acquisitions
based on various factors, including development potential, profit enhancement
opportunity, geographic concentration and reserve and production attributes. In
1996, the Company spent $72.1 million to increase its core holdings in the Gulf
of Mexico.
Cost-Effective Operations. The Company is committed to maintaining a
cost-effective operating structure. During 1996, the Company streamlined its
organizational structure and enhanced its operations by concentrating on core
geographic areas pursuant to its repositioning program. Further, the Company
operates properties collectively representing almost 90% of the Present Value of
its proved reserves, which provides it with significant control over the timing
and the extent of operating and drilling costs.
Financial Flexibility. The Company believes that maintaining financial
flexibility will enable it to respond quickly to acquisition opportunities and
changing market conditions. As of March 31, 1997, on a pro forma basis to
reflect completion of the Offering and application of the proceeds therefrom as
described under "Use of Proceeds," the Company, excluding its Unrestricted
Subsidiaries, would have had no Senior Indebtedness outstanding, and its
borrowing base under the Credit Facility would have been $120.0 million. See
"Description of the Credit Facility." The Company anticipates that it will be
able to fund its capital expenditures largely through operating cash flow. In
addition, the Company has significant investments in Patina and SOCO
International, as described below.
During 1996, the Company consolidated its Wattenberg Field properties in
Colorado with those of Gerrity to create Patina, a New York Stock Exchange
listed company of which the Company owns approximately 74% (14.0 million
shares). Through the formation of Patina, the Company converted its working
interest in the field into a controlling interest in the field's largest
producer. At December 31, 1996, Patina held interests in over 3,600 wells with
proved reserves of approximately 71.9 million BOE, approximately 70% of which
were attributable to natural gas.
The Company's international operations are conducted through its wholly
owned subsidiary, SOCO International. SOCO International operates through a
90%-owned holding company that owns 11.7 million shares (approximately 7%) of
Cairn, a publicly-traded Scotland-based exploration and production company.
Until May 1997, SOCO International also operated through a 90%-owned operating
subsidiary that had investments in Mongolia, Russia and Thailand. Recently,
however, the Company completed a public offering of the international operating
company, whose common stock is now listed on the London Stock Exchange. See
"Prospectus Supplement Summary -- Recent Developments." The Company's
investments in Patina and Cairn had market values of $124.3 million and $98.4
million, respectively, at June 3, 1997.
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DOMESTIC OPERATIONS
GENERAL
During 1996, the Company greatly increased the focus and balance of its
domestic operations by investing capital primarily in its core operating areas
and by selling the majority of its remaining non-core assets. Summary
information at December 31, 1996 regarding the Company's domestic projects is
set forth in the following table.
<TABLE>
<CAPTION>
PROVED RESERVE QUANTITIES
NET -------------------------------- PRESENT VALUE
PRODUCING UNDEVELOPED CRUDE OIL NATURAL OIL --------------------
WELLS ACRES & LIQUIDS GAS EQUIVALENT AMOUNT PERCENT
--------- ----------- --------- ------- ---------- ---------- -------
(MBBL) (MMCF) (MBOE) (000)
<S> <C> <C> <C> <C> <C> <C> <C>
Offshore Division
Main Pass Area........................ 15 8,553 1,570 86,238 15,943 $ 236,349 19%
Other................................. 26 0 851 3,717 1,470 8,488 1
Rocky Mountain Division
Major Gas Projects
Washakie (WY)....................... 154 75,726 1,144 133,101 23,327 147,880 12
Piceance (CO)....................... 70 43,309 118 32,170 5,479 39,045 3
Deep Green River (WY)............... 10 44,355 175 21,717 3,794 27,973 2
Wind River Basin (WY)............... 27 65,577 235 21,151 3,760 15,376 1
Big Horn Basin (WY)................. 0 80,550 0 0 0 0 0
Other Rockies Projects
Northern Wyoming (WY)............... 932 787 12,083 531 12,172 76,938 6
Uinta Basin (UT).................... 127 79,899 1,152 3,861 1,795 9,042 1
Southern Division
North Louisiana (LA).................. 96(a) 318,090(b) 40 2,715 492 6,615 1
Other................................... 117 78,587 654 3,776 1,286 10,501 1
----- ------- ------ ------- ------- ---------- ---
Total Restricted Group.......... 1,574 795,433 18,022 308,977 69,518 $ 578,207 47%
Patina.................................. 3,602(c) 141,713 22,475 296,659 71,918 648,797 53
----- ------- ------ ------- ------- ---------- ---
Total Company................... 5,176 937,146 40,497 605,636 141,436 $1,227,004 100%
===== ======= ====== ======= ======= ========== ===
</TABLE>
- ---------------
(a) Includes royalty interests in 82 wells.
(b) Does not include more than 225,000 additional net acres under lease and
lease option.
(c) Includes royalty interests in 195 wells.
OFFSHORE DIVISION
With three large acquisitions of interests in its major properties and a
recent major discovery, the Company has created a significant presence in the
Gulf of Mexico. The Offshore Division contributes a significant portion of the
Company's reserves and production, with the potential to increase rapidly its
contribution in the future as the Company's Ingrid Field discovery begins
production and pipeline constraints are eliminated in early 1998. The Company
believes that many properties in the Gulf of Mexico are, and will continue to
be, under-exploited and that the potential benefits and exposure to Gulf Coast
markets will complement the Company's western Rocky Mountain activities and
result in significant contributions to the Company.
At December 31, 1996, the Offshore Division had proved reserves of 2.4
million barrels of oil and 90.0 Bcf of gas (17.4 million BOE), up from 748,000
barrels of oil and 16.3 Bcf (3.5 million BOE) at year end 1995. Acquisitions
accounted for 7.8 million BOE of this increase, and the discovery of the Ingrid
Field in Main Pass Block 261 accounted for 6.3 million BOE. At year end, the
Offshore Division had interests in 41 (15.2 net) wells, 35 (14.1 net) of which
were operated by the Company, and held interests in 103,000 (43,600 net) acres.
March 1997 net production averaged 10,155 BOE per day, up from 1,100 BOE per day
in December 1995.
During 1997, the Gulf of Mexico will continue to be a major focus for the
Company. Capital expenditures are expected to total approximately $59 million,
including approximately $20 million to install platforms and related facilities,
$18 million to drill five (3.0 net) development wells and $17 million to drill
five (3.2 net) exploratory wells, primarily on existing projects. In addition,
the Company will continue its acquisition efforts
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<PAGE> 39
in the area, including acquisitions of additional interests in its existing
properties, and will continue to evaluate its existing properties for additional
development or exploratory potential.
Pabst and Busch Fields. The Company's largest project in the Gulf of
Mexico, comprising the Pabst and Busch Fields in Main Pass Blocks 255 and 259,
is in the Main Pass/Viosca Knoll area off the coast of Mississippi. The Company
owns interests in 10 lease blocks in the project area and operates two platforms
there. During 1996, the Company acquired additional interests in these fields
from three joint venture partners, increasing the Company's ownership from 12%
to 60%, and also successfully completed four wells and three workovers. One dry
hole was drilled. By year end, the Company's proved reserves in these fields
totaled 52.1 Bcf of gas and 932,000 barrels of oil (9.6 million BOE),
representing 55% of the Offshore Division's total proved reserves. In 1997, the
Company will continue to evaluate 3-D seismic data from these blocks for
additional exploratory or development potential, with plans to commence five
development wells during the year.
Ingrid Field. During 1996, the Company successfully drilled two exploratory
wells (resulting in the discovery of the Ingrid Field) on farm-in acreage in
Main Pass Block 261, just west of the Pabst and Busch Fields. Initial proved
reserves assigned to the Company's 50% interest in the field were 34.1 Bcf of
gas and 638,000 barrels of oil (6.3 million BOE) at year end 1996. During 1997,
the Company intends to begin installation of a platform and production
facilities, with production initially expected to total 100 MMcf per day (37
MMcf per day net) beginning in early 1998. Full development of the field,
including four productive reservoirs already discovered, as well as additional
prospects, is expected to require at least four additional wells. The Company
plans two additional exploratory wells during 1997.
Other Gulf of Mexico. The Offshore Division also has interests in several
other operated field areas in the Gulf of Mexico, with the Company's interest
exceeding 40% in many cases. During 1997, the Company will continue to evaluate
these blocks for additional development or exploratory potential using recently
acquired 3-D seismic data. The Company may drill up to four exploratory wells in
1997 to test these prospects, including one well begun in February at High
Island 208 off the Texas coast. The Company also signed a farm-in agreement in
late 1996 that will allow the Company to acquire a 50% interest in two suspended
wells and a significant exploratory prospect in South Timbalier 231. The Company
plans to install a platform during the year to produce the suspended wells and
to drill the initial exploratory well in early 1998.
Gulf of Mexico Capacity Constraints. Limited pipeline capacity has
constrained production in the Main Pass/Viosca Knoll area. The Busch and Pabst
Fields in Main Pass 255 and 259 are capable of producing approximately 160 MMcf
per day, but typically are restricted to daily production of approximately 100
MMcf per day (42 MMcf net). The Company has recently signed an agreement with
Viosca Knoll Gathering System ("VK") under which VK will construct an additional
line to the Company's platform in Main Pass 259, as well as a line to the
platform being constructed to produce the Company's Ingrid Field discovery in
Main Pass 261. Upon completion, which is expected in early 1998, the Company
will be able to transport 75 MMcf per day from the Ingrid Field, and firm
capacity for the Company's share of gas from the Pabst and Busch Fields will
increase from 42 MMcf per day to 62 MMcf per day. If the pipeline facilities are
not constructed by the time the Ingrid Field platform is completed, VK will be
obligated to pay nonrecoupable delay payments. VK has the right to terminate the
agreements through June 30, 1997 without the payment of a termination fee. If
the agreement is terminated thereafter, VK must pay a sliding-scale termination
fee, commencing at $2.5 million, to the Company.
In addition, the Company is negotiating agreements with Transcontinental
Gas Pipeline Corporation and other subsidiaries of The Williams Companies
(collectively, "Transco") which will further increase capacity in the Main
Pass/Viosca Knoll area. Transco has made a non-refundable payment of $1.0
million to the Company, and will make an additional $4.0 million payment
following execution of the agreement, to purchase approximately one-half of the
Company's interest in the Ingrid Field platform to use in connection with
facilities related to a new pipeline to be constructed by Transco to the
platform. Transco has agreed to purchase all the Company's production from the
Pabst, Busch and Ingrid Fields at an index-based price for three years after
construction of the Transco facilities, which are expected to be completed by
mid-1998 at the earliest. If the purchase agreement is not extended, Transco has
agreed to transport all the Company's
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<PAGE> 40
production from these blocks for the life of the reserves. The gas purchase
arrangement with Transco is subject to federal regulatory approval acceptable to
Transco. If the arrangement is terminated, Transco will return the interest in
the production platform, but the Company will retain the $5.0 million payment
for such interest.
ROCKY MOUNTAIN DIVISION
During 1996, the Company made significant strides in positioning its
western Rocky Mountain properties for long term growth while maintaining a
modest drilling schedule in view of low prices prevailing during the first ten
months of the year. In addition, significant interests were sold to industry
partners in two major gas projects. The sales will allow expanded development of
these Company-operated projects, while limiting the Company's capital
requirements. In January 1997, the Company sold a one-half interest in two
additional potentially large-scale gas projects scheduled for initial drilling
in 1997. The Company also entered into an alliance with subsidiaries of Coastal
Corporation (together with such subsidiaries, "Coastal") whereby the Company's
gas production throughout most of the region will be pooled with that of other
producers and marketed by Coastal. As part of the venture, most of the Company's
gas facilities were placed under common management with certain of Coastal's
facilities in the western Rocky Mountain area through the formation of Great
Divide Gas Services, LLC ("Great Divide"). The Company expects this alliance to
result in greater efficiency and the opportunity to share in the value
associated with downstream sales of gas.
Capital expenditures are expected to total $43 million for continued
development and exploration in this area during 1997.
Major Gas Projects
Washakie Basin. Since the mid-1980's, the Company's properties in the
Barrel Springs Unit, the Blue Gap Field and the North Standard Draw area of the
Washakie Basin in southern Wyoming, together with its gas gathering and
transportation facilities there, have been one of its most significant assets.
During 1996, the Company continued to develop Mesaverde sands in the Washakie
Basin near its existing properties. Twelve wells were completed in 1996 at
depths ranging from 8,000 to 11,500 feet, increasing the Company's proved
reserves by 1.4 million BOE. Drilling was in progress on three wells at year
end. Net production of gas, which accounts for approximately 95% of the
Company's reserves in this area, averaged 25.5 MMcf per day during 1996,
compared to average 1995 production of 22.9 MMcf per day. Proved reserves at
year end totaled 1.1 million barrels of oil and 133.1 Bcf of gas, or 23.3
million BOE, as compared to 1.1 million barrels and 105 Bcf, or 18.6 million
BOE, at the end of 1995. This increase in reserves is primarily attributable to
increased gas prices at year end 1996 and to development drilling in the field.
The Company expects to accelerate its activity in this area in 1997, with plans
to drill 31 wells at expected drilling costs ranging from $500,000 to $600,000
per well.
The Company operates 128 wells in the Washakie Basin and holds interests in
approximately 97,000 (76,000 net) undeveloped acres. Proved undeveloped reserves
have been assigned to 66 locations in this area.
Deep Green River. Throughout 1996, the Company continued development of the
fluvial Lance sands in the deep portion of the Green River Basin. The Company
participated in eight wells, with two wells in progress at year end. Despite the
sale of a 50% interest in the project to Amoco Production Company in mid-1996,
year end proved reserves totaled 175,000 barrels of oil and 21.7 Bcf of gas, or
3.8 million BOE, as compared to 107,000 barrels of oil and 15.9 Bcf of gas, or
2.8 million BOE, at year end 1995. This increase in reserves is primarily
attributable to extensions of the field and increased gas prices at year end
1996. With 10 wells, six of which are operated by the Company, producing at year
end, net production averaged 832 BOE per day during 1996. The Company holds
interests in approximately 95,000 (44,000 net) undeveloped acres in this
project. At the end of 1996, proved undeveloped reserves were assigned to 17
locations in this area. During 1996, the Company participated in a 51 square
mile 3-D seismic survey that should allow high-grading of future drilling
locations. The Company expects to participate in drilling up to 23 wells in this
area during 1997. Further expansion of drilling is awaiting regulatory approval
of an environmental impact statement, which is expected to be approved by
mid-1997. Assuming the approval is granted, the Company expects to participate
in drilling
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<PAGE> 41
25 to 30 wells per year after 1997 for the foreseeable future. The primary focus
of drilling is the stacked, fluvial sands of the Lance formation at depths of
8,500 to 11,500 feet, at expected drillings costs ranging from $950,000 to $1.3
million per well in 1997.
Piceance Basin. The Company operates the 53,000 acre Hunter Mesa Unit, the
9,000 acre Grass Mesa Unit and the 26,000 acre Divide Creek Unit in the
southeast portion of the Piceance Basin. During 1996, a 45% interest in this
project was sold to Destec Energy Inc. ("Destec"). At year end 1996, the Company
owned approximately 99,000 (43,000 net) undeveloped acres in this area. During
1996, the Company participated in 21 new wells to develop and further delineate
the fields. Twenty-two wells (including two in progress at the beginning of the
year) were completed, and one was in progress at year end. While overall
production from this area increased, net production averaged 9.7 MMcf per day in
1996, down from 1995 average production of 11.9 MMcf per day as a result of the
sale of a 45% interest in the project. At year end 1996, there were 70 producing
wells, 55 of which are operated by the Company. Proved reserves at year end were
32.2 Bcf of gas and 118,000 barrels of oil, or 5.5 million BOE, as compared with
42.6 Bcf and 145,300 barrels, or 7.2 million BOE, at year end 1995. The decrease
in reserves, which primarily resulted from the sale to Destec, was partially
offset by extensions of the field and increased gas prices at year end 1996.
Proved undeveloped reserves were assigned to 37 locations in this area at year
end 1996.
During 1997, the Company plans to drill 23 wells, at expected drilling
costs ranging from $425,000 to $650,000 per well, to develop further the
Company's acreage positions and evaluate the fields, and may expand its
development effort if it can make additional transportation arrangements on
favorable terms and if gas prices stabilize at acceptable levels. The primary
focus of drilling is the stacked, fluvial sands of the Mesaverde formation at
depths of 4,500 to 8,500 feet.
Wind River and Big Horn Basins. The Riverton Dome Field, located in the
Wind River Basin, produces gas primarily from the Frontier and Dakota tight
sands at depths of 8,000 to 10,000 feet, with some sour crude oil production
from the Tensleep and Phosphoria formations. At year end 1996, proved reserves,
nearly all gas, totaled 3.8 million BOE. The Company operates 27 wells having
daily net production of approximately 1,000 BOE, which is processed at a
Company-owned plant.
The Company has assembled approximately 65,000 (63,000 net) undeveloped
acres in an area east of the Riverton Dome Field. In addition, the Company has
obtained an option agreement to exploit oil and gas resources on approximately
33,000 net acres on Shoshone/Arapaho tribal lands in the northeastern part of
the Riverton Dome Field. In January 1997, the Company sold a 50% interest in a
portion of this project, which targets various Cretaceous sands at depths of
8,500 to 12,500 feet, to Belco Oil & Gas Corporation ("Belco"). The Company
expects to drill two wells during 1997 beginning in the second quarter.
In the Big Horn Basin, northwest of the Worland Field, the Company has
assembled approximately 120,000 (81,000 net) undeveloped acres. Belco also
agreed to participate in this project, which targets Cretaceous sands at depths
of 9,500 to 12,000 feet. The first well was commenced in January 1997 and is
being tested.
Other Rockies Projects
Uinta Basin. The Company holds interests in approximately 115,000 (88,000
net) acres in the Uinta Basin. During 1996, the Company participated in drilling
only one non-operated well in the basin as efforts were focused on acquiring and
analyzing 3-D seismic data and implementing two pilot waterflood projects in its
Green River oil projects. The Company began a pilot waterflood in the Leland
Bench Field during the third quarter of 1996 and expects an initial response
early in the second half of 1997. Depending on the response, development should
begin in the second half of 1997. Subject to regulatory approval, a second pilot
project in the Horseshoe Bend Field should commence in mid-1997. The ultimate
success of these projects will be influenced by the response of the pilot
projects and the ability to select locations and enhance waterflood efforts
through the use of 3-D seismic data. These projects are sensitive to oil prices.
During the last half of 1996, oil prices, which had historically been at a
premium to West Texas Intermediate prices, deteriorated and now trade at a
significant discount to such prices. As a result, 1997 activities have been
reduced, with plans to drill only three wells during 1997.
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During 1996, net production from the Uinta Basin averaged 290 barrels of
oil and approximately 1,255 Mcf of gas per day, as compared to 325 barrels and
1,377 Mcf per day during 1995. At year end, the Company had interests in 127
producing wells, 76 of which were operated by the Company. Proved reserves at
year end were 1.2 million barrels of oil and 3.9 Bcf of gas, or 1.8 million BOE,
as compared to 1.6 million barrels and 3.8 Bcf, or 2.2 million BOE, at the end
of 1995. The decreases primarily resulted from production and sales during the
year, as there was no significant development activity. Gas reserves increased
primarily due to higher gas prices prevailing at year end 1996.
Northern Wyoming. The Company holds significant interests in two large,
mature oil fields in Northern Wyoming, the Hamilton Dome and Salt Creek Fields.
In late 1996, the Company unitized the Hamilton Dome Field to achieve common
ownership of all producing horizons across the field. Unitization resulted in an
immediate net production increase to the Company of 140 barrels of oil per day
and is expected to allow the current operator to decrease operating costs
through greater efficiency and to proceed with an expansion of the existing
waterflood and accelerate recompletions. At year end, proved reserves in these
fields totaled 12.2 million BOE, including 12.1 million barrels of oil and 531
MMcf of gas, up from 10.9 million BOE (10.8 million barrels and 455 MMcf) at the
end of 1995. This increase resulted from upward revisions primarily caused by
higher product prices and unitization of Hamilton Dome. Hamilton Dome produces
sour crude oil primarily from the Tensleep, Madison and Phosphoria formations at
depths of 2,500 to 5,500 feet. Salt Creek produces sweet crude oil from the Wall
Creek formation at depths of 2,000 to 2,900 feet.
Transportation and Marketing
The Company owns over 225 miles of pipeline systems, which primarily
transport gas from the Company's properties in the Washakie Basin and Piceance
Basin. Effective January 1, 1997, the Company and Coastal formed Great Divide to
combine the operations of approximately 200 miles of Company-owned pipelines
with over 400 miles of Coastal systems in the Uinta, Washakie and Wind River
Basins. Great Divide, which is 27% owned by the Company and will be jointly
managed by its two participants, operates more than 600 miles of
nonjurisdictional pipelines that connect 650 natural gas wells producing
approximately 165 MMcf per day. Great Divide will oversee the future expansion
of gas pipelines and related facilities within six areas of mutual interest in
Wyoming, Colorado and Utah.
Also effective January 1, 1997, the Company entered into a gas sales
agreement and gas marketing agreement with Coastal to pool the gas supplies of
the Company and other producers in the Rocky Mountain region. The initial supply
pool is expected to exceed 100 MMcf per day, with over half the supply provided
by the Company. The Company sells its gas to Coastal based on agreed market
index prices and shares in the margin earned by Coastal on downstream sales of
the gas, based in part on the portion of the pool represented by Company gas.
Coastal and the Company will also evaluate commitments for firm transportation
or longer term contracts.
The Company expects the joint venture to increase the efficiency of the
Company's pipeline operation and management, as well as to provide greater focus
for future expansion in the region. In addition, the Company hopes that the
pooling of gas supplies and the expertise of Coastal, one of North America's
largest gas marketers, will result in greater downstream marketing
opportunities. The Company and Coastal intend to encourage other Rocky Mountain
producers to join their alliance and thereby enhance its status as a significant
developer of facilities and marketer in the Rocky Mountain region.
SOUTHERN DIVISION
The majority of the Company's producing properties in the Southern
Division, including its properties in the Austin Chalk Trend in Texas, were sold
during 1996. The Southern Division's most significant remaining holding is in
North Louisiana.
North Louisiana
The Company owns over 300,000 net mineral acres, with leases and lease
options covering more than 225,000 additional net acres, in North Louisiana and
also owns royalty interests in approximately 82 producing
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wells. The Company has access to a database of more than 5,000 miles of 2-D
seismic data and in 1996 joined with two partners to shoot a 48 square mile 3-D
seismic survey covering a portion of its acreage. The results of this survey,
which targeted potential significant reef structures in the Cotton Valley
formation, were encouraging, and the partners have commenced a 110 square mile
3-D seismic survey to the west of the previous survey. The Company has
identified a number of reef prospects that will be imaged by the survey, which
should be completed during the second half of 1997. These surveys are being
undertaken at no cost to the Company, which will retain a 25% to 50% interest in
the prospect areas. One well is expected to be commenced by the end of 1997.
PATINA OIL & GAS CORPORATION
During 1996, the Company significantly restructured its Wattenberg Field
assets by creating Patina to hold its properties in the field and to facilitate
the acquisition of Gerrity. The acquisition was completed in May 1996. At year
end 1996, the Company owned 14.0 million, or approximately 74%, of Patina's
common shares, thereby converting its working interest in the field into a
controlling interest in the field's largest producer. At December 31, 1996,
Patina held interests in over 3,600 wells with proved reserves of approximately
71.9 million BOE, approximately 70% of which were attributable to natural gas.
Based on unusually high year end oil and gas prices, these reserves had a
Present Value of $648.8 million. See "Risk Factors -- Price Fluctuations and
Markets."
The Wattenberg Field comprises several productive formations approximately
35 miles north of Denver in the Denver-Julesburg Basin. Three of the formations,
the Codell, Niobrara and J-Sand, are "blanket" zones in the area of Patina's
Wattenberg holdings, while others, such as the D-Sand, Dakota and the shallower
Shannon and Sussex, are more localized. Drilling in Wattenberg is low risk from
the perspective of encountering hydrocarbons with better than 95% of the wells
drilled being completed as producers. Consequently, the field's economic
attractiveness is primarily dependent on energy prices, the reservoir
characteristics of the specific area of the field being drilled and the
operator's ability to minimize capital and operating costs.
As of December 31, 1996, Patina had 728 proved undeveloped locations and
605 proved behind pipe recompletion opportunities. While this inventory provides
the ability to expand development activities should drilling and completion
technologies improve or the recent recovery in Rocky Mountain natural gas prices
continues, a significant portion of Patina's proved undeveloped locations are
projected to provide rates of return below the level judged attractive by its
management based on projected commodity prices and reserve recoveries.
During 1996, Patina focused on combining the operations of its
predecessors, reducing costs and identifying attractive projects for further
development. Only $8.5 million was spent on development and acquisitions,
allowing Patina to use the bulk of its cash flow to reduce debt to $187.4
million at March 31, 1997 (as compared to $220.9 million at June 30, 1996). In
1997, Patina expects to limit its capital expenditures on existing properties to
approximately $15 million. As a result, management believes funds generated from
operations should permit a continued paydown of debt or the pursuit of further
consolidation or acquisition opportunities.
As with all its investments and properties, the Company continuously
evaluates its position in Patina and assesses alternatives to increase value to
the Company and its shareholders. Such alternatives include maintaining its
investment, selling all or part of its investment, either in one transaction or
incrementally, distributing all or part of its investment to its shareholders or
acquiring all of, or an increased interest in, Patina. Any decision will be made
in light of strategic, financial and other factors deemed appropriate by
management at the time.
INTERNATIONAL ACTIVITIES
The Company's international strategy has been to develop projects with the
potential to contribute significantly to production and reserves, while limiting
its financial exposure and political risk through alliances with industry
partners who fund the majority of required capital. SOCO International, a
wholly-owned
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<PAGE> 44
subsidiary of the Company, is the holding company for all international
activities. SOCO International, in turn, owns 90% of SOCO International
Holdings, Inc. ("Holdings"), which owns shares of Cairn, as discussed below,
and, until May 1997, also owned 90% of Operations, which held all other
international investments.
The Company recently completed an offering involving the assets of
Operations on the London Stock Exchange. See "Prospectus Supplement
Summary -- Recent Developments."
Holdings
Holdings currently owns 11.7 million shares (approximately 7%) of Cairn. In
the fourth quarter of 1996, Cairn acquired Command Petroleum Limited, an
Australian company of which Holdings owned 32.6%, in exchange for Cairn common
stock. As a result of the sale, Holdings received 16.2 million shares of Cairn
(approximately 9.6% of the outstanding shares) and realized a pretax gain of
$65.5 million. Cairn holds oil and gas interests in several countries, with a
primary focus in the Bay of Bengal off the coast of Bangladesh, where it
recently announced a major gas discovery. Cairn's position offshore Bangladesh,
where it has identified additional prospects with significant exploratory
potential, together with Command's interest in the Ravva Field offshore India,
position Cairn to contribute significantly to the development of oil and gas
resources in the Indian Subcontinent. Although the potential of Cairn's major
exploratory prospects, and thus the ultimate value of the Company's investment
in Cairn, remains unknown, Cairn's prospects have been well received by the
investment community, increasing the value of the Company's investment from $95
million at the time of the transaction to over $130 million in February 1997.
During February and March 1997, the Company sold 4.5 million shares of Cairn at
an average price of $8.81 per share, realizing proceeds of $39.2 million, which
was applied to repay Holdings' debt to the Company. Gains totaling $13.0 million
were recognized as a result of these transactions. The remaining 11.7 million
shares had a market value of approximately $98.4 million on June 3, 1997. The
Company intends to remain a significant shareholder in Cairn, although it may
elect to liquidate its holdings to redeploy this asset if market conditions
warrant. Holdings has no other significant assets.
Operations
Until the completion of the May 1997 public offering (see "Prospectus
Supplement Summary -- Recent Developments"), Operations engaged in activities
primarily in Russia, Mongolia and Thailand. Operations had a 35% interest in a
joint venture in Russia to develop proven oil fields located in the Volga-Urals
Basin, in which it held exploration and development rights to over 300,000
acres. The four major fields in the basin contained proved reserves of
approximately 8.6 million barrels net to Operations, with significant additional
reserves possible. During 1996, the joint venture produced approximately 776,000
barrels of oil, with all production (other than oil in transit) being exported
and sold on the world market. A company in which Operations owned a 40% interest
holds over 10 million acres covering the entire Tamtsag Basin of northeastern
Mongolia. During 1995 and 1996, two successful exploratory wells were drilled
and established the existence of productive sands across broad areas of the
basin. In early 1995, the company entered into an agreement to sell its
production at world market prices, less $2 per barrel. In Thailand, Operations
was awarded two concessions in 1995 and 1996, and reached an agreement with a
Malaysian-based international oil company to fund the drilling of an exploration
well in 1997.
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<PAGE> 45
PROVED RESERVES
The following table sets forth estimated year end proved reserves for the
three years ended December 31, 1996.
<TABLE>
<CAPTION>
AS OF DECEMBER 31,
-----------------------------------------------
RESTRICTED
HISTORICAL GROUP
---------------------------------- ----------
1994 1995 1996(a) 1996
-------- -------- ---------- ----------
<S> <C> <C> <C> <C>
Crude oil and liquids (MBbl)
Developed............................ 26,104 21,637 31,869 16,070
Undeveloped.......................... 8,873 2,610 8,628 1,952
-------- -------- ---------- --------
Total........................ 34,977 24,247 40,497 18,022
======== ======== ========== ========
Natural gas (MMcf)
Developed............................ 353,930 330,524 443,441 200,664
Undeveloped.......................... 157,321 65,194 162,195 108,313
-------- -------- ---------- --------
Total........................ 511,251 395,718 605,636 308,977
======== ======== ========== ========
Total (MBOE)........................... 120,186 90,200 141,436 69,518
======== ======== ========== ========
Present Value (b)
Developed............................ $355,076 $349,563 $1,023,125 $440,717
Undeveloped.......................... 59,291 23,248 203,879 137,490
-------- -------- ---------- --------
Total........................ $414,367 $372,811 $1,227,004 $578,207
======== ======== ========== ========
</TABLE>
- ---------------
(a) Proved reserves of 8.6 million BOE (with a Present Value of $25.8 million)
assigned to SOCO International projects in Russia are not included in the
table.
(b) Based on benchmark prices of $20.00 per barrel of oil and $2.25 per Mcf of
gas, the Present Value as of December 31, 1996 would have been $690.9
million for the total Company and $326.4 million for the Restricted Group.
See "Risk Factors -- Price Fluctuations and Markets."
Estimated quantities of oil and gas reserves and the Present Value thereof
are based primarily upon reserve reports prepared by the independent petroleum
engineering firms of Netherland, Sewell & Associates, Inc. ("NSAI") and Ryder
Scott Company Petroleum Engineers ("Ryder Scott"), respectively. NSAI estimated
approximately 85%, and Ryder Scott estimated approximately 14%, of the Present
Value of the Company's reserves at December 31, 1996.
Proved developed reserves are proved reserves that are expected to be
recovered from existing wells with existing equipment and operating methods.
Proved undeveloped reserves are proved reserves that are expected to be
recovered from new wells drilled to known reservoirs on undrilled acreage for
which the existence and recoverability of such reserves can be estimated with
reasonable certainty, or from existing wells where a relatively major
expenditure is required to establish production.
There are numerous uncertainties inherent in estimating quantities of
proved reserves and in projecting future rates of production and timing of
development expenditures. The data in the above tables represent estimates only.
Oil and gas reserve engineering is inherently a subjective process of estimating
underground accumulations of oil and gas that cannot be measured exactly, and
estimates of other engineers might differ materially from those shown above. The
accuracy of any reserve estimate is a function of the quality of available data
and engineering and geological interpretation and judgment. Results of drilling,
testing and production after the date of the estimate may justify revisions.
