FILED PURSUANT TO RULE 424(b)(5)
REGISTRATION NO. 333-64692
$200,000,000
[SWIFT LOGO]
9 3/8% Senior Subordinated Notes Due 2012
------------------
We will pay interest on the notes on each May 1 and November 1. The first
interest payment will be made on November 1, 2002. There is no sinking fund for
the notes.
We may redeem the notes on and after May 1, 2007 at the prices listed on
page S-53. Prior to May 1, 2005, we may redeem up to 33 1/3% of the notes at a
price of 109.375% with the proceeds of qualified offerings of our equity.
The notes will be unsecured senior subordinated obligations and will be
subordinated in right of payment to all our existing and future senior debt,
including our bank debt.
INVESTING IN THE NOTES INVOLVES RISKS. SEE "RISK FACTORS" BEGINNING ON
PAGE S-11 OF THIS PROSPECTUS SUPPLEMENT AND ON PAGE 2 OF THE ACCOMPANYING
PROSPECTUS.
UNDERWRITING PROCEEDS TO
PRICE TO DISCOUNTS AND SWIFT ENERGY
PUBLIC(1) COMMISSIONS COMPANY(1)
------------ ------------- ------------
Per Note........................................ 100% 2.5% 97.5%
Total........................................... $200,000,000 $5,000,000 $195,000,000
(1) Plus accrued interest, if any, from April 16, 2002
Delivery of the notes, in book-entry form only, will be made on or about
April 16, 2002.
Neither the Securities and Exchange Commission nor any state securities
commission has approved or disapproved these securities or determined if this
prospectus supplement or the accompanying prospectus to which it relates is
truthful or complete. Any representation to the contrary is a criminal offense.
CREDIT SUISSE FIRST BOSTON
BANC ONE CAPITAL MARKETS, INC. CIBC WORLD MARKETS
A.G. EDWARDS & SONS, INC. FRIEDMAN BILLINGS RAMSEY
JEFFERIES & COMPANY, INC. JPMORGAN
MORGAN STANLEY UBS WARBURG
The date of this prospectus supplement is April 11, 2002
[INSIDER FRONT COVER]
PICTURE
This document is in two parts. The first part is this prospectus
supplement, which describes the terms of the notes. The second part is the
accompanying prospectus, which gives more general information, some of which may
not apply to the notes. In this prospectus supplement, "Swift," "we," "us," and
"our" refer to Swift Energy Company and its subsidiaries, unless otherwise
indicated.
IF THE DESCRIPTION OF THE NOTES VARIES BETWEEN THIS PROSPECTUS SUPPLEMENT
AND THE ACCOMPANYING PROSPECTUS, YOU SHOULD RELY ON THE INFORMATION IN THIS
PROSPECTUS SUPPLEMENT.
YOU SHOULD RELY ONLY ON THE INFORMATION WE HAVE INCLUDED OR INCORPORATED BY
REFERENCE IN THIS PROSPECTUS SUPPLEMENT AND THE ACCOMPANYING PROSPECTUS. WE HAVE
NOT AUTHORIZED ANYONE TO PROVIDE YOU WITH ADDITIONAL OR DIFFERENT INFORMATION.
IF YOU RECEIVE ANY UNAUTHORIZED INFORMATION, YOU MUST NOT RELY ON IT. WE ARE
OFFERING TO SELL THE NOTES ONLY IN STATES WHERE SALES ARE PERMITTED. YOU SHOULD
NOT ASSUME THAT THE INFORMATION WE HAVE INCLUDED IN THIS PROSPECTUS SUPPLEMENT
OR THE ACCOMPANYING PROSPECTUS IS ACCURATE AS OF ANY DATE OTHER THAN THE DATE OF
THIS PROSPECTUS SUPPLEMENT OR THE ACCOMPANYING PROSPECTUS OR THAT ANY
INFORMATION WE HAVE INCORPORATED BY REFERENCE IS ACCURATE AS OF ANY DATE OTHER
THAN THE DATE OF THE DOCUMENT INCORPORATED BY REFERENCE.
See the "Glossary of Terms" beginning on page S-100 for explanations of
abbreviations and terms used in this prospectus supplement.
------------------
TABLE OF CONTENTS
PROSPECTUS SUPPLEMENT
PAGE
-----
SUMMARY.............................. S-1
RISK FACTORS......................... S-11
USE OF PROCEEDS...................... S-15
CAPITALIZATION....................... S-16
SELECTED HISTORICAL CONSOLIDATED
FINANCIAL DATA..................... S-17
NOTES TO SELECTED HISTORICAL
CONSOLIDATED FINANCIAL DATA........ S-18
MANAGEMENT'S DISCUSSION AND ANALYSIS
OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS...................... S-19
BUSINESS AND PROPERTIES.............. S-28
MANAGEMENT........................... S-45
PAGE
-----
DESCRIPTION OF EXISTING
INDEBTEDNESS....................... S-48
DESCRIPTION OF THE NOTES............. S-50
CERTAIN U.S. FEDERAL INCOME TAX
CONSIDERATIONS..................... S-91
UNDERWRITING......................... S-96
NOTICE TO CANADIAN RESIDENTS......... S-97
LEGAL MATTERS........................ S-98
EXPERTS.............................. S-99
OTHER MATTERS........................ S-99
GLOSSARY OF TERMS.................... S-100
CONSOLIDATED FINANCIAL STATEMENTS.... F-1
PROSPECTUS
PAGE
----
ABOUT THIS PROSPECTUS................. 1
WHERE YOU CAN FIND MORE INFORMATION... 1
RISK FACTORS.......................... 2
FORWARD-LOOKING STATEMENTS............ 3
THE COMPANY........................... 4
RATIO OF EARNINGS TO FIXED CHARGES.... 4
USE OF PROCEEDS....................... 5
PAGE
----
DESCRIPTION OF DEBT SECURITIES........ 5
DESCRIPTION OF CAPITAL STOCK.......... 13
DESCRIPTION OF DEPOSITARY SHARES...... 17
DESCRIPTION OF WARRANTS............... 18
SELLING SHAREHOLDERS.................. 18
PLAN OF DISTRIBUTION.................. 19
LEGAL OPINIONS........................ 20
EXPERTS............................... 21
INCORPORATION OF ADDITIONAL DOCUMENTS BY REFERENCE
In addition to the documents referred to under "Where You Can Find More
Information" in the accompanying prospectus, this prospectus supplement
incorporates by reference our Annual Report on Form 10-K for the fiscal year
ended December 31, 2001 filed by us with the Securities and Exchange Commission.
ii
SUMMARY
This summary highlights selected information from this prospectus
supplement and the accompanying prospectus, but may not contain all of the
information that is important to you. This prospectus supplement and the
accompanying prospectus include specifics of the offering of the notes and their
terms and information about our business and financial data. Before making an
investment decision, we encourage you to read this prospectus supplement and the
accompanying prospectus, including the "Risk Factors" section in each
prospectus, and the documents we incorporate by reference. When we describe our
year end 2001 proved reserves on a pro forma basis, we are giving effect to our
January 2002 acquisition of an estimated 62.1 Bcfe of proved reserves at year
end 2001 in the TAWN fields in New Zealand and to our March 2002 acquisition of
an estimated 5.7 Bcfe of proved reserves at year end 2001 in the Rimu/Kauri area
in New Zealand from Antrim Oil and Gas Limited. Our actual year end 2001 proved
reserves prior to the above acquisitions were 645.8 Bcfe.
ABOUT SWIFT
Swift Energy Company engages in developing, exploring, acquiring, and
operating oil and gas properties, with a focus on onshore oil and natural gas
reserves in Texas and Louisiana and onshore oil and natural gas reserves in New
Zealand. At year end 2001, on a pro forma basis, we had estimated proved
reserves of 713.6 Bcfe, concentrated 48% in Texas, 25% in Louisiana and 24% in
New Zealand. Approximately 52% of these reserves are natural gas. For the 12
months ended December 31, 2001, we generated EBITDA of $136.8 million.
The following table of pro forma proved reserves highlights our core areas:
PRO FORMA PROVED RESERVES
AS OF YEAR END 2001
-----------------------------------
PROVED PERCENT OF
AREA LOCATION RESERVES (BCFE) PROVED RESERVES
---- -------- ----------------- ---------------
AWP Olmos........................... South Texas 207.5 29%
Masters Creek....................... Central Louisiana 104.8 15%
Brookeland.......................... East Texas 59.1 8%
Lake Washington..................... South Louisiana 72.5 10%
Rimu/Kauri.......................... New Zealand 107.6 15%
TAWN................................ New Zealand 62.1 9%
Other Domestic..................................... 100.0 14%
----- ----
Total......................................... 713.6 100%
We have a well-balanced portfolio of oil and gas properties and prospects.
The AWP Olmos, Lake Washington and New Zealand areas are characterized by
long-lived reserves that we expect to produce steadily over a long period of
time. The Masters Creek and Brookeland areas are characterized by shorter-lived
reserves with high initial rates of production that decline more rapidly. Based
on 2001 year end domestic proved reserves and 2001 production, our domestic
properties had an estimated average reserve life of 12.3 years. An independent
engineering firm's report in late 2001 estimates the Rimu/Kauri development area
to have a 25-30 year life. In addition to our core areas, we have a number of
emerging growth areas that may become additional core operating areas for us.
These growth areas are described in the "Business and Properties" section of
this prospectus supplement.
RECENT DEVELOPMENTS
Effective January 25, 2002, we expanded our core areas of operation by
acquiring interests in the four TAWN fields in New Zealand for approximately
$54.4 million. This acquisition, which also included significant infrastructure,
added proved developed reserves estimated to be 62.1 Bcfe at December 31, 2001,
all of which are proved producing and approximately 75% of which were classified
as natural gas. In March 2002, we purchased an additional 5% interest in our
permit 38719, where the Rimu and Kauri discoveries are located, from Antrim Oil
and Gas Limited for 220,000 shares of Swift common stock and an effective date
adjustment of approximately $530,000. This acquisition added estimated reserves
at year
S-1
end 2001 of 5.7 Bcfe and increased our interest in the permit to 95%. We also
acquired Antrim's interest in another New Zealand permit, which doubled our
interest there to 15%. In addition, the construction of our Rimu production
station in New Zealand has been completed, which will allow us to commence sale
of production from our Rimu discovery in April 2002.
Since acquiring the Lake Washington field in March 2001, we have drilled a
total of eight wells in this field. The results of these wells support our
belief that there is additional reserves potential in multiple horizons located
around the salt dome in the center of the field ranging from depths of 1,300 to
18,000 feet. We have increased average monthly production in this field net to
Swift's interests from approximately 652 BOE per day when we acquired the field
to approximately 1,236 BOE per day during February 2002. The field currently
produces oil and natural gas liquids from 26 wells. As a result of our drilling
and remapping of the field and improvement in production levels, we are
currently focusing most of our 2002 domestic drilling budget on 20 development
wells and two exploratory wells in this field. We have 29 proved undeveloped
drilling locations in this field.
Our first quarter 2002 production increased over 17.5% to at least 12.1
Bcfe compared to production of 10.3 Bcfe during the first quarter of 2001. This
is also a 5% increase from 11.5 Bcfe produced during the fourth quarter of 2001.
Approximately 20% of the first quarter 2002 production comes from our new TAWN
core area in New Zealand.
On March 28, 2002, we received $7.5 million for our interest in the Samburg
project located in Western Siberia, Russia as a result of the sale by a third
party of its ownership in a Russian joint stock company, which owned and
operated this field. This cash payment will result in our recognition of a $7.5
million non-recurring pre-tax gain in the first quarter of 2002.
In late March and early April 2002, we entered into hedges covering a
portion of both our oil and natural gas production from May 2002 through
December 2002. These hedges are in the form of participating collars that are a
series of puts and calls, in which we will participate in 60% of the price
received above the cap. The counter party to the gas contracts is a member of
our bank syndicate under our credit facility and another member is the counter
party to the oil contracts. One group of oil collars has a floor of $20.00 per
Bbl and a cap of $27.52 per Bbl and covers 25,000 Bbl per month, and the other
group has a floor of $21.00 per Bbl and a cap of $27.65 and covers 20,000 Bbl
per month. One group of natural gas collars has a floor of $2.50 per MMBtu and a
cap of $4.21 per MMBtu and covers 200,000 MMBtu per month of our domestic
production, and the other group has a floor of $2.75 per MMBtu and a cap of
$4.55 per MMBtu and covers 80,000 MMBtu per month of our domestic production.
All of our New Zealand natural gas production for 2002 is contracted for at
defined prices under two long-term, reserve-based contracts.
We have filed a prospectus supplement dated April 9, 2002 with the SEC
relating to the offer and sale of 1,500,000 shares of our common stock with an
over-allotment option, which has been exercised in full, of 225,000 additional
shares of common stock. This stock was offered in a separate public offering
which is expected to close April 12, 2002. The net proceeds of the common stock
offering are estimated to be approximately $30.5 million, which will be used to
reduce a portion of the outstanding indebtedness under our credit facility
incurred in connection with our current acquisitions, development and
exploitation activities. This notes offering and the offering of common stock
are not conditioned upon each other.
On April 8, 2002, Moody's Investors Service announced it had assigned a B3
rating to this notes offering. In connection with this rating, Moody's announced
further that it had changed the rating of our existing $125.0 million of 10 1/4%
senior subordinated notes due 2009 to B3, down from B2. On April 10, 2002,
Standard & Poor's announced it had assigned a B rating to this notes offering.
In connection with this rating, Standard & Poor's announced further that it had
reaffirmed its existing B rating on our 10 1/4% senior subordinated notes due
2009.
S-2
COMPETITIVE STRENGTHS AND BUSINESS STRATEGY
SUCCESSFUL TRACK RECORD
Our growth in reserves and production has resulted primarily from drilling
activities in our core areas combined with producing property acquisitions. Over
the five-year period ended December 31, 2001, our estimated proved reserves grew
from 258.7 Bcfe to 713.6 Bcfe on a pro forma basis. Over the same period, our
net cash provided by operations increased from $37.1 million to $139.9 million.
We believe that our experience in growing our reserves will be beneficial to us
as we continue to pursue our business strategy.
BALANCED APPROACH TO ADDING RESERVES
Over the past five years, we have spent an average of 11% of our capital
expenditure budget on exploration drilling, 51% on development activities, 19%
on proved property acquisitions and 14% on lease acquisitions. Currently our
2002 capital expenditures are focused on developing and producing long-lived
reserves in Lake Washington and New Zealand, which should flatten our overall
production decline curve, strengthen our ongoing production profile and extend
our average reserve life. Our strategy is to grow through drilling on our core
properties and in emerging growth areas when oil and gas prices are strong, with
a shift toward acquisitions when prices weaken. We believe this balanced
approach has resulted in our ability to grow reserves in a relatively low cost
manner, while participating in the upside potential of exploration. Over the
five-year period ended December 31, 2001, we replaced 302% of our production at
an average cost of $1.26 per Mcfe.
CONCENTRATED FOCUS ON CORE AREAS
Our concentration of reserves and our significant acreage positions in our
core areas allow us to realize economies of scale in drilling and production.
Our domestic operations are concentrated in Texas and Louisiana, where 96% of
our domestic reserves are located. All of our international operations are
currently concentrated in New Zealand. We enhance the value of these
concentrations by acting as operator of 95% of our proved reserves at year end
2001. Our focus in our core areas has enabled us to develop and utilize several
innovative technology applications adapted to those areas, which we believe
provide us with an advantage over our competitors.
ABILITY TO BUILD UPON OUR SUCCESSFUL DISCOVERIES AND ACQUISITIONS IN NEW ZEALAND
Our New Zealand activities provide us with long-term growth opportunities
and significant potential reserves in a country with stable political and
economic conditions, existing oil and gas infrastructure and favorable tax and
royalty regimes. In April 2001, we began selling oil from extended production
testing of our New Zealand wells. We expect production and gas processing
facilities will be operational in April 2002, a significantly faster period from
initial discovery to commercial production than similar projects previously
conducted in New Zealand of which we are aware. In January 2002, we acquired the
TAWN fields. From the closing of the TAWN acquisition on January 25, 2002
through March 25, 2002, these fields have generated average daily net production
of approximately 40 MMcfe. In our TAWN acquisition, we also acquired extensive
associated processing facilities and pipelines, which give us a competitive
advantage through infrastructure that complements our existing fields, providing
us with access to export terminals and markets and additional excess processing
capacity for both oil and natural gas. We also have prospective areas in New
Zealand outside of the Rimu/Kauri area that we will evaluate for drilling in the
future.
EXPERIENCED TECHNICAL TEAM
We employ 35 oil and gas professionals, including geophysicists,
petrophysicists, geologists, petroleum engineers and production and reservoir
engineers, who have an average of approximately 25 years of experience in their
technical fields and have been employed by Swift for an average of over 10
years. This level of expertise and experience, coupled with our employees'
longevity with Swift, gives us a unique in-house ability to apply advanced
technologies to our drilling, acquisition and production activities.
S-3
FINANCIAL DISCIPLINE
We practice a disciplined approach to financial management and have
historically maintained a strong capital structure that preserves our ability to
execute our business plan. Key components of our financial discipline include
maintaining a balanced capital budget, establishing leverage ratios that are
appropriate given the volatility of the oil and gas markets and
opportunistically accessing the capital markets. After giving effect to our
common stock offering and this offering, as of December 31, 2001, our long-term
debt would have comprised approximately 49% of our total capitalization. As of
March 31, 2002, after the TAWN acquisition in January 2002 and the Antrim
acquisition in March 2002, and after giving effect to our common stock offering
and this offering, our long-term debt would have comprised approximately 49% of
our total capitalization. Additionally, after applying the net proceeds from our
common stock offering and this offering to reduce amounts outstanding under our
credit facility, based on our March 31, 2002 balance, we expect to have
approximately $188.9 million of available borrowing capacity. By replacing
indebtedness incurred under our revolving credit facility in connection with
acquisition, development and exploitation activity with the net proceeds from
our common stock offering and this offering, we will be implementing our
strategy of matching long-lived assets with long-term debt and equity.