Accordingly, reserve estimates are often materially different from the
quantities of oil and gas that are ultimately recovered.
Future prices received for production and future production costs may vary,
perhaps significantly, from the prices and costs assumed for purposes of these
estimates. The Present Values shown should not be construed as the current
market value of the reserves. The 10% discount factor used to calculate present
value, which is specified by the Commission, is not necessarily the most
appropriate discount rate, and present value,
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<PAGE> 46
no matter what discount rate is used, is materially affected by assumptions as
to timing of future production, which may prove to be inaccurate. For properties
operated by the Company, expenses exclude the Company's share of overhead
charges. In addition, the calculation of estimated future net revenues does not
take into account the effect of various cash outlays, including, among other
things, general and administrative costs and interest expense. See "Risk
Factors -- Uncertainty of Estimates of Reserves and Future Net Revenues."
PRODUCTION AND PRICE HISTORY
The following table sets forth information regarding (i) net production of
crude oil, liquids and natural gas and (ii) certain price and cost information
for each of the years in the five year period ended December 31, 1996.
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
-----------------------------------------------------------
RESTRICTED
HISTORICAL GROUP
---------------------------------------------- ----------
1992 1993 1994 1995 1996 1996
------ ------ ------ ------ ------ ----------
<S> <C> <C> <C> <C> <C> <C>
Production
Oil (MBbl)................ 1,776 3,451 4,366 4,278 3,884 2,196
Gas (MMcf)................ 23,090 35,080 43,809 53,227 55,840 31,893
MBOE(a)................... 5,989 9,297 11,668 13,149 13,191 7,512
Production data
Average sales price(b)
Oil (per Bbl)............. $18.87 $15.41 $14.80 $16.96 $20.39 $ 20.33
Gas (per Mcf)(a).......... 1.74 1.94 1.67 1.35 1.97 1.96
BOE(a).................... 12.92 13.41 11.82 11.00 14.35 14.26
Direct operating cost (per
BOE)...................... $ 4.68 $ 4.45 $ 3.97 $ 3.99 $ 3.76 $ 4.67
</TABLE>
- ---------------
(a) Gas production is converted to oil equivalents at the rate of 6 Mcf per
barrel. Prior to 1993, certain high priced gas was converted based on price
equivalency. The average gas prices shown exclude this high priced gas
production.
(b) Sales of natural gas liquids are included in gas revenues.
PRODUCING WELLS
The following table sets forth certain information at December 31, 1996
relating to the producing wells in which the Company owned a working interest.
The Company also held royalty interests in 277 producing wells. Wells are
classified as oil or gas wells according to their predominant production stream.
<TABLE>
<CAPTION>
AVERAGE
GROSS NET WORKING
WELLS WELLS INTEREST
----- ----- --------
<S> <C> <C> <C>
Restricted Group
Crude oil and liquids................. 1,162 353 30%
Natural gas........................... 330 208 63%
----- -----
Total......................... 1,492 561 38%
===== =====
Total Company
Crude oil and liquids................. 3,956 2,924 74%
Natural gas........................... 943 721 76%
----- -----
Total......................... 4,899 3,645 74%
===== =====
</TABLE>
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<PAGE> 47
ACREAGE
The following table sets forth certain information at December 31, 1996
relating to acreage held by the Company. Undeveloped acreage is acreage held
under lease, permit, contract or option that is not in a spacing unit for a
producing well, including leasehold interests identified for development or
exploratory drilling.
<TABLE>
<CAPTION>
GROSS ACREAGE NET ACREAGE
------------- -----------
<S> <C> <C>
Restricted Group(a)
Developed(b).......................... 181,000 98,000
Undeveloped(c)........................ 1,161,000 795,000
---------- ---------
Total......................... 1,342,000 893,000
========== =========
Total Company
Domestic
Developed(b)....................... 359,000 236,000
Undeveloped(c)..................... 1,322,000 937,000
---------- ---------
Total......................... 1,681,000 1,173,000
========== =========
International
Undeveloped
Russia........................... 306,000 53,000
Mongolia......................... 10,796,000 4,534,000
Thailand......................... 2,520,000 1,071,000
---------- ---------
Total......................... 13,622,000 5,658,000
========== =========
</TABLE>
- ---------------
(a) All domestic.
(b) Developed acreage is acreage assigned to producing wells.
(c) The Company also held leases and lease options covering more than 225,000
additional net undeveloped acres in North Louisiana at December 31, 1996.
DRILLING RESULTS
The following table sets forth information with respect to domestic wells
drilled during the past three years. The information should not be considered
indicative of future performance, nor should it be assumed that there is
necessarily any correlation between the number of productive wells drilled,
quantities of reserves found or economic value. Productive wells are those that
produce commercial quantities of hydrocarbons whether or not they produce a
reasonable rate of return.
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
------------------------------------
RESTRICTED
HISTORICAL GROUP
---------------------- ----------
1994 1995 1996 1996
----- ----- ---- ----------
<S> <C> <C> <C> <C>
Development wells
Productive
Gross.............................. 466.0 223.0 69.0 57.0
Net................................ 390.6 133.1 38.9 26.9
Dry
Gross.............................. 12.0 5.0 2.0 2.0
Net................................ 11.1 3.8 0.5 0.5
Exploratory wells
Productive
Gross.............................. -- -- 3.0 3.0
Net................................ -- -- 0.5 0.5
Dry
Gross.............................. 13.0 -- 2.0 2.0
Net................................ 10.5.. -- 1.6 1.6
</TABLE>
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<PAGE> 48
At December 31, 1996, the Company had 17 (13.1 net) development wells and 2
(1.0 net) exploratory wells in progress. During the first quarter of 1997, the
Company spudded 26 wells, 29 (23.2 net) wells (including wells in progress at
year end) had been completed and 12 (7.4 net) development wells and 4 (2.1 net)
exploratory wells were in progress.
CUSTOMERS AND MARKETING
The Company's oil and gas production is principally sold to end users,
marketers and other purchasers having access to nearby pipeline facilities.
Where there is no practical access to pipelines, crude oil is trucked to storage
facilities. In 1994 and 1995, sales to Amoco Production Company accounted for
approximately 11% and 10% of Company revenues, respectively. In 1996, PanEnergy
Field Services, Inc., which purchases a significant portion of Patina's gas
production, accounted for approximately 11% of revenues. The Company's marketing
of oil and gas can be affected by factors beyond its control whose effects
cannot be accurately predicted. The Company does not believe, however, that the
loss of any of its customers would have a material adverse effect on its
operations.
During 1996, the volume of the Company's gas production marketed by the
Company averaged approximately 136 MMcf per day. Unfavorable market conditions
in 1995 and early 1996 highlighted the need to create new market outlets for
Rocky Mountain gas. To that end, the Company has pursued transactions that
effectively transfer the price that it receives for a portion of its Rocky
Mountain gas to the Gulf Coast market. See Note 2 to the Consolidated Financial
Statements of the Company. As of December 31, 1996, 61% of the Company's
production was sold under arrangements that are responsive to Rocky Mountain
market conditions, and 39% was sold in the Gulf Coast market. See "-- Domestic
Operations -- Rocky Mountain Division -- Transportation and Marketing."
Effective January 1, 1997, the Company's Rocky Mountain gas production
(excluding Patina) is being pooled with that of other producers and marketed by
Coastal. The Company expects this pooling of gas supplies and Coastal's
expertise to increase opportunities for downstream marketing of the Company's
Rocky Mountain gas.
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<PAGE> 49
MANAGEMENT
Listed below are the executive officers and directors of the Company and a
summary of their recent business experience.
<TABLE>
<CAPTION>
NAME POSITION
---- --------
<S> <C>
John C. Snyder........................................................ Chairman and Director
William G. Hargett.................................................... President, Chief Operating Officer and Director
Charles A. Brown...................................................... Senior Vice President -- Rocky Mountain Division
Steven M. Burr........................................................ Vice President -- Engineering and Planning
Peter C. Forbes....................................................... Vice President -- Offshore
Peter E. Lorenzen..................................................... Vice President -- General Counsel and Secretary
H. Richard Pate....................................................... Vice President -- Major Gas Projects
David M. Posner....................................................... Vice President -- Gas Management
James H. Shonsey...................................................... Vice President -- Finance
Edward T. Story....................................................... Vice President -- International and Director
Rodney L. Waller...................................................... Vice President -- Special Projects
Vice President -- Southern Division and
Richard A. Wollin..................................................... Acquisitions
Roger W. Brittain..................................................... Director
John A. Hill.......................................................... Director
William J. Johnson.................................................... Director
Harold R. Logan, Jr................................................... Director
B. J. Kellenberger.................................................... Director
James E. McCormick.................................................... Director
</TABLE>
John C. Snyder (55), Chairman and a director, founded a predecessor of the
Company in 1978. From 1973 to 1977, Mr. Snyder was an independent oil operator
in Texas and Oklahoma. Previously, he was a director and the Executive Vice
President of May Petroleum, Inc. where he served from 1971 to 1973. Mr. Snyder
was the first president of Canadian-American Resources Fund, Inc., which he
founded in 1969. From 1964 to 1966, Mr. Snyder was employed by Humble Oil and
Refining Company (currently Exxon Co., USA) as a petroleum engineer. Mr. Snyder
received his Bachelor of Science Degree in Petroleum Engineering from the
University of Oklahoma and his Masters Degree in Business Administration from
the Harvard University Graduate School of Business Administration. Mr. Snyder
also serves as a director of Patina.
William G. Hargett (47), President, Chief Operating Officer and a director,
has been with the Company since April 1997. Prior to joining the Company, Mr.
Hargett served as President of Greenhill Petroleum Corporation from 1994 to
1997, Amax Oil & Gas, Inc. from 1993 to 1994 and North Central Oil Corporation
from 1988 to 1993. Mr. Hargett earned B.S. and M.S. degrees from the University
of Alabama.
Charles A. Brown (50), Senior Vice President -- Rocky Mountain Division,
joined the Company in 1987. He was a petroleum engineering consultant from 1986
to 1987. He served as President of CBW Services, Inc., a petroleum engineering
consulting firm, from 1979 to 1986 and was employed by Kansas Nebraska Natural
Gas Company from 1971 to 1979 and Amerada Hess Corporation from 1969 to 1971.
Mr. Brown received his Bachelor of Science Degree in Petroleum Engineering from
the Colorado School of Mines.
Steven M. Burr (40), Vice President -- Engineering and Planning, joined the
Company in 1987. From 1982 to 1987, he was a Vice President with the petroleum
engineering consulting firm of Netherland, Sewell & Associates, Inc. From 1978
to 1982, Mr. Burr was employed by Exxon Company, USA in the Production
Department. Mr. Burr received his Bachelor of Science Degree in Civil
Engineering from Tulane University.
Peter C. Forbes (51), Vice President -- Offshore, who was appointed to that
position in 1996, joined the Company as Executive Vice President of SOCO
Offshore, Inc., the Company's Gulf Coast subsidiary, in July 1995 and has been
President of that company since July 1996. From 1994 to 1995, he was President
and
S-49
<PAGE> 50
Chief Executive Officer of SD Resources, Inc., the general partner of Sand
Dollar Resources L.P., a partnership with Enron Gas Services Corp., a subsidiary
of Enron Corp. From 1992 to 1993, Mr. Forbes was Vice President in charge of the
oil and gas property acquisition unit of Enron Gas Services Corp. From 1988 to
1992, he was President and a director of American Exploration Company. Prior
thereto, Mr. Forbes was Vice President, Finance of Browning-Ferris Industries,
Inc. during 1988 and Senior Vice President and Chief Financial Officer of Zapata
Corporation from 1985 to 1987. He served in several positions, including Vice
President and Treasurer, at Texas Eastern Transmission Corporation from 1975 to
1985. Mr. Forbes received his Bachelor of Arts Degree from Edinburgh University
and is a Scottish Chartered Accountant.
Peter E. Lorenzen (47), Vice President -- General Counsel and Secretary,
joined the Company in 1991. From 1983 through 1991, he was a shareholder in the
Dallas law firm of Johnson & Gibbs, P.C. Prior to that, Mr. Lorenzen was an
associate with Cravath, Swaine & Moore. Mr. Lorenzen received his law degree
from New York University School of Law and his Bachelor of Arts Degree from The
Johns Hopkins University.
H. Richard Pate (43), Vice President -- Major Gas Projects, joined the
Company in 1988. From 1981 to 1988, Mr. Pate held various positions with
Mitchell Energy Corporation, including Region Engineer and Production Manager.
He was employed by Champlin Petroleum Company from 1979 to 1981 and Atlantic
Richfield Corporation from 1975 to 1979. Mr. Pate received his Bachelor of
Science Degree in Chemical Engineering from the University of Wyoming.
David M. Posner (43), Vice President -- Gas Management, joined the Company
in 1991. From 1980 to 1991 he held various positions with Ladd Petroleum
Corporation (a subsidiary of the General Electric Company) including Vice
President of Gas Gathering, Processing and Marketing. Mr. Posner received his
Bachelor of Arts degree from Brown University and his Master of Science in
Mineral Economics from the Colorado School of Mines.
James H. Shonsey (45), Vice President -- Finance, joined the Company in
1991. From 1987 to 1991, Mr. Shonsey served in various capacities, including as
Director of Operations Accounting, for Apache Corporation. From 1976 to 1987 he
held various positions with Deloitte & Touche, Quantum Resources Corporation,
Flare Energy Corporation and Mizel Petro Resources, Inc. Mr. Shonsey received
his Bachelor of Science Degree in Accounting from Regis University and his
Master of Science Degree in Accounting from the University of Denver.
Edward T. Story (53), a director and Vice President -- International of the
Company and President of SOCO International, joined the Company in 1991 and
became a director in February 1996. From 1990 to 1991, Mr. Story was Chairman of
the Board of a jointly-owned Thai/US company, Thaitex Petroleum Company. Mr.
Story was co-founder, Vice Chairman of the Board and Chief Financial Officer of
Conquest Exploration Company from 1981 to 1990. He served as Vice President,
Finance and Chief Financial Officer of Superior Oil Company from 1979 to 1981.
Mr. Story held the positions of Exploration and Production Controller and
Refining Controller with Exxon USA from 1975 to 1979. He held various positions
in Esso Standard's international companies from 1966 to 1975. Mr. Story received
a Bachelor of Science Degree in Accounting from Trinity University, San Antonio,
Texas and a Masters of Business Administration from the University of Texas in
Austin. Mr. Story serves as a director of First BanksAmerica, Inc., a bank
holding company, Hi/Lo Automotive, Inc., a distributor of automobile parts,
Hallwood Realty Corporation, the general partner of Hallwood Realty Partners,
L.P., an American Stock Exchange-listed real estate limited partnership, and
Seaunion Holdings Limited, an oil and gas company listed on the Hong Kong Stock
Exchange.
Rodney L. Waller (47), Vice President -- Special Projects, joined the
Company in 1977. Previously, Mr. Waller was employed by Arthur Andersen & Co.
Mr. Waller received his Bachelor of Arts Degree from Harding University.
Richard A. Wollin (44), Vice President -- Southern Division and
Acquisitions, joined the Company in 1990. From 1983 to 1989, Mr. Wollin served
in various management capacities at Quinoco Petroleum, Inc., including as
Executive Vice President with primary responsibility for acquisition,
divestiture and corporate finance activities. From 1976 to 1983, he was employed
in various capacities for The St. Paul Companies, Inc.,
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<PAGE> 51
including Senior Vice President of St. Paul Oil & Gas Corp. Mr. Wollin received
his Bachelor of Science Degree from St. Olaf College and his law degree from the
University of Minnesota Law School. Mr. Wollin is a member of the Minnesota Bar
Association.
Roger W. Brittain (60), director since 1983, is a director of Guinness
Mahon & Co. Limited ("GM&Co."), a London merchant bank. In March 1990, he became
the Managing Director of Guinness Mahon Energy Services Limited, a subsidiary of
GM&Co. formed to provide investment banking and consultant services to the oil
and gas industry. Mr. Brittain was a founder and the Managing Director of Energy
Management and Finance Limited ("EMF"), a position he held from 1985 to
September 1989. EMF managed TR Energy Public Limited Company ("TR Energy"), an
investment company making oil and gas investments in the United States. From
1980 through October 1989, Mr. Brittain was first Managing Director and from
mid-1987 an Executive Director of TR Energy. From 1977 to 1980, Mr. Brittain was
a director of Shaw Wallace & Co. Ltd., Calcutta, India. From 1967 to 1977, he
was associated with Hill Samuel & Co. Ltd., William Brandts & Sons Ltd. and
Edward Bates and Sons Ltd., merchant banks in London. Prior to that time, Mr.
Brittain was with Her Majesty's Foreign Service. Mr. Brittain serves as Chairman
of the Audit Committee and is a member of the Compensation Committee. Mr.
Brittain serves as a director of Seaunion Holdings Limited, an oil and gas
company listed on the Hong Kong Stock Exchange.
John A. Hill (55), director since 1981, is a Managing Director of First
Reserve Corporation, an oil and gas investment management company. Prior to
joining First Reserve, Mr. Hill was President, Chief Executive Officer and
Director of Marsh & McLennan Asset Management Company, the money management
subsidiary of Marsh & McLennan Companies, Inc. From 1979 to 1980, Mr. Hill
served as President and Chief Executive Officer of Eberstadt Asset Management
Company, the asset management division of F. Eberstadt & Co., Inc. Prior to
1976, Mr. Hill held several senior positions in the federal government including
Deputy Administrator of the Federal Energy Administration from 1975 to 1976 and
Deputy Associate Director of the Office of Management and Budget from 1973 to
1974. Mr. Hill received his Bachelors Degree in Economics from Southern
Methodist University and pursued graduate studies there as a Woodrow Wilson
Fellow. Mr. Hill is a trustee of the Putnam Funds in Boston and a director of
Maverick Tube Corporation, a supplier of tubular goods, and Weatherford-Enterra
Corporation, an oil field services company. Mr. Hill serves as Chairman of the
Compensation and Governance Committees and as a member of the Executive
Committee.
William J. Johnson (62), director since 1994, is a private consultant for
the oil and gas industry and is President and a director of JonLoc Inc., an oil
and gas company of which he and his family are the sole shareholders. From 1991
to 1994, Mr. Johnson was President, Chief Operating Officer and a director of
Apache Corporation. Previously, he was a director, President and Chief Executive
Officer of Tex/Con Oil and Gas, where he served from 1989 to 1991. Prior
thereto, Mr. Johnson served in various capacities with major oil companies,
including director and President USA of BP Exploration Company, President of
Standard Oil Production Company and Senior Vice President of The Standard Oil
Company. Mr. Johnson received a Bachelor of Science degree in Petroleum Geology
from Mississippi State University and completed the Advanced Management Course
at the University of Houston. Mr. Johnson is a director of Patina. Mr. Johnson
serves as a director of Tesoro Petroleum Corporation, an integrated petroleum
and oil field service company, and Camco International, an oilfield
manufacturing company. Mr. Johnson also serves on the advisory board of Texas
Commerce Bank National Association, Houston. Mr. Johnson serves on the Audit,
Compensation and Governance Committees.
B. J. Kellenberger (71), director since 1989, is the founder and owner of
Kelloil, Inc., which is engaged in exploration and production of oil and natural
gas and secondary recovery of oil. In 1965, he founded Shenandoah Oil
Corporation and served as President, Chief Executive Officer and Chairman of the
Board until Shenandoah's voluntary liquidation in 1979. Mr. Kellenberger is a
director of The Jefferson Energy Foundation and a trustee of the Cassata
Learning Center. Mr. Kellenberger serves on the Audit and Executive Committees.
Harold R. Logan, Jr. (52), director since 1997, is Executive Vice
President/Finance and a director of TransMontaigne Oil Company, a holding
company engaged in providing distribution and marketing services to
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<PAGE> 52
the downstream sector of the oil and gas industry. Previously, from 1984 to
1994, Mr. Logan was Senior Vice President/Finance and a director of Associated
Natural Gas Corporation. Prior to joining Associated Natural Gas Corporation,
Mr. Logan was with Dillon, Read & Co. Inc. and Rothschild, Inc. Mr. Logan also
serves as a director of Suburban Propane Partners, L.P.
James E. McCormick (69), director since 1992, served as President, Chief
Operating Officer and a director of Oryx Energy Company from its inception in
November 1988 until his retirement in March 1992. Prior to his service with
Oryx, Mr. McCormick served from 1953 in a number of positions with the Sun
organization, most recently serving as President, Chief Executive Officer and a
director of Sun Exploration and Production Company. Mr. McCormick serves as a
director of Lone Star Technologies, Inc., B. J. Services, Inc., an oilfield
service company, and TESCO Corporation, a manufacturer of oil field drilling
systems. Mr. McCormick serves on the Compensation and Governance Committees.
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<PAGE> 53
DESCRIPTION OF NOTES
GENERAL
The Notes will be issued pursuant to an Indenture to be dated as of June
10, 1997 (the "Original Indenture") between the Company, as issuer, and Texas
Commerce Bank National Association, as trustee (the "Trustee"), and two
Supplemental Indentures to be dated as of June 10, 1997 (collectively, the
"Supplemental Indenture" and, together with the Original Indenture, the
"Indenture"), among the Company, certain subsidiaries named in the Supplemental
Indenture, as Subsidiary Guarantors, and the Trustee. The terms of the Notes
include those stated in the Indenture and those made part of the Indenture by
reference to the Trust Indenture Act of 1939, as amended (the "Trust Indenture
Act"). The Notes are subject to all such terms, and Holders are referred to the
Indenture and the Trust Indenture Act for a statement thereof. The following
summary of certain provisions of the Indenture does not purport to be complete
and is qualified in its entirety by reference to the Indenture, including the
definitions therein of certain terms used below. For purposes of this section of
this Prospectus Supplement references to the "Company" mean Snyder Oil
Corporation excluding its subsidiaries. The definitions of certain terms used in
the following summary are set forth below under "-- Certain Definitions."
Each of Patina and SOCO International will be Unrestricted Subsidiaries. As
a result, the activities, including the incurrence of indebtedness, of these
subsidiaries will not be restricted by the Indenture. In addition, the Company
will be permitted to dispose of interests in these subsidiaries without
restrictions imposed by the Indenture and any proceeds so realized will not be
restricted by the Indenture. All other active subsidiaries of the Company will
be Restricted Subsidiaries and Subsidiary Guarantors.
PRINCIPAL, MATURITY AND INTEREST
The Notes will be general unsecured senior subordinated obligations of the
Company, limited in aggregate principal amount to $175,000,000, and will mature
on June 15, 2007. Interest on the Notes will accrue at the rate of 8 3/4% per
annum and will be payable semiannually in arrears on June 15 and December 15,
commencing on December 15, 1997 to Holders at the close of business on the June
1 or December 1 next preceding such interest payment date. Interest on the Notes
will accrue from the most recent date to which interest has been paid or, if no
interest has been paid, from the date of original issuance. 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 transferable, at the office or agency of the Company
maintained for such purpose within the City and State of New York. In addition,
in the event the Notes do not remain in book-entry form, interest may be paid,
at the option of the Company, by check mailed to the Holders at their respective
addresses as set forth on the Note Register. No service charge will be made for
any transfer or exchange of Notes, but the Company or the Trustee may require
payment of a sum sufficient to cover any tax or other governmental charge that
may be payable in connection therewith. The Notes will be issued in
denominations of $1,000 and integral multiples thereof.
SUBORDINATION
The payment of the principal of, and premium, if any, and interest on the
Notes will be subordinated in right of payment, as set forth in the Indenture,
to the prior payment in full of Senior Indebtedness, which will include
borrowings under the Credit Facility, whether outstanding on the date of the
Supplemental Indenture or thereafter incurred. In the event of any insolvency or
bankruptcy case or proceeding, or any receivership, liquidation, reorganization
or other similar case or proceeding in connection therewith, relating to the
Company or to its creditors, as such, or to its assets, or any liquidation,
dissolution or other winding-up of the Company, whether voluntary or involuntary
and whether or not including insolvency or bankruptcy, or any assignment for the
benefit of creditors or other marshaling of assets or liabilities of the Company
(provided that this provision will not require the repayment of all Senior
Indebtedness in full in connection with the consolidation or merger of the
Company or its liquidation or dissolution following the conveyance, transfer,
lease or other disposition of all or substantially all the properties and assets
of the Company and its Restricted Subsidiaries on a consolidated basis upon the
terms and conditions described under "-- Merger, Consolidation or Sale of
Assets" below as a prerequisite to any payments being made to Holders), the
holders of Senior
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Indebtedness will first be entitled to receive payment in full of all amounts
due on or in respect of all Senior Indebtedness, or provision must be made for
such payment, before Holders will be entitled to receive any direct or indirect
payment or distribution of any kind or character (other than any payment or
distribution in the form of Permitted Junior Securities) on account of principal
of, premium, if any, on or interest on the Notes or on account of the purchase
or redemption or other acquisition of the Notes (including pursuant to an
optional redemption, a Change of Control Offer or a Net Proceeds Offer). In the
event that, notwithstanding the foregoing, the Trustee or the Holder of any Note
receives any payment or distribution of properties or assets of the Company of
any kind or character, whether in cash, property or securities, by set-off or
otherwise, in respect of principal of (or premium, if any, on) or interest on
the Notes before all Senior Indebtedness is paid or provided for in full, then
the Trustee or Holders receiving any such payment or distribution (other than a
payment or distribution in the form of Permitted Junior Securities or from the
trust described below under "-- Legal Defeasance and Covenant Defeasance") will
be required to pay or deliver such payment or distribution forthwith to the
trustee in bankruptcy, receiver, liquidating trustee, custodian, assignee, agent
or other Person making payment or distribution of assets of the Company for
application to the payment of all Senior Indebtedness remaining unpaid, to the
extent necessary to pay all Senior Indebtedness in full.
The Company also may not make any payment or distribution of any properties
or assets of the Company of any kind or character (other than Permitted Junior
Securities or from the trust described below under "-- Legal Defeasance and
Covenant Defeasance") on account of principal of, premium, if any, on or
interest on the Notes or on account of the purchase or redemption or other
acquisition of Notes upon the occurrence of a Payment Event of Default and
receipt by the Trustee of written notice thereof until such Payment Event of
Default shall have been cured or waived or shall have ceased to exist or such
Senior Indebtedness shall have been paid in full or otherwise discharged, after
which the Company shall resume making any and all required payments in respect
of the Notes, including any missed payments.
The Company also may not make any payment or distribution of any properties
or assets of the Company of any kind or character (other than Permitted Junior
Securities or from the trust described below under "-- Legal Defeasance and
Covenant Defeasance") on account of any principal of, premium, if any, on or
interest on the Notes or on account of the purchase or redemption or other
acquisition of Notes for the period specified below ("Payment Blockage Period")
upon the occurrence of a Non-payment Event of Default and receipt by the Trustee
and the Company of written notice thereof from one or more of the holders of
Specified Senior Indebtedness (or their representative). The Payment Blockage
Period will commence upon the earlier of the dates of receipt by the Trustee or
the Company of such notice from one of more of the holders of Specified Senior
Indebtedness (or their representative) and shall end on the earliest of (i) 179
days thereafter, (ii) the date, as set forth in a written notice from the
holders of the Specified Senior Indebtedness, (or their representative) to the
Company or the Trustee, on which such Non-payment Event of Default is cured,
waived in writing or ceases to exist or such Specified Senior Indebtedness is
discharged or (iii) the date on which such Payment Blockage Period shall have
been terminated by written notice to the Company or the Trustee from one or more
of such holders (or their representative) initiating such Payment Blockage
Period, after which the Company will resume (unless otherwise prohibited
pursuant to the immediately preceding paragraph) making any and all required
payments in respect of the Notes, including any missed payments. In any event,
not more than one Payment Blockage Period may be commenced during any period of
360 consecutive days. No Non-payment Event of Default that existed or was
continuing on the date of delivery of any Payment Blockage Notice to the Trustee
can be made the basis for a subsequent Payment Blockage Notice. In the event
that, notwithstanding the foregoing, the Company makes any payment to the
Trustee or any Holder prohibited by the subordination provision of the
Indenture, then such payment will be required to be paid over and delivered
forthwith to the Company.
If the Company fails to make any payment on the Notes when due or within
any applicable grace period whether or not on account of the payment blockage
provision described above, such failure would constitute an Event of Default
under the Indenture and would enable Holders to accelerate the maturity thereof.
See "-- Events of Default and Remedies."
As a result of such subordination provisions described above, in the event
of a distribution of assets upon the liquidation, receivership, reorganization
or insolvency of the Company, creditors of the Company who are
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holders of Senior Indebtedness may recover more, ratably, than the Holders of
the Notes, and assets which would otherwise be available to pay obligations in
respect of the Notes will be available only after all Senior Indebtedness has
been paid in full, and there may not be sufficient assets remaining to pay
amounts due on any or all of the Notes.
The subordination provisions described above will cease to be applicable to
the Notes upon any Legal Defeasance or Covenant Defeasance of the Notes as
described under "-- Legal Defeasance and Covenant Defeasance."
The Notes will be structurally subordinated to all existing and future
liabilities of Subsidiaries of the Company other than Subsidiary Guarantors. See
"-- Senior Subordinated Guarantees of Notes."
At March 31, 1997, after giving pro forma effect to the transactions
described under "Capitalization" and the application of the estimated net
proceeds therefrom as described in "Use of Proceeds," the Company would have had
no Senior Indebtedness outstanding. See "Use of Proceeds" and "Capitalization."
Although the Indenture will contain limitations on the amount of additional
Indebtedness that the Company and its Subsidiaries may incur, the amounts of
such Indebtedness could be substantial and, in any case, such Indebtedness may
be Senior Indebtedness or Guarantor Senior Indebtedness. See "-- Certain
Covenants -- Incurrence of Indebtedness."
SENIOR SUBORDINATED GUARANTEES OF NOTES
Each Subsidiary Guarantor will unconditionally guarantee, jointly and
severally, to each Holder and the Trustee the full and prompt performance of the
Company's obligations under the Indenture and the Notes, including the payment
of principal of (and premium, if any, on) and interest on the Notes pursuant to
its Subsidiary Guarantee. The obligations of each Subsidiary Guarantor will be
limited to the maximum amount as will, after giving effect to all other
contingent and fixed liabilities (including, but not limited to, Guarantor
Senior Indebtedness) of such Subsidiary Guarantor and after giving effect to any
collections from or payments made by or on behalf of any other Subsidiary
Guarantor in respect of the obligations of such other Subsidiary Guarantor under
its Subsidiary Guarantee or pursuant to its contribution obligations under the
Indenture, result in the obligations of such Subsidiary Guarantor under the
Subsidiary Guarantee not constituting a fraudulent conveyance or fraudulent
transfer under federal or state law. Each Subsidiary Guarantor that makes a
payment or distribution under a Subsidiary Guarantee shall be entitled to a
contribution from each other Subsidiary Guarantor in a pro rata amount based on
the Adjusted Net Assets of each Subsidiary Guarantor.
Each Subsidiary Guarantor may consolidate with or merge into or sell or
otherwise dispose of all or substantially all of its properties and assets to
the Company or another Subsidiary Guarantor without limitation, except to the
extent any such transaction is subject to the "Merger, Consolidation or Sale of
Assets" covenant of the Indenture. Each Subsidiary Guarantor may consolidate
with or merge into or sell all or substantially all of its properties and assets
to a Person other than the Company or another Subsidiary Guarantor (whether or
not Affiliated with the Subsidiary Guarantor); provided that (a) if the
surviving Person is not the Subsidiary Guarantor, the surviving Person agrees to
assume the Subsidiary Guarantor's Subsidiary Guarantee and all its obligations
pursuant to the Indenture (except to the extent the following paragraph would
result in the release of such Subsidiary Guarantee) and (b) such transaction
does not (i) violate any of the covenants described under the heading
"-- Certain Covenants" or (ii) result in a Default or Event of Default
immediately thereafter that is continuing.