S-4
THE OFFERING
Issuer........................ Swift Energy Company
Securities Offered............ $200.0 million aggregate principal amount of
9 3/8% senior subordinated notes due 2012.
Maturity Date................. May 1, 2012.
Interest Payment Dates........ May 1 and November 1 of each year, commencing
on November 1, 2002.
Ranking....................... The notes:
- are unsecured senior subordinated
obligations;
- are subordinate in right of payment to all
existing and future senior debt, including
our bank debt;
- rank equally with our senior subordinated
notes due 2009 and any future senior
subordinated debt; and
- are senior to any future junior subordinated
debt.
Subsidiary Guaranty........... If certain of our subsidiaries incur debt,
issue preferred stock or guarantee any of our
other debt, that subsidiary generally will be
required to guarantee the notes. As of the date
of this prospectus supplement, there are no
subsidiary guarantors. The guarantee of any
subsidiary will be subordinated in right of
payment to the senior debt of the subsidiary
guarantor and senior in right of payment to any
junior subordinated debt of the subsidiary
guarantor.
Optional Redemption........... On or after May 1, 2007, we may redeem some or
all of the notes at any time at the prices
listed under the heading "Description of the
Notes -- Optional Redemption."
Before May 1, 2005, we may redeem up to 33 1/3%
of the aggregate principal amount of the notes
originally issued with the proceeds from
qualified offerings of our equity at a price
equal to 109.375% of the principal amount of
the redeemed notes, plus accrued interest to
the redemption date, provided that at least
66 2/3% of the aggregate principal amount of
the notes originally issued remains
outstanding.
Change of Control Offer....... If a change in control of Swift occurs, we must
offer to repurchase the notes at a purchase
price of 101% of their face amount, plus
accrued interest to the date we repurchase the
notes.
Certain Covenants............. We will issue the notes under an indenture
containing covenants for your benefit. These
covenants restrict our ability and the ability
of our subsidiaries to:
- incur additional debt or issue preferred
stock;
- create liens;
- pay dividends or make other restricted
payments;
- issue and sell capital stock of our
restricted subsidiaries;
- transfer or sell assets;
S-5
- enter into transactions with affiliates;
- consolidate, merge or transfer all or
substantially all of our assets;
- incur dividend or other payment restrictions
affecting subsidiaries; or
- make investments.
These covenants are subject to important
exceptions and qualifications, which are
described in "Description of the
Notes -- Certain Covenants."
Use of Proceeds............... The net proceeds from this offering are
estimated to be approximately $194.5 million.
The net proceeds will be used to reduce the
outstanding indebtedness under our credit
facility incurred in connection with our recent
acquisition, development and exploitation
activities.
RISK FACTORS
Before making an investment decision, you should consider all of the
information in this prospectus supplement and the accompanying prospectus, and
should carefully evaluate the risks in the "Risk Factors" section beginning on
page S-11 of this prospectus supplement and page 2 of the accompanying
prospectus.
S-6
SUMMARY CONSOLIDATED FINANCIAL DATA
The summary consolidated financial data presented below for each of the
five years in the period ended December 31, 2001 has been derived from our
audited consolidated financial statements. For a discussion of our significant
financial results and conditions during 2001, 2000 and 1999, see "Management's
Discussion and Analysis of Financial Condition and Results of Operations" in
this prospectus supplement.
YEAR ENDED DECEMBER 31,
----------------------------------------------------
2001 2000 1999 1998 1997
-------- -------- -------- -------- --------
(IN THOUSANDS, EXCEPT RATIOS)
INCOME STATEMENT DATA:
Revenues:
Oil and gas sales......................................... $181,185 $189,139 $108,899 $ 80,068 $ 69,015
Fees from limited partnerships and joint ventures......... 427 332 230 334 746
Interest income........................................... 49 1,339 833 107 2,395
Price risk management and other, net...................... 2,146 815 709 1,960 2,556
-------- -------- -------- -------- --------
Total revenues...................................... 183,807 191,625 110,671 82,469 74,712
-------- -------- -------- -------- --------
Costs and expenses:
General and administrative, net of reimbursement.......... 8,187 5,586 4,497 3,854 3,524
Depreciation, depletion, and amortization................. 59,502 47,771 42,349 39,343 24,247
Oil and gas production.................................... 36,720 29,221 19,646 13,139 8,779
Interest expense, net..................................... 12,627 15,968 14,443 8,752 5,033
Other expenses............................................ 2,102 -- -- -- --
Write-down of oil and gas properties(a)................... 98,862 -- -- 90,772 --
-------- -------- -------- -------- --------
Total costs and expenses............................ 218,000 98,546 80,935 155,860 41,583
-------- -------- -------- -------- --------
Income (loss) before income taxes and extraordinary item and
change in accounting principle............................ (34,193) 93,079 29,736 (73,391) 33,129
Provision (benefit) for income taxes........................ (12,238) 33,265 10,450 (25,166) 10,819
-------- -------- -------- -------- --------
Income (loss) before extraordinary item and change in
accounting principle...................................... (21,955) 59,814 19,286 (48,225) 22,310
Extraordinary loss on early extinguishment of debt (net of
taxes)(b)................................................. -- 630 -- -- --
Cumulative effect of change in accounting principle (net of
taxes)(c)................................................. 393 -- -- -- --
-------- -------- -------- -------- --------
Net income (loss)........................................... $(22,348) $ 59,184 $ 19,286 $(48,225) $ 22,310
======== ======== ======== ======== ========
OTHER FINANCIAL DATA:
EBITDA(d)................................................... $136,799 $156,819 $ 86,528 $ 65,476 $ 62,410
Net cash provided by operating activities................... 139,884 128,197 73,603 54,249 55,256
Capital expenditures........................................ 275,126 173,277 78,113 183,816 131,967
Ratio of earnings to fixed charges(e)....................... -- 5.2x 2.4x -- 5.2x
Ratio of EBITDA to cash interest(d)(f)...................... 7.4x 7.6x 6.6x 5.1x 8.6x
BALANCE SHEET DATA (AT END OF PERIOD):
Working capital (deficit)................................... $(36,492) $(22,452) $ 16,535 $ 3,831 $ 1,464
Total assets................................................ 671,685 572,387 454,299 403,645 339,115
Long-term debt:
Bank borrowings........................................... 134,000 10,600 -- 146,200 7,915
6 1/4% convertible subordinated notes..................... -- -- 115,000 115,000 115,000
10 1/4% senior subordinated notes......................... 124,197 124,129 124,068 -- --
Stockholders' equity........................................ 312,653 332,154 170,404 109,363 159,401
(Notes on following page)
S-7
NOTES TO SUMMARY CONSOLIDATED FINANCIAL DATA
(a) In the fourth quarter of 2001, prices for both oil and gas at December 31,
2001, necessitated a pre-tax domestic full cost ceiling write-down of oil
and gas properties of $98.9 million, or $63.5 million after-tax.
Additionally, in the third quarter of 1998, we took a non-cash write-down
of domestic oil and gas properties as lower prices for both oil and gas at
September 30, 1998, necessitated a pre-tax domestic full cost ceiling
write-down in 1998 of $77.2 million, or $50.9 million after-tax. Also in
the third quarter of 1998, we impaired our total investment in Russia of
$10.8 million and impaired our capitalized unproved properties costs in
Venezuela of $2.8 million. The impairment of the unproved properties costs
in these two countries resulted in a separate 1998 non-cash pre-tax charge
to earnings of $13.6 million, or $9.0 million after-tax. The combination of
the non-cash full cost domestic ceiling write-down and the non-cash foreign
impairment charges in 1998 resulted in a combined non-cash charge to
earnings of $90.8 million pre-tax, or $59.9 million after-tax.
(b) In December 2000, we called for redemption of all our 6.25% Convertible
Subordinated Notes due 2006, or Convertible Notes, at 103.75% of their
principal amount. Holders of approximately $100.0 million of the
Convertible Notes elected to convert their notes into 3,164,644 shares of
our common stock. Holders of the approximately $15.0 million remaining
Convertible Notes elected to redeem their notes for cash plus accrued
interest. This cash redemption resulted in our recognizing an extraordinary
loss on the early extinguishment of debt (net of taxes) of $0.6 million.
(c) We adopted SFAS No. 133 effective January 1, 2001. Accordingly, we marked
our open derivative contracts at December 31, 2000 to fair value at that
date resulting in a one-time net of taxes charge of $0.4 million which is
recorded as a cumulative effect of change in accounting principle.
(d) EBITDA represents income before interest expense, income tax, and
depreciation, depletion and amortization (including the write-down of oil
and gas properties). We have reported EBITDA because we believe EBITDA is a
measure commonly reported and widely used by investors as an indicator of a
company's operating performance and ability to incur and service debt. We
believe EBITDA assists such investors in comparing a company's performance
on a consistent basis without regard to depreciation, depletion and
amortization, which can vary significantly depending upon accounting
methods or nonoperating factors such as historical cost. EBITDA is not a
calculation based on GAAP and should not be considered an alternative to
net income in measuring our performance or used as an exclusive measure of
cash flow because it does not consider the impact of working capital
growth, capital expenditures, debt principal reductions and other sources
and uses of cash which are disclosed in our Consolidated Statements of Cash
Flows. Investors should carefully consider the specific items included in
our computation of EBITDA. While EBITDA has been disclosed herein to permit
a more complete comparative analysis of our operating performance and debt
servicing ability relative to other companies, investors should be
cautioned that EBITDA as reported by us may not be comparable in all
instances to EBITDA as reported by other companies. EBITDA amounts may not
be fully available for management's discretionary use, due to certain
requirements to conserve funds for capital expenditures, debt service and
other commitments. The definition of EBITDA stated herein differs from the
definition of EBITDA applicable to the covenants for the notes, in that the
notes definition makes certain exclusions to net income, some of which
would reduce EBITDA. See "Description of the Notes -- Certain
Definitions -- Consolidated Net Income" and "-- EBITDA."
(e) For purposes of calculating the ratio of earnings to fixed charges, fixed
charges include interest expense, capitalized interest, amortization of
debt issuance costs and that portion of non-capitalized rental expense
deemed to be the equivalent of interest. Earnings represents income before
income taxes from continuing operations before fixed charges. Due to the
$98.9 million and $90.8 million non-cash charges incurred in 2001 and 1998,
respectively, resulting from a write-down in the carrying value of natural
gas and oil properties, 2001 and 1998 earnings were insufficient by $40.2
million and $76.9 million to cover fixed charges in 2001 and 1998,
respectively. If these non-cash charges were excluded, the ratio of
earnings to fixed charges would have been 4.1x for 2001 and 2.1x for 1998.
(f) Cash interest is defined as the total amount of interest paid on our
obligations, prior to any allowed capitalized amount.
S-8
SUMMARY RESERVES AND PRODUCTION DATA
The following tables set forth certain summary information with respect to
estimates of our oil and gas reserves, and data about production and sales of
oil and gas for the periods indicated. Reserves were determined by us and
audited by H.J. Gruy and Associates, Inc., independent petroleum consultants.
The net reserves and cash flows for New Zealand were prepared by us. See
"Business and Properties -- Oil and Gas Reserves" and "Risk Factors."
AS OF AND FOR THE YEAR ENDED DECEMBER 31,
------------------------------------------------------------
2001 2000 1999 1998 1997
---------- ---------- -------- -------- --------
ESTIMATED PROVED OIL AND GAS RESERVES(A):
Net gas reserves (MMcf):
Proved developed...................................... 181,652 215,170 174,046 197,106 191,108
Proved undeveloped.................................... 143,260 203,444 155,914 155,295 123,198
---------- ---------- -------- -------- --------
Total........................................... 324,912 418,614 329,960 352,401 314,306
========== ========== ======== ======== ========
Net oil reserves (MBbls):
Proved developed...................................... 23,760 10,980 8,437 7,143 4,289
Proved undeveloped.................................... 29,723 24,154 12,369 6,815 3,570
---------- ---------- -------- -------- --------
Total........................................... 53,483 35,134 20,806 13,958 7,859
========== ========== ======== ======== ========
TOTAL PROVED OIL AND GAS RESERVES (MMCFE)....... 645,808 629,416 454,797 436,148 361,459
========== ========== ======== ======== ========
ESTIMATED PRESENT VALUE OF PROVED RESERVES (IN
THOUSANDS):
Estimated present value of future net cash flows from
proved reserves discounted at 10% per annum, "PV-10
Value"(a):
Proved developed...................................... $ 344,479 $1,257,571 $301,200 $243,124 $244,365
Proved undeveloped.................................... 258,507 1,055,684 262,855 97,661 105,980
---------- ---------- -------- -------- --------
PV-10 Value(a).......................................... $ 602,986(b) $2,313,255(b) $564,055 $340,785 $350,345
========== ========== ======== ======== ========
Standardized measure of discounted estimated future net
cash flows after income taxes(a)...................... $ 454,558 $1,577,958 $438,944 $290,273 $292,838
========== ========== ======== ======== ========
PRICES USED IN CALCULATING END OF YEAR PROVED RESERVES:
Oil (per Bbl)........................................... $ 18.45 $ 24.62 $ 23.69 $ 11.23 $ 15.76
Gas (per Mcf)........................................... $ 2.51 $ 9.86 $ 2.58 $ 2.23 $ 2.78
OTHER RESERVES DATA:
Three year reserve replacement cost (per Mcfe)(c)....... $ 1.40 $ 1.00 $ 1.09 $ 0.96 $ 0.73
Three year reserve replacement rate(d).................. 263% 319% 287% 422% 590%
Gas as percent of total proved reserve quantities....... 50% 67% 73% 81% 87%
Proved developed reserves as percent of total proved
reserves.............................................. 50% 45% 49% 55% 60%
YEAR ENDED DECEMBER 31,
------------------------------------------------------------
2001 2000 1999 1998 1997
---------- ---------- -------- -------- --------
NET SALES VOLUME:
Oil (MBbls)............................................. 3,055 2,472 2,565 1,801 672
Gas (MMcf)(e)........................................... 26,459 27,525 27,485 28,226 21,359
Total production (MMcfe)(e)............................. 44,791 42,357 42,874 39,030 25,394
WEIGHTED AVERAGE SALES PRICES:
Oil (per Bbl)........................................... $ 22.64 $ 29.35 $ 16.75 $ 11.86 $ 17.59
Gas (per Mcf)........................................... $ 4.23 $ 4.24 $ 2.40 $ 2.08 $ 2.68
SELECTED DATA PER MCFE:
Production costs........................................ $ 0.82 $ 0.69 $ 0.46 $ 0.34 $ 0.35
Depreciation, depletion, and amortization............... $ 1.33 $ 1.13 $ 0.99 $ 1.01 $ 0.95
General and administrative, net of reimbursement........ $ 0.18 $ 0.13 $ 0.10 $ 0.10 $ 0.14
(Notes on following page)
S-9
NOTES TO SUMMARY RESERVES AND PRODUCTION DATA
(a) Quantity estimates, their PV-10 Value and the standardized measure of
future net cash flows are affected by the change in crude oil and gas
prices at the end of each year.
(b) Under SEC guidelines, estimates of the PV-10 Value of proved reserves must
be made using oil and gas sales prices at the date for the valuation, which
prices are held constant throughout the life of the properties. Our year
end 2001 average prices used to calculate PV-10 Value were $2.51 per Mcf
and $18.45 per Bbl. The year end 2001 gas price of $2.51 was significantly
lower than the average gas price of $4.23 we received during 2001. The year
end 2001 oil price of $18.45 was also lower than the average oil price of
$22.64 we received in 2001. Had year end reserves been calculated using the
average 2001 prices we received, $22.64 for oil and $4.23 for gas, the
PV-10 Value would have been approximately $947.8 million compared to the
$603.0 million reported using year end 2001 prices. Conversely, commodity
prices were unusually high at year end 2000, especially gas prices. Our
year end 2000 average prices used to calculate PV-10 Value were $9.86 per
Mcf and $24.62 per Bbl. Had year end 2000 reserves been calculated using
the average 2000 prices we received, $29.35 for oil and $4.24 for gas, the
PV-10 Value would have been approximately $1.1 billion compared to the $2.3
billion reported using year end 2000 prices.
(c) Calculated for a three-year period ending with the year presented by
dividing total acquisition, exploration and development costs, excluding
future development costs, during such period by net reserves added during
the period, excluding any revisions of those reserves.
(d) Calculated for a three-year period ending with the year presented by
dividing the increase in net reserves, including any revisions of those
reserves, by the production quantities for such period.
(e) Natural gas production for the years ended 2000, 1999, 1998 and 1997
includes 405, 728, 866 and 1,015 MMcf, respectively, delivered under the
volumetric production payment agreement pursuant to which we were obligated
to deliver certain monthly quantities of gas to a third party through
October 2000. Remaining obligated volumes associated with the volumetric
production payment were not included in our estimate of net reserves for
the relevant years.
S-10
RISK FACTORS
An investment in our notes involves significant risks. You should carefully
consider the following risk factors before you decide to purchase the notes. You
should also carefully read and consider all of the information we have included,
or incorporated by reference, in this prospectus supplement and the accompanying
prospectus before you decide to purchase the notes.
OIL AND NATURAL GAS PRICES ARE VOLATILE. A SUBSTANTIAL DECREASE IN OIL AND
NATURAL GAS PRICES WOULD ADVERSELY AFFECT OUR FINANCIAL RESULTS.
Our future financial condition, results of operations and the value of our
oil and natural gas properties depend primarily upon market prices for oil and
natural gas. Oil and natural gas prices historically have been volatile and will
likely continue to be volatile in the future. Oil and natural gas prices
received in the second half of 2001 were significantly lower than the average
prices we received during the first half of 2001, and lower than the average
prices received for most of 2000. Both commodity prices continued to drop during
the early part of the first quarter of 2002. The prices for oil and natural gas
are subject to wide fluctuation in response to relatively minor changes in the
supply of and demand for oil and natural gas, market uncertainty, worldwide
economic conditions, weather conditions, import prices, political conditions in
major oil producing regions, especially the Middle East, and actions taken by
OPEC. A significant decrease in price levels for an extended period would
negatively affect us in several ways:
- our cash flow would be reduced, decreasing funds available for capital
expenditures employed to replace reserves or increase production;
- certain reserves would no longer be economic to produce, leading to both
lower proved reserves and cash flow;
- our lenders could reduce the borrowing base under our credit facility
because of lower oil and gas reserve values, reducing our liquidity and
possibly requiring mandatory loan repayments; and
- access to other sources of capital, such as equity or long-term debt
markets, could be severely limited or unavailable in a low price
environment.