Upon the sale or other disposition (by merger or otherwise) of a Subsidiary
Guarantor (or all or substantially all of its properties and assets) to a Person
other than the Company or another Subsidiary Guarantor and pursuant to a
transaction that is otherwise in compliance with the Indenture (including as
described in the foregoing paragraph), such Subsidiary Guarantor shall be deemed
released from its Subsidiary Guarantee and the related obligations set forth in
the Indenture; provided, however, that any such termination shall occur only to
the extent that all obligations of such Subsidiary Guarantor under all of its
guarantees of, and under all of its pledges of assets or other security
interests which secure, other Indebtedness of the Company or any other
Restricted Subsidiary shall also terminate upon such sale or other disposition.
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The obligations of each Subsidiary Guarantor under its Subsidiary Guarantee
are subordinated to the prior payment in full of all Guarantor Senior
Indebtedness of such Subsidiary Guarantor (including its guarantee of
Indebtedness of the Company under the Credit Facility) to substantially the same
extent as the Notes are subordinated to Senior Indebtedness. At March 31, 1997,
the only Guarantor Senior Indebtedness outstanding consisted of guarantees of
Company obligations under the Credit Facility.
The initial Subsidiary Guarantors are the Company's principal subsidiaries
other than Patina and SOCO International. Although the Indenture does not
contain any requirement that any other existing Subsidiary execute and deliver a
Subsidiary Guarantee, certain covenants described below require a future
Restricted Subsidiary to execute and deliver a Subsidiary Guarantee prior to the
guarantee or the incurrence of certain other Indebtedness. See "Certain
Covenants -- Limitation on Guarantees of Indebtedness by Restricted
Subsidiaries."
OPTIONAL REDEMPTION
The Notes will not be redeemable at the Company's option prior to June 15,
2002. Thereafter, the Notes will be subject to redemption at the option of the
Company, in whole or in part, upon not less than 30 or more than 60 days'
notice, at the redemption prices (expressed as percentages of principal amount)
set forth below plus accrued and unpaid interest to the applicable redemption
date, if redeemed during the twelve-month period beginning on June 15 of the
years indicated below:
<TABLE>
<CAPTION>
YEAR PERCENTAGE
---- ----------
<S> <C>
2002.............................................. 104.375%
2003.............................................. 102.916%
2004.............................................. 101.458%
2005 and thereafter............................... 100.000%
</TABLE>
In addition, at any time and from time to time prior to June 15, 2000, the
Company may, at its option, redeem in the aggregate up to 30% of the aggregate
principal amount of the Notes originally issued under the Indenture with the
proceeds of one or more Public Equity Offerings by the Company at a redemption
price (expressed as a percentage of principal amount) of 108.75%, plus accrued
and unpaid interest, if any, to the redemption date (subject to the right of
Holders on the relevant record date to receive interest due on the relevant
interest payment date); provided, however, that at least $122.5 million
aggregate principal amount of the Notes must remain outstanding after each such
redemption. In order to effect the foregoing redemption, the Company must mail
notice of redemption no later than 60 days after the related Public Equity
Offering and must consummate such redemption within 90 days of the closing of
the Public Equity Offering.
If less than all the Notes are to be redeemed at any time, selection of
Notes for redemption will be made by the Trustee on a pro rata basis, provided
that no Notes of $1,000 or less shall be redeemed in part. Notices of redemption
shall be mailed by first class mail at least 30 but not more than 60 days before
the redemption date to each Holder to be redeemed at its registered address. If
any Note is to be redeemed in part only, the notice of redemption that relates
to such Note shall state the portion of the principal amount thereof to be
redeemed. A new Note in principal amount equal to the unredeemed portion thereof
will be issued in the name of the Holder thereof upon surrender of the original
Note. On and after the redemption date, interest will cease to accrue on Notes
or portions thereof called for redemption.
MANDATORY REDEMPTION
The Company is not required to make mandatory redemption or sinking fund
payments with respect to the Notes.
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REPURCHASE AT THE OPTION OF HOLDERS
Change of Control
Upon the occurrence of a Change of Control, each Holder will have the right
to require the Company to repurchase all or any part (equal to $1,000 or an
integral part thereof) of such Holder's Notes pursuant to the offer described
below (the "Change of Control Offer") at an offer price in cash equal to 101% of
the aggregate principal amount thereof plus accrued and unpaid interest (the
"Change of Control Purchase Price") to the date of purchase (the "Change of
Control Payment Date"). Within 30 days following any Change of Control, the
Company will mail a notice to the Trustee and each Holder describing the
transaction or transactions that constitute the Change of Control and offering
to repurchase Notes pursuant to the procedures required by the Indenture and
described in such notice. The Change of Control Payment Date shall be a Business
Day not less than 30 days nor more than 60 days after such notice is mailed. The
Company will comply 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 repurchase of the Notes as
a result of 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 herein by virtue thereof.
On the Change of Control Payment Date, the Company will, to the extent
lawful, (i) accept for payment all Notes or portions thereof properly tendered
pursuant to the Change of Control Offer, (ii) deposit with the Paying Agent an
amount equal to the Change of Control Purchase Price in respect of all Notes or
portions thereof so tendered and (iii) deliver or cause to be delivered to the
Trustee the Notes so accepted together with an Officers' Certificate stating the
aggregate principal amount of Notes or portions thereof being purchased by the
Company. The Paying Agent will promptly mail to each Holder of Notes so tendered
the Change of Control Payment for such Notes, and the Trustee will promptly
authenticate and mail (or cause to be transferred by book entry) to each Holder
a new Note equal in principal amount to any unpurchased portion of the Notes
surrendered, if any; provided that each such new Note will be in a principal
amount of $1,000 or an integral multiple thereof. The Indenture will provide
that, prior to complying with the provisions of this covenant, but in any event
within 30 days following a Change of Control, the Company will either repay all
outstanding Senior Indebtedness or obtain the requisite consents, if any, under
all agreements governing outstanding Senior Indebtedness to permit the
repurchase of Notes required by this covenant. The Company will publicly
announce the results of the Change of Control Offer on or as soon as practicable
after the Change of Control Payment Date.
Except as described above with respect to a Change of Control, the
Indenture will not contain provisions that permit Holders to require that the
Company repurchase or redeem the Notes in the event of a takeover,
recapitalization or similar restructuring.
The Credit Facility provides that certain change of control events with
respect to the Company constitute a default thereunder. Any future credit
agreements or other agreements relating to Senior Indebtedness to which the
Company becomes a party may contain similar restrictions and provisions. In the
event a Change of Control occurs at a time when the Company is prohibited from
purchasing Notes, the Company could seek the consent of its lenders to the
purchase of Notes or could attempt to refinance the borrowings that contain such
prohibition. If the Company does not obtain such a consent or repay such
borrowings, the Company will remain prohibited from purchasing Notes. In such
case, the Company's failure to purchase tendered Notes would constitute an Event
of Default under the Indenture which would, in turn, constitute a default under
the Credit Facility. In such circumstances, the subordination provisions in the
Indenture would likely restrict payments to Holders. The definition of Change of
Control includes an event by which the Company sells, assigns, conveys,
transfers or leases all or substantially all of its properties to any Person;
the phrase "all or substantially all" is subject to applicable legal precedent
and as a result in the future there may be uncertainty as to whether a Change of
Control has occurred.
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 at the same
purchase price, at the same times and otherwise in
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substantial compliance with the requirements 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.
Asset Sales
The Indenture will provide that the Company will not and will not permit
any Restricted Subsidiary to, engage in 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 assets
and properties sold or otherwise disposed of pursuant to the Asset Sale (as
determined by the Board of Directors of the Company in the case of Asset Sales
greater than $5,000,000, whose determination shall be conclusive and evidenced
by a Board Resolution), (ii) at least 85% of the consideration received by the
Company or the Restricted Subsidiary, as the case may be, in respect of such
Asset Sale consists of cash, Cash Equivalents or properties used in the Oil and
Gas Business of the Company and its Restricted Subsidiaries and (iii) the
Company delivers to the Trustee an Officers' Certificate, which shall be
conclusive, certifying that such Asset Sale complies with clauses (i) and (ii).
The amount (without duplication) of any Indebtedness (other than Subordinated
Indebtedness or Pari Passu Indebtedness) of the Company or such Restricted
Subsidiary that is expressly assumed by the transferee in such Asset Sale and
with respect to which the Company or such Restricted Subsidiary, as the case may
be, is unconditionally released by the holder of such Indebtedness shall be
deemed to be cash or Cash Equivalents for purposes of clause (ii) and shall also
be deemed to constitute a repayment of, and a permanent reduction in, the amount
of such Indebtedness for purposes of the following paragraph.
If the Company or any Restricted Subsidiary engages in an Asset Sale, the
Company or such Restricted Subsidiary may, no later than 365 days after such
Asset Sale, either (i) apply all or any of the Net Cash Proceeds therefrom to
repay Indebtedness (other than Subordinated Indebtedness or Pari Passu
Indebtedness) of the Company or any Restricted Subsidiary, provided, in each
case, that the related loan commitment (if any) is thereby permanently reduced
by the amount of such Indebtedness so repaid, or (ii) invest all or any part of
the Net Cash Proceeds thereof in properties and assets that will be used in the
Oil and Gas Business of the Company or its Restricted Subsidiaries, as the case
may be. The amount of such Net Cash Proceeds not applied or invested as provided
in this paragraph will constitute "Excess Proceeds."
When the aggregate amount of Excess Proceeds equals or exceeds $10,000,000,
the Company shall make an offer to purchase, from all Holders and holders of any
then outstanding Pari Passu Indebtedness required to be repurchased or repaid on
a permanent basis in connection with an Asset Sale, an aggregate principal
amount of Notes and any such Pari Passu Indebtedness equal to such Excess
Proceeds as follows:
(i) The Company shall make an offer to purchase (a "Net Proceeds
Offer") from all Holders in accordance with the procedures set forth in the
Indenture the maximum principal amount (expressed as a multiple of $1,000)
of Notes that may be purchased out of an amount (the "Payment Amount")
equal to the product of such Excess Proceeds multiplied by a fraction, the
numerator of which is the outstanding principal amount of the Notes and the
denominator of which is the sum of the outstanding principal amount of the
Notes and such Pari Passu Indebtedness, if any (subject to proration in the
event such amount is less than the aggregate Offered Price (as defined in
clause (ii) below) of all Notes tendered) and, to the extent required by
any such Pari Passu Indebtedness and provided there is a permanent
reduction in the principal amount of such Pari Passu Indebtedness, the
Company shall make an offer to purchase such Pari Passu Indebtedness (a
"Pari Passu Offer") in an amount (the "Pari Passu Indebtedness Amount")
equal to the excess of the Excess Proceeds over the Payment Amount.
(ii) The offer price for the Notes shall be payable in cash in an
amount equal to 100% of the aggregate principal amount of the Notes
tendered pursuant to a Net Proceeds Offer, plus accrued and unpaid
interest, if any, to the date such Net Proceeds Offer is consummated (the
"Offered Price"), in accordance with the procedures set forth in the
Indenture. If the aggregate Offered Price of Notes validly tendered and not
withdrawn by Holders thereof exceeds the Payment Amount, Notes to be
purchased will be selected on a pro rata basis. To the extent that the
aggregate Offered Price of the Notes tendered pursuant to a Net Proceeds
Offer is less than the Payment Amount relating thereto or the aggregate
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amount of the Pari Passu Indebtedness that is purchased or repaid pursuant
to the Pari Passu Offer is less than the Pari Passu Indebtedness Amount
(such shortfall constituting a "Net Proceeds Deficiency"), the Company may
use such Net Proceeds Deficiency, or a portion thereof, for general
corporate purposes, subject to the limitations of the "Restricted Payments"
covenant.
(iii) Upon completion of such Net Proceeds Offer and Pari Passu Offer,
the amount of Excess Proceeds shall be reset to zero.
The Credit Facility prohibits the Company from purchasing any Notes from the Net
Cash Proceeds of Asset Sales. Any future credit agreements or other agreements
relating to Senior Indebtedness to which the Company becomes a party may contain
similar restrictions and provisions. In the event a Net Proceeds Offer occurs at
a time when the Company is prohibited from purchasing the Notes, the Company
could seek the consent of its lenders to the purchase or could attempt to
refinance the Senior Indebtedness that contains such prohibition. If the Company
does not obtain such a consent or repay such Senior Indebtedness, the Company
may remain prohibited from purchasing the Notes. In such case, the Company's
failure to purchase tendered Notes would constitute an Event of Default under
the Indenture which would, in turn, constitute a default under the Credit
Facility and possibly a default under other agreements relating to Senior
Indebtedness. In such circumstances, the subordination provisions in the
Indenture would likely restrict payments to Holders.
CERTAIN COVENANTS
Ownership of Capital Stock
The Indenture will provide that the Company (i) will not permit any
Restricted Subsidiary to issue any Capital Stock (other than to the Company or a
Wholly Owned Restricted Subsidiary) and (ii) will not permit any Person (other
than the Company or a Wholly Owned Restricted Subsidiary) to own any Capital
Stock of any Restricted Subsidiary, except, in each case, for (a) directors'
qualifying shares, (b) Capital Stock of a Restricted Subsidiary organized in a
foreign jurisdiction required to be issued to, or owned by, the government of
such foreign jurisdiction or individual or corporate citizens of such foreign
jurisdiction in order for such Restricted Subsidiary to transact business in
such foreign jurisdiction, (c) a sale of all or substantially all of the Capital
Stock of a Restricted Subsidiary effected in accordance with the "Asset Sales"
and "Restricted Payments" covenants, (d) the issuance of Capital Stock by a
Restricted Subsidiary to a Person other than the Company or a Restricted
Subsidiary made in accordance with the "Asset Sales" and "Restricted Payments"
covenants and (e) 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 the Restricted
Subsidiary; provided, however, that any Capital Stock retained by the Company or
a Restricted Subsidiary in the case of clauses (c), (d) or (e) shall be treated
as an Investment for purposes of the "Restricted Payments" covenant, if the
amount of such Capital Stock represents less than a majority of the Voting Stock
of such Restricted Subsidiary.
Restricted Payments
(i) The Indenture will provide that the Company will not, and will not
permit any Restricted Subsidiary to, directly or indirectly, take the following
actions:
(a) declare or pay any dividend or make any distribution on account of
the Company's Capital Stock (other than dividends or distributions payable
solely in shares of Qualified Capital Stock of the Company or in options,
warrants or other rights to purchase Qualified Capital Stock of the Company
or dividends or distributions payable to the Company or any Wholly Owned
Restricted Subsidiary);
(b) purchase, redeem or otherwise acquire or retire for value any
Capital Stock of the Company or any Subsidiary or other Affiliate of the
Company (other than Capital Stock owned by the Company or any Wholly Owned
Restricted Subsidiary) or any options, warrants or other rights to acquire
such Capital Stock;
(c) make any principal payment on, or repurchase, redeem, defease or
otherwise acquire or retire for value, prior to any scheduled principal
payment, scheduled sinking fund payment or maturity, any Pari
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Passu Indebtedness or Subordinated Indebtedness, except (1) pursuant to a
Pari Passu Offer or a Net Proceeds Deficiency pursuant to the "Asset Sales"
covenant described above or (2) upon a Change of Control to the extent
required by the indenture or other agreement or instrument pursuant to
which such Pari Passu Indebtedness or Subordinated Indebtedness was issued,
provided the Company is then in compliance with the "Change of Control"
covenant described above;
(d) declare or pay any dividend on, or make any distribution to the
holders of, any shares of Capital Stock of any Restricted Subsidiary (other
than to the Company or any of its Wholly Owned Restricted Subsidiaries) or
purchase, redeem or otherwise acquire or retire for value any Capital Stock
of any Restricted Subsidiary or any options, warrants or other rights to
acquire any such Capital Stock (other than with respect to any such Capital
Stock held by the Company or any Wholly Owned Restricted Subsidiary of the
Company); or
(e) make any Investment (other than any Permitted Investment);
(such payments or other actions described in (but not excluded from) clauses (a)
through (e) are collectively referred to as "Restricted Payments"), unless at
the time of and after giving effect to the proposed Restricted Payment (the
amount of any such Restricted Payment, if other than cash, shall be the amount
determined by the Board of Directors of the Company, whose determination shall
be conclusive and evidenced by a Board Resolution), (1) no Default or Event of
Default shall have occurred and be continuing, (2) the Company could incur $1.00
of additional Indebtedness (excluding Permitted Indebtedness) in accordance with
the covenant described under "-- Incurrence of Indebtedness," and (3) the
aggregate amount of all Restricted Payments declared or made after the date of
the Supplemental Indenture shall not exceed the sum (without duplication) of the
following:
(A) 50% of the aggregate Consolidated Net Income of the Company
accrued on a cumulative basis during the period beginning on the first day
of the month in which the Supplemental Indenture is signed and ending on
the last day of the Company's last fiscal quarter ending prior to 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 received after the date of the
Supplemental Indenture by the Company as capital contributions to the
Company (other than from any Restricted Subsidiary), plus
(C) the aggregate net cash proceeds received after the date of the
Supplemental Indenture by the Company from the issuance or sale (other than
to any of its Restricted Subsidiaries) of shares of Qualified Capital Stock
of the Company or any option, warrants or rights to purchase such shares of
Qualified Capital Stock of the Company, plus
(D) the aggregate net cash proceeds received after the date of the
Supplemental Indenture by the Company (other than from any of its
Restricted Subsidiaries) upon the exercise of any options, warrants or
rights to purchase shares of Qualified Capital Stock of the Company, plus
(E) the aggregate net cash proceeds received after the date of the
Supplemental Indenture by the Company from the issuance or sale (other than
to any of its Restricted Subsidiaries) of debt securities or shares of
Redeemable Capital Stock that have been converted into or exchanged for
Qualified Capital Stock of the Company, together with the aggregate cash
received by the Company at the time of such conversion or exchange, plus
(F) to the extent not otherwise included in the Company's Consolidated
Net Income, the net reduction in Investments in Unrestricted Subsidiaries
resulting from the payments of interest on Indebtedness, dividends,
repayments of loans or advances, or other transfers of assets, in each case
to the Company or a Restricted Subsidiary after the date of the
Supplemental Indenture from any Unrestricted Subsidiary or from the
redesignation of an Unrestricted Subsidiary (other than Patina or SOCO
International) as a Restricted Subsidiary (in an amount equal to the fair
market value of the net assets of such Unrestricted Subsidiary at the time
that such Unrestricted Subsidiary is designated a Restricted Subsidiary),
not to exceed in the case of such Unrestricted Subsidiary the total amount
of Investments
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(other than Permitted Investments) in such Unrestricted Subsidiary made by
the Company and its Restricted Subsidiaries in such Unrestricted Subsidiary
after the date of the Supplemental Indenture, plus
(G) to the extent not otherwise included in the Company's Consolidated
Net Income, an amount equal to (x) the aggregate net proceeds received by
the Company or any Restricted Subsidiary as a result of the sale (net of
all provisions for all taxes payable as a result of such sale) after the
date of the Supplemental Indenture of securities in or assets of Patina or
SOCO International or both or (y) the net reduction in Investments in
Unrestricted Subsidiaries resulting from the redesignation of Patina or
SOCO International as a Restricted Subsidiary (in an amount equal to the
fair market value of the net assets of Patina or SOCO International, as the
case may be, at the time such Unrestricted Subsidiary is designated a
Restricted Subsidiary), plus
(H) $25,000,000.
(ii) Notwithstanding paragraph (i) above, the Company and its Restricted
Subsidiaries may take the following actions so long as in the case of clauses
(b), (c), (d), (e) and (f) no Default or Event of Default shall have occurred
and be continuing:
(a) the payment of any dividend on any Capital Stock of the Company or
any Restricted Subsidiary within 60 days after the date of declaration
thereof, if at such declaration date such declaration complied with the
provisions of paragraph (i) above (and such payment shall be deemed to have
been paid on such date of declaration for purposes of any calculation
required by the provisions of paragraph (i) above);
(b) the payment of any dividend or the making of any distribution on
account of or the repurchase of the Company's Capital Stock payable solely
in shares of Capital Stock of either Patina or SOCO International
(including cash in lieu of fractional shares in an amount not to exceed the
aggregate proceeds from the sale of such fractional shares) provided that
Patina or SOCO International, as the case may be, is an Unrestricted
Subsidiary at the time of such distribution;
(c) the payment of dividends in an aggregate annual amount not in
excess of (A) $6,200,000 on any shares of the Company's 6% convertible
preferred stock, par value $.01 per share ("6% Convertible Preferred
Stock") of the Company outstanding on the date of the Supplemental
Indenture (and on shares of Common Stock into which the shares of 6%
Convertible Preferred Stock are converted) and (B) $8,500,000 on shares of
the Company's Common Stock, provided that (1) such dividends are paid
within 60 days of the date of declaration thereof and (2) on the date of
declaration and having given pro forma effect to the making of such payment
(x) the Company could incur $1.00 of additional Indebtedness (excluding
Permitted Indebtedness) in accordance with the covenant described under
"-- Incurrence of Indebtedness" and (y) the ratio of the Company's Adjusted
Consolidated Net Tangible Assets to total Indebtedness is equal to or
greater than 2.0 to 1.0;
(d) the repurchase, redemption or other acquisition or retirement of
any shares of any class of Capital 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 Restricted
Subsidiary) of shares of Qualified Capital Stock of the Company;
(e) the repurchase, redemption, repayment, defeasance or other
acquisition or retirement for value of any Pari Passu Indebtedness or
Subordinated Indebtedness (other than Redeemable Capital Stock) in exchange
for, or out of the aggregate net cash proceeds of, a substantially
concurrent issuance and sale (other than to a Restricted Subsidiary) of
shares of Qualified Capital Stock of the Company;
(f) the purchase, redemption, repayment, defeasance or other
acquisition or retirement for value of Pari Passu Indebtedness or
Subordinated Indebtedness in exchange for, or out of the aggregate net cash
proceeds of, a substantially concurrent incurrence (other than to a
Restricted Subsidiary) of Pari Passu Indebtedness or Subordinated
Indebtedness so long as (A) the principal amount of such new Indebtedness
does not exceed the principal amount (or, if such Pari Passu Indebtedness
or Subordinated Indebtedness being refinanced provides for an amount less
than the principal amount thereof to be due
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and payable upon a declaration of acceleration thereof, such lesser amount
as of the date of determination) of the Indebtedness being so purchased,
redeemed, repaid, defeased, acquired or retired, plus the amount of any
premium required to be paid in connection with such refinancing pursuant to
the terms of the Indebtedness refinanced or the amount of any premium
reasonably determined by the Company as necessary to accomplish such
refinancing plus the amount of expenses of the Company incurred in
connection with such refinancing, (B) such new Indebtedness is pari passu
with or subordinated to the Notes at least to the same extent as such
Indebtedness so purchased, redeemed, repaid, defeased, acquired or retired,
and (C) such new Indebtedness has an Average Life to Stated Maturity that
is longer than the Average Life to Stated Maturity of the Notes and such
new Indebtedness has a Stated Maturity for its final scheduled principal
payment that is at least 91 days later than the Stated Maturity for the
final scheduled principal payment of the Notes; and
(g) the redemption of the Convertible Subordinated Notes out of the
aggregate net cash proceeds of the Offering of the Notes.
The actions described in clauses (a), (c), (d) and (e) of this paragraph (ii)
shall be Restricted Payments that shall be permitted to be taken in accordance
with this paragraph (ii) but shall reduce the amount that would otherwise be
available for Restricted Payments under clause (3) of paragraph (i) (provided
that any dividend paid pursuant to clauses (a) and (c) of this paragraph (ii)
shall reduce the amount that would otherwise be available under clause (3) of
paragraph (i) when declared, but not when subsequently paid pursuant to such
clause (a) or (c), as the case may be), and the actions described in clauses
(b), (f) and (g) of this paragraph (ii) shall be Restricted Payments that shall
be permitted to be taken in accordance with this paragraph and shall not reduce
the amount that would otherwise be available for Restricted Payments under
clause (3) of paragraph (i). Further, the Company or any Restricted Subsidiary
may make a Restricted Payment, if at the time the Company or any Restricted
Subsidiary first incurred a commitment for such Restricted Payment such
Restricted Payment could have been made; provided that all commitments incurred
and outstanding shall be treated as if such commitments were Restricted Payments
expended by the Company or a Restricted Subsidiary at the time the commitments
were incurred, except that commitments incurred and outstanding which are
treated as a Restricted Payment expended by the Company or a Restricted
Subsidiary and which are terminated shall no longer be treated as a Restricted
Payment expended by the Company or a Restricted Subsidiary upon the termination
of such commitment for such purposes; and provided further, that at the time
such Restricted Payment is made no Default or Event of Default shall have
occurred and be continuing and the Company could incur $1.00 of additional
Indebtedness (excluding Permitted Indebtedness) in accordance with the
"Incurrence of Indebtedness" covenant.
Incurrence of Indebtedness
The Indenture will provide that the Company will not, and will not permit
any of its Restricted Subsidiaries to, create, incur, assume, guarantee or
otherwise become directly or indirectly liable for the payment of (collectively,
"incur") any Indebtedness (including any Acquired Indebtedness), other than
Permitted Indebtedness, unless (i) at the time of such event and after giving
effect thereto on a pro forma basis the Company's Consolidated Fixed Charge
Coverage Ratio for the four full fiscal quarters immediately preceding such
event, taken as one period, would have been at least equal to 2.5 to 1.0. (ii)
no Default or Event of Default shall have occurred and be continuing at the time
such additional Indebtedness is incurred or would occur as a consequence of the
incurrence of the additional Indebtedness.
Liens
The Indenture will provide that the Company will not, and will not permit
any Restricted Subsidiary to, directly or indirectly, create, incur, assume or
suffer to exist any Lien of any kind, except for Permitted Liens, upon any of
their respective assets or properties, whether now owned or acquired after the
date of the Supplemental Indenture, or any income or profits therefrom, to
secure any Pari Passu Indebtedness or Subordinated Indebtedness, unless prior to
or contemporaneously therewith the Notes are directly secured equally and
ratably, provided that (i) if such secured Indebtedness is Pari Passu
Indebtedness, the Lien securing such Pari Passu Indebtedness shall be
subordinate and junior to, or pari passu with, the Lien securing
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the Notes and (ii) if such secured Indebtedness is Subordinated Indebtedness,
the Lien securing such Subordinated Indebtedness shall be subordinate and junior
to the Lien securing the Notes at least to the same extent as such Subordinated
Indebtedness is subordinated to the Notes.
Limitation on Guarantees of Indebtedness by Restricted Subsidiaries
The Indenture will provide that the Company will not permit any Restricted
Subsidiary that is not a Subsidiary Guarantor to guarantee the payment of any
Indebtedness of the Company unless (a)(1) such Restricted Subsidiary
simultaneously executes and delivers a supplemental indenture to the Indenture
providing for a Subsidiary Guarantee of the Notes by such Restricted Subsidiary,
which Subsidiary Guarantee will be subordinated to Guarantor Senior Indebtedness
(but no other Indebtedness) to the same extent that the Notes are subordinated
to Senior Indebtedness and (2) with respect to any guarantee of Subordinated
Indebtedness by a Restricted Subsidiary, any such guarantee shall be
subordinated to such Restricted Subsidiary's Subsidiary Guarantee at least to
the same extent as such Subordinated Indebtedness is subordinated to the Notes;
(b) such Restricted Subsidiary waives and agrees not in any manner whatsoever to
claim or take the benefit or advantage of, any rights of reimbursement,
indemnity or subrogation or any other rights against the Company or any other
Restricted Subsidiary as a result of any payment by such Restricted Subsidiary
under its Subsidiary Guarantee until such time as the obligations guaranteed
thereby are paid in full; and (c) such Restricted Subsidiary shall deliver to
the Trustee an opinion of counsel to the effect that such Subsidiary Guarantee
has been duly executed and authorized and constitutes a valid, binding and
enforceable obligation of such Restricted Subsidiary, except insofar as
enforcement thereof may be limited by bankruptcy, insolvency or similar laws
(including, without limitation, all laws relating to fraudulent transfers) and
except insofar as enforcement thereof is subject to general principles of
equity; provided that this paragraph shall not be applicable to any guarantee by
any Restricted Subsidiary that (x) existed at the time such Person became a
Restricted Subsidiary of the Company and (y) was not incurred in connection
with, or in contemplation of, such Person becoming a Restricted Subsidiary of
the Company. Any Subsidiary Guarantee incurred by a Restricted Subsidiary shall
be deemed released upon the release or discharge of the guarantee which resulted
in the creation of such Subsidiary Guarantee of the Notes, except a discharge or
release by or as a result of payment under such guarantee.
Dividends and Other Payment Restrictions Affecting Restricted Subsidiaries
The Indenture will provide that the Company will not, and will not permit
any Restricted Subsidiary to, directly or indirectly, create or otherwise cause
or suffer to exist or become effective any consensual encumbrance or restriction
of any kind on the ability 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 to the Company or any other Restricted Subsidiary, (ii) pay any
Indebtedness owed to the Company or any other Restricted Subsidiary, (iii) make
loans or advances to the Company or any Restricted Subsidiary, (iv) transfer any
of its properties or assets to the Company or any other Restricted Subsidiary,
(v) grant liens or security interests on its properties or assets in favor of
the Holders or (vi) guarantee the Notes or any renewals or refinancings thereof,
except for such encumbrances or restrictions existing as of the date of the
Supplemental Indenture except in each instance for such encumbrances or
restrictions pursuant to (a) the Indenture, the Credit Facility or any other
agreement in effect as of the date of the Supplemental Indenture, (b) any
agreement or other instrument of a Person acquired by the Company or any
Restricted Subsidiary in existence at the time of such acquisition (but not
created in contemplation thereof), which encumbrance or restriction is not
applicable to any other Person, or the properties or assets of any other Person,
other than the Person, or the property or assets of the Person, so acquired, (c)
customary restrictions in leases and licenses relating to the property covered
thereby and entered into in the ordinary course of business or (d) any agreement
that extends, renews, refinances or replaces the agreements containing the
restrictions in the foregoing clauses (a) through (c), provided that the terms
and conditions of any such restrictions are not materially less favorable to the
Holders than those under or pursuant to the agreement evidencing the
Indebtedness so extended, renewed, refinanced or replaced, and except with
respect to clause (iv) only, (1) restrictions in the form of Liens which are not
prohibited as described in the "Liens" covenant and which contain customary
limitations on the transfer of
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collateral and (2) customary restrictions contained in asset sale agreements
limiting the transfer of such assets pending the closing of such sale.
Limitation on Layering Debt
The Indenture will provide that (i) the Company will not incur, or permit
to remain outstanding, any Indebtedness (including Acquired Indebtedness and
Permitted Indebtedness) other than the Notes, that is subordinated in right of
payment to any Senior Indebtedness, unless such Indebtedness is also pari passu
with, or subordinated in right of payment to, the Notes pursuant to
subordination provisions substantially similar to those contained in the
Indenture and (ii) the Company will not permit any Subsidiary Guarantor to
incur, or to permit to remain outstanding, any Indebtedness (including Acquired
Indebtedness and Permitted Indebtedness) other than such Subsidiary Guarantor's
Subsidiary Guarantee, that is subordinated in right of payment to any Guarantor
Senior Indebtedness unless such Indebtedness is also pari passu with, or
subordinated in right of payment to, such Subsidiary Guarantee pursuant to
subordination provisions substantially similar to those contained in the
Indenture.