Consequently, our revenues and profitability would suffer.
OUR DEBT REDUCES OUR FINANCIAL FLEXIBILITY, AND OUR DEBT LEVELS MAY INCREASE.
As of March 31, 2002, after the TAWN acquisition in January 2002 and the
Antrim acquisition in March 2002, and after giving effect to our common stock
offering and this offering, our long-term debt would have comprised
approximately 49% of our total capitalization. Increased debt:
- would require us to dedicate a significant portion of our cash flow to
the payment of interest;
- would subject us to a higher financial risk in an economic downturn due
to substantial debt service costs;
- would limit our ability to obtain financing or raise equity capital in
the future; and
- may place us at a competitive disadvantage to the extent that we are more
highly leveraged than some of our peers.
Subject to restrictions in our credit facility and the indenture for our
senior subordinated notes due 2009, as of March 31, 2002, we had a $300.0
million credit facility with a borrowing base of $275.0 million of which $44.0
million was available for borrowing. If we increase our debt levels further, the
risks discussed above would become greater.
IF WE CANNOT REPLACE OUR RESERVES, OUR REVENUES AND FINANCIAL CONDITION WILL
SUFFER.
Unless we successfully replace our reserves, our production will decline,
resulting in lower revenues and cash flow. This is accentuated by the fact that
in our Masters Creek area new production added by
S-11
drilling has not kept up with the decline in production. When oil and gas prices
decrease, our cash flow decreases, resulting in less available cash to drill and
replace our reserves and an increased need to draw on our bank line of credit.
DRILLING WELLS IS SPECULATIVE AND CAPITAL INTENSIVE.
Developing and exploring for oil and gas properties requires significant
capital expenditures and involves a high degree of financial risk. The budgeted
costs of drilling, completing and operating wells are often exceeded and can
increase significantly when drilling costs rise. Drilling may be unsuccessful
for many reasons, including title problems, weather, cost overruns, equipment
shortages and mechanical difficulties. Moreover, the successful drilling of an
oil or gas well does not ensure a profit on investment. Exploratory wells bear a
much greater risk of loss than development wells. A variety of factors, both
geological and market-related, can cause a well to become uneconomical or only
marginally economical. In addition to their cost, unsuccessful wells can hurt
our efforts to replace reserves.
ESTIMATES OF PROVED RESERVES ARE UNCERTAIN, AND REVENUES FROM PRODUCTION MAY
VARY FROM EXPECTATIONS SIGNIFICANTLY.
The quantities and values of our proved reserves included in this
prospectus supplement and in our documents we have incorporated by reference are
only estimates and subject to numerous uncertainties. Estimates by other
engineers might differ materially. The accuracy of any reserve estimate is a
function of the quality of available data and of engineering and geological
interpretation. These estimates depend on assumptions regarding quantities and
production rates of recoverable oil and gas reserves, future prices for oil and
gas, timing and amounts of development expenditures and operating expenses, all
of which will vary from those assumed in our estimates. These variances may be
significant. For example, in 2001 the net reduction in our estimate of proved
reserves in New Zealand was approximately 37 Bcfe.
Any significant variance from the assumptions used could result in the
actual amounts of oil and gas ultimately recovered and future net cash flows
being materially different from the estimates in our reserve reports. In
addition, results of drilling, testing, production and changes in prices after
the date of the estimate may result in substantial downward revisions. These
estimates may not accurately predict the present value of net cash flows from
oil and gas reserves.
At December 31, 2001, approximately 50% of our estimated proved reserves
were undeveloped. Recovery of undeveloped reserves generally requires
significant capital expenditures and successful drilling operations. The reserve
data assumes that we can and will make these expenditures and conduct these
operations successfully, which may not occur.
WE INCURRED A WRITE-DOWN OF THE CARRYING VALUES OF OUR PROPERTIES IN THE FOURTH
QUARTER OF 2001 AND COULD INCUR ADDITIONAL WRITE-DOWNS IN THE FUTURE.
Under the full cost method of accounting, SEC accounting rules require that
on a quarterly basis we review the carrying value of our oil and gas properties
on a country by country basis for possible write-down or impairment. Under these
rules, capitalized costs of proved reserves may not exceed a ceiling calculated
at the present value of estimated future net revenues from those proved
reserves, determined using a 10% per year discount and unescalated prices in
effect as of the end of each fiscal quarter. Capital costs in excess of the
ceiling must be permanently written down.
We recorded an after-tax, non-cash charge during the fourth quarter of 2001
of $63.5 million. This write-down results in a charge to earnings and a
reduction of shareholders' equity, but does not impact our cash flow from
operating activities. Once incurred, write-downs are not reversible at a later
date. If commodity prices continue to decline or if we have downward oil and gas
revisions, we could incur additional write-downs in the future. See
"Management's Discussion and Analysis of Financial Condition and Results of
Operations -- Critical Accounting Policies -- Property and Equipment."
S-12
RESERVES ON PROPERTIES WE BUY MAY NOT MEET OUR EXPECTATIONS AND COULD CHANGE THE
NATURE OF OUR BUSINESS.
Property acquisition decisions are based on various assumptions and
subjective judgments that are speculative. Although available geological and
geophysical information can provide information about the potential of a
property, it is impossible to predict accurately a property's production and
profitability. Furthermore, future acquisitions may change the nature of our
operations and business. For example, an acquisition of producing properties
containing primarily oil reserves could change our current emphasis on gas
reserves.
In addition, we may have difficulty integrating future acquisitions into
our operations, and they may not achieve our desired profitability objectives.
Likewise, as is customary in the industry, we generally acquire oil and gas
acreage without any warranty of title except through the transferor. In many
instances, title opinions are not obtained if, in our judgment, it would be
uneconomical or impractical to do so. Losses may result from title defects or
from defects in the assignment of leasehold rights. While our current operations
are primarily in Texas, Louisiana and New Zealand, we may pursue acquisitions of
properties located in other geographic areas, which would decrease our
geographical concentration, and could also be in areas in which we have no or
limited experience.
WE MAY HAVE DIFFICULTY COMPETING FOR OIL AND GAS PROPERTIES OR SUPPLIES.
We operate in a highly competitive environment, competing with major
integrated and independent energy companies for desirable oil and gas
properties, as well as for the equipment, labor and materials required to
develop and operate such properties. Many of these competitors have financial
and technological resources substantially greater than ours. The market for oil
and gas properties is highly competitive and we may lack technological
information or expertise available to other bidders. We may incur higher costs
or be unable to acquire and develop desirable properties at costs we consider
reasonable because of this competition.
GOVERNMENTAL LAWS AND REGULATIONS ARE COSTLY AND COMPLEX, ESPECIALLY THOSE
RELATING TO ENVIRONMENTAL PROTECTION.
Our exploration, production and marketing operations are subject to
extensive laws and regulations at the international, federal, state and local
levels. These laws and regulations affect the costs, manner and feasibility of
our operations. As an owner and operator of oil and gas properties, we are
subject to international, federal, state and local laws and regulations relating
to discharge of materials into, and protection of, the environment. We have made
and will continue to make significant expenditures in our efforts to comply with
the requirements of these environmental laws and regulations, which may impose
liability on us for the cost of pollution clean-up resulting from operations,
subject us to penalties and liabilities for pollution damages and require
suspension or cessation of operations in affected areas. Changes in or additions
to laws and regulations regarding the protection of the environment could
increase our compliance costs and might hurt our business.
We are subject to state and local laws and regulations domestically and are
subject to New Zealand laws and regulations that impose permitting, reclamation,
land use, conservation and other restrictions on our ability to drill and
produce oil and natural gas. These laws and regulations can require well and
facility sites to be closed and reclaimed. We frequently buy and sell interests
in properties that have been operated in the past, and as a result of these
transactions we may retain or assume clean-up or reclamation obligations for our
own operations or those of third parties.
WE MAY BE EXPOSED TO FINANCIAL AND OTHER LIABILITIES AS THE GENERAL PARTNER IN
71 LIMITED PARTNERSHIPS.
We currently serve as the managing general partner of 71 limited
partnerships, all but six of which are in the process of selling their
properties and liquidating. We are contingently liable for our obligations as a
general partner, including responsibility for day-to-day operations and any
liabilities that cannot be repaid
S-13
from partnership assets or insurance proceeds. In the future, we may be exposed
to litigation in connection with the partnerships.
YOUR RIGHT TO RECEIVE PAYMENTS ON THE NOTES IS JUNIOR TO OUR EXISTING SENIOR
INDEBTEDNESS.
The indebtedness evidenced by the notes will be senior subordinated
obligations of Swift. The payment of the principal of, premium on, if any, and
interest on the notes is subordinate in right of payment to the prior payment in
full of all senior indebtedness of Swift.
Based upon our outstanding indebtedness at March 31, 2002, after the TAWN
acquisition in January 2002 and the Antrim acquisition in March 2002, and after
giving effect to our common stock offering and this offering, we expect to have
approximately $6.1 million in senior indebtedness outstanding. Any future
borrowings under our bank credit facility will also constitute senior
indebtedness. Although the indenture contains limitations on the amount of
additional indebtedness that we may incur, the amount of such indebtedness could
be substantial and senior to the notes. See "Description of the Notes -- Certain
Covenants -- Limitation on Indebtedness."
IF WE EXPERIENCE A CHANGE OF CONTROL, WE MAY BE UNABLE TO REPURCHASE THE NOTES
AS REQUIRED UNDER THE INDENTURE.
In the event of a change of control, you will have the right to require us,
subject to various conditions, to repurchase the notes. We may not have
sufficient financial resources to pay the repurchase price for the notes, or may
be prohibited from doing so under our credit facility or other debt agreements.
In addition, before we can purchase any notes, we may be required to:
- repay our bank debt or other debt that ranks senior to the notes; or
- obtain a consent from lenders of senior debt to repurchase the notes.
If a change of control occurs and we are prohibited from repurchasing the
notes, our failure to do so would cause us to default under the indenture, which
in turn is likely to be a default under our credit facility, our outstanding
senior subordinated notes due 2009 and any future debt. Any other default under
our credit facility or other debt would also likely prohibit our repurchasing
the notes.
THE NOTES HAVE NO EXISTING MARKET, AND A MARKET MAY NOT DEVELOP.
There is no existing market for the notes, and we are not applying to list
the notes on any securities exchange. Therefore, no liquid market may exist for
the notes at any time, which may depress the prices at which you will be able to
sell your notes.
FRAUDULENT CONVEYANCE CONSIDERATIONS COULD AVOID GUARANTEES FOR THE NOTES.
In the future, some of our subsidiaries might guarantee our obligations
under the notes on an unsecured senior subordinated basis. Under fraudulent
conveyance laws, a court might subordinate or avoid any guarantees of the notes
by our subsidiaries in favor of a subsidiary's other debts or liabilities. To
the extent a subsidiary's guarantee of the notes is avoided as a result of
fraudulent conveyance laws or held unenforceable for any other reason, you would
receive no payments under that subsidiary's guarantee and would be creditors
solely of us and any subsidiaries whose guarantees were not avoided.
S-14
USE OF PROCEEDS
We estimate that the net proceeds from the sale of the notes will be
approximately $194.5 million. We intend to use the net proceeds to repay a large
portion of the outstanding indebtedness under our credit facility and to use the
funds then made available under our credit facility for capital expenditures,
acquisitions, and general corporate purposes.
In January 2002, upon closing of the New Zealand TAWN acquisition, our
credit facility increased from $250.0 million to $300.0 million and the
borrowing base increased from $200.0 million to $275.0 million. At March 31,
2002, $231.0 million was outstanding under our credit facility at a weighted
average interest rate of 3.53%. The amount available for borrowing is subject to
a borrowing base determination that is recalculated at least every six months,
and is subject to reduction upon the closing of this offering. Our bank credit
facility is described in more detail in the "Description of Existing
Indebtedness" section of this prospectus supplement.
S-15
CAPITALIZATION
The following table sets forth as of December 31, 2001:
- our historical capitalization;
- our capitalization as adjusted for the estimated net proceeds of $30.5
million from the sale of our common stock; and
- our capitalization as further adjusted for the estimated net proceeds of
$194.5 million from this offering.
This notes offering and our offering of common stock are not conditioned
upon each other. This table does not reflect the TAWN acquisition or the
issuance of 220,000 shares of our common stock in March 2002 to acquire the New
Zealand assets of Antrim Oil and Gas Limited or 2,639,504 shares that may be
issued pursuant to outstanding stock compensation plans as of December 31, 2001.
This table should be read in conjunction with "Management's Discussion and
Analysis of Financial Condition and Results of Operations," the consolidated
financial statements, and the related notes contained in this prospectus
supplement.
AS OF DECEMBER 31, 2001
------------------------------------------
AS ADJUSTED
AS ADJUSTED FOR BOTH
SOLELY FOR COMMON STOCK
COMMON STOCK AND NOTES
HISTORICAL OFFERING OFFERINGS
---------- ------------ --------------
(IN THOUSANDS, EXCEPT SHARE DATA)
Cash and cash equivalents(a)......................... $ 2,149 $ 2,149 $ 93,083
======== ======== ========
Long-term debt
Bank borrowings(a)................................. 134,000 103,516 --
10 1/4% Senior Subordinated Notes due 2009......... 124,197 124,197 124,197
9 3/8% Senior Subordinated Notes due 2012.......... -- -- 200,000
-------- -------- --------
Total long-term debt....................... $258,197 $227,713 $324,197
-------- -------- --------
Stockholders' equity
Preferred stock, $.01 par value, 5,000,000 shares
authorized, none outstanding.................... -- -- --
Common stock, $.01 par value, 85,000,000 shares
authorized, 25,634,598 and 27,359,598 shares
issued and 24,795,564 and 26,520,564 shares
outstanding, respectively, as adjusted for the
common stock offering........................... 257 274 274
Additional paid-in capital......................... 296,173 326,640 326,640
Treasury stock held, at cost, 839,034 shares....... (12,033) (12,033) (12,033)
Retained earnings.................................. 28,256 28,256 28,256
-------- -------- --------
Total stockholders' equity................. 312,653 343,137 343,137
-------- -------- --------
Total capitalization....................... $570,850 $570,850 $667,334
======== ======== ========
---------------
(a) As of March 31, 2002, our outstanding bank borrowings were $231.0 million.
Accordingly, after repaying a portion of amounts outstanding with the net
proceeds from the common stock offering, our bank borrowings as of March
31, 2002 would have been approximately $200.5 million, and our cash and
cash equivalents would have been approximately $2.1 million. After repaying
a portion of amounts outstanding with the net proceeds expected from the
common stock offering and net proceeds expected from this offering, these
amounts would have been approximately $6.1 million and $2.1 million,
respectively.
S-16
SELECTED HISTORICAL CONSOLIDATED FINANCIAL DATA
The selected historical consolidated financial data presented below for
each of the five years in the period ended December 31, 2001 has been derived
from our audited consolidated financial statements. For a discussion of our
significant financial results and conditions during 2001, 2000 and 1999, see
"Management's Discussion and Analysis of Financial Condition and Results of
Operations" in this prospectus supplement.
YEAR ENDED DECEMBER 31,
----------------------------------------------------
2001 2000 1999 1998 1997
-------- -------- -------- -------- --------
(IN THOUSANDS, EXCEPT RATIOS)
INCOME STATEMENT DATA:
Revenues:
Oil and gas sales......................................... $181,185 $189,139 $108,899 $ 80,068 $ 69,015
Fees from limited partnerships and joint ventures......... 427 332 230 334 746
Interest income........................................... 49 1,339 833 107 2,395
Price risk management and other, net...................... 2,146 815 709 1,960 2,556
-------- -------- -------- -------- --------
Total revenues...................................... 183,807 191,625 110,671 82,469 74,712
-------- -------- -------- -------- --------
Costs and expenses:
General and administrative, net of reimbursement.......... 8,187 5,586 4,497 3,854 3,524
Depreciation, depletion, and amortization................. 59,502 47,771 42,349 39,343 24,247
Oil and gas production.................................... 36,720 29,221 19,646 13,139 8,779
Interest expense, net..................................... 12,627 15,968 14,443 8,752 5,033
Other expenses............................................ 2,102 -- -- -- --
Write-down of oil and gas properties(a)................... 98,862 -- -- 90,772 --
-------- -------- -------- -------- --------
Total costs and expenses............................ 218,000 98,546 80,935 155,860 41,583
-------- -------- -------- -------- --------
Income (loss) before income taxes and extraordinary item and
change in accounting principle............................ (34,193) 93,079 29,736 (73,391) 33,129
Provision (benefit) for income taxes........................ (12,238) 33,265 10,450 (25,166) 10,819
-------- -------- -------- -------- --------
Income (loss) before extraordinary item and change in
accounting principle...................................... (21,955) 59,814 19,286 (48,225) 22,310
Extraordinary loss on early extinguishment of debt (net of
taxes)(b)................................................. -- 630 -- -- --
Cumulative effect of change in accounting principle (net of
taxes)(c)................................................. 393 -- -- -- --
-------- -------- -------- -------- --------
Net income (loss)........................................... $(22,348) $ 59,184 $ 19,286 $(48,225) $ 22,310
======== ======== ======== ======== ========
OTHER FINANCIAL DATA:
EBITDA(d)................................................... $136,799 $156,819 $ 86,528 $ 65,476 $ 62,410
Net cash provided by operating activities................... 139,884 128,197 73,603 54,249 55,256
Capital expenditures........................................ 275,126 173,277 78,113 183,816 131,967
Ratio of earnings to fixed charges(e)....................... -- 5.2x 2.4x -- 5.2x
Ratio of EBITDA to cash interest(d)(f)...................... 7.4x 7.6x 6.6x 5.1x 8.6x
BALANCE SHEET DATA (AT END OF PERIOD):
Working capital (deficit)................................... $(36,492) $(22,452) $ 16,535 $ 3,831 $ 1,464
Total assets................................................ 671,685 572,387 454,299 403,645 339,115
Long-term debt:
Bank borrowings........................................... 134,000 10,600 -- 146,200 7,915
6 1/4% convertible subordinated notes..................... -- -- 115,000 115,000 115,000
10 1/4% senior subordinated notes......................... 124,197 124,129 124,068 -- --
Stockholders' equity........................................ 312,653 332,154 170,404 109,363 159,401
Notes on following page)
S-17
NOTES TO SELECTED HISTORICAL CONSOLIDATED FINANCIAL DATA
(a) In the fourth quarter of 2001, prices for both oil and gas at December 31,
2001, necessitated a pre-tax domestic full cost ceiling write-down of oil
and gas properties of $98.9 million, or $63.5 million after-tax.
Additionally, in the third quarter of 1998, we took a non-cash write-down
of domestic oil and gas properties as prices for both oil and gas at
September 30, 1998, necessitated a pre-tax domestic full-cost ceiling
write-down in 1998 of $77.2 million, or $50.9 million after-tax. Also in
the third quarter of 1998 we impaired our total investment in Russia of
$10.8 million and impaired our capitalized unproved properties costs in
Venezuela of $2.8 million. The impairment of the unproved properties costs
in these two countries resulted in a separate 1998 non-cash pre-tax charge
to earnings of $13.6 million, or $9.0 million after-tax. The combination of
the non-cash full cost domestic ceiling write-down and the non-cash foreign
impairment charges in 1998 resulted in a combined non-cash charge to
earnings of $90.8 million pre-tax, or $59.9 million after-tax.
(b) In December 2000, we called for redemption of all of our Convertible Notes
at 103.75% of their principal amount. Holders of approximately $100.0
million of the Convertible Notes elected to convert their notes into
3,164,644 shares of our common stock. Holders of the approximately $15.0
million remaining Convertible Notes elected to redeem their notes for cash
plus accrued interest. This cash redemption resulted in our recognizing an
extraordinary loss on the early extinguishment of debt (net of taxes) of
$0.6 million.
(c) We adopted SFAS No. 133 effective January 1, 2001. Accordingly, we marked
our open derivative contracts at December 31, 2000 to fair value at that
date resulting in a one-time net of taxes charge of $0.4 million which is
recorded as a cumulative effect of change in accounting principle.
(d) EBITDA represents income before interest expense, income tax, and
depreciation, depletion and amortization (including the write-down of oil
and gas properties). We have reported EBITDA because we believe EBITDA is a
measure commonly reported and widely used by investors as an indicator of a
company's operating performance and ability to incur and service debt. We
believe EBITDA assists such investors in comparing a company's performance
on a consistent basis without regard to depreciation, depletion and
amortization, which can vary significantly depending upon accounting
methods or nonoperating factors such as historical cost. EBITDA is not a
calculation based on GAAP and should not be considered an alternative to
net income in measuring our performance or used as an exclusive measure of
cash flow because it does not consider the impact of working capital
growth, capital expenditures, debt principal reductions and other sources
and uses of cash which are disclosed in our Consolidated Statements of Cash
Flows. Investors should carefully consider the specific items included in
our computation of EBITDA. While EBITDA has been disclosed herein to permit
a more complete comparative analysis of our operating performance and debt
servicing ability relative to other companies, investors should be
cautioned that EBITDA as reported by us may not be comparable in all
instances to EBITDA as reported by other companies. EBITDA amounts may not
be fully available for management's discretionary use, due to certain
requirements to conserve funds for capital expenditures, debt service and
other commitments. The definition of EBITDA stated herein differs from the
definition of EBITDA applicable to the covenants for the notes, in that the
notes definition makes certain exclusions to net income, some of which
would reduce EBITDA. See "Description of the Notes -- Certain
Definitions -- Consolidated Net Income" and "-- EBITDA."
(e) For purposes of calculating the ratio of earnings to fixed charges, fixed
charges include interest expense, capitalized interest, amortization of
debt issuance costs and that portion of non-capitalized rental expense
deemed to be the equivalent of interest. Earnings represents income before
income taxes from continuing operations before fixed charges. Due to the
$98.9 million and $90.8 million non-cash charges incurred in 2001 and 1998,
respectively, resulting from a write-down in the carrying value of natural
gas and oil properties, 2001 and 1998 earnings were insufficient by $40.2
million and $76.9 million to cover fixed charges in 2001 and 1998,
respectively. If these non-cash charges were excluded, the ratio of
earnings to fixed charges would have been 4.1x for 2001 and 2.1x for 1998.
(f) Cash interest is defined as the total amount of interest paid on our
obligations, prior to any allowed capitalized amount.
S-18
MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
You should read the following discussion and analysis in conjunction with
our financial information and our consolidated financial statements and notes
thereto included or incorporated by reference in this prospectus supplement. The
following information contains forward-looking statements. For a discussion of
limitations inherent in forward-looking statements, see "Forward-Looking
Information" in the accompanying prospectus on page 3.
GENERAL
Over the last several years, we have emphasized adding reserves through
drilling activity. We also add reserves through strategic purchases of producing
properties when oil and gas prices are at lower levels and other market
conditions are appropriate. During the past three years, we have used this
flexible strategy of employing both drilling and acquisitions to add more
reserves than we have depleted through production.
CRITICAL ACCOUNTING POLICIES. The following summarizes several of our
critical accounting policies. See a complete list of significant accounting
policies in Note 1 to the Consolidated Financial Statements.
Use of Estimates. The preparation of financial statements in conformity
with accounting principles generally accepted in the United States requires
management to make estimates and assumptions that affect the reported amounts of
assets and liabilities and disclosure of contingent assets and liabilities, if
any, at the date of the financial statements and the reported amounts of
revenues and expenses during the reporting period. Actual results could differ
from estimates.
Property and Equipment. We follow the "full cost" method of accounting for
oil and gas property and equipment costs. Under this method of accounting, all
productive and nonproductive costs incurred in the exploration, development, and
acquisition of oil and gas reserves are capitalized.
The cost of unproved properties not being amortized is assessed quarterly,
on a country-by-country basis, to determine whether such properties have been
impaired. In determining whether such costs should be impaired, our management
evaluates, among other factors, current drilling results, lease expiration
dates, current oil and gas industry conditions, international economic
conditions, capital availability, foreign currency exchange rates, the political
stability in the countries in which we have an investment, and available
geological and geophysical information. Any impairment assessed is added to the
cost of proved properties being amortized. To the extent costs accumulate in
countries where there are no proved reserves, any costs determined by management
to be impaired are charged to income.
Full Cost Ceiling Test. At the end of each quarterly reporting period, the
unamortized cost of oil and gas properties, net of related deferred income
taxes, is limited to the sum of the estimated future net revenues from proved
properties using period-end prices, discounted at 10%, and the lower of cost or
fair value of unproved properties, adjusted for related income tax effects
("Ceiling Test"). This calculation is done on a country-by-country basis for
those countries with proved reserves.
The calculation of the Ceiling Test is based on estimates of proved
reserves. There are numerous uncertainties inherent in estimating quantities of
proved reserves and in projecting the future rates of production, timing, and
plan of development. The accuracy of any reserves estimate is a function of the
quality of available data and of engineering and geological interpretation and
judgment. Results of drilling, testing, and production subsequent to the date of
the estimate may justify revision of such estimate. Accordingly, reserves
estimates are often different from the quantities of oil and gas that are
ultimately recovered.
In 2001, as a result of low oil and gas prices at December 31, 2001, we
reported a non-cash write-down on a before-tax basis of $98.9 million ($63.5
million after tax) on our domestic properties. We had no write-down on our New
Zealand properties.
In addition, any unsuccessful exploratory well costs in countries in which
there are no proved reserves are charged to expense as incurred. During the
second quarter of 1999, we charged to income as additional
S-19
depreciation, depletion, and amortization costs our portion of drilling costs
associated with an unsuccessful exploratory well drilled by another operator in
New Zealand. This charge was $290,000.
Because of the delineation of our 1999 Rimu discovery with two successful
delineation wells drilled in 2000, proved reserves were recognized in New
Zealand as of December 31, 2000.
Given the volatility of oil and gas prices, our estimates of discounted
future net cash flows from proved oil and gas reserves are subject to change. If
oil and gas prices decline significantly, even if only for a short period, it is
possible that additional write-downs of oil and gas properties could occur in
the future.
Price-Risk Management Activities. In June 1998, the Financial Accounting
Standards Board issued SFAS No. 133, "Accounting for Derivative Instruments and
Hedging Activities." The statement establishes accounting and reporting
standards requiring that every derivative instrument (including certain
derivative instruments embedded in other contracts) be recorded in the balance
sheet as either an asset or a liability measured at its fair value. SFAS No. 133
requires that changes in the derivative's fair value be recognized currently in
earnings unless specific hedge accounting criteria are met. Special accounting
for qualifying hedges allows the gains and losses on derivatives to offset
related results on the hedged item in the income statements and requires that a
company must formally document, designate, and assess the effectiveness of
transactions that receive hedge accounting. SFAS No. 133, as amended by SFAS No.
137 and SFAS No. 138, was adopted by us on January 1, 2001.
We have a policy to use derivative instruments, mainly the buying of
protection price floors, to protect against price declines in oil and gas
prices. We elected not to designate our price floors for special hedge
accounting treatment under SFAS No. 133, as amended. However, we have elected to
use mark-to-market accounting treatment for our derivative contracts. Upon
adoption of SFAS No. 133 on January 1, 2001, we recorded a net of taxes charge
of $392,868, which is recorded as a Cumulative Effect of Change in Accounting
Principle. During 2001 we recognized net gains of $1,173,094 relating to our
derivative activities, with $16,784 in unrealized losses at year end 2001. This
activity is recorded in Price-risk management and other, net on the accompanying
statements of income.
At December 31, 2001, we had open price floor contracts covering notional
volumes of 2.0 million MMBtu of natural gas. These natural gas price floor
contracts relate to the NYMEX contract months of February and March 2002 at an
average price of $2.33 per MMBtu. The fair value of our open price floor
contracts at December 31, 2001, totaled $296,000 and is included in Other
current assets on the accompanying balance sheet.
PROVED OIL AND GAS RESERVES. At year end 2001, our total proved reserves
were 645.8 Bcfe with a PV-10 Value of $603.0 million. In 2001, our proved
natural gas reserves decreased 93.7 Bcf, or 22%, while our proved oil reserves
increased 18.3 MMBbl, or 52%, for a total equivalent increase of 16.4 Bcfe, or
3%. From 1999 to 2000, our proved natural gas reserves increased by 88.7 Bcf, or
27%, while our proved oil reserves increased by 14.3 MMBbl, or 69%, for a total
equivalent increase of 174.6 Bcfe, or 38%. We added reserves from 2000 to 2001
through both our drilling activity and through purchases of minerals in place.
Through drilling we added 105.8 Bcfe (17.4 Bcfe of which came from New Zealand)
of proved reserves in 2001, 184.7 Bcfe (122.5 Bcfe of which came from New
Zealand) in 2000, and 64.9 Bcfe in 1999. Through acquisitions we added 54.6 Bcfe
of proved reserves in 2001, 39.7 Bcfe in 2000, and 20.1 Bcfe in 1999. At year
end 2001, 50% of our total proved reserves were proved developed, compared with
45% at year end 2000 and 49% at year end 1999.
While our total proved reserves quantities increased by 3% during 2001, the
PV-10 Value of those reserves decreased 74%, primarily due to significantly
lower prices at year end 2001 than at year end 2000. Between year end 2000 and
year end 2001, there was a 75% decrease in natural gas prices and a 25% decrease
in oil prices. Gas prices were $2.51 per Mcf at year end 2001, compared to $9.86
per Mcf at year end 2000. Oil prices were $18.45 per Bbl at year end 2001,
compared to $24.62 a year earlier. These decreases in prices resulted in 47.1
Bcfe of the downward reserve revisions. Under SEC guidelines, estimates of
proved reserves must be made using year end oil and gas sales prices and are
held constant throughout the life of the properties. Subsequent changes to such
year end oil and gas prices could have a
S-20
significant impact on the calculated PV-10 Value. The year end 2001 gas price of
$2.51 was significantly lower than the average gas price of $4.23 we received
during 2001. The year end 2001 oil price of $18.45 per barrel was also lower
than the average oil price of $22.64 we received in 2001. Had year end reserves
been calculated using the average 2001 prices we received, $22.64 for oil and
$4.23 for gas, the PV-10 Value would have been approximately $947.8 million
compared to the $603.0 million reported using year end prices.
RECENT EVENTS
TAWN ACQUISITION. Through our subsidiary, Swift Energy New Zealand
Limited, we acquired Southern Petroleum Exploration Limited ("Southern NZ") from
an affiliate of Shell New Zealand in January 2002 for approximately $54.4
million. Through Southern NZ we now own interests in four onshore producing oil
and gas fields, extensive associated hydrocarbon-processing facilities and
pipelines complementing our existing fields by providing us with access to
export terminals and markets and additional excess processing capacity for both
oil and natural gas. As of December 31, 2001, the reserves associated with this
acquisition were estimated to be approximately 62.1 Bcfe, all of which were
proved developed. This acquisition was accounted for using the purchase method
of accounting. Upon the closing of this acquisition, our credit facility was
increased to $300.0 million, and the borrowing base became $275.0 million.
In conjunction with the TAWN acquisition, we granted Shell New Zealand a
short-term option to acquire an undivided 25% interest in our permit 38719,
which includes our Rimu and Kauri areas, as well as a 25% interest in our Rimu
Production Station. We do not know if Shell New Zealand will exercise this
option. Any exercise of the option would be subject to numerous notifications,
governmental approvals and consents. If Shell New Zealand does not exercise its
option, we intend to pursue discussions with several other companies that have
expressed interest in acquiring up to a 25% interest in the permit.
ANTRIM ACQUISITION. We purchased through our subsidiary, Swift Energy New
Zealand Limited, all of the New Zealand assets owned by Antrim Oil and Gas
Limited for 220,000 shares of Swift Energy Company common stock and an effective
date adjustment of approximately $530,000. Antrim owned a 5% interest in permit
38719 and a 7.5% interest in permit 38716. As of December 31, 2001, the reserves
associated with this acquisition were estimated to be approximately 5.7 Bcfe.
This transaction closed in March 2002.
RUSSIA. On March 28, 2002, we received $7.5 million for our interest in
the Samburg project located in Western Siberia, Russia as a result of the sale
by a third party of its ownership in a Russian joint stock company, which owned
and operated this field. This will result in a $7.5 million non-recurring,
pre-tax gain in the first quarter of 2002.
RESULTS OF OPERATIONS
REVENUES. Our revenues in 2001 decreased by 4% compared to revenues in
2000 due primarily to decreases in oil prices.
Oil and gas sales revenues in 2001 decreased by 4%, or $8.0 million, from
the level of those revenues for 2000 even though our net sales volumes in 2001
increased by 6%, or 2.4 Bcfe, over net sales volumes in 2000. Average prices
received for oil decreased to $22.64 per Bbl in 2001 from $29.35 per Bbl in
2000. Average gas prices received decreased slightly to $4.23 per Mcf in 2001
from $4.24 per Mcf in 2000.
In 2001, our $8.0 million decrease in oil and gas sales resulted from:
- Price variances that had a $20.6 million unfavorable impact on sales, of
which $20.5 million was attributable to the 23% decrease in average oil
prices received and $0.1 million was attributable to the slight decrease
in average gas prices received; and
- Volume variances that had a $12.6 million favorable impact on sales, with
$17.1 million of increases coming from the 583,000 Bbl increase in oil
sales volumes, partially offset by a decrease of $4.5 million from the
1.1 Bcf decrease in gas sales volumes.
S-21
Revenues in 2000 increased by 73% compared to 1999 revenues. In 2000, oil
and gas sales revenues increased by 74%, or $80.2 million, over those revenues
in 1999. In 2000, net sales volumes decreased by 1%, or 0.5 Bcfe, compared to
net sales volumes in 1999. Average oil prices received went from $16.75 per Bbl
in 1999 to $29.35 per Bbl in 2000, and average gas prices received increased
from $2.40 per Mcf in 1999 to $4.24 per Mcf in 2000.
In 2000, our $80.2 million increase in oil and gas sales resulted from:
- Price variances that had an $81.7 million favorable impact on sales, of
which $31.1 million was attributable to the 75% increase in average oil
prices received and $50.6 million was attributable to the 77% increase in
average gas prices received; and
- Volume variances that had a $1.5 million unfavorable impact on sales,
with $1.6 million of decreases coming from the 93,000 Bbl decrease in oil
sales volumes, partially offset by an increase of $0.1 million from the
40,000 Mcf increase in gas sales volumes.
The following table provides additional information regarding our oil and
gas sales:
NET SALES VOLUME AVERAGE SALES PRICE
------------------------- ---------------------
OIL GAS COMBINED OIL GAS
(MBBL) (BCF) (BCFE) (PER BBL) (PER MCF)
------ ----- -------- --------- ---------
2001:
First Qtr. .................................... 603 6.7 10.3 $27.63 $6.86
Second Qtr. ................................... 691 7.1 11.3 26.05 4.66
Third Qtr. .................................... 813 6.8 11.7 23.76 2.94
Fourth Qtr. ................................... 948 5.9 11.5 16.02 2.21
----- ---- ----
3,055 26.5 44.8 $22.64 $4.23
2000:
First Qtr. .................................... 653 6.6 10.6 $27.35 $2.93
Second Qtr. ................................... 650 6.9 10.8 27.55 3.99
Third Qtr. .................................... 591 7.0 10.5 30.68 4.39
Fourth Qtr. ................................... 578 7.0 10.5 32.26 5.55
----- ---- ----
2,472 27.5 42.4 $29.35 $4.24
1999:
First Qtr. .................................... 728 7.2 11.6 $10.87 $1.82
Second Qtr. ................................... 644 6.7 10.6 15.25 2.05
Third Qtr. .................................... 612 6.9 10.5 18.46 2.84
Fourth Qtr. ................................... 581 6.7 10.2 23.99 2.91
----- ---- ----
2,565 27.5 42.9 $16.75 $2.40
Revenues from our oil and gas sales comprised 99% of total revenues for
both 2001 and 2000 and 98% of total revenues for 1999. Natural gas production
made up 59% of our production volumes in 2001, 65% in 2000, and 64% in 1999.