Merger, Consolidation or Sale of Assets
The Indenture will provide that the Company will not, in any single
transaction or series of related transactions, consolidate or merge with or into
any other Person, or sell, assign, convey, transfer, lease or otherwise dispose
of all or substantially all of the properties and assets of the Company and its
Restricted Subsidiaries on a consolidated basis to any Person or group of
Affiliated Persons, and the Company will not permit any of its Restricted
Subsidiaries to enter into any such transaction or series of transactions if
such transaction or series of transaction, in the aggregate, would result in a
sale, assignment, conveyance, transfer, lease or other disposition of all or
substantially all of the properties and assets of the Company and its Restricted
Subsidiaries on a consolidated basis to any other Person or group of Affiliated
Persons, unless at the time and after giving effect thereto (i) either (a) if
the transaction is a merger or consolidation, the Company shall be the surviving
Person of such merger or consolidation, or (b) the Person (if other than the
Company) formed by such consolidation or into which the Company is merged or to
which the properties and assets of the Company or its Restricted Subsidiaries,
as the case may be, are sold, assigned, conveyed, transferred, leased or
otherwise disposed of (any such surviving Person or transferee Person being the
"Surviving Entity") shall be a corporation organized and existing under the laws
of the United States of America, any state thereof or the District of Columbia
and shall, in either case, expressly assume by a supplemental indenture to the
Indenture executed and delivered to the Trustee, in form satisfactory to the
Trustee, all the obligations of the Company under the Notes and the Indenture,
and, in each case, the Indenture shall remain in full force and effect; (ii)
immediately before and immediately after giving effect to such transaction or
series of transactions on a pro forma basis (and treating any Indebtedness not
previously an obligation of Company or any of its Restricted Subsidiaries in
connection with or as a result of such transaction as having been incurred at
the time of such transaction), no Default or Event of Default shall have
occurred and be continuing; (iii) except in the case of the consolidation or
merger of any Restricted Subsidiary with or into the Company, immediately after
giving effect to such transaction or transactions on a pro forma basis, the
Consolidated Net Worth of the Company (or the Surviving Entity if the Company is
not the continuing obligor under the Indenture) is at least equal to the
Consolidated Net Worth of the Company immediately before such transaction or
transactions; (iv) except in the case of the consolidation or merger of the
Company with or into a Wholly Owned Restricted Subsidiary or any Restricted
Subsidiary with or into the Company or any Wholly Owned Restricted Subsidiary,
immediately before and immediately after giving effect to such transaction or
transactions on a pro forma basis (on the assumption that the transaction or
transactions occurred on the first day of the period of four fiscal quarters
ending immediately prior to the consummation of such transaction or
transactions) the Company (or the Surviving Entity if the Company is not the
continuing obligor under the Indenture) could incur $1.00 of additional
Indebtedness (excluding Permitted Indebtedness) pursuant to the covenant
described under "-- Incurrence of Indebtedness"; (v) if any of the properties or
assets of the Company or any of its Restricted Subsidiaries would upon such
transaction or series of related transactions become subject to any Lien (other
than a Permitted Lien), the creation and imposition of such Lien shall have been
in compliance with the "Liens" covenant; (vi) if the Company is not the
continuing obligor under
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the Indenture, then any Subsidiary Guarantor, unless it is the Surviving Entity,
shall have by supplemental indenture to the Indenture confirmed its Subsidiary
Guarantee of the Notes shall apply to the Surviving Entity's obligations under
the Indenture and the Notes; and (vii) the Company (or the Surviving Entity if
the Company is not the continuing obligor under the Indenture) shall have
delivered to the Trustee, in form and substance reasonably satisfactory to the
trustee, (a) an Officers' Certificate stating that such consolidation, merger,
transfer, lease or other disposition and the supplemental indenture, if any, in
respect thereto comply with the requirements under the Indenture, and (b) an
Opinion of Counsel stating that the requirements of clause (i) of this paragraph
have been satisfied.
Upon any consolidation or merger or any sale, assignment, conveyance,
transfer, lease or other disposition of all or substantially all of the
properties and assets of the Company and its Restricted Subsidiaries on a
consolidated basis in accordance with the foregoing, in which the Company is not
the continuing corporation, the Surviving Entity shall succeed to, and be
substituted for, and may exercise every right and power of, the Company under
the Indenture with the same effect as if the Surviving Entity had been named as
the Company therein, and thereafter the Company, except in the case of a lease,
will be discharged from all obligations and covenants under the Indenture and
the Notes and may be dissolved and liquidated.
Transactions with Affiliates
The Indenture will provide that the Company will not, and will not permit
any of its Restricted Subsidiaries to, directly or indirectly, enter into or
suffer to exist any transaction or series of related transactions (including,
without limitation, the sale, purchase, exchange or lease of assets, property or
services) with any Affiliate of the Company (other than the Company or a
Restricted Subsidiary) unless (i) such transaction or series of related
transactions is on terms that are no less favorable to the Company or such
Restricted Subsidiary, as the case may be, than would be available in a
comparable transaction in arm's length dealings with an unrelated third party,
(ii) with respect to a transaction or series of related transactions involving
payments in excess of $1,000,000 in the aggregate, the Company delivers an
Officers' Certificate to the Trustee certifying that such transaction complies
with clause (i) above, (iii) with respect to a transaction or series of related
transactions involving payments in excess of $5,000,000 but less than
$15,000,000 in the aggregate, the Company delivers an Officers' Certificate to
the Trustee certifying that (a) such transaction or series of related
transactions complies with clause (i) above and (b) such transaction or series
of related transactions shall have been approved by a majority of the
independent directors of the Board of Directors of the Company and (iv) with
respect to a transaction or series of transactions involving payments of
$15,000,000 or more in the aggregate, the Company delivers an Officers'
Certificate to the Trustee certifying that (a) such transaction or series of
related transactions complies with clause (i) above; (b) such transaction or
series of related transactions shall have been approved by a majority of the
independent directors of the Board of Directors of the Company and (c) the
Company shall have received the written opinion of a firm of investment bankers
nationally recognized in the United States that such transaction or series of
transactions is fair, from a financial point of view, to the Company or such
Restricted Subsidiary; provided however, that the foregoing restriction shall
not apply to (1) loans or advances to officers, directors and employees of the
Company or any Restricted Subsidiary made in the ordinary course of business and
consistent with past practices of the Company and its Restricted Subsidiaries in
an aggregate amount not to exceed $3,000,000 outstanding at any one time, (2)
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 Affiliate, (3) the Company's employee compensation and other benefit
arrangements or (4) indemnities of officers and directors of the Company or any
Subsidiary consistent with such Person's charter and bylaws and applicable
statutory provisions.
Reports
The Indenture will require that the Company file on a timely basis with the
Securities and Exchange Commission ("Commission"), to the extent such filings
are accepted by the Commission and whether or not the Company has a class of
securities registered under the Securities Exchange Act of 1934, as amended
("Exchange Act"), the annual reports, quarterly reports and other documents that
the Company would be required to file if it were subject to Section 13 or 15 of
the Exchange Act. The Company will also be required
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(i) to file with the Trustee (with exhibits), and provide to each Holder of
Notes (without exhibits), without cost to such Holder, copies of such reports
and documents within 30 days after the date on which the Company files such
reports and documents with the Commission or the date on which the Company would
be required to file such reports and documents if the Company were so required
and (ii) if filing such reports and documents with the Commission is not
accepted by the Commission or is prohibited under the Exchange Act, to supply at
its cost copies of such reports and documents (including any exhibits thereto)
to any Holder of Notes, securities analyst or prospective investor promptly upon
written request.
Events of Default and Remedies
The Indenture will provide that each of the following constitutes an "Event
of Default:"
(i) default for 30 days in the payment when due of interest on the
Notes; or
(ii) default in the Payment when due of the principal of or premium,
if any, on the Notes, whether such payment is due at maturity, upon
redemption, upon repurchase pursuant to a Change of Control Offer or a Net
Proceeds Offer, upon acceleration or otherwise; or
(iii) default in the performance or breach of the provisions described
under the "Merger, Consolidation or Sale of Assets" covenant, the failure
to make or consummate a Change of Control Offer in accordance with the
provisions of the "Change of Control" covenant or the failure to make or
consummate a Net Proceeds Offer in accordance with the provisions of the
"Asset Sales" covenant; or
(iv) failure by the Company or any Subsidiary Guarantor to comply with
any other term, covenant or agreement contained in the Notes, any
Subsidiary Guarantee or the Indenture (other than a default specified in
(i), (ii) or (iii) above) for a period of 30 days after written notice of
such failure stating that it is a "notice of default" under the Indenture
and requiring the Company or such Subsidiary Guarantor, as the case may be,
to remedy the same shall have been given (a) to the Company by the Trustee
or (b) to the Company and the Trustee by the Holders of at least 25% in
aggregate principal amount of the Notes then outstanding; or
(v) the occurrence and continuation beyond any applicable grace period
of any default in the payment of the principal of or premium, if any, on or
interest on any Indebtedness of the Company (other than the Notes) or any
Restricted Subsidiary for money borrowed when due, or any other default
resulting in acceleration of any Indebtedness of the Company or any
Restricted Subsidiary for money borrowed, provided that the aggregate
principal amount of such Indebtedness shall exceed $10,000,000, and
provided, further, that if any such default is cured or waived or any such
acceleration rescinded, or such Indebtedness is repaid, within a period of
10 days from the continuation of such default beyond the applicable grace
period or the occurrence of such acceleration, as the case may be, such
Event of Default under the Indenture and any consequential acceleration of
the Notes shall be automatically rescinded, so long as such rescission does
not conflict with any judgment or decree; or
(vi) any Subsidiary Guarantee shall for any reason cease to be, or be
asserted by the Company or any Subsidiary Guarantor, as applicable, not to
be, in full force and effect, enforceable in accordance with its terms
(except pursuant to the release or termination of any such Subsidiary
Guarantee in accordance with the Indenture); or
(vii) final judgments or orders rendered against the Company or any
Restricted Subsidiary that are unsatisfied and that require the payment in
money, either individually or in an aggregate amount, that is more than
$10,000,000 over the coverage under applicable insurance policies and
either (a) commencement by any creditor of an enforcement proceeding upon
such judgment (other than a judgment that is stayed by reason of pending
appeal or otherwise) or (b) the occurrence of a 60-day period during which
a stay of such judgment or order, by reason of pending appeal or otherwise,
was not in effect; or
(viii) the entry of a decree or order by a court having jurisdiction
in the premises (A) for relief in respect of the Company or any Material
Subsidiary in an involuntary case or proceeding under any
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applicable federal or state bankruptcy, insolvency, reorganization or other
similar law or (B) adjudging the Company or any Material Subsidiary
bankrupt or insolvent, or approving a petition seeking reorganization,
arrangement, adjustment or composition of the Company or any Material
Subsidiary under any applicable federal or state law, or appointing under
any such law a custodian, receiver, liquidator, assignee, trustee,
sequestrator or other similar official of the Company or any Material
Subsidiary or of a substantial part of its consolidated assets, or ordering
the winding up or liquidation of its affairs, and the continuance of any
such decree or order for relief or any such other decree or order unstayed
and in effect for a period of 60 consecutive days; or
(ix) the commencement by the Company or any Material Subsidiary of a
voluntary case or proceeding under any applicable federal or state
bankruptcy, insolvency, reorganization or other similar law or any other
case or proceeding to be adjudicated a bankrupt or insolvent, or the
consent by the Company or any Material Subsidiary to the entry of a decree
or order for relief in respect thereof in an involuntary case or proceeding
under any applicable federal or state bankruptcy, insolvency,
reorganization or other similar law or to the commencement of any
bankruptcy or insolvency case or proceeding against it, or the filing by
the Company or any Material Subsidiary of a petition or consent seeking
reorganization or relief under any applicable federal or state law, or the
consent by it under any such law to the filing of any such petition or to
the appointment of or taking possession by a custodian, receiver,
liquidator, assignee, trustee or sequestrator (or other similar official)
of any of the Company or any Material Subsidiary or of any substantial part
of its consolidated assets, or the making by it of an assignment for the
benefit of creditors under any such law, or the admission by it in writing
of its inability to pay its debts generally as they become due or taking of
corporate action by the Company or any Material Subsidiary in furtherance
of any such action.
If any Event of Default (other than as specified in clause (viii) or (ix)
above) occurs and is continuing, the Trustee, by written notice to the Company,
or the Holders of at least 25% in aggregate principal amount of the Notes then
outstanding, by notice to the Trustee and the Company, may, and the Trustee upon
the request of the Holders of not less than 25% in aggregate principal amount of
the Notes then outstanding shall, declare the principal of, premium, if any, and
accrued interest on all of the Notes due and payable immediately, upon which
declaration all amounts payable in respect of the Notes shall be immediately due
and payable. If an Event of Default specified in clause (viii) or (ix) above
occurs and is continuing, then the principal of, premium, if any, and accrued
interest on all of the Notes shall automatically become and be immediately due
and payable without any declaration, notice or other act on the part of the
Trustee or any Holder of Notes.
After a declaration of acceleration under the Indenture, but before a
judgment or decree for payment of the money due has been obtained by the
Trustee, the Holders of a majority in aggregate principal amount of the
outstanding Notes, by written notice to the Company, the Subsidiary Guarantors
and the Trustee, may rescind such declaration if (i) the Company or any
Subsidiary Guarantor has paid or deposited with the Trustee a sum sufficient to
pay (a) all sums paid or advanced by the Trustee under the Indenture and the
reasonable compensation, expenses, disbursements and advances of the Trustee,
its agents and counsel, (b) all overdue interest on all Notes, (c) the principal
of (and premium, if any, on) any Notes which have become due otherwise than by
such declaration of acceleration and interest thereon at the rate borne by the
Notes, and (d) to the extent that payment of such interest is lawful, interest
upon overdue interest and overdue principal at the rate borne by the Notes
(without duplication of any amount paid or deposited pursuant to clause (b) or
(c)); (b) the rescission would not conflict with any judgment or decree of a
court of competent jurisdiction; and (iii) all Events of Default, other than the
nonpayment of principal of (and premium, if any, on) or interest on the Notes
that has become due solely by such declaration of acceleration, have been cured
or waived.
No Holder of any of the Notes will have any right to institute any
proceeding with respect to the Indenture or any remedy thereunder, unless such
Holder has notified the Trustee of a continuing Event of Default and the Holders
of at least 25% in aggregate principal amount of the outstanding Notes have made
written request, and offered reasonable indemnity, to the Trustee to institute
such proceeding as Trustee under the Notes and the Indenture, the Trustee has
failed to institute such proceeding within 60 days after receipt of such notice
and the Trustee, within such 60-day period, has not received directions
inconsistent with such written request by Holders of a majority in aggregate
principal amount of the outstanding Notes. Such
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limitations will not apply, however, to a suit instituted by a Holder of a Note
for the enforcement of the payment of the principal of (or premium, if any, on)
or interest on such Note on or after the respective due dates expressed in such
Note.
During the existence of an Event of Default, the Trustee will be required
to exercise such rights and powers vested in it under the Indenture and use the
same degree of care and skill in its exercise thereof as a prudent person would
exercise under the circumstances in the conduct of such person's own affairs.
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 not
be under any obligation to exercise any of its rights or powers under the
Indenture at the request or direction of any of the Holders of Notes unless such
Holders shall have offered to the Trustee reasonable security or indemnity.
Subject to certain provisions concerning the rights of the Trustee, the Holders
of 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 under the Indenture.
If a Default or an Event of Default occurs and is continuing and is
actually known to the Trustee, the Trustee shall mail to each Holder of Notes
notice of the Default or Event of Default within 60 days after the occurrence
thereof. Except in the case of a Default or an Event of Default in payment of
principal of (or premium, if any, on) or interest on any Notes, the Trustee may
withhold the notice to the Holders of Notes if the Trustee determines in good
faith that withholding the notice is in the interest of such Holders.
The Company is required to deliver to the Trustee annual and quarterly
statements regarding compliance with the Indenture, and the Company will also be
required, upon becoming aware of any Default or Event of Default, to deliver to
the Trustee a statement specifying such Default or Event of Default.
LEGAL DEFEASANCE AND COVENANT DEFEASANCE
The Company may, at its option and at any time, elect to have all of the
obligations of the Company and the Subsidiary Guarantors discharged with respect
to the outstanding Notes ("Legal Defeasance"). Such Legal Defeasance means that
the Company and the Subsidiary Guarantors shall be deemed to have paid and
discharged the entire Indebtedness represented by the outstanding Notes and to
have been discharged from all their other obligations with respect to such Notes
and the Subsidiary Guarantees, except for (i) the rights of Holders of
outstanding Notes to receive payment in respect of the principal of and premium,
if any, and interest on such Notes when such payments are due, (ii) the
Company's obligations to replace any temporary Notes, register the transfer or
exchange of any Notes, replace mutilated, destroyed, lost or stolen Notes and
maintain an office or agency for payments in respect of the Notes, (iii) the
rights, powers, trusts, duties and immunities of the Trustee, and (iv) the Legal
Defeasance provisions of the Indenture. In addition, the Company may, at its
option and at any time, elect to have the obligations of the Company and each
Subsidiary Guarantor released with respect to certain covenants that are
described in the Indenture, some of which are described under "-- Certain
Covenants" above, and thereafter any omission to comply with such obligations
shall not constitute a Default or an Event of Default with respect to the Notes
("Covenant Defeasance"). In the event Covenant Defeasance occurs, certain events
(not including nonpayment, bankruptcy, insolvency and reorganization events)
described under "Events of Default and Remedies" will no longer constitute an
Event of Default with respect to the Notes.
In order to exercise either Legal Defeasance or Covenant Defeasance, (i)
the Company or any Subsidiary Guarantor must irrevocably deposit with the
Trustee, in trust, for the benefit of the Holders of the Notes, cash in United
States dollars, U.S. Government Obligations (as defined in the Indenture), or a
combination thereof, in such amounts as will be sufficient, in the opinion of a
nationally recognized firm of independent public accountants, to pay the
principal of (and premium, if any, on) and interest on the outstanding Notes to
redemption or maturity; (ii) the Company shall have delivered to the Trustee an
Opinion of Counsel to the effect that the Holders of the outstanding Notes will
not recognize income, gain or loss for federal income tax purposes as a result
of such Legal Defeasance or Covenant Defeasance and will be subject to federal
income tax on the same amounts, in the same manner and at the same times as
would have been the case if such Legal Defeasance or Covenant Defeasance had not
occurred (in the case of Legal
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Defeasance, such opinion must refer to and be based upon a published ruling of
the Internal Revenue Service or a change in applicable federal income tax laws);
(iii) no Default or Event of Default shall have occurred and be continuing on
the date of such deposit or insofar as clauses (viii) and (ix) under the first
paragraph under "Events of Default and Remedies" are concerned, at any time
during the period ending on the 91st day after the date of deposit; (iv) such
Legal Defeasance or Covenant Defeasance shall not cause the Trustee to have a
conflicting interest under the Indenture or the Trust Indenture Act with respect
to any securities of the Company or any Subsidiary Guarantor; (v) such Legal
Defeasance or Covenant Defeasance shall not result in a breach or violation of,
or constitute a default under, any material agreement or instrument to which the
Company or any Subsidiary Guarantor is a party or by which it is bound, and (vi)
the Company shall have delivered to the Trustee an Officers' Certificate and an
Opinion of Counsel, which, taken together, state that all conditions precedent
under the Indenture to either Legal Defeasance or Covenant Defeasance, as the
case may be, have been complied with.
SATISFACTION AND DISCHARGE
The Indenture will be discharged and will cease to be of further effect
(except as to surviving rights of registration of transfer or exchange of the
Notes, as expressly provided for in the Indenture) as to all outstanding Notes
when (i) either (a) all the Notes theretofore authenticated and delivered
(except lost, stolen or destroyed Notes which have been replaced or paid and
Notes for whose payment money or certain United States governmental obligations
have theretofore been deposited in trust or segregated and held in trust by the
Company and thereafter repaid to the Company or discharged from such trust) have
been delivered to the Trustee for cancellation or (b) all Notes not theretofore
delivered to the Trustee for cancellation have become due and payable or will
become due and payable at their Stated Maturity within one year, or are to be
called for redemption within one year under arrangements satisfactory to the
Trustee for the serving of notice of redemption by the Trustee in the name, and
at the expense, of the Company, and the Company has irrevocably deposited or
caused to be deposited with the Trustee funds in an amount sufficient to pay and
discharge the entire indebtedness on the Notes not theretofore delivered to the
Trustee for cancellation, for principal of (and premium, if any, on) and
interest on the Notes to the date of deposit (in the case of Notes which have
become due and payable) or to the Stated Maturity or Redemption Date, as the
case may be, together with instructions from the Company irrevocably directing
the Trustee to apply such funds to the payment thereof at maturity or
redemption, as the case may be; (ii) the Company has paid all other sums then
due and payable under the Indenture by the Company; and (iii) the Company has
delivered to the Trustee an Officers' Certificate and an Opinion of Counsel,
which, taken together, state that all conditions precedent under the Indenture
relating to the satisfaction and discharge of the Indenture have been complied
with.
AMENDMENT, SUPPLEMENT AND WAIVER
Except as provided in the next two succeeding paragraphs, the Indenture or
the Notes may be amended or supplemented with the consent of the Holders of at
least a majority in principal amount of the Notes then outstanding (including
consents obtained in connection with a tender offer or exchange offer for
Notes), and any existing default or compliance with any provision of the
Indenture or the Notes may be waived with the consent of the Holders of a
majority in principal amount of the then outstanding Notes (including consents
obtained in connection with a tender offer or exchange offer for Notes).
Without the consent of each Holder affected, an amendment or waiver may not
(with respect to any Notes held by a nonconsenting Holder): (i) reduce the
principal amount of Notes whose Holders must consent to an amendment, supplement
or waiver, (ii) reduce the principal of or change the Stated Maturity of any
Note or alter the provisions with respect to the redemption of the Notes (other
than provisions relating to the covenants described above under the caption
"Repurchase at the Option of Holders"), (iii) reduce the rate of or change the
time for payment of interest on any Note, (iv) waive a Default or Event of
Default in the payment of principal of (or the premium, if any, on) or interest
on the Notes (except a rescission of acceleration of the Notes by the Holders of
at least a majority in aggregate principal amount of the Notes and a waiver of
the payment default that resulted from such acceleration), (v) make any Note
payable in money other than that stated in the Notes, (vi) make any change in
the provisions of the Indenture relating to waivers
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of past Defaults or the rights of Holders of Notes to receive payments of
principal of or premium, if any, or interest on the Notes, (vii) waive a
redemption payment with respect to any Note (other than a payment required by
one of the covenants described above under the caption "Repurchase at the Option
of Holders"), (viii) reduce the relative ranking of any Notes or Subsidiary
Guarantees or (ix) make any change in the foregoing amendment and waiver
provisions.
Notwithstanding the foregoing, without the consent of any Holder of Notes,
the Company, the Subsidiary Guarantors and the Trustee may amend or supplement
the Indenture or the Notes to cure any ambiguity, defect or inconsistency, to
add or release any Subsidiary Guarantor pursuant to the terms of the Indenture,
to provide for uncertificated Notes in addition to or in place of certificated
Notes, to provide for the assumption of the Company's obligations to Holders of
Notes in the case of a merger or consolidation, to make any change that would
provide any additional rights or benefits to the Holders of Notes or that does
not adversely affect the interests of any such Holder in any material respect,
or to comply with requirements of the Commission in order to effect or maintain
the qualification of the Indenture under the Trust Indenture Act.
CONCERNING THE TRUSTEE
Texas Commerce Bank National Association will serve as 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 or its Subsidiaries from time to time in the ordinary
course of business.
The Indenture (including the provisions of the Trust Indenture Act
incorporated by reference therein) will contain limitations on the rights of the
Trustee thereunder, should it become a creditor of the Company, to obtain
payment of claims in certain cases or to realize on certain property received by
it in respect of any such claims, as security or otherwise. The Indenture will
permit the Trustee to engage in other transactions; provided, however, if it
acquires any conflicting interest (as defined in the Trust Indenture Act) it
must eliminate such conflict or resign.
GOVERNING LAW
The Indenture, the Notes and the Subsidiary Guarantees will be governed by
the laws of the State of New York, without regard to the principles of conflicts
of law.
BOOK-ENTRY, DELIVERY AND FORM
The Notes will be issued in the form of a fully registered Global
Certificate. The Global Certificate will be deposited with, or on behalf of, The
Depository Trust Company, New York, New York (the "Depositary") and registered
in the name of the Depositary's nominee.
Except as set forth below, the Global Certificate may be transferred, in
whole and not in part, only to another nominee of the Depositary or to a
successor of the Depositary or its nominee.
The Depositary has advised the Company and the Underwriters as follows: It
is a limited-purpose trust company which was created to hold securities for its
participating organizations (the "Participants") and to facilitate the clearance
and settlement of transactions such securities between Participants through
electronic book-entry changes in accounts of its Participants. Participants
include securities brokers and dealers (including the Underwriters), banks,
trust companies, clearing corporations and certain other organizations. Access
to the Depositary'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
("Indirect Participants"). Persons who are not Participants may beneficially own
securities held by the Depositary only through Participants or indirect
Participants.
The Depositary has also advised that pursuant to procedures established by
it (i) upon the issuance by the Company of the Notes, the Depositary will credit
the accounts of Participants designated by the Underwriters with the principal
amount of the Notes purchased by the Underwriters, and (ii) ownership of
beneficial interests in the Global Certificate will be shown on, and the
transfer of that ownership will be
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effected only through, records maintained by the Depositary (with respect to
Participants' interests), the Participants and the Indirect Participants. The
laws of some states require that certain persons take physical delivery in
definitive form of securities which they own. Consequently, the ability to
transfer beneficial interests in the Global Certificate is limited to such
extent.
So long as a nominee of the Depositary is the registered owner of the
Global Certificate, such nominee will be considered the sole owner or holder of
the Notes for all purposes under the Indenture. Except as provided below, owners
of beneficial interests in the Global Certificate will not be entitled to have
Notes registered in their names, will not receive or be entitled to receive
physical delivery of Notes in definitive form and will not be considered the
owners or holders thereof under the Indenture.
Neither the Company, the Trustee, the paying agent, nor the Notes registrar
will have any responsibility or liability for any aspect of the records relating
to or payments made on account of beneficial ownership interests in the Global
Certificate, or for maintaining, supervising or reviewing any records relating
to such beneficial ownership interests.
Principal and interest payments on the Global Certificate registered in the
name of the Depositary's nominee will be made by the Company, either directly or
through a paying agent, to the Depositary's nominee as the registered owner of
the Global Certificate. Under the terms of the Indenture, the Company and the
Trustee will treat the persons in whose names the Notes are registered as the
owners of such Notes for the purpose of receiving payments of principal and
interest on such Notes and for all other purposes whatsoever. Therefore, neither
the Company, the Trustee nor any paying agent has any direct responsibility or
liability for the payment of principal or interest on the Notes to owners of
beneficial interests in the Global Certificate. The Depositary has advised the
Company and the Trustee that its present practice is, upon receipt of any
payment of principal or interest, to credit immediately the accounts of the
Participants with payment in amounts proportionate to their respective holdings
in principal amount of beneficial interests in the Global Certificate as shown
on the records of the Depositary. Payments by Participants and Indirect
Participants to owners of beneficial interests in the Global Certificate will be
governed by standing instructions and customary practices, as is now the case
with securities held for the accounts of customers in bearer form or registered
in "street name" and will be the responsibility of such Participants or Indirect
Participants.
As long as the Notes are represented by a Global Certificate, the
Depositary's nominee will be the holder of the Notes and therefore will be the
only entity that can exercise a right to repayment or repurchase of the Notes.
See "-- Repurchase at the Option of Holders -- Change of Control" and "-- Asset
Sales." Notice by Participants or Indirect Participants or by owners of
beneficial interests in a Global Certificate held through such Participants or
Indirect Participants of the exercise of the option to elect repayment of
beneficial interests in Notes represented by a Global Certificate must be
transmitted to the Depositary in accordance with its procedures on a form
required by the Depositary and provided to Participants. In order to ensure that
the Depositary's nominee will timely exercise a right to repayment with respect
to a particular Note, the beneficial owner of such Note must instruct the broker
or other Participant or Indirect Participant through which it holds an interest
in such Note to notify the Depositary of its desire to exercise a right to
repayment. Different firms have cut-off times for accepting instructions from
their customers and, accordingly, each beneficial owner should consult the
broker or other Participant or Indirect Participant through which it holds an
interest in a Note in order to ascertain the cut-off time by which such an
instruction must be given in order for timely notice to be delivered to the
Depositary. The Company will not be liable for any delay in delivery of notices
of the exercise of the option to elect repayment.
The Company will issue Notes in definitive form in exchange for the Global
Certificate if, and only if, either (1) the Depositary is at any time unwilling
or unable to continue as depositary and a successor depositary is not appointed
by the Company within 90 days, or (2) an Event of Default has occurred and is
continuing and the Notes registrar has received a request from the Depositary to
issue Notes in definitive form in lieu of all or a portion of the Global
Certificate. In either instance, an owner of a beneficial interest in the Global
Certificate will be entitled to have Notes equal in principal amount to such
beneficial interest registered in its name and will be entitled to physical
delivery of such Notes in definitive form. Notes so issued
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in definitive form will be issued in denominations of $1,000 and integral
multiples thereof and will be issued in registered form only, without coupons.
CERTAIN DEFINITIONS
Set forth below are certain defined terms used in the Indenture. Reference
is made to the Indenture for a full disclosure of all such terms, as well as any
other capitalized terms used herein for which no definition is provided.
"Acquired Indebtedness" means Indebtedness of a Person (a) assumed in
connection with an acquisition of properties or assets from such Person or (b)
outstanding at the time such Person becomes a Subsidiary of any other Person
(other than any Indebtedness incurred in connection with, or in contemplation
of, such acquisition or such Person becoming such a Subsidiary). Acquired
Indebtedness shall be deemed to be incurred on the date of the related
acquisition of properties or assets from any Person or the date the acquired
Person becomes a Subsidiary.
"Adjusted Consolidated Net Tangible Assets" means (without duplication), as
of the date of determination, (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 or federal
income taxes, with no less than 90% of such discounted future net revenues
estimated or audited by one or more nationally recognized firms of independent
petroleum engineers in a reserve report prepared as of the end of the Company's
most recently completed fiscal year, 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 the date of 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 the date of such year-end
reserve report 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 the date of
such year-end reserve report and (4) estimated oil and gas reserves attributable
to downward revisions of estimates of proved oil and gas reserves since the date
of such year-end reserve report 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 in the event that there is a Material Change as a
result of such acquisitions, dispositions or revisions, then 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 of the Company and its
Restricted Subsidiaries on a date no earlier than the date of the Company's
latest annual or quarterly financial statements and (d) the greater of (i) the
net book value on a date no earlier than the date of the Company's latest annual
or quarterly financial statements or (ii) 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 (other than a minority interest in a Subsidiary that is a
business trust or similar entity formed for the primary purpose of issuing
preferred securities the proceeds of which are loaned to the Company or a
Restricted Subsidiary), (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 on the schedules specified with
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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 revenue 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 on the schedules specified with
respect thereto. If the Company changes its method of accounting from the
successful efforts method to the full cost 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 successful efforts method of
accounting.
"Adjusted Net Assets" of a Subsidiary Guarantor at any date means the
amount by which the fair value of the properties and assets of such Subsidiary
Guarantor exceeds the total amount of liabilities, including, without
limitation, contingent liabilities (after giving effect to all other fixed and
contingent liabilities incurred or assumed on such date), but excluding
liabilities under its Subsidiary Guarantee, of such Subsidiary Guarantor at such
date.
"Affiliate" of any specified Person means (i) any other Person directly or
indirectly controlling or controlled by or under direct or indirect common
control with such specified Person or (ii) any other Person who is a director or
executive officer of (a) such specified Person or (b) any Person described in
the preceding clause (i). For the purposes of this definition, "control"
(including, with correlative meanings, the terms "controlling," "controlled by"
and "under common control with") as used with respect to any Person, shall mean
the possession, directly or indirectly, of the power to direct or cause the
direction of the management or policies of such Person, whether through the
ownership of voting securities, by agreement or otherwise, provided that
beneficial ownership of 10% or more of the Voting Stock of a Person shall be
deemed to be control.