COSTS AND EXPENSES. Our general and administrative expenses, net in 2001
increased $2.6 million, or 47%, from the level of such expenses in 2000, while
2000 general and administrative expenses increased $1.1 million, or 24%, over
1999 levels. These increases reflect the increase in our corporate activities
along with a reduction in reimbursement from partnerships we manage as these
continue undergoing planned liquidation as voted upon by their limited partners.
Our general and administrative expenses per Mcfe produced increased to $0.18 per
Mcfe in 2001 from $0.13 per Mcfe in 2000 and $0.10 per Mcfe in 1999. The portion
of supervision fees netted from general and administrative expenses was $3.1
million for 2001, $3.4 million for 2000, and $3.2 million for 1999.
Depreciation, depletion, and amortization of our assets, or DD&A, increased
$11.7 million, or 25%, in 2001 from 2000, while 2000 DD&A increased $5.4
million, or 13%, from 1999 levels. In 2001, the increase was primarily due to
additional dollars spent to add to our reserves and increased associated service
costs
S-22
in an environment where demand for such services had increased compared to 2000,
along with a 6% increase in production. In 2000, the increase was primarily due
to the additional dollars spent to add to our reserves and associated costs in
2000 over 1999. Our DD&A rate per Mcfe of production was $1.33 in 2001, $1.13 in
2000, and $0.99 in 1999, reflecting variations in per unit cost of reserves
additions.
Our production costs in 2001 increased $7.5 million, or 26%, over such
expenses in 2000, while those expenses in 2000 increased $9.6 million, or 49%,
over 1999 costs. Our production costs per Mcfe produced were $0.82 in 2001,
$0.69 in 2000, and $0.46 in 1999. The portion of supervision fees netted from
production costs was $3.1 million for 2001, $3.4 million for 2000, and $3.2
million for 1999. Approximately $1.7 million of the increase in production costs
during 2001 was related to severance taxes. Severance taxes increased primarily
from the expiration of certain specific well severance tax exemptions. The
remainder of the increase reflected costs associated with new wells drilled and
acquired and the related increase in costs in procuring such services in an
environment where demand for such services has increased from the prior year.
While our production costs increased 49% in 2000, our oil and gas sales
increased 74%. That increase in oil and gas sales had a direct impact on the
increase in production costs, as severance taxes have a direct correlation to
sales and were $4.9 million higher in 2000. Also, the increase in commodity
prices brought increased demand and competition for field services that resulted
in an increase in the cost of those services. Remedial well work and workover
costs increased $1.2 million over 1999 levels. In the Masters Creek area,
salt-water disposal charges, which increased $0.4 million over 1999 charges,
increased as the volume of water associated with that production increased. Also
in the Masters Creek area, production chemical costs increased $0.6 million as
we began our scale inhibitor program in that area.
Interest expense on our Senior Notes issued in July 1999, including
amortization of debt issuance costs, totaled $13.1 million in both 2001 and 2000
and $5.3 million in 1999. Interest expense on our Convertible Notes due 2006,
including amortization of debt issuance costs, totaled $7.4 million in 2000 and
$7.5 million in 1999. Interest expense on the credit facility, including
commitment fees and amortization of debt issuance costs, totaled $5.8 million in
2001, $0.7 million in 2000 and $6.1 million in 1999. The total interest expense
in 2001 was $18.9 million, of which $6.3 million was capitalized. The 2000 total
interest expense was $21.2 million, of which $5.2 million was capitalized. The
1999 total interest expense was $18.9 million, of which $4.5 million was
capitalized. We capitalize that portion of interest related to our exploration,
partnership, and foreign business development activities. The decrease in total
interest expense in 2001 was attributed to the conversion and extinguishment of
our Convertible Notes in December 2000 and the increase in capitalized interest,
partially offset by the increase in interest paid on our credit facility. The
increase in interest expense in 2000 was attributed to the replacement of our
bank borrowings in August 1999 with the Senior Notes that carry a higher
interest rate.
In the fourth quarter of 2001, we took a domestic non-cash write-down of
oil and gas properties, as discussed in Note 1 to the Consolidated Financial
Statements. Lower prices for both oil and natural gas at December 31, 2001,
necessitated a pre-tax domestic full cost ceiling write-down of $98.9 million,
or $63.5 million after tax. In addition to this domestic ceiling write-down, we
expensed $2.1 million of non-recurring charges in the fourth quarter of 2001 for
certain delinquent accounts receivable, the majority of which was related to gas
sold to Enron, and a write-off of debt issuance costs for a planned offering
that was cancelled based upon market conditions following the events of
September 11, 2001.
As discussed in Note 1 to the Consolidated Financial Statements, we adopted
SFAS No. 133, amended by SFAS No. 137 and SFAS No. 138, on January 1, 2001. Our
adoption of SFAS No. 133 resulted in a one-time net of taxes charge of $392,868,
which is recorded as a Cumulative Effect of Change in Accounting Principle on
our Consolidated Statement of Income.
In the fourth quarter of 2000, we recorded a $0.6 million non-recurring
loss on the early extinguishment of debt (net of taxes), as discussed in Note 4
to the Consolidated Financial Statements. We called our Convertible Notes for
redemption effective December 26, 2000. Holders of approximately $100.0 million
of the Convertible Notes elected to convert their notes into shares of our
common stock.
S-23
Holders of the remaining $15.0 million of the Convertible Notes elected to
redeem their notes for cash plus accrued interest. This cash redemption resulted
in this non-recurring item.
NET INCOME (LOSS). Our loss before extraordinary item and change in
accounting principle in 2001 of $(22.0) million was 137% lower and Basic loss
per share ("Basic EPS") before extraordinary item and change in accounting
principle of $(0.89) was 132% lower than our 2000 net income of $59.8 million
and Basic EPS of $2.82. These decreases reflected the effect of $101.0 million
in non-recurring charges in 2001 as described above. The lower percentage
decrease in Basic EPS reflects a 16% increase in weighted average shares
outstanding in 2001, primarily due to the conversion of our Convertible Notes
into 3.2 million shares of common stock in December 2000.
Our net loss for 2001 was $(22.3) million with a loss per share of $(0.90)
per diluted share. Our net income for 2001, excluding non-recurring charges of
$101.0 million as described above, totaled $42.5 million with EPS of $1.67 per
diluted share. These amounts are lower than our 2000 net income of $59.8 million
and EPS of $2.53 per diluted share, primarily due to significantly lower oil
prices and overall increased costs.
Our income before extraordinary item in 2000 of $59.8 million was 210%
higher and Basic EPS before extraordinary item of $2.82 was 164% higher than our
1999 net income of $19.3 million and Basic EPS of $1.07. These increases
reflected the effect of the 75% increase in average oil prices received and 77%
increase in average gas prices received. Oil and gas prices rose each quarter
and resulted in quarterly sequential increases in earnings. The lower percentage
increase in Basic EPS reflects an 18% increase in weighted average shares
outstanding in 2000, primarily due to our third-quarter 1999 public sale of 4.6
million shares of common stock.
RELATED-PARTY TRANSACTIONS
We are the operator of a number of properties owned by our affiliated
limited partnerships and joint ventures and, accordingly, charge these entities
and third-party joint interest owners operating fees. The operating fees charged
to the partnerships in 2001, 2000, and 1999 totaled approximately $925,000,
$1,775,000, and $1,970,000, respectively. We are also reimbursed for direct,
administrative, and overhead costs incurred in conducting the business of the
limited partnerships, which totaled approximately $3,140,000, $4,465,000, and
$4,000,000 in 2001, 2000, and 1999, respectively. In partnerships in which the
limited partners have voted to sell their remaining properties and liquidate
their limited partnerships, we are also reimbursed for direct, administrative,
and overhead costs incurred in the disposition of such properties, which costs
totaled approximately $2,360,000, $1,220,000, and $850,000 in 2001, 2000, and
1999, respectively.
CONTRACTUAL COMMITMENTS AND OBLIGATIONS
Our contractual commitments for the next four years and thereafter are as
follows:
2002 2003 2004 2005 THEREAFTER TOTAL
---------- ---------- ---------- ------------ ------------ ------------
Non-cancelable operating lease
commitments....................... $1,393,095 $1,480,092 $1,492,268 $ 248,711 $ -- $ 4,614,166
Senior Subordinated Notes due August
2009.............................. -- -- -- -- 125,000,000 125,000,000
Credit Facility which expires in
October 2005(1)................... -- -- -- 134,000,000 -- 134,000,000
---------- ---------- ---------- ------------ ------------ ------------
$1,393,095 $1,480,092 $1,492,268 $134,248,711 $125,000,000 $263,614,166
========== ========== ========== ============ ============ ============
(1) The repayment of the credit facility is based upon the balance at December
31, 2001. The amount borrowed under this facility has increased from 2001
year end levels. This amount excludes $0.8 million of a standby letter of
credit issued under this facility.
S-24
LIQUIDITY AND CAPITAL RESOURCES
During 2001, we relied both upon internally generated cash flows of $139.9
million and $123.4 million of additional borrowings from our bank credit
facility to fund capital expenditures of $275.1 million. During 2000, we
primarily used internally generated cash flows of $128.2 million to fund capital
expenditures of $173.3 million, along with the remaining net proceeds from our
third quarter 1999 issuance of Senior Notes and common stock.
NET CASH PROVIDED BY OPERATING ACTIVITIES. In 2001, net cash provided by
our operating activities increased by 9% to $139.9 million, as compared to
$128.2 million in 2000 and $73.6 million in 1999. The 2001 increase of $11.7
million was primarily due to reductions in working capital as oil and gas sales
receivables decreased in 2001 along with a reduction in interest expense of $3.3
million. These increases in cash flow were offset by an $8.0 million reduction
of oil and gas sales, a $7.5 million increase in oil and gas production costs,
and a $2.6 million increase in general and administrative expense. The 2000
increase of $54.6 million was primarily due to $80.2 million of additional oil
and gas sales, partially offset by $12.2 million of increases in oil and gas
production costs, general and administrative expenses, and interest expense.
EXISTING CREDIT FACILITIES. At December 31, 2001, we had $134.0 million in
outstanding borrowings under our credit facility. Our credit facility at year
end 2001 consisted of a $250.0 million revolving line of credit with a $200.0
million borrowing base. The borrowing base is redetermined at least every six
months. Our revolving credit facility includes, among other restrictions,
requirements as to maintenance of certain minimum financial ratios (principally
pertaining to working capital, debt, and equity ratios) and limitations on
incurring other debt. We are in compliance with the provisions of this
agreement. The credit facility extends until October 2005. At December 31, 2000,
we had $10.6 million in outstanding borrowings under this facility.
Subsequent to December 31, 2001, upon the closing of the New Zealand TAWN
acquisition, the credit facility was increased to $300.0 million and the
borrowing base became $275.0 million. Our bank facility is described in more
detail in "Description of Existing Indebtedness."
WORKING CAPITAL. Our working capital further declined from a deficit of
$22.5 million at December 31, 2000, to a deficit of $36.5 million at December
31, 2001. The decrease was primarily due to reductions in oil and gas sales
receivables, as oil and gas prices were lower at year end 2001, and an increase
in payables to partnerships related to December 2001 oil and gas property sales.
CAPITAL EXPENDITURES IN 2001. Our capital expenditures of approximately
$275.1 million included:
Domestic activities of $224.3 million as follows:
- $120.6 million, or 44%, for developmental drilling;
- $40.5 million, or 15%, for producing properties acquisitions, with
approximately $32.6 million spent on the Lake Washington acquisition and
the remainder for the purchase of property interests from partnerships
managed by us;
- $36.4 million, or 13%, for exploratory drilling;
- $25.3 million, or 9%, for domestic prospect costs, principally leasehold,
seismic, and geological costs;
- $1.1 million, or less than 1%, for fixed assets;
- $0.3 million for field compression facilities; and
- $0.1 million for gas processing plants in the Brookeland and Masters
Creek areas.
S-25
New Zealand activities of $50.8 million as follows:
- $19.0 million, or 7%, for developmental drilling to further delineate the
Rimu and Kauri areas;
- $17.9 million, or 7%, for the Rimu Production Station;
- $7.2 million, or 3%, for exploratory drilling in the Rimu and Kauri
areas;
- $5.5 million, or 2%, for prospect costs, principally seismic and
geological costs;
- $0.8 million, or less than 1%, for producing properties acquisition
evaluation costs related to our TAWN acquisition; and
- $0.4 million for fixed assets, principally computers and office furniture
and fixtures.
In 2001, we participated in drilling 40 development wells and 13
exploratory wells, of which 38 development wells and six exploratory wells were
successes. Four of the development wells were drilled in New Zealand to
delineate the Rimu and Kauri areas, two of which were successful. Two of the
exploratory wells were drilled in New Zealand; one unsuccessful and one was
temporarily abandoned. Of our $95.9 million of unproved property costs, $72.3
million relates to our inventory of developmental and exploratory acreage to
sustain drilling activity for future growth, while the remaining $23.6 million
pertains to the Rimu Production Station which will be reclassified to proved
properties once it comes on-line near the end of the first quarter of 2002.
CAPITAL EXPENDITURES FOR 2002. We estimate we will spend approximately
$132.5 million during 2002. Approximately $39.8 million of the 2002 budget is
allocated to domestic drilling, primarily in the Lake Washington area. In New
Zealand, approximately $11.2 million of the 2002 budget is allocated to
drilling, with another $8.7 million expected to be spent primarily for
production facilities. In 2002, we anticipate drilling 20 development wells and
2 exploratory wells domestically, along with six development wells and one
exploratory well in New Zealand. Approximately $54.6 million is targeted towards
producing property acquisitions, the majority for the TAWN properties in New
Zealand that closed in January 2002. Of the remainder, $13.5 million will be
used primarily for domestic leasehold, seismic, and geological costs, and $4.7
million is budgeted for such costs in New Zealand. This $132.5 million budget
also excludes any producing property acquisitions that may arise in this low
price environment and also excludes any property sales. Although we expect our
2002 total production to increase by 10% to 20% over 2001 due to the focus of
our budget in the Lake Washington area and in New Zealand, we expect production
to decline in our other core areas as no new drilling is currently budgeted to
offset their natural production decline.
We believe that the anticipated internally generated cash flows for 2002,
together with bank borrowings under our credit facility, will be sufficient to
finance the costs associated with our currently budgeted 2002 capital
expenditures. Should other producing property acquisitions activity become
attractive in the current environment, we intend to explore the use of debt and
or equity offerings to fund such activity.
CAPITAL EXPENDITURES IN 2000 AND 1999. Our capital expenditures were
approximately $173.3 million in 2000 and $78.1 million in 1999. During 1999, we
used internally generated cash flows of $73.6 million to fund capital
expenditures of $78.1 million. During 2000, we primarily used internally
generated cash flows of $128.2 million to fund capital expenditures of $173.3
million, along with part of the remaining net proceeds from our third quarter
1999 issuance of Senior Notes and common stock. Our capital expenditures in 2000
included:
Domestic activities of $157.9 million as follows:
- $90.3 million, or 52%, for developmental drilling;
- $33.4 million, or 19%, for producing properties acquisitions,
approximately half of which was for the purchase of property interests
from partnerships managed by us, with the other half purchased from a
third party;
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- $16.3 million, or 9%, for domestic prospect costs, principally leasehold,
seismic, and geological costs;
- $15.5 million, or 9%, for exploratory drilling;
- $1.4 million, or 1%, for fixed assets;
- $0.8 million, or less than 1%, for gas processing plants in the
Brookeland and Masters Creek areas; and
- $0.2 million for field compression facilities.
New Zealand activities of $15.4 million as follows:
- $7.6 million, or 4%, for developmental drilling to further delineate the
Rimu area;
- $4.5 million, or 3%, for prospect costs, principally seismic and
geological costs;
- $2.1 million, or 1%, for exploratory drilling;
- $1.1 million, or 1%, for the initial stages of production facilities; and
- $0.1 million, or less than 1%, for fixed assets, principally a field
office and warehouse.
In 2000, we participated in drilling 61 development wells and nine
exploratory wells, of which 54 development wells and five exploratory wells were
successes. Two of the development wells were drilled in New Zealand to delineate
the Rimu area, both of which were successful.
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BUSINESS AND PROPERTIES
GENERAL
Swift Energy Company engages in developing, exploring, acquiring, and
operating oil and gas properties, with a focus on onshore oil and natural gas
reserves in Texas and Louisiana and onshore oil and natural gas reserves in New
Zealand. At year end 2001, on a pro forma basis, we had estimated proved
reserves of 713.6 Bcfe, concentrated 48% in Texas, 25% in Louisiana and 24% in
New Zealand. Approximately 52% of these reserves are natural gas.
We currently focus our business in the following six core areas:
- AWP Olmos -- South Texas
- Masters Creek -- Central Louisiana
- Brookeland -- East Texas
- Lake Washington -- South Louisiana
- Rimu/Kauri -- New Zealand
- TAWN -- New Zealand
COMPETITIVE STRENGTHS AND BUSINESS STRATEGY
We believe that we have the competitive strengths that together with a
balanced and comprehensive business strategy provide us with the flexibility and
capability to accomplish our goals.
Successful track record
Our growth in reserves and production has resulted primarily from drilling
activities in our core areas combined with producing property acquisitions. In
2001, we increased our proved reserves by 3%, which replaced 136% of our 2001
production. Our net cash provided by operations increased from $37.1 million in
1996 to $139.9 million in 2001. While 2001 production increased 6% in relation
to 2000 production, we have increased our production from 19.4 Bcfe in 1996 to
44.8 Bcfe in 2001. We believe our experience in growing our reserves will be
beneficial to us as we continue to pursue our business strategy.
Balanced Approach to Adding Reserves
Over the past five years, we have spent an average of 11% of our capital
expenditure budget on exploration drilling, 51% on development activities, 19%
on proved property acquisitions and 14% on lease acquisitions. When we believe
the market favors increasing reserves through acquisitions, we apply our
considerable experience in evaluating and negotiating prospective acquisitions.
For example, in 1998, when commodity prices were relatively weak, 32% of our
capital expenditures consisted of property acquisitions, with 37% committed to
our drilling activities. In contrast, in 2001, when commodity prices were
relatively strong in the first half of the year, only 15% of our capital
expenditures were spent on property acquisitions, with our drilling expenditures
increasing to 67% of total capital expended. We believe this balanced approach
has resulted in our ability to grow reserves in a relatively low cost manner,
while participating in the upside potential of exploration. Over the five-year
period ended December 31, 2001, we replaced 302% of our production at an average
cost of $1.26 per Mcfe.
In this current environment of stronger oil prices in relation to gas
prices, our 2002 capital expenditures are focused on developing and producing
long-lived oil reserves in Lake Washington and in the Rimu/Kauri area. Our
current focus on developing and acquiring long-lived reserves with an overall
flatter production decline curve should strengthen our ongoing production
profile and extend our average reserve life.
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Concentrated Focus on Core Areas
Our concentration of reserves and our significant acreage positions in our
core areas allow us to realize economies of scale in drilling and production. We
enhance the value of this concentration by acting as operator of 95% of our
proved reserves at year end 2001. Our operational control allows us to better
manage production, control our expenses, allocate capital and time field
development. We intend to continue to acquire large acreage positions in
under-explored and under-exploited areas where, as operator, we can exploit
successful discoveries to create new core areas or grow production from
developed fields. In executing this strategy:
- We focus our resources on acquiring properties that we can operate, and
in which we can obtain a significant working interest. With operational
control, we can apply our technical and operational expertise to optimize
our exploration and exploitation of the properties that we acquire.
- We acquire and operate domestic properties in a limited number of
geographic areas. Operating in a concentrated area helps us to better
control our overhead by enabling us to manage a greater amount of acreage
with fewer employees, minimizing incremental costs of increased drilling
and production.
- We continue to believe in natural gas prospects and reserves in the
United States. The natural gas market in the United States has a
well-developed infrastructure. Natural gas is viewed by many as the
preferred fuel in North America for several reasons, including
environmental concerns. We have a strong inventory of natural gas that
can be developed in a higher priced environment.
- We seek to operate large acreage positions with high exploration and
development potential. For example, on our original 100,000 acre New
Zealand permit, only two wells had been drilled at the time that we
acquired our interest. The Masters Creek, Brookeland and Lake Washington
areas also had significant additional development potential when we first
acquired our interest in those areas.
Ability to Build Upon our Successful Discoveries and Acquisitions in New
Zealand
Our New Zealand activities provide us with long-term growth opportunities
and significant potential reserves in a country with stable political and
economic conditions, existing oil and gas infrastructure and favorable tax and
royalty regimes. We have completed construction of our Rimu production and gas
processing facilities. We expect that the Rimu production station will be
operational in April 2002, enabling us to begin the sale of production from the
Rimu/Kauri area. We were able to bring our Rimu discovery on commercial
production in a significantly shorter period than any other similar project
previously undertaken in New Zealand of which we are aware.
During 2001 we produced and sold 84,261 Bbls on an extended production test
basis at an average sales price of $21.64 per Bbl from our Rimu and Kauri wells.
We have several exploration and delineation wells planned in the Rimu/Kauri
area, as well as prospective areas in New Zealand outside of the Rimu/Kauri area
that we will evaluate for drilling in the future.
In January 2002, we acquired the TAWN fields. From the closing of the TAWN
acquisition on January 25, 2002 through March 25, 2002, these fields have
generated an average daily net production of approximately 40 MMcfe. In our TAWN
acquisition, we also acquired extensive associated processing facilities and
pipelines, which give us a competitive advantage through infrastructure that
complements our existing fields, providing us with increased access to export
terminals and markets and additional excess processing capacity for both oil and
natural gas.
Experienced Technical Team
We employ oil and gas professionals, including geophysicists,
petrophysicists, geologists, petroleum engineers and production and reservoir
engineers, who have an average of approximately 25 years of experience in their
technical fields and have been employed by Swift for an average of over 10
years. We
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continually apply our extensive in-house expertise and current advanced
technologies to benefit our drilling and production operations. We have
developed a particular expertise in drilling horizontal wells at vertical depths
below 10,000 feet, often in a high pressure environment, involving single or
dual lateral legs of several thousand feet. This results in an integrated
approach to exploration using multidisciplinary data analysis and interpretation
that has helped us identify a number of exploration prospects.
We use various recovery techniques, including water flooding and acid
treatments, fracturing reservoir rock through the injection of high-pressure
fluid, and inserting coiled tubing velocity strings to enhance and maintain gas
flow. We believe that the application of fracturing technology and coiled tubing
has resulted in significant increases in production and decreases in completion
and operating costs, particularly in our AWP Olmos area.
We have increasingly used seismic technology to enhance the results of our
drilling and production efforts, including 2-D and 3-D seismic analysis,
amplitude versus offset studies and detailed formation depletion studies. As a
result, we have maintained internal seismic expertise and have compiled an
extensive database.
When appropriate, we develop new applications for existing technology. For
example, in New Zealand we acquired seismic data by effectively combining marine
data with the acquisition of land seismic data, an application we have not seen
any other company use in New Zealand.
Financial Discipline
We practice a disciplined approach to financial management and have
historically maintained a strong capital structure that preserves our ability to
execute our business plan. Key components of our financial discipline include
maintaining a balanced capital budget, establishing leverage ratios that are
appropriate given the volatility of the oil and gas markets and
opportunistically accessing the capital markets. After giving effect to our
common stock offering and this offering, as of December 31, 2001, our long-term
debt would have comprised approximately 49% of our total capitalization. As of
March 31, 2002, after the TAWN acquisition in January 2002 and the Antrim
acquisition in March 2002, and after giving effect to our common stock offering
and this offering, our long-term debt would have comprised approximately 49% of
our total capitalization. Additionally, after applying the net proceeds from our
common stock offering and this offering to reduce amounts outstanding under our
credit facility, based on our March 31, 2002 balance, we expect to have
approximately $188.9 million of available borrowing capacity. By replacing
indebtedness incurred under our revolving credit facility in connection with
acquisition, development and exploitation activity with the net proceeds from
our common stock offering and this offering, we will be implementing our
strategy of matching long-lived assets with long-term debt and equity.
DOMESTIC CORE OPERATING AREAS
AWP Olmos Area
We began drilling and operating wells in the AWP Olmos area in 1988. Since
that time, we have gained extensive expertise with the low-permeability,
tight-sand formations typical of these fields. Our net proved reserves for this
area of 207.5 Bcfe as of December 31, 2001 constituted 32% of our total reserves
at that date. This field is characterized by long-lived reserves, with 74% of
the reserves at year end 2001 comprised of natural gas.
Additionally, AWP Olmos area has yielded a steady production base,
producing an average of approximately 35,700 Mcfe per day in 2001. We have
maintained these rates by performing fracture extensions and installing coiled
tubing velocity strings. During 2001, approximately 76% of our production from
this field was natural gas. As of December 31, 2001, we owned interests in 496
wells and were the operator of 492 wells in this area producing gas from the
Olmos Sand formation at depths from 10,000 to 11,500 feet. We own nearly a 100%
working interest in almost all wells in this area in which we have an interest.
As of December 31, 2001, we owned drilling and production rights to
approximately 28,562 net acres in this area in South Texas.
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Geologically, this region is characterized by a blanket sand with an
extensive fault system. In 2001, all 11 development wells we drilled in the AWP
Olmos area were successful. As of December 31, 2001, we had 122 proved
undeveloped locations in this area. Our planned 2002 capital expenditures in
this area will focus on performing fracture extensions and installing coiled
tubing velocity strings.
Masters Creek Area
We acquired our interest in this area in mid-1998 as part of a larger
property acquisition. Located just east of the Texas-Louisiana border in the
Louisiana parishes of Vernon and Rapides, this area contains our operated fields
of Masters Creek and South Burr Ferry as well as other fields in which we have
interests, but which are operated by others. As of December 31, 2001, we owned
drilling and production rights to 194,212 gross acres, 149,400 net acres, and
141,000 fee mineral acres in this area.
The Masters Creek area contains horizontal wells producing both oil and gas
from the Austin Chalk formation. In 2001, this area produced 15.3 Bcfe. In 2001,
we drilled or participated in drilling nine development wells, all successful.
As of December 31, 2001, we had 18 proved undeveloped drilling locations.
Brookeland Area
This area is located in southeast Texas in Jasper and Newton counties near
the Texas-Louisiana border. This area also was a part of the 1998 property
acquisition in which we acquired our interest in the Masters Creek area and
contains horizontal wells producing both oil and gas from the Austin Chalk
formation. In 2001, we drilled or participated in the drilling of 11 development
wells, all successful. Our reserves in this area are approximately 60% oil and
natural gas liquids.
As of December 31, 2001, we owned drilling and production rights to 127,703
gross acres, 79,874 net acres, and 15,000 fee mineral acres containing
substantial proved undeveloped reserves. As of December 31, 2001, we had 17
proved undeveloped drilling locations in this field.
Lake Washington Field
We acquired interests in Lake Washington Field, located in Plaquemines
Parish, Louisiana, effective March 1, 2001. Lake Washington Field produces oil
from multiple Miocene sands ranging in depth from less than 2,000 feet to
greater than 10,000 feet. This field is located on a salt dome and has produced
over 300 million BOE since its inception. The area around the dome is heavily
faulted, thereby creating a large number of potential traps. Since our
acquisition of this field, we have mapped multiple zones covering all sides of
the salt dome. We see both significant development opportunities and several
distinct exploration plays on the property. Oil and gas from approximately 26
producing wells is gathered from four platforms located in water depths ranging
from six feet to 11 feet, with drilling and workover operations performed with
barge rigs. We have identified a number of under-exploited fault blocks in this
area.
In 2001, we drilled four development wells and one exploratory well, and in
2002 we drilled two additional wells and a salt water disposal well, all of
which were successful. As a result of our drilling and production activities, we
have increased average production in the field net to our interest from
approximately 652 BOE per day in March 2001, when we acquired the field, to
approximately 1,236 BOE per day during February 2002. As of December 31, 2001,
we owned drilling and production rights to 13,595 net acres. Our reserves in
this field are approximately 95% oil and natural gas liquids. As of year end
2001, we had 29 proved undeveloped drilling locations in this field. Our planned
2002 capital expenditures in this field are approximately $25.0 million and
include 20 development wells and two exploratory wells.
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DOMESTIC EMERGING GROWTH AREAS
We are pursuing development and exploration activities in the following
emerging growth areas, including areas where we drilled a number of wells in
2001. The timing and scope of our drilling in these areas depends upon changes
in the relative prices of oil and gas and other market factors.
Frio (Garcia Ranch) Area in South Texas
This area, near the southern tip of Texas in Willacy and Kenedy counties,
features the Frio formation at depths ranging from 10,000 to 16,000 feet. The
traps are structure related and consist of faulted anticlines and three-way
upthrown fault traps. Our prospects are defined by 3-D seismic surveys that were
shot in the mid-1990s. We had two discoveries in the area in 2001, one in the
Rome prospect in Willacy County at a depth of 16,388 feet, and the other in the
Siena prospect in Kenedy County at a depth of 16,300 feet. We have a 65% working
interest in these prospects.
Wilcox Area in Texas Gulf Coast
This area is located along the Texas Gulf Coast in Goliad, Lavaca and
Zapata counties. Our primary objectives are the Austin, Nita, Cameron, Brandon,
Tina, Gracie, and Tyler Upper Wilcox sands. Traps in the Wilcox sand are both
structural and stratigraphic and include upthrown fault traps as well as buried
sand bars and sand channels, with formation depths ranging from 10,000 to 15,000
feet, as defined by both 2-D and 3-D seismic surveys.
Our 2001 exploration activity in this area had three discoveries in the
Wilcox sands, two of which were located in Goliad County, Texas: the Nita
prospect drilled to a depth of approximately 15,000 feet and the Brandon
prospect drilled to a depth of about 13,000 feet. Our working interests in these
two wells are 73% and 60%, respectively. The third well was in the Falcon Ridge
prospect in Zapata County, Texas in which we have a 25% working interest.
Additionally, in Lavaca County we have another Wilcox prospect, the Pearl
prospect. We currently have a 100% working interest in this prospect, but we
have undertaken to market interests in the prospect to potential industry
partners. The Pearl prospect has a projected depth for the test well of 14,500
feet. Additionally, we have other prospects in this area that we are considering
for our future drilling activities.
Woodbine Area in East Texas
The Woodbine formation is located in southeast Texas in San Jacinto, Polk
and Tyler counties. We drilled one well to the Woodbine formation during
2001 -- in the Lion prospect in San Jacinto County, Texas, to a depth of 15,800
feet. Although hydrocarbon-bearing intervals were found, the well was determined
to be noncommercial.
Additionally, we have two other Woodbine prospects for future drilling: the
Jaguar and Bobcat prospects, both located in Polk County, where we would serve
as operator with approximately a 75% working interest.
Miocene Area in South Louisiana
We successfully drilled our first exploratory well in the Miocene sands in
our new Lake Washington Area in Plaquemines Parish, Louisiana -- to a depth of
3,200 feet with a retained interest of 100%. This area has substantial
exploration and development potential, with sands extending from shallow depths
down to 10,000 feet or more. Current plans are to drill another exploratory well
in the area during 2002.
Also in Plaquemines Parish, about 50 miles north of the Lake Washington
Area, is the Delacroix area where we have been developing prospects for both
shallow and deep horizons in the Miocene sands. The first well in this area, in
the Grand Lake prospect, was drilled to a depth of 18,000 feet early in 2002 and
was temporarily abandoned but may become a possible sidetrack well in the
future.
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NEW ZEALAND CORE OPERATING AREAS
Our activity in New Zealand began when we were issued two petroleum
exploration permits in 1995 and 1996, which we combined in 1998 after
surrendering a portion of this acreage. In 1999, we expanded this permit by
adding 12,800 offshore acres. As of December 31, 2001 our permit 38719 included
approximately 50,300 acres in the Taranaki Basin of New Zealand's North Island.
We have a 95% working interest in this permit, and have fulfilled all current
obligations under this permit. The initial five-year term of the permit ended on
August 12, 2001. We have, however, extended our petroleum exploration permit an
additional five years by relinquishing 50% of the acreage within the permit
under the terms of the Crown Minerals Act of 1991. Specifically, we have chosen
to relinquish acreage on the western and eastern portions of our permit that we
feel is not prospective. The approximately 50,300 gross acres that we retain
include all of the acreage that we believe is prospective, and include our Rimu
and Kauri areas as well as our Tawa and Matai prospects.
As of December 31, 2001, our investment in New Zealand totaled
approximately $84.4 million. Approximately $45.6 million of our investment costs
have been included in the proved properties portion of our oil and gas
properties and $38.8 million is included as unproved properties. After giving
effect to our acquisitions in the first quarter of 2002, our total investment in
New Zealand would have been $143.5 million, $54.4 million of which was used to
acquire the TAWN assets, containing all proved producing reserves, and $4.7
million of which was used to acquire the Antrim assets.
At year end 2001, our proved reserves in the Rimu/Kauri area were estimated
at 101.9 Bcfe, with 64% of such reserves classified as oil, natural gas liquids
and condensates. We built production and processing facilities, which are
initially designed to handle 3,500 Bbls of oil per day and 10,000 Mcf of
processed natural gas per day. These facilities will allow us to commence sale
of production from our Rimu discovery in April 2002. We recently entered into an
agreement to sell to Genesis Power Limited approximately 38.0 Bcf of natural gas
over a 10-year period. Natural gas deliveries from our Rimu discovery will begin
under this contract once the Rimu production station is operational.
We expanded our operation in New Zealand in January 2002 with our purchase
of Southern NZ Exploration, Ltd., from Shell New Zealand, through which we
acquired interests in four fields and significant infrastructure assets. We have
estimated the proved reserves associated with the TAWN acquisition at year end
2001 to be approximately 62.1 Bcfe, of which approximately 75% is natural gas.
First quarter 2002 net daily production from the TAWN fields is estimated to be
1,071 Bbl of oil, 30 MMcf of natural gas, and 561 Bbl of natural gas liquids per
day, or a total net daily production of approximately 40 MMcfe of natural gas
per day.
Rimu Area
In 1996 we acquired our interest in permit 38719, which is located in the
eastern onshore portion of the Taranaki Basin in New Zealand. In 1997, we
acquired 2-D seismic data for two key areas in this permit. Based on analysis of
this data, the first exploratory well, Rimu-A1, was drilled onshore in 1999. In
late 1999, we successfully completed and production tested the Rimu-A1. Based
upon additional 2-D seismic data acquired in March 2000, which better identified
the extent of the Rimu structure, we drilled and tested two delineation wells,
the Rimu-B1 and the Rimu-B2. In 2001 we have drilled and tested three more Rimu
delineation wells, the Rimu-A2, Rimu-A3 and Rimu-B3. The Rimu-A3 was successful;
the Rimu-A2 and Rimu-B3 were dry. Early in 2002, the Rimu-A2 was sidetracked and
was successfully completed. The Rimu-B3 was also sidetracked in early 2002 and
again was unsuccessful.
Early in 2002, we were awarded petroleum mining permit 38151 by the New
Zealand Ministry for Economic Development for the development of the Rimu
discovery over a 5,524-acre area for a primary term of 30 years. We plan to add
up to three drilling pads in the permit area, for a total of five pads, with
each able to handle multiple wells. Nine additional wells are currently planned
within the mining permit, one gas injection well and eight development wells
targeting the Upper Tariki and Lower Tariki sandstones and the Upper Rimu
limestone.