"Asset Sale" means any sale, issuance, conveyance, transfer, lease or other
disposition to any Person other than the Company or any of its Restricted
Subsidiaries (including, without limitation, by way of merger or consolidation)
(collectively, for purposes of this definition, a "transfer"), directly or
indirectly, in one or a series of related transactions, of (i) any Capital Stock
of any Restricted Subsidiary held by the Company or any Restricted Subsidiary,
(ii) all or substantially all of the properties and assets of the Company or any
of its Restricted Subsidiaries or (iii) any other properties or assets of the
Company or any of its Restricted Subsidiaries (including Production Payments)
other than (a) a disposition of hydrocarbons or other mineral products (other
than Production Payments), inventory, accounts receivable, cash, Cash
Equivalents or other property in the ordinary course of business, (b) any lease,
abandonment, disposition, relinquishment or farm-out of any oil and gas property
in the ordinary course of business or (c) the liquidation of property or assets
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. For
the purposes of this definition, the term "Asset Sale" shall not include (i) any
transfer of properties or assets that is governed by, and made in accordance
with, the provisions described under "-- Merger, Consolidation or Sale of
Assets"; (ii) any transfer of properties or assets to an Unrestricted
Subsidiary, if permitted under the "Restricted Payments" covenant; (iii) any
transfer of the securities of or property or assets of Patina or SOCO
International; or (iv) any transfer, in one or a series of related Transactions,
of properties or assets having a fair market value of less than $2,000,000.
"Attributable Indebtedness" in respect of a Sale and Leaseback Transaction
means, at the time of determination, the present value (discounted at the rate
of interest implicit in such transaction, determined in accordance with GAAP) of
the obligation of the lessee for net rental payments during the remaining term
of the lease included in such Sale and Leaseback Transaction (including any
period for which such lease has been extended or may, at the option of the
lessor, be extended).
"Average Life" means, with respect to any Indebtedness, as 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,
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without limitation, 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.
"Capital Stock" means, with respect to any Person, any and all shares,
interests, participations, rights in or other equivalents in the equity
interests (however designated) in such Person, and any rights (other than debt
securities convertible into an equity interest), warrants or options exercisable
for, exchangeable for or convertible into such an equity interest in such
Person.
"Capitalized Lease Obligation" means any obligation to pay rent or other
amounts under a lease of (or other agreement conveying the right to use) any
property (whether real, personal or mixed) that is required to be classified and
accounted for as a capital lease obligation under GAAP, and, for the purpose of
the Indenture, the amount of such obligation at any date shall be the
capitalized amount thereof at such date, determined in accordance with GAAP.
"Cash Equivalents" means (i) any evidence of Indebtedness with a maturity
of 365 days or less issued or directly and fully guaranteed or insured by the
United States of America or any agency or instrumentality thereof (provided that
the full faith and credit of the United States of America is pledged in support
thereof); (ii) demand and time deposits and certificates of deposit or
acceptances with a maturity of 365 days or less of any financial institution
that is a member of the Federal Reserve System having combined capital and
surplus and undivided profits of not less than $500,000,000; (iii) commercial
paper with a maturity of 365 days or less issued by a corporation that is not an
Affiliate of the Company and is organized under the laws of any state of the
United States or the District of Columbia and rated at least A-1 by S&P or at
least P-1 by Moody's; (iv) repurchase obligations with a term of not more than
seven days for underlying securities of the types described in clause (i) above
entered into with any commercial bank meeting the specifications of clause (ii)
above; (v) overnight bank deposits and bankers' acceptances at any commercial
bank meeting the qualifications specified in clause (ii) above; (vi) deposits
available for withdrawal on demand with any commercial bank not meeting the
qualifications specified in clause (ii) above but which 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 are required to be made in such accounts in the ordinary course of
business, (b) such deposits do not at any one time exceed $5,000,000 in the
aggregate and (c) no funds so deposited remain on deposit in such bank for more
than 30 days; (vii) deposits available for withdrawal on demand with any
commercial bank not meeting the qualifications specified in clause (ii) above
but which is a lending bank under any of the Company's or any Restricted
Subsidiary's credit facilities, provided all such deposits do not exceed
$5,000,000 in the aggregate at any one time; and (viii) investments in money
market funds substantially all of whose assets comprise securities of the types
described in clauses (i) through (v).
"Change of Control" means the occurrence of any of the following events:
(i) any "person" or "group" (as such terms are used in Sections 13(d) and 14(d)
of the Exchange Act), other than the Permitted Holder, is or becomes the
"beneficial owner" (as defined in Rule 13d-3 under the Exchange Act), directly
or indirectly, of more than 50% of the total voting power of the outstanding
Voting Stock of the Company; (ii) the Company is merged with or into or
consolidated with another Person and, immediately after giving effect to the
merger or consolidation, (a) less than 50% of the total voting power of the
outstanding Voting Stock of the surviving or resulting Person is then
"beneficially owned" (within the meaning of Rule 13d-3 under the Exchange Act)
in the aggregate by the stockholders of the Company immediately prior to such
merger or consolidation, and (b) any "person" or "group" (as defined in Section
13(d) (3) or 14(d) (2) of the Exchange Act) has become the direct or indirect
"beneficial owner" (as defined in Rule 13d-3 under the Exchange Act) of more
than 50% of the total voting power of the Voting Stock of the surviving or
resulting Person; (iii) the Company, either individually or in conjunction with
one or more Restricted Subsidiaries, sells, assigns, conveys, transfers, leases
or otherwise disposes of, or one or more Restricted Subsidiaries sells, assigns,
conveys, transfers, leases or otherwise disposes of, all or substantially all of
the properties and assets of the Company and the Restricted Subsidiaries, taken
as a whole (either in one transaction or a series of related transactions),
including Capital Stock of the Restricted Subsidiaries, to any Person (other
than the Company or a Wholly Owned Restricted Subsidiary); (iv) during any
consecutive two-year period, individuals who at the beginning of such period
constituted the Board of Directors of the Company (together with any new
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directors whose election by such Board of Directors or whose nomination for
election by the stockholders 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 Board of
Directors of the Company then in office or (v) the liquidation or dissolution of
the Company.
"Common Stock" of any Person means Capital Stock of such Person that does
not rank 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.
"Consolidated Exploration Expenses" means, for any period, exploration
expenses of the Company and its Restricted Subsidiaries for such period as
determined on a consolidated basis in accordance with GAAP.
"Consolidated Fixed Charge Coverage Ratio" means, for any period, the ratio
of (i) the sum of Consolidated Net Income, Consolidated Interest Expense,
Consolidated Exploration Expenses, Consolidated Income Tax Expense and
Consolidated Non-cash Charges deducted in computing Consolidated Net Income, in
each case, for such period of the Company and its Restricted Subsidiaries on a
consolidated basis, all determined in accordance with GAAP, decreased (to the
extent included in determining Consolidated Net Income) by the sum of (a) the
amount of deferred revenues that are amortized during such period and are
attributable to reserves that are subject to Volumetric Production Payments and
(b) amounts recorded in accordance with GAAP as repayments of principal and
interest pursuant to Dollar-Denominated Production Payments, to (ii) the
Consolidated Interest Expense for such period; provided, however, that (a) the
Consolidated Fixed Charge Coverage Ratio shall be calculated on the assumption
that (1) the Indebtedness to be incurred (and all other Indebtedness incurred
after the first day of such period of four full fiscal quarters referred to in
the covenant described under "-- Certain Covenants -- Incurrence of
Indebtedness" through and including the date of determination) and (if
applicable) the application of the net proceeds therefrom (and from any other
such Indebtedness), including to refinance other Indebtedness, had been incurred
on the first day of such four-quarter period and, in the case of Acquired
Indebtedness, on the assumption that the related transaction (whether by means
of purchase, merger or otherwise) also had occurred on such date with the
appropriate adjustments with respect to such acquisition being included in such
pro forma calculation and (2) any acquisition or disposition by the Company or
any Restricted Subsidiary of any properties or assets outside the ordinary
course of business, or any repayment of any principal amount of any Indebtedness
of the Company or any Restricted Subsidiary prior to the Stated Maturity
thereof, in either case since the first day of such period of four full fiscal
quarters through and including the date of determination, had been consummated
on such first day of such four-quarter period, (b) in making such computation,
the Consolidated Interest Expense attributable to interest on any Indebtedness
required to be computed on a pro forma basis in accordance with the covenant
described under "-- Certain Covenants -- Incurrence of Indebtedness" and (1)
bearing a floating interest rate shall be computed as if the rate in effect on
the date of computation had been the applicable rate for the entire period and
(2) which was not outstanding during the period for which the computation is
being made but which bears, at the option of the Company, a fixed or floating
rate of interest, shall be computed by applying, at the option of the Company,
either the fixed or floating rate, (c) in making such computation, the
Consolidated Interest Expense attributable to interest on any Indebtedness under
a revolving credit facility required to be computed on a pro forma basis in
accordance with the covenant described under "-- Certain Covenants -- Incurrence
of Indebtedness" shall be computed based upon the average daily balance of such
Indebtedness during the applicable period, provided that such average daily
balance shall be reduced by the amount of any repayment of Indebtedness under a
revolving credit facility during the applicable period, which repayment
permanently reduced the commitments or amounts available to be reborrowed under
such facility, (d) notwithstanding clauses (b) and (c) of this proviso, interest
on Indebtedness determined on a fluctuating basis, to the extent such interest
is covered by agreements relating to Interest Rate Protection Obligations, shall
be deemed to have accrued at the rate per annum resulting after giving effect to
the operation of such agreements, (e) in making such calculation, Consolidated
Interest Expense shall exclude interest attributable to Dollar-Denominated
Production Payments, and (f) if after the first day of the period referred to in
clause (i) of this definition the Company has retired any Indebtedness out of
the net cash proceeds of the issue and sale of shares of Qualified Capital Stock
of the Company within
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30 days of such issuance and sale, Consolidated Interest Expense shall be
calculated on a pro forma basis as if such Indebtedness had been retired an the
first day of such period.
"Consolidated Income Tax Expense" means, for any period, the provision for
federal, state, local and foreign income taxes (including any state franchise
taxes accounted for as income taxes in accordance with GAAP) of the Company and
its Restricted Subsidiaries for such period as determined on a consolidated
basis in accordance with GAAP.
"Consolidated Interest Expense" means, for any period, without duplication,
(i) the sum of (a) the interest expense of the Company and its Restricted
Subsidiaries for such period as determined on a consolidated basis in accordance
with GAAP, including, without limitation, (1) any amortization of debt discount,
(2) the net cost under Interest Rate Protection Obligations (including any
amortization of discounts), (3) the interest portion of any deferred payment
obligation constituting Indebtedness, (4) all commissions, discounts and other
fees and charges owed with respect to letters of credit and bankers' acceptance
financing and (5) all accrued interest, in each case to the extent attributable
to such period, (b) to the extent any Indebtedness of any Person (other than the
Company or a Restricted Subsidiary) is guaranteed by the Company or any
Restricted Subsidiary, the aggregate amount of interest paid (to the extent not
accrued in a prior period) or accrued by such other Person during such period
attributable to any such Indebtedness, in each case to the extent attributable
to that period, (c) the aggregate amount of the interest component of
Capitalized Lease Obligations paid (to the extent not accrued in a prior
period), accrued and/or scheduled to be paid or accrued by the Company and its
Restricted Subsidiaries during such period as determined on a consolidated basis
in accordance with GAAP and (d) the aggregate amount of dividends paid (to the
extent not accrued in a prior period) or accrued on Redeemable Capital Stock or
6% Convertible Preferred Stock of the Company and its Restricted Subsidiaries,
to the extent such Redeemable Capital Stock or 6% Convertible Preferred Stock is
owned by Persons other than the Company or its Restricted Subsidiaries, and to
the extent such dividends are not paid in Common Stock, divided by one minus the
applicable actual combined federal, state, local and foreign income tax rate of
the Company and its Subsidiaries (expressed as a decimal), on a consolidated
basis, for the period preceding the date of the transaction giving rise to the
need to calculate Consolidated Interest Expense, less (ii) to the extent
included in (i) above, amortization of capitalized debt issuance costs of the
Company and its Restricted Subsidiaries during such period.
"Consolidated Net Income" means, for any period, the consolidated net
income (or loss) of the Company and its Restricted Subsidiaries for such period
as determined in accordance with GAAP, adjusted by excluding (i) net after-tax
extraordinary gains or losses (less all fees and expenses relating thereto),
(ii) net after-tax gains or losses (less all fees and expenses relating thereto)
attributable to Asset Sales, (iii) the net income (or net loss) of any Person
(other than the Company or any of its Restricted Subsidiaries), in which the
Company or any of its Restricted Subsidiaries has an ownership interest, except
to the extent of the amount of dividends or other distributions or interest on
indebtedness actually paid to the Company or any of its Restricted Subsidiaries
in cash by such other Person during such period (regardless of whether such cash
dividends, distributions or interest on indebtedness is attributable to net
income (or net loss) of such Person during such period or during any prior
period), (iv) net income (or net loss) of any Person combined with the Company
or any of its Restricted Subsidiaries on a "pooling of interests" basis
attributable to any period prior to the date of combination, (v) the net income
of any Restricted Subsidiary to the extent that the declaration or payment of
dividends or similar distributions by that Restricted Subsidiary is not at the
date of determination permitted, directly or indirectly, by operation of the
terms of its charter or any agreement, instrument, judgment, decree, order,
statute, rule or governmental regulation applicable to that Restricted
Subsidiary or its stockholders, (vi) income resulting from the transfers of
property or assets received by the Company or Restricted Subsidiaries from
Unrestricted Subsidiaries, (vii) the cumulative effect of a change in accounting
principles and (viii) any write-downs of non-current assets, provided, however,
that any ceiling limitation write-downs shall be treated as capitalized costs.
Notwithstanding the foregoing, any net gains or losses related to the sale or
disposition of any securities of or any properties or assets of Patina or SOCO
International shall be excluded from the determination of Consolidated Net
Income.
"Consolidated Net Worth" means, at any date, the consolidated stockholders'
equity of the Company and its Restricted Subsidiaries less the amount of such
stockholders' equity attributable to Redeemable Capital
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Stock or treasury stock of the Company and its Restricted Subsidiaries, as
determined in accordance with GAAP.
"Consolidated Non-cash Charges" means, for any period, the aggregate
depreciation, depletion, amortization and other non-cash expenses of the Company
and its Restricted Subsidiaries reducing Consolidated Net Income for such
period, determined on a consolidated basis in accordance with GAAP (excluding
any such non-cash charge which requires an accrual of or reserve for cash
charges for any future period).
"Credit Facility" means that certain Fifth Restated Credit Agreement, as
amended, among the Company, NationsBank of Texas, N.A., as agent, and the other
banks named therein, as the same may be amended, modified, supplemented,
extended, restated, replaced, renewed or refinanced from time to time.
"Default" means any event that is or with the passage of time or the giving
of notice or both would be an Event of Default.
"Dollar-Denominated Production Payments" means production payment
obligations recorded as liabilities in accordance with GAAP, together with all
undertakings and obligations in connection therewith.
"Event of Default" has the meaning set forth above under the caption
"Events of Default and Remedies."
"GAAP" means generally accepted accounting principles, consistently
applied, that are set forth in the opinions and pronouncements of the Accounting
Principles Board of the American Institute of Certified Public Accountants and
statements and pronouncements of the Financial Accounting Standards Board or in
such other statements by such other entity as may be approved by a significant
segment of the accounting profession of the United States of America, which are
effective on the date of the Supplemental Indenture.
The term "guarantee" means, as applied to any obligation, (i) a guarantee
(other than by endorsement of negotiable instruments or documents for collection
in the ordinary course of business), direct or indirect, in any manner, of any
part or all of such obligation and (ii) an agreement, direct or indirect,
contingent or otherwise, the practical effect of which is to assure in any way
the payment or performance (or payment of damages in the event of
nonperformance) of all or any part of such obligation, including, without
limiting the foregoing, the payment of amounts drawn down by letters of credit;
provided, however, that a guarantee by any Person shall not include a
contractual commitment by one Person to invest in another Person provided that
such Investment is otherwise permitted by the Indenture. When used as a verb,
"guarantee" shall have a corresponding meaning.
"Guarantor Senior Indebtedness" means the principal of (and premium, if
any, on) and interest on (including interest accruing after the filing of a
petition initiating any proceeding pursuant to any bankruptcy law) and other
amounts due on or in connection with (including any fees, premiums, expenses,
including costs of collection, and indemnities) any Indebtedness of a Subsidiary
Guarantor, whether outstanding on the date of the Supplemental Indenture or
thereafter created, incurred or assumed, 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 will be
pari passu with or subordinated in right of payment to its Subsidiary Guarantee.
Notwithstanding the foregoing, Guarantor Senior Indebtedness of a Subsidiary
Guarantor will not include (i) Indebtedness of such Subsidiary Guarantor
evidenced by its Subsidiary Guarantee, (ii) Indebtedness of such Subsidiary
Guarantor that is expressly pari passu with its Subsidiary Guarantee or is
expressly subordinated in right of payment to any Guarantor Senior Indebtedness
of such Subsidiary Guarantor or its Subsidiary Guarantee, (iii) Indebtedness of
such Subsidiary Guarantor to the extent incurred in violation of the "Incurrence
of Indebtedness" covenant of the Indenture, (iv) Indebtedness of such Subsidiary
Guarantor to the Company or any of the Company's other Subsidiaries or to any
Affiliate of the Company or any Subsidiary of such Affiliate and (v) any
Indebtedness which when incurred and without regard to any election under
Section 1111 (b) of the Federal Bankruptcy Code is without recourse to such
Subsidiary Guarantor.
"Holder" means a Person in whose name a Note is registered in the Note
Register.
"Indebtedness" means, with respect to any Person, without duplication, (i)
all liabilities of such Person for borrowed money or for the deferred purchase
price of property or services (excluding any trade accounts
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payable and other accrued current liabilities incurred in the ordinary course of
business), and all liabilities of such Person incurred in connection with any
letters of credit, bankers' acceptances or other similar credit transactions or
any agreement to purchase, redeem, exchange, convert or otherwise acquire for
value any Capital Stock of such Person or any warrants, rights or options to
acquire such Capital Stock outstanding on the date of the Supplemental Indenture
or thereafter, if, and to the extent, any of the foregoing would appear as a
liability upon a balance sheet of such Person prepared in accordance with GAAP,
(ii) all obligations of such Person evidenced by bonds, notes, debentures or
other similar instruments, if, and to the extent, any of the foregoing would
appear as a liability upon a balance sheet of such Person prepared in accordance
with GAAP, (iii) all Indebtedness of such Person created or arising under any
conditional sale or other title retention agreement with respect to property
acquired by such Person (even if the rights and remedies of the seller or lender
under such agreement in the event of default are limited to repossession or sale
of such property), but excluding trade accounts payable arising in the ordinary
course of business, (iv) all Capitalized Lease Obligations of such Person, (v)
the Attributable Indebtedness (in excess of any Capitalized Lease Obligations)
related to any Sale and Leaseback Transaction of such Person, (vi) all
Indebtedness referred to in the preceding clauses of other Persons and all
dividends of other Persons, the payment of which is secured by (or for which the
holder of such Indebtedness has an existing right to be secured by) any Lien
upon property (including, without limitation, accounts and contract rights)
owned by such Person, even though such Person has not assumed or become liable
for the payment of such Indebtedness (the amount of such obligation being deemed
to be the lesser of the value of such property or asset or the amount of the
obligation so secured), (vii) all guarantees by such Person of Indebtedness
referred to in this definition (including, with respect to any Production
Payment, any warranties or guaranties of production or payment by such Person
with respect to such Production Payment but excluding other contractual
obligations of such Person with respect to such Production Payment), (viii) all
Redeemable Capital Stock of such Person valued at the greater of its voluntary
or involuntary maximum fixed repurchase price plus accrued dividends, (ix) all
obligations of such Person under or in respect of currency exchange contracts,
oil or natural gas price hedging arrangements and Interest Rate Protection
Obligations, (x) Preferred Stock of any Restricted Subsidiary of the Company
(other than Preferred Stock held by the Company or any of its Restricted
Subsidiaries) and (xi) any amendment, supplement, modification, deferral,
renewal, extension or refunding of any liability of such Person of the types
referred to in clauses (i) through (x) above. For purposes hereof, the "maximum
fixed repurchase price" of any Redeemable Capital Stock which does not have a
fixed repurchase price shall be calculated in accordance with the terms of such
Redeemable Capital Stock as if such Redeemable Capital Stock were purchased on
any date on which Indebtedness shall be required to be determined pursuant to
the Indenture, and if such price is based upon, or measured by, the fair market
value of such Redeemable Capital Stock, such fair market value shall be
determined in good faith by the board of directors of the issuer of such
Redeemable Capital Stock; provided, however, that if such Redeemable Capital
Stock is not at the date of determination permitted or required to be
repurchased, the "maximum fixed repurchase price" shall be the book value of
such Redeemable Capital Stock. Subject to clause (vii) of the first sentence of
this definition, neither Dollar-Denominated Production Payments nor Volumetric
Production Payments shall be deemed to be Indebtedness.
"Interest Rate Protection Obligations" means the obligations of any Person
pursuant to any arrangement with any other Person whereby, directly or
indirectly, such Person is entitled to receive from time to time periodic
payments calculated by applying either a floating or a fixed rate of interest on
a stated notional amount in exchange for periodic payments made by such Person
calculated by applying a fixed or a floating rate of interest on the same
notional amount and shall include, without limitation, interest rate swaps,
caps, floors, collars and similar agreements or arrangements designed to protect
against or manage such Person's and any of its Subsidiaries' exposure to
fluctuations in interest rates.
"Investment" means, with respect to any Person, any direct or indirect
advance, loan, guarantee of Indebtedness or other extension of credit or capital
contribution to (by means of any transfer of cash or other property or assets to
others or any payment for property, assets or services for the account or use of
others), or any purchase or acquisition by such Person of any Capital Stock,
bonds, notes, debentures or other securities (including derivatives and
including, without limitation, any interests in any partnership or joint
venture) or evidences of Indebtedness issued by, any other Person. In addition,
(i) the fair market value of the net assets
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of any Restricted Subsidiary at the time that such Restricted Subsidiary is
designated an Unrestricted Subsidiary shall be deemed to be an "Investment" made
by the Company in such Unrestricted Subsidiary at such time and (ii) the fair
market value of Capital Stock retained by the Company or a Restricted Subsidiary
in connection with the sale or issuance of Capital Stock of a Restricted
Subsidiary in accordance with the "Ownership of Capital Stock" covenant that, as
a result of such transaction, is no longer a Restricted Subsidiary shall be
deemed to be an "Investment" made at the time of such transaction. "Investments"
shall exclude (a) extensions of trade credit under a joint operating agreement
or otherwise in the ordinary course of business, workers' compensation, utility,
lease and similar deposits and prepaid expenses made in the ordinary course of
business, (b) Interest Rate Protection Obligations entered into in the ordinary
course of business or as required by any Permitted Indebtedness or any other
Indebtedness incurred in compliance with the "Incurrence of Indebtedness"
covenant, but only to the extent that the stated aggregate notional amounts of
such Interest Rate Protection Obligations do not exceed 105% of the aggregate
principal amount of such Indebtedness to which such Interest Rate Protection
Obligations relate, (c) bonds, notes, debentures or other securities received in
compliance with the "Asset Sales" covenant, and (d) endorsements of negotiable
instruments and documents for collection in the ordinary course of business.
"Lien" means any mortgage, charge, pledge, lien (statutory or other),
security interest, hypothecation, assignment for security, claim, or preference
or priority or other encumbrance or similar agreement or preferential
arrangement of any kind or nature whatsoever (including, without limitation, any
agreement to give or grant a Lien or any lease, conditional sale or other title
retention agreement having substantially the same economic effect as any of the
foregoing) upon or with respect to any property of any kind. A Person shall be
deemed to own subject to a Lien any property which such Person has acquired or
holds subject to the interest of a vendor or lessor under any conditional sale
agreement, capital lease or other title retention agreement.
"Material Change" means an increase or decrease (excluding changes that
result solely from changes in prices) of more than 20% 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
that have been estimated by a nationally recognized firm of independent
petroleum engineers and on which a report or reports exist and (ii) any
disposition of properties held at the beginning of such quarter that have been
disposed of as provided in the "Assets Sales" covenant.
"Material Subsidiary" means, at any particular time, any Restricted
Subsidiary that, together with its Subsidiaries, (a) accounted for more than 5%
of the consolidated revenues of the Company and its Restricted Subsidiaries for
the most recently completed fiscal year of the Company, or (b) was the owner of
more than 5% of the consolidated assets of the Company and its Restricted
Subsidiaries at the end of such fiscal year, all as shown in the case of (a) and
(b) on the consolidated financial statements of the Company and its Restricted
Subsidiaries for such fiscal year.
"Maturity" means, with respect to any Note, the date on which any principal
of such Note becomes due and payable as provided therein or in the Indenture,
whether at the Stated Maturity with respect to such principal or by declaration
of acceleration, call for redemption or purchase or otherwise.
"Moody's" means Moody's Investors Service, Inc. and its successors.
"Net Cash Proceeds" means, with respect to any Asset Sale, the proceeds
thereof in the form of cash or Cash Equivalents including payments in respect of
deferred payment obligations when received in the form of cash or Cash
Equivalents (except to the extent that such obligations are financed or sold
with recourse to the Company or any Restricted Subsidiary), net of (i) brokerage
commissions and other fees and expenses (including fees and expenses of legal
counsel and investment banks) related to such Asset Sale, (ii) provisions for
all taxes payable as a result of such Asset Sale, (iii) amounts required to be
paid to any Person (other than the Company or any Restricted Subsidiary) owning
a beneficial interest in the assets subject to the Asset Sale and (iv)
appropriate amounts to be provided by the Company or any Restricted Subsidiary,
as the case may be, as a reserve required in accordance with GAAP consistently
applied against any liabilities associated with
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such Asset Sale and retained by the Company or any Restricted Subsidiary, as the
case may be, after such Asset Sale, including, without limitation, pension and
other post-employment benefit liabilities, liabilities related to environmental
matters and liabilities under any indemnification obligations associated with
such Asset Sale, all as reflected in an Officers' Certificate delivered to the
Trustee; provided, however, that any amounts remaining after adjustments,
revaluations or liquidations of such reserves shall constitute Net Cash
Proceeds.
"Net Working Capital" means (i) all current assets of the Company and its
Restricted Subsidiaries, minus (ii) all current liabilities of the Company and
its Restricted Subsidiaries, except current liabilities included in
Indebtedness, in each case as set forth in financial statements of the Company
prepared in accordance with GAAP.
"Non-payment Event of Default" means any event (other than a Payment Event
of Default), the occurrence of which (with or without notice or the passage of
time) entitles one or more Persons to accelerate the maturity of any Specified
Senior Indebtedness.
"Non-Recourse Indebtedness" means Indebtedness or that portion of
Indebtedness of the Company or a Restricted Subsidiary incurred in connection
with the acquisition by the Company or a Restricted Subsidiary of any property
or assets and as to which (a) the holders of such Indebtedness agree that they
will look solely to the property or assets so acquired and securing such
Indebtedness for payment on or in respect of such Indebtedness and (b) no
default with respect to such Indebtedness would permit (after notice or passage
of time or both), according to the terms thereof, any holder of any Indebtedness
of the Company or a Restricted Subsidiary to declare a default on such
Indebtedness or cause the payment thereof to be accelerated or payable prior to
its stated maturity.
"Note Register" means the register maintained by or for the Company in
which the Company shall provide for the registration of the Notes and of
transfer of the Notes.
"Oil and Gas Business" means (i) the acquisition, exploration, development,
operation and disposition of interests in oil, gas and other hydrocarbon
properties, (ii) the gathering, marketing, treating, processing, storage,
selling and transporting of any production from such interests or properties,
(iii) any business relating to or arising from exploration for or development,
production, treatment, processing, storage, transportation or marketing of oil,
gas, hydrocarbons and other minerals and products produced in association
therewith and (iv) any activity necessary, appropriate or incidental to the
activities described in the foregoing clauses (i) through (iii) of this
definition.
"Pari Passu Indebtedness" means any Indebtedness of the Company that is
pari passu in right of payment to the Notes.
"Payment Event of Default" means any default in the payment or required
prepayment of principal of (or premium, if any, on) or interest on any Specified
Senior Indebtedness when due (whether at final maturity, upon scheduled
installment, upon acceleration or otherwise).
"Permitted Designees" means (i) trusts for the benefit of the Permitted
Holder and (ii) in the event of death or incompetence of the Permitted Holder,
his estate, heirs, executor, administrator, committee or other personal
representative, provided that if any such estate, heir, executor, administrator,
committee or other personal representative acquires, subsequent to the death or
incapacity of the Permitted Holder, any additional shares of Voting Stock of the
Company, such person will cease to be a Permitted Designee.
"Permitted Holder" means John C. Snyder and his Permitted Designees.
"Permitted Indebtedness" means any of the following:
(i) Indebtedness under the Credit Facility in an aggregate principal
amount at any one time outstanding not to exceed the greater of (a)
$250,000,000 and (b) an amount equal to the sum of (1) $100,000,000 and (2)
15% of Adjusted Consolidated Net Tangible Assets, less any amounts applied
to repay or prepay permanently any such Indebtedness in accordance with the
"Asset Sales" covenant, including any guarantee of any such Indebtedness
(including by any Subsidiary) and any fees, premiums,
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expenses (including costs of collection), indemnities and other amounts
payable in connection with such Indebtedness;
(ii) Indebtedness under the Notes and the Subsidiary Guarantees;
(iii) Indebtedness outstanding on the date of the Supplemental
Indenture (and not repaid or defeased with the proceeds of the offering of
the Notes);
(iv) obligations of the Company or a Restricted Subsidiary pursuant to
Interest Rate Protection Obligations, but only to the extent that the
stated aggregate notional amounts of such obligations do not exceed 105% of
the aggregate principal amount of the Indebtedness covered by such Interest
Rate Protection Obligations; obligations under currency exchange contracts
entered into in the ordinary course of business; and hedging arrangements
that the Company or a Restricted Subsidiary enters into in the ordinary
course of business for the purpose of protecting its production against
fluctuations in oil or natural gas prices;
(v) Indebtedness of the Company to a Wholly Owned Restricted
Subsidiary and Indebtedness of a Restricted Subsidiary to the Company or a
Wholly Owned Restricted Subsidiary; provided, however, that upon any
subsequent issuance or transfer of any Capital Stock or any other event
which results in any such Wholly Owned Restricted Subsidiary ceasing to be
a Wholly Owned Restricted Subsidiary or any other subsequent transfer of
any such Indebtedness (except to the Company or a Wholly Owned Restricted
Subsidiary), such Indebtedness shall be deemed, in each case, to be
incurred and shall be treated as an incurrence for purposes of the
"Incurrence of Indebtedness" covenant at the time the Wholly Owned
Restricted Subsidiary in question ceased to be a Wholly Owned Restricted
Subsidiary;
(vi) in-kind obligations relating to net gas balancing positions
arising in the ordinary course of business and consistent with past
practice;
(vii) Indebtedness in respect of bid, performance or surety bonds
issued for the account of the Company or any Restricted Subsidiary in the
ordinary course of business, including guaranties and letters of credit
supporting such bid, performance or surety obligations (in each case other
than for an obligation for money borrowed);
(viii) any guarantee of Senior Indebtedness or Guarantor Senior
Indebtedness, incurred in compliance with the "Incurrence of Indebtedness"
covenant, by a Restricted Subsidiary or the Company;
(ix) any renewals, substitutions, refinancings or replacements (each,
for purposes of this clause, a "refinancing") by the Company or a
Restricted Subsidiary of any Indebtedness incurred pursuant to clause (ii)
or (iii) of this definition, including any successive refinancings by the
Company or such Restricted Subsidiary, so long as (a) any such new
Indebtedness shall be in a principal amount that does not exceed the
principal amount (or, if such Indebtedness being refinanced 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) so refinanced plus the amount of any premium required to be
paid in connection with such refinancing pursuant to the terms of the
Indebtedness refinanced or the amount of any premium reasonably determined
by the Company or such Restricted Subsidiary as necessary to accomplish
such refinancing, plus the amount of expenses of the Company or such
Restricted Subsidiary incurred in connection with such refinancing, and (b)
in the case of any refinancing of Indebtedness of the Company that is not
Senior Indebtedness, such new Indebtedness is either pari passu with the
Notes or subordinated to the Notes at least to the same extent as the
Indebtedness being refinanced and (c) such new Indebtedness has an Average
Life equal to or longer than the Average Life of the Indebtedness being
refinanced and a final Stated Maturity equal to or later than the final
Stated Maturity of the Indebtedness being refinanced;
(x) Non-Recourse Indebtedness; and
(xi) any additional Indebtedness in an aggregate principal amount not
in excess of $25,000,000 at any one time outstanding.
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<PAGE> 82
"Permitted Investments" means any of the following: (i) Investments in Cash
Equivalents; (ii) Investments in the Company or any of its Restricted
Subsidiaries; (iii) Investments in an amount not to exceed $10,000,000 at any
one time outstanding; (iv) Investments by the Company or any of its Restricted
Subsidiaries in another Person, if as a result of such Investment (A) such other
Person becomes a Restricted Subsidiary or (B) such other Person is merged or
consolidated with or into, or transfers or conveys all or substantially all of
its properties and Assets to, the Company or a Restricted Subsidiary; (v)
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 exploiting, exploring for, acquiring, developing, processing,
gathering, marketing or transporting oil and gas through agreements,
transactions, interests or arrangements which permit a Person 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, without limitation, (a)
ownership interests in oil and gas properties or gathering systems and (b)
Investments and expenditures in the form of or pursuant to operating agreements,
processing agreements, farm-in agreements, farm-out 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), subscription
agreements, stock purchase agreements and other similar agreements with third
parties (including Unrestricted Subsidiaries); (vi) entry into any hedging
arrangements in the ordinary course of business for the purpose of protecting
the Company's or any Restricted Subsidiary's production against fluctuations in
oil or natural gas prices; (vii) entry into any currency exchange contract in
the ordinary course of business; and (viii) Investments in stock, obligations or
securities received in settlement of debts owing to the Company or a Restricted
Subsidiary as a result of bankruptcy or insolvency proceedings or upon the
foreclosure, perfection or enforcement of any Lien in favor of the Company or a
Restricted Subsidiary, in each case as to debt owing to the Company or a
Restricted Subsidiary that arose in the ordinary course of business of the
Company or any such Restricted Subsidiary.
"Permitted Junior Securities" means any equity securities or subordinated
debt securities of the Company or any successor obligor with respect to the
Senior Indebtedness provided for by a plan of reorganization or readjustment
that, in the case of any such subordinated debt securities, are subordinated in
right of payment to all Senior Indebtedness that may at the time be outstanding
to substantially the same degree as, or to a greater extent than, the Notes are
so subordinated as provided in the Indenture.
"Permitted Liens" means the following types of Liens:
(a) Liens existing as of the date the Notes are first issued (except
to the extent such Liens secure Indebtedness that is repaid or defeased
with proceeds of the offering of the Notes), and any renewal, extension or
refinancing of any such Lien provided that thereafter such Lien extends
only to the properties that were subject to such Lien prior to the renewal,
extension or refinancing thereof;
(b) Liens securing the Notes or the Subsidiary Guaranties; and
(c) Liens in favor of the Company.
"Person" means any individual, corporation, limited liability company,
partnership, joint venture, association, joint stock company, trust,
unincorporated organization or government or any agency or political subdivision
thereof.
"Preferred Stock" means, with respect to any Person, any and all shares,
interests, participations or other equivalents (however designated) of such
Person's preferred or preference stock, whether now outstanding or issued after
the date of the Supplemental Indenture, including, without limitation, all
classes and series of preferred or preference stock of such Person.
"Production Payments" means, collectively, Dollar-Denominated Production
Payments and Volumetric Production Payments.
"Public Equity Offering" means an underwritten public offering for cash by
the Company of its Qualified Capital Stock pursuant to a registration statement
that has been declared effective by the Commission (other
S-82
<PAGE> 83
than a registration statement on Form S-8 or any successor form or otherwise
relating to equity securities issuable under any employee benefit plan of the
Company).
"Qualified Capital Stock" of any Person means any and all Capital Stock of
such Person other than Redeemable Capital Stock.
"Redeemable Capital Stock" means any Capital Stock that, either by its
terms, by the terms of any security into which it is convertible or exchangeable
or by contract or otherwise, is, or upon the happening of an event or passage of
time would be, required to be redeemed prior to the final Stated Maturity of the
Notes or is redeemable at the option of the holder thereof at any time prior to
such final Stated Maturity, or is convertible into or exchangeable for debt
securities at any time prior to such final Stated Maturity.
"Restricted Subsidiary" means any Subsidiary of the Company, whether
existing on or after the date of the Supplemental Indenture, unless such
Subsidiary of the Company is an Unrestricted Subsidiary or is designated as an
Unrestricted Subsidiary pursuant to the terms of the Indenture.
"S&P" means Standard & Poor's Ratings Service, a division of McGraw-Hill,
Inc., and its successors.
"Sale and Leaseback Transaction" means, with respect to any Person, any
direct or indirect arrangement pursuant to which properties or assets are sold
or transferred by such Person or a Subsidiary of such Person and are thereafter
leased back from the purchaser or transferee thereof by such Person or one of
its Subsidiaries.
"Senior Indebtedness" means the principal of (and premium, if any, on) and
interest on (including interest accruing after the filing of a petition
initiating any proceeding pursuant to any bankruptcy law) and other amounts due
on or in connection with (including any fees, premiums, expenses, including
costs of collection, and indemnities) any Indebtedness of the Company, whether
outstanding on the date of the Indenture or thereafter created, incurred or
assumed, 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 will be pari passu with or
subordinated in right of payment to the Notes. Notwithstanding the foregoing,
"Senior Indebtedness" will not include (i) Indebtedness evidenced by the Notes,
(ii) Indebtedness of the Company that is Pari Passu Indebtedness or is expressly
subordinated in right of payment to any other Indebtedness of the Company, (iii)
Indebtedness that is represented by Redeemable Capital Stock, (iv) Indebtedness
of the Company to the extent incurred in violation of the covenant described
under "-- Covenants -- Incurrence of Indebtedness," (v) Indebtedness of the
Company to any Subsidiary of the Company or any other Affiliate of the Company
or any subsidiary of such Affiliate and (vi) Indebtedness which when incurred
and without regard to any election under Section 1111(b) of the Federal
Bankruptcy Code is without recourse to the Company.
"Specified Senior Indebtedness" means (i) all Senior Indebtedness of the
Company in respect of the Credit Facility and any renewals, amendments,
extensions, supplements, modifications, deferrals, refinancings, or replacements
(each, for purpose of this definition, a "refinancing") thereof by the Company,
including any successive refinancings thereof by the Company and (ii) any other
Senior Indebtedness and any refinancings thereof by the Company having a
principal amount of at least $10,000,000 as of the date of determination and
provided that the agreements, indentures or other instruments evidencing such
Senior Indebtedness or pursuant to which such Senior Indebtedness was issued
specifically designates such Senior Indebtedness as "Specified Senior
Indebtedness" for purposes of the Indenture. For purposes of this definition, a
refinancing of any Specified Senior Indebtedness shall be treated as a Specified
Senior Indebtedness only if the Indebtedness issued in such refinancing ranks or
would rank pari passu with the Specified Senior Indebtedness refinanced and only
if Indebtedness issued in such refinancing is permitted by the covenant
described under "-- Covenants -- Incurrence of Indebtedness."
"Stated Maturity" means, when used with respect to any Note or any
installment of interest thereon, the date specified in such Note as the fixed
date on which the principal of such Note or such installment of interest is due
and payable, and, when used with respect to any other Indebtedness or any
installment of interest thereon, means the date specified in the instrument
evidencing or governing such Indebtedness as the fixed date on which the
principal of such Indebtedness or such installment of interest is due and
payable.
S-83
<PAGE> 84
"Subordinated Indebtedness" means Indebtedness of the Company which is
expressly subordinated in right of payment to the Notes.
"Subsidiary" means, with respect to any Person, (i) a corporation a
majority of whose Voting Stock is at the time, directly or indirectly, owned by
such Person, by one or more Subsidiaries of such Person or by such Person and
one or more Subsidiaries thereof or (ii) any other Person (other than a
corporation), including, without limitation, a joint venture, in which such
Person, one or more Subsidiaries thereof or such Person and one or more
Subsidiaries thereof, directly or indirectly, at the date of determination
thereof, have at least majority ownership interest entitled to vote in the
election of directors, managers or trustees thereof (or other Persons performing
similar functions).
"Subsidiary Guarantee" means any guarantee of the Notes by any Subsidiary
Guarantor in accordance with the provisions set forth in "-- Senior Subordinated
Guarantees of Notes."
"Subsidiary Guarantor" means (i) initially the several Restricted
Subsidiaries named in the Indenture as a party thereto, (ii) each of the other
Restricted Subsidiaries, if any, executing a supplemental indenture in
compliance with the provisions described under "-- Limitation on Guarantees of
Indebtedness by Restricted Subsidiaries" and (iii) any Person that becomes a
successor guarantor of the Notes in compliance with the provisions described
under "-- Senior Subordinated Guarantees of Notes."
"Unrestricted Subsidiary" means (i) any Subsidiary of the Company that at
the time of determination is designated an Unrestricted Subsidiary by the Board
of Directors of the Company as provided below and (ii) any Subsidiary of an
Unrestricted Subsidiary. The Board of Directors of the Company may designate any
Subsidiary of the Company as an Unrestricted Subsidiary so long as (a) neither
the Company nor any Restricted Subsidiary is directly or indirectly liable
pursuant to the terms of any Indebtedness of such Subsidiary; (b) no default
with respect to any Indebtedness of such Subsidiary would permit (upon notice,
lapse of time or otherwise) any holder of any other Indebtedness of the Company
or any Restricted Subsidiary to declare a default on such other Indebtedness or
cause the payment thereof to be accelerated or payable prior to its Stated
Maturity; (c) the Company certifies to the Trustee that such designation
complies with the "Restricted Payments" covenant; and (d) such designation shall
not result in the creation or imposition of any Lien on any of the properties or
assets of the Company or any Restricted Subsidiary (other than any Permitted
Lien or any Lien the creation or imposition of which shall have been in
compliance with the "Liens" covenant); provided, however, that with respect to
clause (a), the Company or a Restricted Subsidiary may be liable for
Indebtedness of an Unrestricted Subsidiary if (x) such liability constituted a
Permitted Investment or a Restricted Payment permitted by the "Restricted
Payments" covenant, in each case at the time of incurrence, or (y) the liability
would be a Permitted Investment at the time of designation of such Subsidiary as
an Unrestricted Subsidiary. Any such designation by the Board of Directors of
the Company shall be evidenced to the Trustee by filing a Board Resolution with
the Trustee giving effect to such designation. The Board of Directors of the
Company may designate any Unrestricted Subsidiary as a Restricted Subsidiary if,
immediately after giving effect to such designation, (i) no Default or Event of
Default shall have occurred and be continuing, (ii) the Company could incur
$1.00 of additional Indebtedness (other than Permitted Indebtedness) under the
"Incurrence of Indebtedness" covenant and (iii) if any of the properties or
assets of the Company or any of its Restricted Subsidiaries would upon such
designation become subject to any Lien (other than a Permitted Lien), the
creation or imposition of such Lien shall have been in compliance with the
"Liens" covenant.
"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" means any class or classes of Capital Stock pursuant to
which the holders thereof have the general voting power under ordinary
circumstances to elect at least a majority of the board of directors, managers
or trustees of any Person (irrespective of whether or not, at the time, stock of
any other class or classes shall have, or might have, voting power by reason of
the happening of any contingency).
"Wholly Owned Restricted Subsidiary" means any Restricted Subsidiary to the
extent (i) all of the Capital Stock or other ownership interests in such
Restricted Subsidiary, other than any directors' qualifying
S-84
<PAGE> 85
shares mandated by applicable law, is owned directly or indirectly by the
Company or (ii) such Restricted Subsidiary is organized in a foreign
jurisdiction and is required by the applicable laws and regulations of such
foreign jurisdiction to be partially owned by the government of such foreign
jurisdiction or individual or corporate citizens of such foreign jurisdiction in
order for such Restricted Subsidiary to transact business in such foreign
jurisdiction, provided that the Company, directly or indirectly, owns the
remaining Capital Stock or ownership interest in such Restricted Subsidiary and,
by contract or otherwise, controls the management and business of such
Restricted Subsidiary and derives the economic benefits of ownership of such
Restricted Subsidiary to substantially the same extent as if such Restricted
Subsidiary were a wholly owned Subsidiary.
S-85
<PAGE> 86
DESCRIPTION OF THE CREDIT FACILITY
The Company is party to a credit agreement with NationsBank of Texas, N.
A., as agent, and the other banks specified therein (the "Credit Facility"). The
Credit Facility provides for a revolving line of credit, with aggregate
borrowings thereunder limited to the lesser of $500.0 million (the
"Commitment"), which is divided into a $400.0 million long-term portion
("Facility A") and a $100.0 million short-term portion ("Facility B"), and the
Total Borrowing Base (as therein defined). The Total Borrowing Base, which
generally is determined semi-annually and which is based in part on the value
assigned at each Determination Date (as therein defined) to the Company's oil
and gas reserves and related assets, was $140.0 million at March 31, 1997, with
$90.0 million allocated to Facility A and $50.0 million allocated to Facility B.
Upon completion of the Offering, the Total Borrowing Base will be $120.0
million, with $70.0 million allocated to Facility A and $50.0 million allocated
to Facility B. Facility A terminates on December 31, 2000, and Facility B
terminates October 30, 1997. The Facility B termination date generally is
extended every six months prior to maturity for an additional one-year period.
The Company's Credit Facility obligations are unsecured (except by the capital
stock of the Company's Restricted Subsidiaries, as such term is defined in the
Credit Facility).
Borrowings under the Credit Facility bear interest at any of the following
rates selected from time to time by the Company: (i) the agent bank's floating
"prime rate," (ii) the London Interbank Offered Rate plus 0.75% (the "LIBOR
Rate"), (iii) a rate based on certain dealer's bids for certificates of deposit
plus 0.75% (the "CD Rate") and (iv) a rate obtained by competitive bidding among
the banks participating in the Credit Facility. The margin on LIBOR Rate or CD
Rate loans increases to 1.0% when the Company's consolidated senior debt becomes
greater than 80% of its consolidated tangible net worth, as therein defined.
During 1996, the average interest rate under the Credit Facility was 6.4%. The
Company also pays certain fees based on the unused portion of the Total
Borrowing Base.
The Credit Facility contains a number of customary covenants that, among
other things, (i) require the maintenance of certain coverage ratios, (ii) limit
the incurrence of additional indebtedness, (iii) restrict the payment of
dividends, (iv) restrict stock repurchases, certain investments and unrelated
business activities and (v) restrict the Company's right to consolidate or merge
with another entity or to dispose of its assets. The Credit Facility also
contains customary events of default.
S-86
<PAGE> 87
UNDERWRITING
Upon the terms and subject to the conditions of the Underwriting Agreement
(the "Underwriting Agreement") among the Company and NationsBanc Capital
Markets, Inc., Chase Securities Inc., Smith Barney Inc. and Petrie Parkman &
Co., Inc. (the "Underwriters"), the Underwriters severally have agreed to
purchase from the Company and the Company has agreed to sell to the Underwriters
severally the principal amount of Notes set forth opposite the names of such
Underwriters below:
<TABLE>
<CAPTION>
UNDERWRITER PRINCIPAL AMOUNT
----------- ----------------
<S> <C>
NationsBanc Capital Markets, Inc. .......................... $ 87,500,000
Chase Securities Inc. ...................................... 52,500,000
Smith Barney Inc. .......................................... 26,250,000
Petrie Parkman & Co., Inc. ................................. 8,750,000
------------
Total............................................. $175,000,000
============
</TABLE>
In the Underwriting Agreement, the several Underwriters have agreed,
subject to certain conditions, to purchase all of the Notes, if any are
purchased. The Underwriting Agreement provides that, in the event of a default
by an Underwriter, in certain circumstances, the purchase commitments of
non-defaulting Underwriters may be increased or the Underwriting Agreement may
be terminated.
The Company has been advised by the Underwriters that they propose to offer
the Notes to the public initially at the price to the public set forth on the
cover page of this Prospectus Supplement, to certain securities dealers (who may
include Underwriters) at such price less a concession not in excess of 0.25% of
the amount per Note and that the Underwriters and such dealers may reallow a
discount not in excess of 0.125% of the amount per Note to other dealers,
including the Underwriters. After the closing of the Offering, the public
offering price, the concession and the discount to other dealers may be changed
by the Underwriters.
There is no currently existing trading market for the Notes and, although
certain of the Underwriters have advised the Company that they currently intend
to make a market in the Notes, they are not obligated to do so and any such
market making may be discontinued at any time, without notice, in the sole
discretion of the Underwriters. Accordingly, there can be no assurance as to the
development or liquidity of any market that may develop for the Notes.
The Company and the Subsidiary Guarantors have agreed to indemnify the
Underwriters against certain liabilities, including liabilities under the
Securities Act of 1933, as amended (the "Securities Act"), or to contribute to
payments that the Underwriters may be required to make in respect thereof.
NationsBanc Capital Markets, Inc. is an affiliate of NationsBank of Texas,
N.A. and Chase Securities Inc. is an affiliate of Texas Commerce Bank National
Association. NationsBank of Texas, N.A. and Texas Commerce Bank National
Association are lenders under the Credit Facility. See "Description of the
Credit Facility." Each of NationsBank of Texas, N.A. and Texas Commerce Bank
National Association will receive its proportionate share of the repayment by
the Company of borrowings under the Credit Facility from the net proceeds of the
Offering. Texas Commerce Bank National Association will also act as Trustee for
the Notes and will receive customary compensation for such services. Petrie
Parkman & Co., Inc. has provided various investment banking services for the
Company and received customary compensation for such services.
In connection with the Offering, the Underwriters may engage in
transactions that stabilize, maintain or otherwise affect the price of the
Notes. Specifically, the Underwriters may over allot the Offering, creating a
syndicate short position. In addition, the Underwriters may bid for, and
purchase, Notes in the open market to cover syndicate shorts or to stabilize the
price of the Notes. Finally, the underwriting syndicate may reclaim selling
concessions allowed for distributing in the Offering if the syndicate
repurchases previously distributed Notes in syndicate covering transactions, in
stabilization transactions or otherwise. Any of these activities may stabilize
or maintain the market price of Notes above independent market levels. The
Underwriters are not required to engage in these activities and may end any of
these activities at any time.
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<PAGE> 88
LEGAL MATTERS
Certain legal matters in connection with the Notes will be passed upon for
the Company by Peter E. Lorenzen, Vice President -- General Counsel and
Secretary of the Company, and for the Underwriters by Baker & Botts, L.L.P.,
Dallas, Texas. Mr. Lorenzen beneficially owns 35,000 shares of Common Stock of
the Company and hold options to purchase an additional 65,200 shares of Common
Stock of which 36,020 options are exercisable.
EXPERTS
The consolidated financial statements and schedules of the Company as of
December 31, 1995 and 1996 and for each of the three years in the period ended
December 31, 1996, have been audited by Arthur Andersen LLP, independent public
accountants, as indicated in their report with respect thereof, and are included
and incorporated herein in reliance upon the authority of such firm as experts
in accounting and auditing in giving said reports.
The information included and incorporated herein regarding proved reserves
and related future net revenues and the present value thereof is derived, as and
to the extent described herein and therein, from reserve reports prepared by
Netherland, Sewell & Associates, Inc. and Ryder Scott Company Petroleum
Engineers, independent oil and gas consultants, and, to such extent, are
included and incorporated by reference in reliance upon the authority of such
firms as experts with respect to the matters contained in such reports.
S-88
<PAGE> 89
GLOSSARY
The following are definitions of certain terms used in this Prospectus
Supplement.
Bbl -- One stock tank barrel, or 42 US gallons liquid volume, used herein
in reference to crude oil or other liquid hydrocarbons.
Bcf -- One billion cubic feet.
BOE -- Barrels of oil equivalent (converting six Mcf of natural gas to one
Bbl of oil).
Developed Acreage -- Acreage that is allocated or assignable to producing
wells or wells capable of production.
Development Well -- A well drilled within the proved area of an oil and
natural gas reservoir to the depth of a stratigraphic horizon known to be
productive.
Dry Well -- A well found to be incapable of producing either oil or natural
gas in sufficient quantities to justify completion as an oil or natural gas
well.
Exploratory Well -- A well drilled to find and produce oil or natural gas
in an unproved area, to find a new reservoir in a field previously found to be
productive of oil or natural gas in another reservoir, or to extend a known
reservoir.
Gross Acres or Gross Wells -- The total acres or wells, as the case may be,
in which a working interest is owned.
MBbl -- One thousand Bbl.
MBOE -- One thousand barrels of oil equivalent.
Mcf -- One thousand cubic feet.
MMBtu -- One million British Thermal Units.
MMcf -- One million cubic feet.
MMcfe -- One million cubic feet of natural gas equivalent.
Net Acres or Net Wells -- The sum of the fractional working interests owned
in gross acres or gross wells.
Oil and Natural Gas Lease -- An instrument by which a mineral fee owner
grants to lessee the right for a specific period of time to explore for oil and
natural gas underlying the lands covered by the lease and the right to produce
any oil and natural gas so discovered generally for so long as there is
production in economic quantities from such lands.
Present Value -- The discounted future net cash flows for proved oil and
natural gas reserves computed on the same basis as the Standardized Measure, but
without deducting income taxes, which is not in accordance with generally
accepted accounting principles. Present Value is an important financial measure
for evaluating the relative significance of oil and natural gas properties and
acquisitions, but should not be construed as an alternative to the Standardized
Measure (as determined in accordance with generally accepted accounting
principles).
Productive Well -- A well that is producing oil or natural gas or that is
capable of production.
Proved Developed Reserves -- Reserves that can be expected to be recovered
through existing wells with existing equipment and operating methods.
Proved Reserves -- The estimated quantities of crude oil, natural gas and
natural gas liquids which geological and engineering data demonstrate with
reasonable certainty to be recoverable in future years from known reservoirs
under existing economic and operating conditions.
Proved Undeveloped Reserves or PUD -- Reserves that are expected to be
recovered from new wells on undrilled acreage, or from existing wells where
relatively major expenditures are required for completion.
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<PAGE> 90
Recompletion -- The completion for production of an existing well bore in
another formation from that in which the well has been previously completed.
Royalty Interest -- An interest in an oil and natural gas property
entitling the owner to a share of oil and natural gas production free of costs
of production.
Secondary Recovery -- A method of oil and natural gas extraction in which
energy sources extrinsic to the reservoir are utilized.
Standardized Measure -- The estimated future net cash flows from proved oil
and natural gas reserves computed using prices and costs, at the dates
indicated, after income taxes and discounted at 10%.
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.
Waterflood -- The injection of water into a reservoir to fill pores vacated
by produced fluids, thus maintaining reservoir pressure and assisting
production.
Working Interest -- The operating interest which gives the owner the right
to drill, produce and conduct operating activities on the property and a share
of production, subject to all royalties, overriding royalties and other burdens
and to all costs of exploration, development and operations and all risks in
connection therewith.
Workover -- Operations on a producing well to restore or increase
production.
S-90
<PAGE> 91
INDEX TO FINANCIAL STATEMENTS
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
Report of Independent Public Accountants.................... F-2
Consolidated Balance Sheets as of December 31, 1995 and 1996
and March 31, 1997........................................ F-3
Consolidated Statements of Operations for the years ended
December 31, 1994, 1995 and 1996 and the three months
ended March 31, 1996 and 1997............................. F-4
Consolidated Statements of Changes in Stockholders' Equity
for the years ended
December 31, 1994, 1995 and 1996 and the three months
ended March 31, 1997................................... F-5
Consolidated Statements of Cash Flows for the years ended
December 31, 1994, 1995 and 1996 and the three months
ended March 31, 1996 and 1997............................. F-6
Notes to Consolidated Financial Statements.................. F-7
</TABLE>
F-1
<PAGE> 92
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Stockholders of Snyder Oil Corporation:
We have audited the accompanying consolidated balance sheets of Snyder Oil
Corporation (a Delaware corporation) and subsidiaries as of December 31, 1995
and 1996, and the related consolidated statements of operations, changes in
stockholders' 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 Snyder Oil Corporation and
subsidiaries as of December 31, 1995 and 1996, 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.
As explained in Note 2 to the financial statements, the Company adopted
Statement of Financial Accounting Standards No. 121, "Accounting for the
Impairment of Long-Lived Assets and for Long-Lived Assets to Be Disposed Of", in
1995.
ARTHUR ANDERSEN LLP
Fort Worth, Texas,
February 17, 1997
F-2
<PAGE> 93
SNYDER OIL CORPORATION
CONSOLIDATED BALANCE SHEETS
(IN THOUSANDS)
<TABLE>
<CAPTION>
DECEMBER 31,
---------------------- MARCH 31,
1995 1996 1997
--------- --------- -----------
(UNAUDITED)
<S> <C> <C> <C>
ASSETS
Current assets
Cash and equivalents.................................. $ 27,263 $ 27,922 $ 37,892
Accounts receivable................................... 29,259 58,944 44,085
Inventory and other................................... 11,769 11,212 7,976
--------- --------- ---------
68,291 98,078 89,953
--------- --------- ---------
Investments............................................. 33,220 129,681 124,015
--------- --------- ---------
Oil and gas properties, successful efforts method....... 675,961 887,721 910,182
Accumulated depletion, depreciation and
amortization....................................... (240,744) (252,334) (274,549)
--------- --------- ---------
435,217 635,387 635,633
--------- --------- ---------
Gas facilities and other................................ 30,506 28,111 23,740
Accumulated depreciation and amortization............. (11,741) (11,798) (10,810)
--------- --------- ---------
18,765 16,313 12,930
--------- --------- ---------
$ 555,493 $ 879,459 $ 862,531
========= ========= =========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities
Accounts payable...................................... $ 36,353 $ 51,867 $ 51,163
Accrued liabilities................................... 26,096 37,043 38,702
--------- --------- ---------
62,449 88,910 89,865
--------- --------- ---------
Senior debt............................................. 150,001 188,231 140,751
Subordinated notes...................................... -- 103,094 99,913
Convertible subordinated notes.......................... 84,058 80,748 80,324
Deferred taxes payable.................................. -- 9,034 25,294
Other noncurrent liabilities............................ 20,016 28,064 28,766
Minority interest....................................... 3,601 86,710 86,289
Commitments and contingencies
Stockholders' equity
Preferred stock, $.01 par, 10,000,000 shares
authorized, 6% Convertible preferred stock,
1,035,000, 1,033,500 and 1,033,500 shares issued
and outstanding.................................... 10 10 10
Common stock, $.01 par, 75,000,000 shares authorized,
31,430,227, 31,456,027 and 31,543,665 shares
issued............................................. 314 315 315
Capital in excess of par value........................ 265,911 260,221 260,411
Retained earnings (deficit)........................... (29,001) 25,711 42,030
Common stock held in treasury, 134,191, 250,000 and
989,800 shares at cost............................. (2,457) (3,510) (15,712)
Unrealized foreign currency translation gain.......... 380 -- --
Unrealized gain on investments........................ 211 11,921 24,275
--------- --------- ---------
235,368 294,668 311,329
--------- --------- ---------
$ 555,493 $ 879,459 $ 862,531
========= ========= =========
</TABLE>
The accompanying notes are an integral part of these statements.
F-3
<PAGE> 94
SNYDER OIL CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS
(IN THOUSANDS EXCEPT PER SHARE DATA)
<TABLE>
<CAPTION>
THREE MONTHS
YEAR ENDED DECEMBER 31, ENDED MARCH 31,
------------------------------ -----------------
1994 1995 1996 1996 1997
-------- -------- -------- ------- -------
(UNAUDITED)
<S> <C> <C> <C> <C> <C>
Revenues
Oil and gas sales........................... $137,858 $144,608 $189,327 $36,122 $67,848
Gas transportation, processing and
marketing................................ 107,247 38,256 17,655 4,451 4,209
Gains on sales of equity interests in
investees................................ 9,747 2,183 69,343 407 13,000
Gains (losses) on sales of properties....... 1,969 12,254 8,786 (20) 2,607
Other....................................... 5,507 4,859 7,303 759 1,091
-------- -------- -------- ------- -------
262,328 202,160 292,414 41,719 88,755
-------- -------- -------- ------- -------
Expenses
Direct operating............................ 46,267 52,486 49,638 10,759 14,021
Cost of gas and transportation.............. 94,177 29,374 15,020 3,696 4,191
Exploration................................. 6,505 8,033 4,232 514 1,700
General and administrative.................. 12,853 17,680 17,143 3,868 5,492
Interest.................................... 10,337 21,679 23,587 3,614 6,787
Other....................................... 2,126 5,322 5,312 679 1,756
Depletion, depreciation and amortization.... 70,770 76,378 84,547 16,771 23,208
Property impairments........................ 5,783 27,412 2,753 -- --
Litigation settlement....................... -- 4,400 -- -- --
Loss on sale of subsidiary interest......... -- -- 15,481 -- --
-------- -------- -------- ------- -------
Income (loss) before taxes and minority
interest.................................... 13,510 (40,604) 74,701 1,818 31,600
-------- -------- -------- ------- -------
Provision (benefit) for income taxes
Current..................................... -- 25 33 25 --
Deferred.................................... 967 (1,370) 4,313 (335) 8,871
-------- -------- -------- ------- -------
967 (1,345) 4,346 (310) 8,871
-------- -------- -------- ------- -------
Minority interest in subsidiaries............. 171 572 7,405 351 2,803
-------- -------- -------- ------- -------
Net income (loss)............................. 12,372 (39,831) 62,950 1,777 19,926
Preferred stock dividends..................... 10,806 6,210 6,210 1,553 1,550
-------- -------- -------- ------- -------
Net income available (loss applicable) to
common...................................... $ 1,566 $(46,041) $ 56,740 $ 224 $18,376
======== ======== ======== ======= =======
Net income (loss) per common share............ $ .07 $ (1.53) $ 1.81 $ .01 $ .59
======== ======== ======== ======= =======
Weighted average shares outstanding........... 23,704 30,186 31,308 31,302 31,030
======== ======== ======== ======= =======
</TABLE>
The accompanying notes are an integral part of these statements.