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Kauri Area
In 2000, we acquired approximately 45 miles of data from a number of 2-D
transitional zone seismic lines tied to existing marine and land seismic grids
to study the Kauri structure, which is to the south and southeast of our Rimu
discovery. We based our well location on our interpretation of these data. We
drilled our Kauri-A1 well to a total depth of 14,760 feet in the third quarter
of 2001. We encountered significant hydrocarbon-bearing intervals in this well,
and we intend to conduct extensive testing and analysis on these intervals in
the future.
The initial hydrocarbon-bearing zone encountered in the Kauri-A1 well was
found in a shallow section of the Miocene-Pliocene age sandstones, the Manutahi
sand, beginning at a depth of 3,746 feet. Petrophysical analysis of logging
data, along with laboratory analysis of sidewall cores, confirm an oil column of
approximately 39 feet with excellent porosities and permeabilities. Based on
electric log analysis and saturation measurements of the sidewall cores, an
oil/water contact was found at 3,815 feet. Current geologic mapping indicates
that this location is approximately 66 feet low to the top of the structure that
covers approximately 1,000 acres of aerial extent in this fault block. We
commenced drilling the Kauri-A2 development well in September 2001 in order to
further evaluate this prospective interval. This well successfully tested the
Manutahi Sands.
The second significant hydrocarbon-bearing interval encountered in the
Kauri-A1 well was found in the Miocene age sandstones, the Kauri sand, beginning
at a depth of 9,473 feet. This interval largely consists of multiple sections of
sandstones and claystones that yielded oil and gas shows associated with
drilling breaks and appears to be hydrocarbon bearing based on log analysis.
Further petrophysical analysis of this data indicates a hydrocarbon-bearing
sandstone interval of approximately 577 feet with good porosity. This same
interval was also encountered, although not tested, in all of the previously
drilled Rimu wells, with varying degrees of hydrocarbon shows. This interval in
the Kauri-A1 well has greater sand development than in the Rimu wells, with mud
log shows while drilling significantly better than in any of the previous wells
drilled at Rimu.
The third and fourth hydrocarbon-bearing intervals encountered in this well
were found in the Upper Tariki sand beginning at a depth of 11,126 feet and the
Upper Rimu limestone beginning at a depth of 11,270 feet. Both of these
intervals have also been present in all five wells drilled at Rimu, extending
both of these intervals over a distance in excess of five miles. Based upon
analysis of mud logs as well as the logging while drilling tools, the Upper
Tariki appears to have a gross thickness of 30 feet and the Upper Rimu limestone
appears to have a gross thickness of 33 feet.
The Kauri-B1 exploratory well was drilled approximately 1.75 miles to the
southeast of the Kauri-A pad and targeted the Manutahi sands. This well was
plugged and abandoned in late 2001.
TAWN Assets
The TAWN acquisition consisted of a 96.76% working interest in four
petroleum mining licenses, or PML, covering producing oil and gas fields, and
extensive associated hydrocarbon-processing facilities and pipelines, which give
us a competitive advantage through infrastructure that complements our existing
fields, providing us with increased access to export terminals and markets and
additional excess processing capacity for both oil and natural gas. The TAWN
assets are located approximately 17 miles north of the Rimu area.
The properties are collectively identified as the TAWN properties, an
acronym derived from the first letters of the field names -- the Tariki Field
(PML 38138), the Ahuroa Field (PML 38139), the Waihapa Field (PML 38140), and
the Ngaere Field (PML 38141). The Tariki Field and Ahuroa Field both produce
from the Tariki formation, while the Waihapa Field and Ngaere Field produce from
the Tikorangi formation. The four fields include 17 wells where the purchaser of
gas has contracted to take minimum gas quantities and can call for higher
production levels (which has occurred throughout 2002) to meet electrical demand
in New Zealand.
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Solution gas gathered from an oil facility, the Waihapa Production Station,
or WPS, flows to the Tariki Ahuroa gas plant. The current processing capacity of
the WPS facility is over 15,000 bbl of oil and 40 MMcf of natural gas per day. A
32 mile, eight inch diameter oil export line runs from the WPS to the Omata Tank
Farm at New Plymouth, where oil export facilities allow for sales into
international markets. An additional 32 mile, eight inch diameter natural gas
pipeline runs from the WPS to the Taranaki Combined Cycle Electric Generation
Facility near Stratford and on to the New Plymouth Power Station.
We have a service agreement with the owner of the Omata Tank Farm to
utilize the blending, storage, and export capabilities of the facility. The
operator of the facility provides services for a fixed fee per barrel received
and other variable costs as required by the agreement. Under the terms of the
agreement, crude oil produced from the Rimu/Kauri area will also have access to
the Omata Tank Farm.
NEW ZEALAND EMERGING GROWTH AREAS
Tawa Prospect
The Tawa prospect is located on the southeast flank of Kapuni Field and its
main targets are the Tikorangi limestone, the Upper Otaraoa sandstone and the
Tariki sandstone. This is a combination structural and stratigraphic trap. This
prospect was developed based upon our analysis of existing 3-D seismic data as
well as new 2-D seismic surveys we acquired in 1997 and 2000.
Matai Prospect
The Matai prospect is located on the southeast flank of the Tawa prospect
and its main target is the Moki sandstone. This prospect was identified based
upon our analysis of new 2-D seismic data we acquired in 2000. We acquired
additional seismic data in early 2002 to further evaluate this prospect.
Tuihu Prospect
In 2000, we entered into an agreement with Shell New Zealand whereby we
earned a 20% participating interest in petroleum exploration permit 38718
containing approximately 57,400 acres. In January 2001, the operator temporarily
abandoned the Tuihu #1 exploratory well pending further analysis. The permit now
contains approximately 28,700 acres after a scheduled acreage surrender during
December 2000. Additional analysis of the data from the well, as well as
reinterpretation of the seismic data, is underway in order to determine further
development plans.
Huinga Prospect
In 1998, we entered into agreements for a 7.5% working interest held by
Antrim Oil and Gas Limited, a Canadian company, in permit 38716 operated by
Marabella Enterprises Ltd. In turn, Antrim became 5% working interest owners in
our permit 38719. An exploratory well was drilled on the 7.5% working interest
permit and the well has been temporarily abandoned pending further evaluation.
Operations to re-enter and sidetrack this well commenced in April 2002 to target
a location to the west of the initial well. A five year extension was granted on
this permit in 2001 upon the surrender of 50% of the acreage. As part of our
March 2002 acquisition of Antrim's New Zealand assets, we acquired an additional
7.5% working interest in permit 38716, giving us a current 15.0% working
interest in this prospect.
OIL AND GAS RESERVES
The following table presents information regarding proved reserves of oil
and gas attributable to our interests in producing properties as of December 31,
2001, 2000, and 1999. The information set forth in the table regarding reserves
is based on proved reserves reports prepared by us and audited by H. J. Gruy and
Associates, Inc., Houston, Texas, independent petroleum engineers. Gruy's audit
was based upon
S-35
review of production histories and other geological, economic, ownership, and
engineering data provided by us.
In accordance with Securities and Exchange Commission guidelines, estimates
of future net revenues from our proved reserves and the PV-10 Value must be made
using oil and gas sales prices in effect as of the dates of such estimates and
are held constant throughout the life of the properties, except where such
guidelines permit alternate treatment, including, in the case of gas contracts,
the use of fixed and determinable contractual price escalations. Proved reserves
as of December 31, 2001, were estimated based upon prices in effect at year end.
The weighted averages of such year end prices domestically were $2.68 per Mcf of
natural gas and $18.51 per barrel of oil, compared to $11.25 and $25.50 at year
end 2000 and $2.58 and $23.69 at year end 1999. The weighted averages of such
year end 2001 prices for New Zealand were $1.18 per Mcf of natural gas and
$18.25 per barrel of oil, compared to $0.71 and $22.30 in 2000. The weighted
averages of such year end 2001 prices for all our reserves, both domestically
and in New Zealand, were $2.51 per Mcf of natural gas and $18.45 per barrel of
oil, compared to $9.86 and $24.62 in 2000. We have interests in certain tracts
that are estimated to have additional hydrocarbon reserves that cannot be
classified as proved and are not reflected in the following table. The proved
reserves presented for all periods also exclude any reserves attributable to the
volumetric production payment that was in effect in 2000 and 1999.
At year end 2001, 50% of our proved reserves were developed reserves. At
year end 2000, 45% of our proved reserves were developed.
Changes in quantity estimates and the estimated present value of proved
reserves are affected by the change in crude oil and natural gas prices at the
end of each year. While our total proved reserves quantities, on an equivalent
Bcfe basis, at year end 2001 increased by 3% over reserves quantities a year
earlier, the PV-10 Value of those reserves decreased 74% from the PV-10 Value at
year end 2000. The decrease in prices resulted in 47.1 Bcfe of downward reserve
revision, primarily attributed to the decrease in prices used at year end 2001.
Our total proved reserves quantities at year end 2000 increased by 38% over
reserves quantities a year earlier, while the PV-10 Value of those reserves
increased 310% from the PV-10 Value at year end 1999. The PV-10 Value decrease
in 2001 and the PV-10 increase in 2000 were heavily influenced by pricing
decreases at year end 2001 as compared to year end 2000 and by pricing increases
from year end 2000 as compared to year end 1999. Product prices for natural gas
decreased 75% during 2001, from $9.86 per Mcf at December 31, 2000, to $2.51 per
Mcf at year end 2001, while oil prices decreased 25% between the two dates, from
$24.62 to $18.45 per barrel. Product prices for natural gas increased 282%
during 2000, from $2.58 per Mcf at December 31, 1999, to $9.86 per Mcf at year
end 2000, while oil prices increased 4% between the two dates, from $23.69 to
$24.62 per barrel. Product prices for natural gas increased 16% during 1999,
from $2.23 per Mcf at December 31, 1998, to $2.58 per Mcf at year end 1999,
matched by a 111% increase in the price of oil between the two dates, from
$11.23 to $23.69 per barrel.
The table sets forth estimates of future net revenues presented on the
basis of unescalated prices and costs in accordance with criteria prescribed by
the SEC and their PV-10 Value. Operating costs, development costs, and certain
production-related taxes were deducted in arriving at the estimated future net
revenues. No provision was made for income taxes. The estimates of future net
revenues and their present value differ in this respect from the standardized
measure of discounted future net cash flows of $454.6 million at year end 2001,
$1,578.0 million at year end 2000 and $438.9 million at year end 1999 set forth
in Supplemental Information to our Consolidated Financial Statements, which is
calculated after provision for future income taxes.
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YEAR ENDED DECEMBER 31, 2001
--------------------------------------------------
TOTAL DOMESTIC NEW ZEALAND
-------------- -------------- ------------
ESTIMATED PROVED OIL AND GAS RESERVES
Net natural gas reserves (Mcf):
Proved developed................................... 181,651,578 167,401,736 14,249,842
Proved undeveloped................................. 143,260,547 121,087,764 22,172,783
-------------- -------------- ------------
Total....................................... 324,912,125 288,489,500 36,422,625
============== ============== ============
Net oil reserves (Bbl):
Proved developed................................... 23,759,574 20,393,142 3,366,432
Proved undeveloped................................. 29,723,062 22,171,591 7,551,471
-------------- -------------- ------------
Total....................................... 53,482,636 42,564,733 10,917,903
============== ============== ============
ESTIMATED PRESENT VALUE OF PROVED RESERVES
Estimated present value of future net cash flows from
proved reserves discounted at 10% per annum:
Proved developed................................... $ 344,478,834 $ 306,095,381 $ 38,383,453
Proved undeveloped................................. 258,507,354 186,012,413 72,494,941
-------------- -------------- ------------
Total....................................... $ 602,986,188 $ 492,107,794 $110,878,394
============== ============== ============
YEAR ENDED DECEMBER 31, 2000
--------------------------------------------------
TOTAL DOMESTIC NEW ZEALAND
-------------- -------------- ------------
ESTIMATED PROVED OIL AND GAS RESERVES
Net natural gas reserves (Mcf):
Proved developed................................... 215,169,833 215,169,833 --
Proved undeveloped................................. 203,444,143 148,130,666 55,313,477
-------------- -------------- ------------
Total....................................... 418,613,976 363,300,499 55,313,477
============== ============== ============
Net oil reserves (Bbl):
Proved developed................................... 10,980,196 10,980,196 --
Proved undeveloped................................. 24,153,400 12,962,513 11,190,887
-------------- -------------- ------------
Total....................................... 35,133,596 23,942,709 11,190,887
============== ============== ============
ESTIMATED PRESENT VALUE OF PROVED RESERVES
Estimated present value of future net cash flows from
proved reserves discounted at 10% per annum:
Proved developed................................... $1,257,570,764 $1,257,570,764 $ --
Proved undeveloped................................. 1,055,684,045 919,388,009 136,296,036
-------------- -------------- ------------
Total....................................... $2,313,254,809 $2,176,958,773 $136,296,036
============== ============== ============
YEAR ENDED DECEMBER 31, 1999
--------------------------------------------------
TOTAL DOMESTIC NEW ZEALAND
-------------- -------------- ------------
ESTIMATED PROVED OIL AND GAS RESERVES
Net natural gas reserves (Mcf):
Proved developed................................... 174,046,096 174,046,096 --
Proved undeveloped................................. 155,913,654 155,913,654 --
-------------- -------------- ------------
Total....................................... 329,959,750 329,959,750 --
============== ============== ============
Net oil reserves (Bbl):
Proved developed................................... 8,437,299 8,437,299 --
Proved undeveloped................................. 12,368,964 12,368,964 --
-------------- -------------- ------------
Total....................................... 20,806,263 20,806,263 --
============== ============== ============
ESTIMATED PRESENT VALUE OF PROVED RESERVES
Estimated present value of future net cash flows from
proved reserves discounted at 10% per annum:
Proved developed................................... $ 301,199,660 $ 301,199,660 $ --
Proved undeveloped................................. 262,854,849 262,854,849 --
-------------- -------------- ------------
Total....................................... $ 564,054,509 $ 564,054,509 $ --
============== ============== ============
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Proved reserves are estimates of hydrocarbons to be recovered in the
future. Reservoir engineering is a subjective process of estimating the sizes of
underground accumulations of oil and gas that cannot be measured in an exact
way. The accuracy of any reserves estimate is a function of the quality of
available data and of engineering and geological interpretation and judgment.
Reserves reports of other engineers might differ from the reports contained
herein. Results of drilling, testing, and production subsequent to the date of
the estimate may justify revision of such estimate. Future prices received for
the sale of oil and gas may be different from those used in preparing these
reports. The amounts and timing of future operating and development costs may
also differ from those used. Accordingly, reserves estimates are often different
from the quantities of oil and gas that are ultimately recovered. There can be
no assurance that these estimates are accurate predictions of the present value
of future net cash flows from oil and gas reserves.
A portion of our proved reserves has been accumulated through our interests
in the limited partnerships for which we serve as general partner. The estimates
of future net cash flows and their present values, based on period end prices,
assume that some of the limited partnerships in which we own interests will
achieve payout status in the future. At December 31, 2001, 32 of the limited
partnerships managed by us had achieved payout status.
No other reports on our reserves have been filed with any federal agency.
OIL AND GAS WELLS
As we continue to sell properties on behalf of limited partnerships which
have voted to liquidate, our total well count decreased. Acquisitions such as
Lake Washington, where we own nearly a 100% interest in all operated wells, have
increased well ownership on a net basis. The following table sets forth the
gross and net wells in which we owned an interest at the following dates:
OIL WELLS GAS WELLS TOTAL WELLS(1)
--------- --------- --------------
DECEMBER 31, 2001
Gross.................................................... 396 786 1,182
Net...................................................... 297.0 467.9 764.9
DECEMBER 31, 2000
Gross.................................................... 599 904 1,503
Net...................................................... 165.2 484.7 649.9
DECEMBER 31, 1999
Gross.................................................... 577 947 1,524
Net...................................................... 105.5 449.2 554.7
---------------
(1) Excludes 48 service wells in 2001, 25 service wells in 2000, and 33 service
wells in 1999. Also excludes 5 wells in 2001 and 3 wells in 2000 in New
Zealand, temporarily shut-in awaiting the commissioning of the Rimu
Production Station.
OIL AND GAS ACREAGE
As is customary in the industry, we generally acquire oil and gas acreage
without any warranty of title except as to claims made by, through, or under the
transferor. Although we have title to developed acreage examined prior to
acquisition in those cases in which the economic significance of the acreage
justifies the cost, there can be no assurance that losses will not result from
title defects or from defects in the assignment of leasehold rights. In many
instances, title opinions may not be obtained if in our judgment it would be
uneconomical or impractical to do so.
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The following table sets forth the developed and undeveloped leasehold
acreage held by us at December 31, 2001:
DEVELOPED(1) UNDEVELOPED(1)
----------------- -----------------
GROSS NET GROSS NET
------- ------- ------- -------
Alabama........................................ 10,092 2,862 776 292
Arkansas....................................... 762 558 2,040 679
Kansas......................................... -- -- 4,520 1,909
Louisiana...................................... 135,148 92,489 138,532 89,804
Mississippi.................................... 730 176 -- --
Texas.......................................... 232,258 145,162 96,817 64,807
Wyoming........................................ 522 120 84,212 74,997
All other states............................... -- -- 5,928 981
Offshore Louisiana............................. 4,609 276 25,000 1,536
Offshore Texas................................. 14,400 1,601 450 23
------- ------- ------- -------
Total -- Domestic............................ 398,521 243,244 358,275 235,028
New Zealand(2)................................. 24,901 22,411 135,459 79,552
------- ------- ------- -------
Total..................................... 423,422 265,655 493,734 314,580
======= ======= ======= =======
---------------
(1) Fee mineral acreage acquired in the Masters Creek and Brookeland areas
acquisition are not included in the above leasehold acreage table. We have
26,345 developed fee mineral acres and 114,655 undeveloped fee mineral acres
in these two areas for a total of 141,000 fee mineral acres.
(2) Excludes 24,602 gross, and 23,805 net acres acquired in the TAWN acquisition
that closed in January 2002, as well as 2,478 net acres acquired in the
Antrim acquisition which closed in March 2002.