F-4
<PAGE> 95
SNYDER OIL CORPORATION
CONSOLIDATED STATEMENTS OF CHANGES IN
STOCKHOLDERS' EQUITY
(IN THOUSANDS)
<TABLE>
<CAPTION>
PREFERRED STOCK COMMON STOCK CAPITAL IN RETAINED
--------------- --------------- EXCESS OF EARNINGS TREASURY
SHARES AMOUNT SHARES AMOUNT PAR VALUE (DEFICIT) STOCK
------ ------ ------ ------ ---------- --------- --------
<S> <C> <C> <C> <C> <C> <C> <C>
Balance, December 31, 1993....... 2,221 $ 22 23,260 $233 $249,713 $ 25,308 $ --
Common stock grants and
exercise of options......... -- -- 414 4 2,851 -- (2,288)
Conversion of preferred to
common...................... (1,186) (12) 6,535 65 (53) -- --
Issuance of warrants........... -- -- -- -- 3,450 -- --
Dividends...................... -- -- -- -- -- (16,721) --
Net income..................... -- -- -- -- -- 12,372 --
------ ---- ------ ---- -------- -------- --------
Balance, December 31, 1994....... 1,035 10 30,209 302 255,961 20,959 (2,288)
Common stock grants and
exercise of options......... -- -- 138 1 856 -- (169)
Issuance of common............. -- -- 1,083 11 13,021 -- --
Dividends...................... -- -- -- -- (3,927) (10,129) --
Net loss....................... -- -- -- -- -- (39,831) --
------ ---- ------ ---- -------- -------- --------
Balance, December 31, 1995....... 1,035 10 31,430 314 265,911 (29,001) (2,457)
Common stock grants and
exercise of options......... -- -- 267 3 3,179 -- (258)
Issuance of common............. -- -- 399 4 3,689 -- --
Repurchase of common........... -- -- (640) (6) (6,243) -- (795)
Repurchase of preferred........ (1) -- -- -- (142) -- --
Dividends...................... -- -- -- -- (6,173) (8,238) --
Net income..................... -- -- -- -- -- 62,950 --
------ ---- ------ ---- -------- -------- --------
Balance, December 31, 1996....... 1,034 10 31,456 315 260,221 25,711 (3,510)
Common stock grants and
exercise of options......... -- -- 88 -- 190 -- --
Repurchase of common........... -- -- -- -- -- -- (12,202)
Dividends...................... -- -- -- -- -- (3,607) --
Net income..................... -- -- -- -- -- 19,926 --
------ ---- ------ ---- -------- -------- --------
Balance, March 31, 1997
(Unaudited).................... 1,034 $ 10 31,544 $315 $260,411 $ 42,030 $(15,712)
====== ==== ====== ==== ======== ======== ========
</TABLE>
The accompanying notes are an integral part of these statements.
F-5
<PAGE> 96
SNYDER OIL CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
(IN THOUSANDS)
<TABLE>
<CAPTION>
THREE MONTHS
YEAR ENDED DECEMBER 31, ENDED MARCH 31,
----------------------------------- --------------------
1994 1995 1996 1996 1997
--------- --------- --------- -------- --------
(UNAUDITED)
<S> <C> <C> <C> <C> <C>
Operating activities
Net income (loss)......................... $ 12,372 $ (39,831) $ 62,950 $ 1,777 $ 19,926
Adjustments to reconcile net income (loss)
to net cash provided by operations
Amortization of deferred credits...... (2,986) (2,511) (1,052) (534) --
Gains on sales of equity interests in
investees.......................... (9,747) (809) (68,343) (407) (13,000)
(Gains) losses on sales of
properties......................... (1,969) (12,254) (8,786) 20 (2,607)
Equity in (earnings) losses of
investees.......................... (1,355) 1,319 (421) 88 (222)
Exploration expense................... 6,505 8,033 4,232 514 1,700
Loss on sale of subsidiary interest... -- -- 15,481 -- --
Depletion, depreciation and
amortization....................... 70,770 76,378 84,547 16,771 23,208
Property impairments.................. 5,783 27,412 2,753 -- --
Deferred taxes........................ 967 (1,370) 4,313 (335) 8,871
Minority interest in subsidiaries..... 171 572 7,405 351 2,803
Changes in operating assets and
liabilities
Decrease (increase) in
Accounts receivable.............. 11,024 7,142 (15,869) (3,611) 14,859
Inventory and other.............. (9,241) 3,617 5,175 50 (74)
Increase (decrease) in
Accounts payable................. 1,901 (8,521) 2,771 16,390 (704)
Accrued liabilities.............. 1,841 5,165 (316) 1,050 (3,109)
Other liabilities................ 361 4,779 6,890 (5,415) 124
--------- --------- --------- -------- --------
Net cash provided by operations.... 86,397 69,121 101,730 26,709 51,775
--------- --------- --------- -------- --------
Investing activities
Acquisition, exploration and
development............................. (237,879) (92,353) (128,598) (14,088) (55,913)
Purchase of controlling interest in
subsidiary.............................. (6,645) -- -- -- --
Proceeds from investments................. 5,019 14,786 1,635 774 40,153
Outlays for investments................... (8,804) -- (9,013) (165) --
Proceeds from sales of properties......... 2,806 109,988 73,620 (63) 8,380
--------- --------- --------- -------- --------
Net cash realized (used) by
investing........................ (245,503) 32,421 (62,356) (13,542) (7,380)
--------- --------- --------- -------- --------
Financing activities
Issuance of common........................ 1,157 688 1,523 512 739
Increase (decrease) in indebtedness....... 187,138 (86,193) (13,289) 6,102 (15,639)
Debt issuance costs....................... (2,855) -- -- -- --
Dividends................................. (16,721) (14,056) (14,411) (3,589) (3,607)
Deferred credits.......................... 2,356 3,549 (120) (120) --
Repurchase of stock....................... (1,149) -- (7,186) -- (12,202)
Repurchase of subordinated notes.......... -- -- (5,232) -- (3,716)
--------- --------- --------- -------- --------
Net cash realized (used) by
financing........................ 169,926 (96,012) (38,715) 2,905 (34,425)
--------- --------- --------- -------- --------
Increase in cash............................ 10,820 5,530 659 16,072 9,970
Cash and equivalents, beginning of period... 10,913 21,733 27,263 27,263 27,922
--------- --------- --------- -------- --------
Cash and equivalents, end of period......... $ 21,733 $ 27,263 $ 27,922 $ 43,335 $ 37,892
========= ========= ========= ======== ========
Noncash investing and financing activities
Gas plant capital lease................... $ 21,000 -- -- -- --
Acquisition of properties and stock via
stock issuances......................... -- $ 13,032 $ 3,693 -- --
Acquisition of properties recorded as
senior debt............................. -- -- $ 31,730 -- --
Acquisition via subsidiary stock
issuance................................ -- -- $ 115,067 -- --
</TABLE>
The accompanying notes are an integral part of these statements.
F-6
<PAGE> 97
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(INFORMATION FOR MARCH 31, 1996 AND 1997 IS UNAUDITED)
(1) ORGANIZATION AND NATURE OF BUSINESS
Snyder Oil Corporation (the "Company") is primarily engaged in the
acquisition, exploration and development of oil and gas properties principally
in the Rocky Mountain and Gulf Coast regions of the United States. The Company
also gathers, transports and markets natural gas. The Company is also engaged in
international acquisition, exploration and development, primarily through
affiliates. The Company, a Delaware corporation, is the successor to a company
formed in 1978.
(2) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation
The consolidated financial statements include the accounts of Snyder Oil
Corporation ("SOCO") and its subsidiaries (collectively, the "Company").
Affiliates in which the Company owns more than 50% but less than 100% are fully
consolidated, with the related minority interest being deducted from subsidiary
earnings and stockholders' equity. Affiliates being accounted for in this manner
include Patina Oil & Gas Corporation ("Patina"), SOCO International Holdings,
Inc. ("Holdings") and SOCO International Operations, Inc. ("Operations"). SOCO
Offshore, Inc. ("SOCO Offshore") was accounted for in this manner until all
remaining minority interests were acquired in June 1996. Affiliates in which the
Company owns between 20% and 50% are accounted for under the equity method.
Affiliates being accounted for in this manner include SOCO Perm Russia, Inc.
("SOCO Perm"), a Russian affiliate, and SOCO Tamtsag Mongolia, Inc. ("SOCO
Tamtsag"), a Mongolian affiliate. Command Petroleum Limited ("Command"), an
Australian affiliate, was accounted for in this manner until the Company
disposed of this investment in November 1996. Affiliates in which the Company
owns less than 20% are accounted for under the cost method. Affiliates being
accounted for in this manner include Cairn Energy plc ("Cairn"). The Company
accounts for its interest in joint ventures and partnerships using the
proportionate consolidation method, whereby its share of assets, liabilities,
revenues and expenses are consolidated.
Producing Activities
The Company utilizes the successful efforts method of accounting for its
oil and gas properties. Consequently, leasehold costs are capitalized when
incurred. Unproved properties are assessed periodically within specific
geographic areas and impairments in value are charged to expense. During the
year ended December 31, 1996 and the three months ended March 31, 1997, the
Company provided unproved property impairments of $2.8 million and $296,000,
respectively. Exploratory expenses, including geological and geophysical
expenses and delay rentals, are charged to expense as incurred. Exploratory
drilling costs are initially capitalized, but charged to expense if and when the
well is determined to be unsuccessful. Costs of productive wells, unsuccessful
developmental wells and productive leases are capitalized and amortized on a
unit-of-production basis over the life of the remaining proved or proved
developed reserves, as applicable. Gas is converted to equivalent barrels at the
rate of 6 Mcf to 1 barrel. Amortization of capitalized costs is generally
provided on a property-by-property basis. Estimated future abandonment costs
(net of salvage values) are accrued at unit-of-production rates and taken into
account in determining depletion, depreciation and amortization.
Prior to 1995, the Company provided impairments for significant proved oil
and gas property groups to the extent that net capitalized costs exceeded the
undiscounted future cash flows. During 1995, the Company adopted Statement of
Financial Accounting Standards No. 121 ("SFAS 121"), "Accounting for the
Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed Of".
SFAS 121 requires the Company to assess the need for an impairment of
capitalized costs of oil and gas properties on a property-by-property basis. If
an impairment is indicated based on undiscounted expected future cash flows,
then it is recognized to the extent that net capitalized costs exceed discounted
expected future cash flows. Accordingly,
F-7
<PAGE> 98
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
in 1995 the Company provided for $27.4 million of such impairments. During the
year ended December 31, 1996 and the three months ended March 31, 1997, the
Company did not provide for any such impairments.
Unrealized Foreign Currency Translation Gain
The Company follows SFAS 52, "Foreign Currency Translation", which requires
that business transactions and foreign operations recorded in a foreign currency
must be restated in U.S. dollars. Gains or losses resulting from the translation
process increases or decreases the book value of investments and must be
accumulated in a separate component of stockholders' equity. Command's
functional currency is the Australian dollar. The foreign currency translation
gain reported in the balance sheet as of December 31, 1995 was the result of the
translation of the Australian dollar balance sheet into United States dollars at
then current exchange rates.
Section 29 Tax Credits
The Company from time to time enters into arrangements to monetize its
Section 29 tax credits. These arrangements result in revenue increases of
approximately $.40 per Mcf on production volumes from qualified Section 29
properties. As a result of such arrangements, the Company recognized additional
gas revenues of $2.5 million in both 1995 and 1996 and $534,000 and $801,000
during the three month periods ended March 31, 1996 and 1997. These arrangements
are expected to continue through 2002.
Gas Imbalances
The Company uses the sales method to account for gas imbalances. Under this
method, revenue is recognized based on the cash received rather than the
proportionate share of gas produced. Gas imbalances at year end 1995 and 1996
and March 31, 1997 were insignificant.
Financial Instruments
The following table sets forth the book value and estimated fair values of
financial instruments (in thousands):
<TABLE>
<CAPTION>
DECEMBER 31, 1995 DECEMBER 31, 1996 MARCH 31, 1997
--------------------- --------------------- ---------------------
BOOK FAIR BOOK FAIR BOOK FAIR
VALUE VALUE VALUE VALUE VALUE VALUE
--------- --------- --------- --------- --------- ---------
<S> <C> <C> <C> <C> <C> <C>
Cash and equivalents......... $ 27,263 $ 27,263 $ 27,922 $ 27,922 $ 37,892 $ 37,892
Investments.................. 33,220 52,203 129,681 163,477 124,015 145,366
Senior debt.................. (150,001) (150,001) (188,231) (188,231) (140,751) (140,751)
Subordinated notes........... -- -- (103,094) (105,650) (99,913) (102,948)
Convertible subordinated
notes...................... (84,058) (79,997) (80,748) (82,866) (80,324) (82,739)
Long-term commodity
contracts.................. -- 11,623 -- 5,040 -- 4,936
Interest rate swap........... -- 107 -- (19) -- 40
</TABLE>
The book value of cash and equivalents approximates fair value because of
the short maturity of those instruments. See Note (3) for a discussion of the
Company's investments. The fair value of senior debt is presented at face value
given its floating rate structure. The fair value of the subordinated notes and
convertible subordinated notes are estimated based on their December 31, 1995
and 1996 and March 31, 1997 closing prices on the New York Stock Exchange.
From time to time, the Company enters into commodity contracts to hedge the
price risk of a portion of its production. Gains and losses on such contracts
are deferred and recognized in income as an adjustment to
F-8
<PAGE> 99
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
oil and gas sales revenue in the period to which the contracts relate. In 1994,
the Company entered into a long-term gas swap arrangement in order to lock in
the price differential between the Rocky Mountain and Henry Hub prices on a
portion of its Rocky Mountain gas production. The contract covers 20,000 MMBtu
per day through 2004. At March 31, 1997, that volume represented approximately
15% of the Company's consolidated Rocky Mountain gas production. The fair value
of the contract was based on the market price quoted for a similar instrument.
In September 1995, the Company entered into an interest rate swap covering
$50 million of its bank debt. The agreement requires payment to a counterparty
based on a fixed rate of 5.585% and requires the counterparty to pay the Company
interest at the then current 30 day LIBOR rate. Accounts receivable or payable
under this agreement are recorded as adjustments to interest expense and are
settled on a monthly basis. The agreement matures in September 1997, with the
counterparty having the option to extend it for two years. At December 31, 1995
and 1996 and March 31, 1997, the fair value of the agreement was estimated at
the net present value discounted at 10%.
Risks and Uncertainties
Historically, the market for oil and gas has experienced significant price
fluctuations. Prices for gas in the Rocky Mountain region, where the Company
currently produces over 70% of its natural gas, have traditionally been
particularly volatile. Prices are significantly impacted by the local weather,
supply in the area, seasonal variations in local demand and limited
transportation capacity to other regions of the country. Increases or decreases
in prices received, particularly in the Rocky Mountains, could have a
significant impact on the Company's future results of operations.
The Company's strategy internationally is to develop a portfolio of
projects that have the potential to make a major contribution to its production
and reserves while limiting its financial exposure and mitigating political risk
by seeking industry partners and investors to fund the majority of the required
capital. Such projects are subject to a number of political and economic
uncertainties, in addition to the typical risks and volatility associated with
the oil and gas industry. There is no assurance that the Company's international
operations will reach a level reasonably required to fully exploit the projects,
nor is there any assurance of economic success should such a level be reached.
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.
Other
All liquid investments with an original maturity of three months or less
are considered to be cash equivalents. Certain amounts in prior years
consolidated financial statements have been reclassified to conform with current
classification.
F-9
<PAGE> 100
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(3) INVESTMENTS
The Company has investments in foreign and domestic energy companies and
long-term notes receivable. The following table sets forth the book values and
estimated fair values of these investments:
<TABLE>
<CAPTION>
DECEMBER 31, 1995 DECEMBER 31, 1996 MARCH 31, 1997
----------------- ------------------- -------------------
BOOK FAIR BOOK FAIR BOOK FAIR
VALUE VALUE VALUE VALUE VALUE VALUE
------- ------- -------- -------- -------- --------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C> <C>
Equity method investments............ $30,901 $49,884 $ 8,789 $ 42,585 $ 8,649 $ 30,000
Marketable securities................ 652 652 115,558 115,558 110,503 110,503
Long-term notes receivable........... 1,667 1,667 5,334 5,334 4,863 4,863
------- ------- -------- -------- -------- --------
$33,220 $52,203 $129,681 $163,477 $124,015 $145,366
======= ======= ======== ======== ======== ========
</TABLE>
The Company follows SFAS 115, "Accounting for Certain Investments in Debt
and Equity Securities", which requires that investments in marketable securities
accounted for on the cost method and long-term notes receivable must be adjusted
to their market value with a corresponding increase or decrease to stockholders'
equity. The pronouncement does not apply to investments accounted for by the
equity method.
Command Petroleum Limited
From May 1993 to November 1996, the Company had an investment in Command,
an Australian oil company, which was accounted for by the equity method. Command
was listed on the Australian Stock Exchange. In 1995, the Company acquired an
additional 4.7 million shares of Command common stock in exchange for an
interest in the Fejaj Permit in Tunisia. As a result, the Company's ownership in
Command increased to 30.0% and a $1.4 million gain was recognized during 1995.
In June 1996, the Company purchased 8.5 million shares of Command common stock
for $3.6 million, increasing its ownership to 32.6%. In October 1996, Command
announced that it had completed merger negotiations with Cairn, an international
independent oil company based in Edinburgh, Scotland with shares listed on the
London Stock Exchange. In November 1996, the Company accepted Cairn's offer for
its interest in Command. The Company received 16.2 million shares of freely
marketable Cairn common stock, and recognized a gain of $65.5 million in the
fourth quarter of 1996. The Company's investment in Cairn is accounted for under
the cost method and is reflected as marketable securities in the table above.
Immediately prior to the acceptance of Cairn's offer, the Company accrued for a
transaction in which a director of the Company exchanged his option to purchase
10% of the outstanding common stock of SOCO International, Inc. (through which
the investment in Command was held) and issued promissory notes to the Company
totaling $591,000 for 10% of the outstanding common stock of two SOCO
International, Inc. subsidiaries, Holdings and Operations. As a result of this
transaction, the Company recorded a $260,000 loss. Additionally, minority
interest expense of $4.3 million was recorded related to the director's 10%
ownership as a result of the Command gain. The actual exchange occurred in
December 1996 and the promissory notes remained outstanding at March 31, 1997.
SOCO International Operations, Inc.
In 1993, SOCO Perm, an affiliate of Operations, was organized by the
Company and a U.S. industry participant. SOCO Perm and a Russian partner formed
the Permtex joint venture to develop proven oil fields in the Volga-Urals Basin
of Russia. To finance a portion of its planned development expenditures, SOCO
Perm closed a private placement of its equity securities with three industry
participants in 1994. As a result, the Company's investment was reduced from 75%
to 41.25% and a $3.5 million gain was recorded. In 1995, the three industry
participants paid the final installments of their contributions to SOCO Perm and
as a result, the Company recognized an additional gain of $1.1 million. In April
1996, SOCO Perm closed a private placement which reduced the Company's interest
to 34.91%. The Company recognized a gain of $2.6 million
F-10
<PAGE> 101
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
as a result of this transaction. The private placement agreement requires SOCO
Perm to list its common shares on a securities exchange no later than 1998. If
such listing does not occur, the new shareholders have the right to require the
Company to purchase their share at a formula price. The Company's investment in
SOCO Perm had a carrying cost at both December 31, 1996 and March 31, 1997 of
$7.0 million.
In 1994, the Company formed a consortium to explore the Tamtsag Basin of
eastern Mongolia, then sold a portion of its interest to three industry
participants. One participant committed to fund the drilling of two wells, the
second purchased its interest for cash and a third participant assigned its
exploration rights in the basin to the consortium. Accordingly, the Company's
investment in SOCO Tamtsag, an affiliate of Operations, was reduced from 100% to
49% and a $1.5 million gain was recognized. In 1996, the Company completed the
exchange of a portion of its interest to an industry participant for consulting
services valued at $1.5 million. As a result of this transaction, the Company's
ownership was reduced to 42% and an $832,000 gain was recognized. In August
1996, the Mongolian Parliament ratified the grant of two additional concessions
in the area to SOCO Tamtsag, bringing the total acreage position to
approximately 10 million acres. In January 1997, SOCO Tamtsag completed an
equity sale which reduced the Company's investment to 40.3%. The Company's
investment in SOCO Tamtsag had a carrying cost of $1.8 million and $1.6 million,
respectively, at December 31, 1996 and March 31, 1997 in addition to $4.7
million and $4.3 million, respectively, in stockholder loans, which are required
on a pro rata basis by all stockholders, to SOCO Tamtsag which are included in
notes receivable in the table above.
The Company is currently seeking a listing of a newly formed entity, SOCO
International plc ("SOCO plc"), on the London Stock exchange and intends to
conduct an offering of its shares. The Company will contribute to SOCO plc all
the assets of Operations, which includes the Company's interests in Russia,
Mongolia and Thailand. Certain minority interest owners in these ventures are
also expected to contribute their interests. If such listing occurs, it is
expected to meet the requirement to list SOCO Perm. As part of the listing, SOCO
plc will also acquire Cairn's UK onshore company as well as certain assets in
Yemen and Tunisia that were formerly owned by Command. The offering is expected
to raise approximately $75 million of new equity capital for SOCO plc. Following
the offering, the Company which will retain all its shares, expects to have an
approximate 15% to 18% interest in SOCO plc. The Company estimates the fair
value of its investment in Operations at March 31, 1997 to be between $30
million and $37 million based on preliminary indications related to the listing.
The listing and offering are subject to certain conditions and there can be no
assurance that the offering will be consummated.
Marketable Securities
The Company had investments in equity securities of publicly traded
domestic energy companies accounted for on the cost method, with a total cost at
December 31, 1995 of $328,000. The market value of these securities at December
31, 1995 approximated $652,000. In 1996, the Company sold all of these
securities for $968,000 and recognized a corresponding gain of $640,000. In
accordance with SFAS 115 at December 31, 1995, investments were increased by
$324,000 of gross unrealized holding gains, stockholders' equity was increased
by $211,000 and deferred taxes payable were increased by $113,000. The Company
had investments in equity securities of one publicly traded foreign energy
company, Cairn, accounted for on the cost method at December 31, 1996 and March
31, 1997. Cairn has a major development project off the coast of Bangladesh as
well as major producing interests in the United Kingdom and the Dutch North Sea,
and exploration interests in several countries including Thailand, Vietnam and
China. In the first quarter of 1997, the Company sold 4.5 million Cairn shares
at an average of $8.81 per share realizing $39.2 million in proceeds. These
transactions resulted in a gain of $13.0 million. The Company's total cost basis
in the Cairn shares was $95.2 million and $69.0 million at December 31, 1996 and
March 31, 1997, respectively. The market value of the Cairn shares approximated
$115.6 million and $110.5 million at December 31, 1996 and March 31, 1997,
respectively. In accordance with SFAS 115, at December 31, 1996, and March 31,
1997, respectively, investments were increased by $20.4 million and $41.5
million in gross unrealized holding gains, stockholders'
F-11
<PAGE> 102
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
equity was increased by $11.9 million and $24.3 million, minority interest
liability was increased by $1.3 million and $2.7 million and deferred taxes
payable were increased by $7.2 million and $14.5 million.
Notes Receivable
The Company holds long-term notes receivable due from SOCO Tamtsag, other
privately held corporations and a director, with a book value of $1.7 million,
$5.3 million and $4.9 million at December 31, 1995 and 1996 and March 31, 1997.
SOCO Tamtsag shareholder loans, which bear interest at the three month LIBOR
rate plus two percent, are to be repaid from the gross receipts of SOCO Tamtsag
under certain circumstances (i.e., excess cash reserves). Any remaining balances
mature December 31, 2009. If the listing of SOCO plc on the London Stock
Exchange is consummated, these notes are expected to be contributed to the new
public company. The notes from other privately held corporations are secured by
certain assets, including stock and oil and gas properties. The notes from a
director, which originated in connection with an option to purchase 10% of the
Company's international affiliates, are unsecured and are due April 10, 1998.
The Company believes that, based on existing market conditions, the March 31,
1997 balances will be recovered in the long term. At December 31, 1995 and 1996
and March 31, 1997, the fair value of the notes receivable, based on existing
market conditions and the anticipated future net cash flow related to the notes,
approximated their carrying cost.
(4) OIL AND GAS PROPERTIES AND GAS FACILITIES
The cost of oil and gas properties at December 31, 1995 and 1996 and March
31, 1997 includes $24.2 million, $32.7 million and $32.7 million, respectively,
of unevaluated leasehold. Such properties are held for exploration, development
or resale. The following table sets forth costs incurred related to oil and gas
properties and gas processing and transportation facilities:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31, THREE MONTHS
------------------------------- ENDED MARCH 31,
1994 1995 1996 1997
-------- ------- -------- ---------------
(IN THOUSANDS)
<S> <C> <C> <C> <C>
Proved acquisitions.................. $ 44,684 $13,675 $273,088 $ 595
Acreage acquisitions................. 25,571 7,388 24,589 431
Development.......................... 156,912 62,578 43,075 20,259
Gas processing, transportation and
other.............................. 46,607 7,886 3,612 753
Exploration.......................... 5,514 8,214 4,588 1,768
-------- ------- -------- -------
$279,288 $99,741 $348,952 $23,806
======== ======= ======== =======
</TABLE>
During 1996, the Company incurred $273.1 million for domestic proved
acquisitions. Of the total acquisition expenditures, $218.4 million related to
the formation of Patina and the subsequent May 1996 acquisition (the
"Acquisition") of Gerrity Oil & Gas Corporation ("GOG"). As a result, the
Company initially retained 70% of the common stock of Patina and the former GOG
shareholders received 30% of the common stock. The Company currently owns 74% of
Patina, and it is consolidated into the Company's financial statements. The
Company recognized a net loss of $15.5 million in the second quarter of 1996 as
a result of this transaction. In 1996, the Company acquired, via three
acquisitions, incremental interests in certain properties located in the Gulf of
Mexico for a net purchase price of $72.1 million ($22.4 million of which was
classified as acreage acquisitions).
Of the total 1996 development expenditures, $12.8 million was concentrated
in the Gulf of Mexico where four wells were placed on sales with three in
progress at year end. The Company expended $8.6 million in the Piceance Basin of
western Colorado to place 22 wells on sales with one in progress at year end.
The Company expended $5.7 million in the East Washakie Basin of southern Wyoming
to place twelve wells on sales with
F-12
<PAGE> 103
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
three in progress at year end. In the Green River Basin of southern Wyoming,
$2.9 million was incurred to place five wells on sales with two in progress at
year end.
In May 1996, the Company sold a 45% interest in its Piceance Basin holdings
for $22.4 million. The Company recognized a net gain of $2.4 million as a result
of this transaction. In July 1996, the Company sold a 50% interest in its Green
River Basin gas project for $16.9 million. The Company recognized a net gain of
$7.4 million as a result of this transaction. In December 1996, the Company sold
its interests in the Giddings Field of southeast Texas for $11.8 million. The
Company recognized a net loss of $3.3 million as a result of this transaction.
Of the $20.3 million first quarter 1997 development expenditures, the
majority was concentrated in the Gulf of Mexico, the DJ Basin of Colorado, the
Washakie Basin of southern Wyoming, the Green River Basin of southern Wyoming
and the Piceance Basin of western Colorado. During the three months ended March
31, 1997, the Company placed 30 wells on sales, drilled one developmental dry
hole and had 22 wells in progress at quarter end.
The exploration costs incurred in the first quarter of 1997 were primarily
the result of seismic programs in the Gulf of Mexico and north Louisiana.
The following table summarizes the unaudited pro forma effects on the
Company's financial statements assuming significant acquisitions and
divestitures consummated during 1996 had been consummated on January 1, 1995 and
1996. Future results may differ substantially from pro forma results due to
changes in oil and gas prices, production declines and other factors. Therefore,
pro forma statements cannot be considered indicative of future operations.
<TABLE>
<CAPTION>
1995 1996
-------- --------
(IN THOUSANDS
EXCEPT PER SHARE DATA)
<S> <C> <C>
Oil and gas sales........................................... $189,734 $221,368
Total revenues.............................................. $250,986 $324,127
Production direct operating margin.......................... $131,310 $170,612
Net income (loss)........................................... $(43,638) $ 71,125
Net income (loss) per common share.......................... $ (1.65) $ 2.07
Weighted average shares outstanding......................... 30,186 31,308
</TABLE>
(5) INDEBTEDNESS
The following indebtedness was outstanding on the respective dates:
<TABLE>
<CAPTION>
DECEMBER 31,
-------------------- MARCH 31,
1995 1996 1997
-------- -------- ---------
(IN THOUSANDS)
<S> <C> <C> <C>
SOCO bank facility................................. $150,001 $ 93,731 $ 53,301
Patina bank facilities............................. -- 94,500 87,450
Less current portion............................... -- -- --
-------- -------- ---------
Senior debt.............................. $150,001 $188,231 $ 140,751
======== ======== =========
Patina subordinated notes.......................... $ -- $103,094 $ 99,913
======== ======== =========
SOCO convertible subordinated notes................ $ 84,058 $ 80,748 $ 80,324
======== ======== =========
</TABLE>
SOCO maintains a $500 million revolving credit facility ("SOCO Facility").
The facility is divided into a $400 million long-term portion and a $100 million
short-term portion. The borrowing base available under the facility was $140
million at December 31, 1996 and March 31, 1997. The majority of the borrowings
under the
F-13
<PAGE> 104
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
facility currently bear interest at LIBOR plus .75% with the remainder at prime,
with an option to select CD plus .75%. The margin on LIBOR or CD increases to 1%
when the Company's consolidated senior debt becomes greater than 80% of its
consolidated tangible net worth as defined. During 1996, the average interest
rate under the revolver was 6.4%. The Company pays certain fees based on the
unused portion of the borrowing base. Among other requirements, covenants
require maintenance of a current working capital ratio of 1 to 1 as defined,
limit the incurrence of debt and restrict dividends, stock repurchases, certain
investments, other indebtedness and unrelated business activities. Such
restricted payments are limited by a formula that includes underwriting
proceeds, cash flow and other items. Based on such limitations, more than $60
million and $70 million was available for the payment of dividends and other
restricted payments at December 31, 1996 and March 31, 1997, respectively.
Simultaneously with the Acquisition, Patina entered into a bank credit
agreement. The agreement consists of (a) a facility provided to Patina and SOCO
Wattenberg (the "SWAT Facility") and (b) a facility provided to GOG (the "GOG
Facility").
The SWAT Facility is a revolving credit facility in an aggregate amount up
to $102 million. The amount available for borrowing under the SWAT Facility will
be limited to a semiannually adjusted borrowing base that equaled $85 million at
December 31, 1996. At December 31, 1996, $67.5 million was outstanding under the
SWAT Facility.
The GOG Facility is a revolving credit facility in an aggregate amount up
to $51 million. The amount available for borrowing under the GOG Facility will
be limited to a fluctuating borrowing base that equaled $35 million at December
31, 1996. At December 31, 1996, $27.0 million was outstanding under the GOG
Facility. The GOG Facility was used primarily to refinance GOG's previous bank
credit facility and pay for costs associated with the Acquisition.
In March 1997, GOG was merged into Patina and an amended bank credit
agreement (the "Patina Facility") was consummated. The Patina Facility is a
revolving credit facility in an aggregate amount up to $140 million. The
borrowing base available under the facility was $120 million at March 31, 1997.
Effective May 1, 1997, the borrowing base was reduced to $110 million. Patina
may elect that all or a portion of the facility bear interest at a rate per
annum equal to: (i) the higher of (a) prime rate plus a margin equal to .25%
(the "Applicable Margin") and (b) the Federal Funds Effective Rate plus .5% plus
the Applicable Margin, or (ii) the rate at which Eurodollar deposits for one,
two, three or six months (as selected by Patina) are offered in the interbank
Eurodollar market plus a margin which fluctuates from .625% to 1.125% determined
by a debt to EBITDA ratio. During both the period subsequent to the Acquisition
through December 31, 1996 and the three months ended March 31, 1997, the average
interest rate under the facilities was 6.9%.
The Patina Facility agreement contains certain financial covenants,
including but not limited to a maximum total debt to capitalization ratio, a
maximum total debt to EBITDA ratio and a minimum current ratio. The bank credit
agreement also contains certain negative covenants, including but not limited to
restrictions on indebtedness; certain liens; guaranties, speculative derivatives
and other similar obligations; asset dispositions; dividends, loans and
advances; creation of subsidiaries; investments; leases; acquisitions; mergers;
changes in fiscal year; transactions with affiliates; changes in business
conducted; sale and leaseback and operating lease transactions; sale of
receivables; prepayment of other indebtedness; amendments to principal
documents; pledges of assets; issuance of securities; and non speculative
commodity hedging.
Simultaneously with the Acquisition, Patina recorded $100 million of 11.75%
subordinated notes due July 15, 2004 issued by GOG on July 1, 1994. In
connection with the Acquisition, Patina also repurchased $1.2 million of the
notes. As part of the purchase accounting, the remaining notes were reflected in
the accompanying financial statements at a market value of $104.6 million or
105.875% of their principal amount. Patina assumed the notes in March 1997 when
GOG was merged into Patina. During 1996, an additional $1.5 million of the notes
were repurchased by the Company and retired. During the first quarter of 1997,
F-14
<PAGE> 105
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
$3.2 million of the notes were repurchased by the Company and retired. Interest
is payable each January 15 and July 15. The notes are redeemable at the option
of Patina, in whole or in part, at any time on or after July 15, 1999, initially
at 105.875% of their principal amount, declining to 100% on or after July 15,
2001. Upon the occurrence of a change of control, as defined in the notes,
Patina would be obligated to make an offer to purchase all outstanding notes at
a price of 101% of the principal amount thereof. In addition, Patina would be
obligated, subject to certain conditions, to make offers to purchase notes with
the net cash proceeds of certain asset sales or other dispositions of assets at
a price of 101% of the principal amount thereof. The notes are unsecured general
obligations of Patina and are subordinated to all senior indebtedness of Patina
and to any existing and future indebtedness of Patina's subsidiaries. The notes
contain covenants that, among other things, limit the ability of Patina to incur
additional indebtedness, pay dividends, engage in transactions with shareholders
and affiliates, create liens, sell assets, engage in mergers and consolidations
and make investments in unrestricted subsidiaries.
In 1994, SOCO issued $86.3 million of 7% convertible subordinated notes due
May 15, 2001. The net proceeds were $83.4 million. The notes are convertible
into common stock at $22.57 per share. Under the terms of the notes, common
stock dividends not paid out of retained earnings reduce the conversion price
when paid. The notes are redeemable at the option of the Company on or after May
15, 1997, initially at 103.51% of principal, and at prices declining to 100% at
May 15, 2000. During 1996 and the first quarter of 1997, the Company repurchased
$3.8 million and $534,000, respectively, of these notes in accordance with a
repurchase program.
Scheduled maturities of indebtedness for the next five years are zero in
1997 and 1998, $87.5 million in 1999, $53.3 million in 2000 and $81.9 million in
2001. The long-term portions of the Patina Facilities and SOCO Facility are
scheduled to expire in 1999 and 2000. However, it is management's policy to
renew both the short-term and long-term facilities and extend their maturities
on a regular basis.
Consolidated cash payments for interest were $9.9 million, $22.1 million
and $21.9 million, respectively, for 1994, 1995 and 1996. Consolidated cash
payments for interest were $2.2 million and $7.8 million, respectively, for the
quarters ended March 31, 1996 and 1997.
(6) STOCKHOLDERS' EQUITY
A total of 75 million common shares, $.01 par value, are authorized of
which 31.5 million were issued at December 31, 1996 and March 31, 1997. The
Company also has 2.1 million warrants outstanding. The warrants are exercisable
at a price of $21.04 per share. Under the terms of the warrants, common stock
dividends not paid out of retained earnings reduce the exercise price when paid
and increase the number of warrants outstanding. Half of the warrants expire in
each of February 1998 and February 1999. In 1995, the Company issued 1.2 million
shares of common stock, with 1.1 million shares issued in exchange for acquired
property interests and 138,000 shares issued primarily for the exercise of stock
options. In 1996, the Company issued 666,000 shares of common stock, with
399,000 shares issued in exchange for the remaining outstanding stock of SOCO
Offshore and 267,000 shares issued primarily for the exercise of stock options.
In 1996, the Company repurchased 725,000 shares of common stock for $7.0
million. During the three months ended March 31, 1997, the Company issued 88,000
shares of common stock primarily for the exercise of stock options. During the
first quarter of 1997, the Company repurchased 740,000 shares of common stock
for $12.2 million. Quarterly dividends of $.065 per share were paid in 1995 and
1996 and the first quarter of 1997. For book purposes, for the period between
June 1995 and September 1996, the common stock dividends were in excess of
retained earnings and as such were treated as distributions of capital.
A total of 10 million preferred shares, $.01 par value, are authorized. In
1993, 4.1 million depositary shares (each representing a quarter interest in a
share of $100 liquidation value stock) of 6% preferred stock were sold through
an underwriting. The net proceeds were $99.3 million. The stock is convertible
into common stock at $20.46 per share. Under the terms of the stock, common
stock dividends not paid out of retained
F-15
<PAGE> 106
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
earnings reduce the conversion price when paid. The stock is exchangeable at the
option of the Company for 6% convertible subordinated debentures on any dividend
payment date. The 6% convertible preferred stock is currently redeemable at the
option of the Company. The liquidation preference is $25.00 per depositary
share, plus accrued and unpaid dividends. At December 31, 1996 and March 31,
1997, the redemption price was $26.05 and $25.90, respectively, per depositary
share. The redemption price declines $.15 per year to $25.00 per depositary
share in 2003. During 1996, the Company repurchased 6,000 depositary shares for
$142,000. The Company paid $6.2 million, $6.2 million and $1.6 million ($1.50
per 6% convertible depositary share per annum) in preferred dividends during
1995, 1996 and the three months ended March 31, 1997.
Earnings per share are computed by dividing net income, less dividends on
preferred stock, by weighted average shares outstanding. Differences between
primary and fully diluted earnings per share were insignificant for all periods
presented.
The Company maintains a stock option plan for certain employees providing
for the issuance of options at prices not less than fair market value. Options
to acquire up to three million shares of common stock may be outstanding at any
given time. The specific terms of grant and exercise are determined by a
committee of independent members of the Board. A stock grant and option plan is
also maintained by the Company whereby each nonemployee Director receives 500
common shares quarterly in payment of their annual retainer. It also provides
for 2,500 options to be granted annually to each nonemployee Director. The
majority of currently outstanding options vest over a three year period (30%,
60%, 100%) and expire five years from the date of grant.
At December 31, 1996, the Company had two fixed stock option compensation
plans, which are described above. The Company applies APB Opinion No. 25,
"Accounting for Stock Issued to Employees", and related Interpretations in
accounting for the plans. Accordingly, no compensation cost has been recognized
for these fixed stock option plans. Had compensation cost for the Company's
fixed stock option compensation plans been determined consistent with SFAS 123,
"Accounting for Stock-Based Compensation", the Company's net income (in
thousands) and earnings per share would have been reduced to the pro forma
amounts indicated below:
<TABLE>
<CAPTION>
1995 1996
-------- -------
<S> <C> <C> <C>
Net income (loss)................................ As Reported $(39,831) $62,950
Pro forma $(40,567) $61,936
Net income (loss) per share...................... As Reported $ (1.53) $ 1.81
Pro forma $ (1.55) $ 1.78
</TABLE>
The fair value of each option grant is estimated on the date of grant using
the Black-Sholes option-pricing model with the following weighted-average
assumptions used for grants in 1995 and 1996, respectively: dividend yield of
1.9% and 2.8%; expected volatility of 46% and 44%; risk-free interest rates of
7.2% and 5.7%; and an expected life of 4.5 years.
F-16
<PAGE> 107
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
A summary of the status of the Company's two fixed stock option plans as of
December 31, 1994, 1995 and 1996 and changes during the years ended on those
dates is presented below (shares are in thousands):
<TABLE>
<CAPTION>
1994 1995 1996
------------------ ------------------ ------------------
WEIGHTED- WEIGHTED- WEIGHTED-
AVERAGE AVERAGE AVERAGE
EXERCISE EXERCISE EXERCISE
SHARES PRICE SHARES PRICE SHARES PRICE
------ --------- ------ --------- ------ ---------
<S> <C> <C> <C> <C> <C> <C>
Outstanding at beginning of year............ 1,383 $ 5.66 1,484 $12.96 1,711 $13.21
Granted..................................... 510 18.38 610 14.06 519 9.50
Exercised................................... (407) 5.35 (124) 7.34 (255) 6.69
Forfeited................................... (2) 16.14 (259) 16.62 (301) 14.71
----- ----- -----
Outstanding at end of year.................. 1,484 12.96 1,711 13.21 1,674 12.72
===== ===== =====
Options exercisable at year end............. 533 743 772
Weighted-average fair value of options
granted during the year................... N/A $5.78 $3.27
</TABLE>
The following table summarizes information about fixed stock options
outstanding at December 31, 1996:
<TABLE>
<CAPTION>
OPTIONS OUTSTANDING OPTIONS EXERCISABLE
-------------------------------------------------- -------------------------------
WEIGHTED-
NUMBER AVERAGE NUMBER
OUTSTANDING AT REMAINING WEIGHTED- EXERCISABLE AT WEIGHTED-
RANGE OF DECEMBER 31, CONTRACTUAL LIFE AVERAGE DECEMBER 31, AVERAGE
EXERCISE PRICES 1996 (IN YEARS) EXERCISE PRICE 1996 EXERCISE PRICE
--------------- -------------- ---------------- -------------- -------------- --------------
<S> <C> <C> <C> <C> <C>
$ 6.00 to 8.88................ 163,000 0.9 $ 6.09 163,000 $ 6.09
9.38 to 13.75................ 771,000 3.3 10.85 260,000 13.02
14.13 to 20.13................ 740,000 2.6 16.14 349,000 16.98
--------- -------
$ 6.00 to 20.13................ 1,674,000 2.7 $12.72 772,000 $13.35
========= =======
</TABLE>
(7) FEDERAL INCOME TAXES
At December 31, 1996 and March 31, 1997, the Company had no liability for
foreign taxes. A reconciliation of the United States federal statutory rate to
the Company's effective income tax rate for the years ended December 31, 1994,
1995 and 1996 and the three months ended March 31, 1996 and 1997 follows:
<TABLE>
<CAPTION>
THREE MONTHS
ENDED
YEAR ENDED DECEMBER 31, MARCH 31,
----------------------- ------------
1994 1995 1996 1996 1997
----- ----- ----- ---- ----
<S> <C> <C> <C> <C> <C>
Federal statutory rate...................... 35% (35%) 35% 35% 35%
Loss in excess of net deferred tax
liability................................. -- 32% -- -- --
Net change in valuation allowance........... (27%) -- (29%) (56%) (4%)
Alternative minimum taxes................... (1%) -- -- -- --
---- ---- ---- ---- ---
Effective income tax rate................... 7% (3%) 6% (21%) 31%
==== ==== ==== ==== ===
</TABLE>
F-17
<PAGE> 108
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
For book purposes, the components of the net deferred tax asset and
liability at December 31, 1995 and 1996, respectively, were:
<TABLE>
<CAPTION>
1995 1996
-------- ---------
<S> <C> <C>
Deferred tax assets
NOL and capital loss carryforwards........................ $ 53,010 $ 65,126
AMT credit carryforwards.................................. 1,293 644
Production payment receivables............................ -- 32,654
Reserves and other........................................ 1,977 5,613
-------- ---------
56,280 104,037
-------- ---------
Deferred tax liabilities
Depreciable and depletable property....................... (24,018) (59,865)
Investments and other..................................... (2,171) (42,252)
Unrealized investments gains.............................. (317) (7,131)
-------- ---------
(26,506) (109,248)
-------- ---------
Deferred asset (liability).................................. 29,774 (5,211)
Valuation allowance......................................... (29,774) (3,823)
-------- ---------
Net deferred tax liability.................................. $ -- $ (9,034)
======== =========
</TABLE>
For tax purposes, Patina is not included in the Company's consolidated
United States federal income tax return. The Company, excluding Patina, had
regular net operating loss carryforwards of $112 million and alternative minimum
tax loss carryforwards of $28.9 million at December 31, 1996. These
carryforwards expire between 1997 and 2010. At December 31, 1996, the Company,
excluding Patina, had long-term capital loss carryforwards of $3.9 million which
will expire in 2000. At December 31, 1996, the Company, excluding Patina, also
had alternative minimum tax credit carryforwards of $644,000 which are available
indefinitely. Patina had regular net operating loss carryforwards of $70.2
million and alternative minimum tax loss carryforwards of $35.1 million at
December 31, 1996. Utilization of $31.9 million regular net operating loss
carryforwards and $31.6 million alternative minimum tax loss carryforwards will
be limited to $5.2 million per year as a result of the Acquisition. These
carryforwards expire from 2006 through 2011. At December 31, 1996, Patina had
alternative minimum tax credit carryforwards of $478,000 which are available
indefinitely. Current income taxes shown in the financial statements reflect
estimates of alternative minimum taxes.
(8) MAJOR CUSTOMERS
In 1994 and 1995, Amoco Production Company accounted for approximately 11%
and 10%, respectively, of revenues. In 1996, Pan Energy accounted for
approximately 11% of revenues. Management believes that the loss of any
individual purchaser would not have a material adverse impact on the financial
position or results of operations of the Company.
(9) COMMITMENTS AND CONTINGENCIES
The Company rents offices at various locations under noncancelable
operating leases. Minimum future payments under such leases approximate $2.5
million for 1997, $2.4 million for 1998, $2.6 million for 1999, $2.6 million for
2000 and $1.6 million for 2001.
In August 1995, the Company was sued in the United States District Court of
Colorado by seven plaintiffs purporting to represent all persons who, at any
time since January 1, 1960, have had agreements providing for royalties from gas
production in Colorado to be paid by the Company under a number of various lease
provisions. In January 1997, the judge ordered that the class not be certified.
All remaining liability
F-18
<PAGE> 109
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
under this suit was assumed by Patina upon its formation. In January 1996, GOG
was also sued in a similar but separate class action filed in stated court. In
both suits, the plaintiffs allege that unspecified "post-production" costs
incurred prior to calculating royalty payments were deducted in breach of the
relevant lease provisions and that this fact was fraudulently concealed. The
plaintiffs seek unspecified compensatory and punitive damages and a declaratory
judgment prohibiting deduction of post-production costs prior to calculating
royalties paid to the class. The Company believes that calculations of royalties
by it and GOG are and have been proper under the relevant lease provisions, and
intends to defend these and any similar suits vigorously.
In September 1996, the Company and other interest owners in a lease in
southern Texas were sued by the royalty owners in Texas state court in Brooks
County, Texas. The Company's working interest in the lease is approximately 20%.
The complaint alleges, among other things, that the defendants have failed to
pay proper royalties under the lease and have breached their duties to
reasonably develop the lease. The plaintiffs also claim damages for fraud and
trespass, and demand actual and punitive damages. Although the complaint does
not specify the amount of damages claimed, an earlier letter from plaintiffs
claimed damages in excess of $50 million. The Company and the other interest
owners have filed an answer denying the claims and intend to contest the suit
vigorously.
At this time, the Company is unable to estimate the range of potential
loss, if any, from the foregoing uncertainties. However, the Company believes
their resolution should not have a material adverse effect upon the Company's
financial position, although an unfavorable outcome in any reporting period
could have a material impact on the Company's results of operations for that
period.
In April 1995, the Company settled a lawsuit in Harris County, Texas filed
by certain landowners relating to certain alleged problems at a Company well
site. The Company recorded a charge of $4.4 million during the first quarter of
1995 to reflect the cost of the settlement. A primary insurer honored its
commitments in full and participated in the settlement. The Company's excess
carriers have declined, to date, to honor indemnification for the loss. Based on
the advice of counsel, the Company has brought suit against the non-
participating carriers for the great majority of the cost of settlement.
However, given the time period which may be involved in resolving the matter,
the full amount of the settlement was provided for in the financial statements.
In the second quarter of 1996, the Company received $1.5 million in
proceeds which was reflected in other income related to a judgment involving a
pipeline dispute.
The Company's operations are affected by political developments and federal
and state laws and regulations. Oil and gas industry legislation and
administrative regulations are periodically changed for a variety of political,
economic and other reasons. Numerous departments and agencies, federal, state,
local and Indian, issue rules and regulations binding on the oil and gas
industry, some of which carry substantial penalties for failure to comply. The
regulatory burden on the oil and gas industry increases the Company's cost of
doing business, decreases flexibility in the timing of operations and may
adversely affect the economics of capital projects.
The financial statements reflect favorable legal proceedings only upon
receipt of cash, final judicial determination or execution of a settlement
agreement. The Company is a party to various other lawsuits incidental to its
business, none of which are anticipated to have a material adverse impact on its
financial position or results of operations.
F-19
<PAGE> 110
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(10) GUARANTOR CONDENSED CONSOLIDATING FINANCIAL INFORMATION
The Company is currently considering an offering of Senior Subordinated
Notes ("Notes"). Under the proposed terms of the Notes, all of the Company's
active subsidiaries except Patina and SOCO International (the "Unrestricted
Subsidiaries") would be guarantors of the Notes (the "Restricted Group"). The
condensed consolidating financial information below shows the impact of the
guarantors and the Unrestricted Subsidiaries to the Company's consolidated
position. "SOCO" includes all subsidiaries other than SOCO Offshore and the
Unrestricted Subsidiaries. In the aggregate, the subsidiaries other than SOCO
Offshore and the Unrestricted Subsidiaries hold less than 10% of the total
assets and revenues included in SOCO.
CONDENSED CONSOLIDATING BALANCE SHEETS
DECEMBER 31, 1996
(IN THOUSANDS)
<TABLE>
<CAPTION>
RESTRICTED GROUP
--------------------
SOCO UNRESTRICTED
SOCO OFFSHORE SUBSIDIARIES ELIMINATIONS CONSOLIDATED
-------- -------- ------------ ------------ ------------
<S> <C> <C> <C> <C> <C>
ASSETS
Current assets................... $ 71,923 $ 37,396 $(11,241) $ -- $ 98,078
Investments...................... 246,128 -- -- (116,447) 129,681
Oil and gas properties, net...... 154,512 81,722 399,153 -- 635,387
Gas facilities and other, net.... 12,307 -- 4,006 -- 16,313
-------- -------- -------- --------- --------
Total assets........... $484,870 $119,118 $391,918 $(116,447) $879,459
======== ======== ======== ========= ========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities.............. $ 46,481 $ 14,857 $ 27,572 $ -- $ 88,910
Senior debt...................... 93,731 -- 94,500 -- 188,231
Senior subordinated notes........ -- -- 103,094 -- 103,094
Convertible subordinated notes... 80,748 -- -- -- 80,748
Deferred taxes payable........... (21,781) -- 30,815 -- 9,034
Other noncurrent liabilities..... 2,944 15,289 9,831 -- 28,064
Minority interest................ -- -- 86,710 -- 86,710
Total stockholders' equity....... 282,747 88,972 39,396 (116,447) 294,668
-------- -------- -------- --------- --------
Total liabilities and
stockholders'
equity............... $484,870 $119,118 $391,918 $(116,447) $879,459
======== ======== ======== ========= ========
</TABLE>
F-20
<PAGE> 111
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
YEAR ENDED DECEMBER 31, 1996
(IN THOUSANDS EXCEPT PER SHARE DATA)
<TABLE>
<CAPTION>
RESTRICTED GROUP
--------------------
SOCO UNRESTRICTED
SOCO OFFSHORE SUBSIDIARIES CONSOLIDATED
-------- -------- ------------ ------------
<S> <C> <C> <C> <C>
Revenues...................................... $160,497 $22,128 $109,789 $292,414
Expenses...................................... 124,141 13,151 80,421 217,713
-------- ------- -------- --------
Income before taxes and minority interest..... 36,356 8,977 29,368 74,701
Income taxes.................................. (18,256) -- 22,602 4,346
Minority interest in subsidiaries............. -- 639 6,766 7,405
-------- ------- -------- --------
Net income.................................... $ 54,612 $ 8,338 $ -- $ 62,950
======== ======= ======== ========
</TABLE>
CONDENSED CONSOLIDATING BALANCE SHEETS
MARCH 31, 1997
(IN THOUSANDS)
<TABLE>
<CAPTION>
RESTRICTED GROUP
-------------------
SOCO UNRESTRICTED
SOCO OFFSHORE SUBSIDIARIES ELIMINATIONS CONSOLIDATED
-------- -------- ------------ ------------ ------------
<S> <C> <C> <C> <C> <C>
ASSETS
Current assets......................... $ 15,866 $ 45,964 $ 28,123 $ -- $ 89,953
Investments............................ 267,955 -- -- (143,940) 124,015
Oil and gas properties, net............ 156,482 85,849 393,302 -- 635,633
Gas facilities and other, net.......... 9,986 -- 2,944 -- 12,930
-------- -------- -------- --------- --------
Total assets................. $450,289 $131,813 $424,369 $(143,940) $862,531
======== ======== ======== ========= ========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities.................... $ 44,310 $ 21,767 $ 23,788 $ -- $ 89,865
Senior debt............................ 53,301 -- 87,450 -- 140,751
Senior subordinated notes.............. -- -- 99,913 -- 99,913
Convertible subordinated notes......... 80,324 -- -- -- 80,324
Deferred taxes payable................. (17,742) -- 43,036 -- 25,294
Other noncurrent liabilities........... 3,042 13,506 12,218 -- 28,766
Minority interest...................... -- -- 86,289 -- 86,289
Total stockholders' equity............. 287,054 96,540 71,675 (143,940) 311,329
-------- -------- -------- --------- --------
Total liabilities and
stockholders' equity....... $450,289 $131,813 $424,369 $(143,940) $862,531
======== ======== ======== ========= ========
</TABLE>
F-21
<PAGE> 112
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
THREE MONTHS ENDED MARCH 31, 1997
(IN THOUSANDS EXCEPT PER SHARE DATA)
<TABLE>
<CAPTION>
SOCO UNRESTRICTED
SOCO OFFSHORE SUBSIDIARIES
------- ------------ ------------
<S> <C> <C> <C>
Revenues.................................................... $40,974 $16,688 $31,093
Expenses.................................................... 24,574 9,120 23,461
------- ------- -------
Income before taxes and minority interest................... 16,400 7,568 7,632
Income taxes................................................ 1,696 2,346 4,829
Minority interest in subsidiaries........................... -- -- 2,803
------- ------- -------
Net income.................................................. $14,704 $ 5,222 --
======= ======= =======
</TABLE>
(11) UNAUDITED SUPPLEMENTAL OIL AND GAS RESERVE INFORMATION
Independent petroleum consultants directly evaluated 58%, 81%, and 99% of
proved reserves at December 31, 1994, 1995 and 1996, respectively, and performed
a detailed review of properties which comprised in excess of 80% of proved
reserve value in 1994. All reserve estimates are based on economic and operating
conditions at that time. Future net cash flows as of each year end were computed
by applying then current prices to estimated future production less estimated
future expenditures (based on current costs) to be incurred in producing and
developing the reserves.
Future prices received for production and future production costs may vary,
perhaps significantly, from the prices and costs assumed for purposes of these
estimates. There can be no assurance that the proved reserves will be developed
within the periods indicated or that prices and costs will remain constant. With
respect to certain properties that historically have experienced seasonal
curtailment, the reserve estimates assume that the seasonal pattern of such
curtailment will continue in the future. There can be no assurance that actual
production will equal the estimated amounts used in the preparation of reserve
projections.
There are numerous uncertainties inherent in estimating quantities of
proved reserves and in projecting future rates of production and timing of
development expenditures. The data in the tables below represent estimates only.
Oil and gas reserve engineering must be recognized as a subjective process of
estimating underground accumulations of oil and gas that cannot be measured in
an exact way, and estimates of other engineers might differ materially from
those shown below. The accuracy of any reserve estimate is a function of the
quality of available data and engineering and geological interpretation and
judgment. Results of drilling, testing and production after the date of the
estimate may justify revisions. Accordingly, reserve estimates are often
materially different from the quantities of oil and gas that are ultimately
recovered.
F-22
<PAGE> 113
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
All reserves included in the tables below are located onshore in the United
States and in the waters of the Gulf of Mexico.
QUANTITIES OF PROVED RESERVES
<TABLE>
<CAPTION>
CRUDE OIL NATURAL GAS
--------- -----------
(MBBL) (MMCF)
<S> <C> <C>
Balance, December 31, 1993.................................. 31,930 430,089
Revisions................................................. (296) (102,871)
Extensions, discoveries and additions..................... 3,981 136,583
Production................................................ (4,366) (43,809)
Purchases................................................. 3,866 93,334
Sales..................................................... (138) (2,075)
------ --------
Balance, December 31, 1994.................................. 34,977 511,251
Revisions................................................. (3,633) (89,455)
Extensions, discoveries and additions..................... 782 32,835
Production................................................ (4,278) (53,227)
Purchases................................................. 2,002 13,449
Sales..................................................... (5,603) (19,135)
------ --------
Balance, December 31, 1995.................................. 24,247 395,718
Revisions................................................. 4,127 41,385
Extensions, discoveries and additions..................... 1,039 61,821
Production................................................ (3,884) (55,840)
Purchases................................................. 16,725 225,335
Sales..................................................... (1,757) (62,783)
------ --------
Balance, December 31, 1996.................................. 40,497 605,636
====== ========
</TABLE>
The table above includes reserves attributable to minority interests of
18.6 million BOE at December 31, 1996.
The Company's interest in the Russian joint venture (Permtex) is accounted
for under the equity method. At December 31, 1994, 1995 and 1996, the Company's
equity in Permtex proved reserves was 8.0 million BOE, 7.8 million BOE and 8.6
million BOE, respectively. These amounts are not included in the quantities
above.
PROVED DEVELOPED RESERVES
<TABLE>
<CAPTION>
CRUDE NATURAL
OIL GAS
------ -------
(MBBL) (MMCF)
<S> <C> <C>
December 31, 1993........................................... 18,032 268,349
====== =======
December 31, 1994........................................... 26,104 353,930
====== =======
December 31, 1995........................................... 21,637 330,524
====== =======
December 31, 1996........................................... 31,869 443,441
====== =======
</TABLE>
F-23
<PAGE> 114
SNYDER OIL CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
STANDARDIZED MEASURE
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------
1995 1996
---------- ----------
(IN THOUSANDS)
<S> <C> <C>
Future cash inflows......................................... $1,037,363 $3,144,813
Future costs:
Production................................................ (374,516) (781,550)
Development............................................... (57,959) (233,617)
---------- ----------
Future net cash flows....................................... 604,888 2,129,646
Undiscounted income taxes................................... (63,248) (540,520)
---------- ----------
After tax net cash flows.................................... 541,640 1,589,126
10% discount factor......................................... (210,534) (650,534)
---------- ----------
Standardized measure........................................ $ 331,106 $ 938,592
========== ==========
</TABLE>
The table above includes standardized measure attributable to minority
interests of $129.5 million at December 31, 1996.
At December 31, 1995 and 1996, the Company's equity in the net present
value of Permtex proved reserves was $10.6 million and $25.8 million. These
amounts are not included in the standardized measure above.
CHANGES IN STANDARDIZED MEASURE
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
-------------------------------
1994 1995 1996
--------- -------- --------
(IN THOUSANDS)
<S> <C> <C> <C>
Standardized measure, beginning of year........... $ 340,518 $361,682 $331,106
Revisions:
Prices and costs................................ (73,330) 18,975 528,525
Quantities...................................... (42,260) (30,495) 10,915
Development costs............................... (12,995) (2,806) (13,027)
Accretion of discount........................... 34,052 36,168 46,045(a)
Income taxes.................................... 2,195 16,249 (242,536)
Production rates and other...................... (9,506) (29,991) 11,052
--------- -------- --------
Net revisions........................... (101,844) 8,100 340,974
Extensions, discoveries and additions............. 68,002 18,171 111,797
Production........................................ (97,330) (96,232) (146,257)
Future development costs incurred................. 99,175 43,551 18,400
Purchases......................................... 55,072 31,142 330,225(a)
Sales............................................. (1,911) (35,308) (47,653)
--------- -------- --------
Standardized measure, end of year................. $ 361,682 $331,106 $938,592
========= ======== ========
</TABLE>
- ---------------
(a) In 1996, $12.9 million in "Purchases" were included in "Accretion of
Discount" due to the significance of the accretion related to the reserves
purchased in the Acquisition.
F-24
<PAGE> 115
======================================================
NO DEALER, SALESPERSON OR ANY OTHER PERSON HAS BEEN AUTHORIZED TO GIVE ANY
INFORMATION OR TO MAKE ANY REPRESENTATIONS OTHER THAN THOSE CONTAINED IN THIS
PROSPECTUS SUPPLEMENT OR THE ACCOMPANYING PROSPECTUS IN CONNECTION WITH THE
OFFERING COVERED BY THIS PROSPECTUS SUPPLEMENT OR THE ACCOMPANYING PROSPECTUS
AND, IF GIVEN OR MADE, SUCH INFORMATION OR REPRESENTATIONS MUST NOT BE RELIED
UPON AS HAVING BEEN AUTHORIZED BY THE COMPANY OR THE UNDERWRITERS. THIS
PROSPECTUS SUPPLEMENT AND THE ACCOMPANYING PROSPECTUS DO NOT CONSTITUTE AN OFFER
TO SELL OR A SOLICITATION OF AN OFFER TO BUY THE SECURITIES OFFERED HEREBY IN
ANY JURISDICTION WHERE, OR TO ANY PERSON TO WHOM, IT IS UNLAWFUL TO MAKE SUCH
OFFER OR SOLICITATION. NEITHER THE DELIVERY OF THIS PROSPECTUS SUPPLEMENT NOR
THE ACCOMPANYING PROSPECTUS NOR ANY SALE MADE HEREUNDER SHALL, UNDER ANY
CIRCUMSTANCES, CREATE AN IMPLICATION THAT THE INFORMATION CONTAINED HEREIN IS
CORRECT AS OF ANY TIME SUBSEQUENT TO THE DATE HEREOF.
---------------------
TABLE OF CONTENTS
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
PROSPECTUS SUPPLEMENT
Prospectus Supplement Summary................... S-3
Risk Factors.................................... S-12
Forward-Looking Information..................... S-18
Use of Proceeds................................. S-19
Capitalization.................................. S-20
Unaudited Pro Forma Condensed Consolidated
Restricted Group Financial Information........ S-21
Selected Financial Data......................... S-26
Management's Discussion and Analysis of
Financial Condition and Results of
Operations.................................... S-27
Business and Properties......................... S-36
Management...................................... S-49
Description of Notes............................ S-53
Description of the Credit Facility.............. S-86
Underwriting.................................... S-87
Legal Matters................................... S-88
Experts......................................... S-88
Glossary........................................ S-89
Index to Financial Statements................... F-1
PROSPECTUS
Available Information........................... 2
Incorporation of Certain Documents by
Reference..................................... 2
The Company..................................... 3
The Subsidiary Guarantors....................... 3
Use of Proceeds................................. 3
Ratios of Earnings to Fixed Charges and Earnings
to Combined Fixed Charges and Preferred Stock
Dividends..................................... 3
Description of Debt Securities.................. 4
Description of Preferred Stock.................. 14
Description of Depositary Shares................ 17
Description of Common Stock..................... 19
Description of Warrants......................... 21
Global Securities............................... 23
Plan of Distribution............................ 25
Validity of Securities.......................... 26
Experts......................................... 26
</TABLE>
======================================================
======================================================
[SOCO LOGO]
SNYDER OIL CORPORATION
$175,000,000
8 3/4% SENIOR SUBORDINATED NOTES
DUE 2007
---------------------
PROSPECTUS SUPPLEMENT
---------------------
NATIONSBANC CAPITAL MARKETS, INC.
CHASE SECURITIES INC.
SMITH BARNEY INC.
PETRIE PARKMAN & CO.
JUNE 5, 1997
======================================================