DRILLING ACTIVITIES
The following table sets forth the results of our drilling activities
during the three years ended December 31, 2001:
GROSS WELLS NET WELLS
-------------------------------------- -------------------------------------
TEMPORARILY TEMPORARILY
YEAR TYPE OF WELL TOTAL PRODUCING DRY ABANDONED TOTAL PRODUCING DRY ABANDONED
---- ------------ ----- --------- ---- ----------- ----- --------- --- -----------
2001 Exploratory -- Domestic.... 11 6 5 -- 6.2 4.0 2.2 --
Exploratory -- New
Zealand.................... 2 -- 1 1 1.1 -- 0.9 0.2
Development -- Domestic.... 36 36 -- -- 29.5 29.5 -- --
Development -- New
Zealand.................... 4 2 2 -- 3.6 1.8 1.8 --
2000 Exploratory -- Domestic.... 9 5 4 -- 6.2 3.4 2.8 --
Development -- Domestic.... 59 52 7 -- 42.4 37.1 5.3 --
Development -- New
Zealand.................... 2 2 -- -- 1.8 1.8 -- --
1999 Exploratory -- Domestic.... 3 1 2 -- 1.5 0.3 1.2 --
Exploratory -- New
Zealand.................... 2 1 -- 1 1.0 0.9 -- 0.1
Development -- Domestic.... 22 19 3 -- 10.7 9.4 1.3 --
OPERATIONS
We generally seek to be operator in the wells in which we have significant
economic interest. As operator, we design and manage the development of a well
and supervise operation and maintenance activities on a day-to-day basis. We do
not own drilling rigs or other oil field services equipment used for drilling or
maintaining wells on properties we operate. Independent contractors supervised
by us provide all the equipment and personnel. We employ drilling, production
and reservoir engineers, geologists, and other specialists who work to improve
production rates, increase reserves, and lower the cost of operating our oil and
gas properties.
Oil and gas properties are customarily operated under the terms of a joint
operating agreement. These agreements usually provide for reimbursement of the
operator's direct expenses and for payment of
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monthly per-well supervision fees. Supervision fees vary widely depending on the
geographic location and depth of the well and whether the well produces oil or
gas. The fees for these activities paid to us in 2001 ranged from $200 to $2,216
per well per month and totaled $6.2 million.
MARKETING OF PRODUCTION
We typically sell our oil and gas production at market prices near the
wellhead, although in some cases it must be gathered and delivered to a central
point. Gas production is sold in the spot market on a monthly basis, while we
sell our oil production at prevailing market prices. We do not refine any oil we
produce. Two oil or gas purchasers accounted for 10% or more each of our total
revenues during the year ended December 31, 2001. Oil and gas sales to
subsidiaries of Eastex Crude Company were $31.6 million, or 18.1% of oil and gas
sales, while sales to subsidiaries of Enron were $18.2 million, or 10.4% of oil
and gas sales. Our last sale to Enron was for November 2001 production. We
currently have other purchasers for those volumes. For the year ended December
31, 2000, two purchasers accounted for approximately 37% of our total revenues.
However, due to the availability of other purchasers, we do not believe that the
loss of any single oil or gas purchaser or contract would materially affect our
revenues.
In 1998, we entered into gas processing and gas transportation agreements
for our gas production in the AWP Olmos area with PG&E Energy Trading
Corporation, which was assumed in December 2000 by El Paso Hydrocarbon, LP, and
El Paso Industrial, LP, both affiliates of El Paso Merchant Energy, for up to
75,000 Mcf per day, which provides for a ten-year term with automatic one-year
extensions unless earlier terminated. We believe that these arrangements
adequately provide for our gas transportation and processing needs in the AWP
Olmos area for the foreseeable future. Additionally, the gas processed and
transported under these agreements may be sold to El Paso based upon current
natural gas prices.
Our oil production from the Brookeland and Masters Creek areas is sold to
various purchasers at prevailing market prices. Our gas production from these
areas is processed under long-term gas processing contracts with Duke Energy
Field Services, Inc. The processed liquids and residue gas production are sold
in the spot market at prevailing prices.
Our oil production from the Lake Washington area is delivered into
ExxonMobil's crude oil pipeline system for sales to various purchasers at
prevailing market prices. Our gas production from this area is either consumed
on the lease or is delivered into El Paso's Tennessee Gas Pipeline system and
then sold in the spot market at prevailing prices.
Our oil production in New Zealand is sold into the international market at
prices tied to the Asia Petroleum Price Index Tapis posting, less the cost of
storage, trucking, and transportation.
Our gas production from our TAWN fields, which we acquired and closed on in
January 2002, is sold under a long-term contract with Contact Energy. Upon
commissioning of the Rimu Production Station, our gas production from the Rimu
field will be sold to Genesis Power Ltd. under a long-term contract.
Our natural gas liquids production from the TAWN fields is sold to RockGas
under long-term contracts tied to New Zealand's domestic natural gas liquids
market. Upon commissioning of the Rimu Production Station, our natural gas
liquids from the Rimu Field also will be sold to RockGas.
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The following table summarizes sales volumes, sales prices, and production
cost information for our net oil and gas production for the three-year period
ended December 31, 2001. "Net" production is production that is owned by us
either directly or indirectly through partnerships or joint venture interests
and is produced to our interest after deducting royalty, limited partner, and
other similar interests.
YEAR ENDED DECEMBER 31,
---------------------------------------
2001 2000 1999
----------- ----------- -----------
NET SALES VOLUME:
Oil (Bbls).......................................... 3,055,374 2,472,014 2,564,924
Gas (Mcf)........................................... 26,458,958 27,524,621 27,484,759
Gas equivalents (Mcfe).............................. 44,791,202 42,356,705 42,874,303
AVERAGE SALES PRICE:
Oil (Per Bbl)....................................... $ 22.64 $ 29.35 $ 16.75
Gas (Per Mcf)....................................... $ 4.23 $ 4.24 $ 2.40
AVERAGE PRODUCTION COST (PER MCFE).................... $ 0.82 $ 0.69 $ 0.46
Oil production for 2001 includes New Zealand production of 84,261 barrels,
at an average price per barrel of $21.64. Natural gas production for 2000 and
1999 includes 405,130 and 728,235 Mcf, respectively, delivered under the
volumetric production payment agreement pursuant to which we were obligated to
deliver certain monthly quantities of natural gas (see Note 1 to the
Consolidated Financial Statements). Under the volumetric production payment
entered into in 1992, we delivered the last remaining commitment of gas in
October 2000, when such agreement expired.
RISK MANAGEMENT
Our operations are subject to all of the risks normally incident to the
exploration for and the production of oil and gas, including blowouts,
cratering, pipe failure, casing collapse, oil spills, and fires, each of which
could result in severe damage to or destruction of oil and gas wells, production
facilities or other property, or individual injuries. The oil and gas
exploration business is also subject to environmental hazards, such as oil
spills, gas leaks, and ruptures and discharges of toxic substances or gases that
could expose us to substantial liability due to pollution and other
environmental damage. Additionally, as managing general partner of limited
partnerships, we are solely responsible for the day-to-day conduct of the
limited partnerships' affairs and accordingly have liability for expenses and
liabilities of the limited partnerships. We maintain comprehensive insurance
coverage. We believe that our insurance is adequate and customary for companies
of a similar size engaged in comparable operations, but losses could occur for
uninsurable or uninsured risks or in amounts in excess of existing insurance
coverage.
COMPETITION
We operate in a highly competitive environment, competing with major
integrated and independent energy companies for desirable oil and gas
properties, as well as for equipment, labor and materials required to develop
and operate such properties. Many of these competitors have financial and
technological resources substantially greater than ours. We may incur higher
costs or be unable to acquire and develop desirable properties at costs we
consider reasonable because of this competition.
PRICE RISK MANAGEMENT
Our major market risk exposure is the commodity pricing applicable to our
oil and natural gas production. Realized commodity prices received for such
production are primarily driven by the prevailing worldwide price for crude oil
and spot prices applicable to natural gas. The effects of such pricing
volatility are discussed above, and such volatility is expected to continue.
Our price risk program permits the utilization of agreements and financial
instruments, such as futures, forward and options contracts, and swaps, to
mitigate price risk associated with fluctuations in oil and natural gas prices.
In 1998, 1999 and 2000, price floors have been the primary financial instruments
S-41
that we have utilized to hedge our exposure to price risk for the three fiscal
years ended December 31, 2000. During those periods, the costs and any benefits
that we derived from price floors were recorded as a reduction or increase, as
applicable, in oil and gas sales revenues. The costs to purchase put options
were amortized over the option period.
During the fourth quarter of 1999, in addition to the price floor we had in
place, we entered into participating collars to hedge oil production through
June 2000. The participating collars were designated as hedges, and realized
losses were recognized in oil and gas revenues in 2000 when the associated
production occurred. During 1998, 1999 and 2000 we recognized net losses
relating to our price floors and our collars of approximately $276,000, $561,000
and $1,114,000, respectively. This activity is recorded in oil and gas sales on
the accompanying statements of income.
Effective January 1, 2001, we adopted SFAS No. 133. We did not elect to
designate our contracts for special hedge accounting treatment and instead are
using mark-to-market accounting treatment.
During 2001, we have continued our general practice of primarily using
price floors to hedge our exposure to price risk. At December 31, 2001, we had
open price floor contracts covering notional volumes of 2.0 million MMBtu of
natural gas. Natural gas price floor contracts relate to the NYMEX contract
months of February and March 2002, at an average price of $2.33 per MMBtu. The
fair market value of our open price floor contracts at December 31, 2001 totaled
$296,000 and is included under "Other Current Assets" on our December 31, 2001
balance sheet. During 2001 we recognized net gains of $1,173,094 relating to our
derivative activities, with $16,784 of losses unrealized at year end 2001. This
activity is recorded in "Price risk management and other, net" on our statements
of income for 2001. For recent information on our hedging activities, see
"Summary -- Recent Developments."
PARTNERSHIPS
Prior to 1995, we funded a substantial portion of our operations through
109 limited partnerships which we formed and for which we have served as
managing general partner. These partnerships raised a total of $509.5 million,
with the largest portion (81%) raised to acquire interests in producing
properties. Eight of the earliest partnerships and 13 of the most recently
formed partnerships were created to drill for oil and gas. In all of these
partnerships Swift paid for varying percentages of the capital or front-end
costs and continuing costs of the partnerships and, in return, received
differing percentage ownership interests in the partnerships, along with
reimbursement of costs and/or payment of certain fees. At year end 2001, we
continued to serve as managing general partner of 71 of these various
partnerships, of which 65 are production purchase partnerships that have been in
existence from six to fifteen years and the remainder of which are drilling
partnerships that have been in existence from three to five years.
During 1997 and 1998, eight drilling partnerships formed between 1979 and
1985 and 21 of the production purchase partnerships sold their properties and
were dissolved, in each case following a vote of the investors in the particular
partnerships approving such liquidations. Between 1999 and 2001, the investors
in all but six of the remaining partnerships voted to sell the properties or
their interests in the partnerships and dissolve. During 2001, seven drilling
partnerships and two production purchase partnerships were dissolved. We
anticipate that the liquidation and dissolution of the additional 65
partnerships should be substantially completed by the end of 2002. The remaining
six partnerships will continue to operate.
REGULATIONS
Environmental Regulations
The United States federal government and various state and local
governments have adopted laws and regulations regarding the protection of human
health and the environment. These laws and regulations may require the
acquisition of a permit by operators before drilling commences, prohibit
drilling activities on certain lands lying within wilderness areas, wetlands, or
where pollution might cause serious harm, and impose substantial liabilities for
pollution resulting from drilling operations, particularly with respect to
S-42
operations in onshore and offshore waters or on submerged lands. Failure to
comply with these laws and regulations may result in the imposition of
administrative, civil, or criminal penalties or injunctive relief for failure to
comply. These laws and regulations may increase the costs of drilling and
operating wells. Because these laws and regulations change frequently, the costs
of compliance with existing and future environmental laws and regulations cannot
be predicted with certainty.
We currently own or lease, and have in the past owned or leased, numerous
domestic properties that have been used for the exploration and production of
oil and gas, some for many years. Although we have used operating and disposal
practices that were standard in the industry at the time, hydrocarbons or other
wastes may have been released on or under the properties owned or leased by us
or on or under other locations where such wastes have been taken for disposal.
In addition, many of these properties have been operated by third parties whose
treatment and disposal or release of hydrocarbons or other wastes was not under
our control. These properties and the wastes disposed thereon or away from could
be subject to stringent and costly investigatory or remedial requirements under
applicable laws, some of which are strict liability laws without regard to fault
or the legality of the original conduct, including the federal Comprehensive
Environmental Response, Compensation and Liability Act, the federal Resources
Conservation and Recovery Act, the federal Clean Water Act, the federal Oil
Pollution Act, and analogous state laws. Under such laws, we could be required
to remove or remediate previously disposed wastes (including waste disposed of
or released by prior owners or operators) or property contamination (including
groundwater contamination by prior owners or operators), to perform natural
resource mitigation or restoration practices, or to perform remedial plugging or
closure operations to prevent future contamination.
Our oil and gas operations outside of the United States could also
potentially be subject to similar foreign governmental controls and restrictions
pertaining to protection of human health and the environment. Possible controls
and restrictions may include the need to acquire permits, prohibition on
drilling in certain environmentally sensitive areas, performance of clean-ups
for any release of hydrocarbons or other wastes, and payment of penalties for
any violations of applicable laws. We believe that compliance with existing
requirements of such governmental bodies has not had a material adverse effect
on our results of operations.
United States Federal, State and New Zealand Regulation of Oil and Natural Gas
The transportation and certain sales of natural gas in interstate commerce
are heavily regulated by agencies of the federal government and are affected by
the availability, terms and cost of transportation. The price and terms of
access to pipeline transportation are subject to extensive federal and state
regulation. The FERC is continually proposing and implementing new rules and
regulations affecting the natural gas industry, most notably interstate natural
gas transmission companies that remain subject to the FERC's jurisdiction. The
stated purpose of many of these regulatory changes is to promote competition
among the various sectors of the natural gas industry. Some recent FERC
proposals may, however, adversely affect the availability and reliability of
interruptible transportation service on interstate pipelines.
Our sales of crude oil, condensate and natural gas liquids are not
currently subject to FERC regulation. However, the ability to transport and sell
such products is dependent on certain pipelines whose rates, terms and
conditions of service are subject to FERC regulation.
Production of any oil and gas by us will be affected to some degree by
state regulations. Many states in which we operate have statutory provisions
regulating the production and sale of oil and gas, including provisions
regarding deliverability. Such statutes, and the regulations promulgated in
connection therewith, are generally intended to prevent waste of oil and gas and
to protect correlative rights to produce oil and gas between owners of a common
reservoir. Certain state regulatory authorities also regulate the amount of oil
and gas produced by assigning allowable rates of production to each well or
proration unit. Likewise, the government of New Zealand regulates the
exploration, production, sales and transportation of oil and natural gas.
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FEDERAL LEASES
Some of our properties are located on federal oil and gas leases
administered by various federal agencies, including the Bureau of Land
Management. Various regulations and orders affect the terms of leases,
exploration and development plans, methods of operation, and related matters.
LITIGATION
In the ordinary course of business, we have been party to various legal
actions, which arise primarily from our activities as operator of oil and gas
wells. In management's opinion, the outcome of any such currently pending legal
actions will not have a material adverse effect on the financial position or
results of operations of Swift.
EMPLOYEES
At December 31, 2001, we employed 209 persons. In the January 2002 TAWN
acquisition we acquired 22 employees in New Zealand, nine of whom are members of
a union. None of our other employees are represented by a union. Relations with
employees are considered to be good.
FACILITIES
We occupy approximately 91,000 square feet of office space at 16825
Northchase Drive, Houston, Texas, under a ten year lease expiring in 2005. The
lease requires payments of approximately $116,000 per month. We have field
offices in various locations, including New Zealand, from which our employees
supervise local oil and gas operations.
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MANAGEMENT
DIRECTORS AND EXECUTIVE OFFICERS
A. Earl Swift................................ Chairman of the Board
Terry E. Swift............................... President, Chief Executive Officer, Director
Virgil N. Swift.............................. Vice Chairman of the Board
Joseph A. D'Amico............................ Executive Vice President and Chief Operating Officer
Bruce H. Vincent............................. Executive Vice President -- Corporate Development and
Secretary
Alton D. Heckaman, Jr. ...................... Senior Vice President -- Finance and Chief Financial
Officer
James M. Kitterman........................... Senior Vice President -- Operations
Victor R. Moran.............................. Senior Vice President -- Energy Marketing and Business
Development
David W. Wesson.............................. Controller
G. Robert Evans.............................. Director
Henry C. Montgomery.......................... Director
Clyde W. Smith, Jr. ......................... Director
Harold J. Withrow............................ Director
A. Earl Swift, 68, is Chairman of the Board of Directors and has served in
such capacity since Swift's founding in 1979. He previously served as President
from 1979 to November 1997, at which time Terry E. Swift was appointed
President. He also previously served as Chief Executive Officer from 1979 to May
2001, at which time Terry E. Swift was appointed Chief Executive Officer. For
the 17 years prior to 1979, he was employed by affiliates of American Natural
Resources Company. Mr. Swift is a registered professional engineer and holds a
degree in petroleum engineering, Juris Doctor degree and a master's degree in
business administration. He is the father of Terry E. Swift and the brother of
Virgil N. Swift.
Terry E. Swift, 46, has served as a director since the 2000 annual
shareholders meeting. He was appointed President in November 1997 and Chief
Executive Officer in May 2001. He served as Executive Vice President from 1991
to 1997 and was Chief Operating Officer from 1991 to January 2000. He served as
Senior Vice President -- Exploration and Joint Ventures from 1990 to 1991 and as
Vice President -- Exploration and Joint Ventures from 1988 to 1990. Mr. Swift
has a degree in chemical engineering and a master's degree in business
administration. He is the son of A. Earl Swift and the nephew of Virgil N.
Swift.
Virgil N. Swift, 73, has been a director since 1981, and currently serves
as Vice Chairman of the Board. He acted as Executive Vice President -- Business
Development between November 1991 and June 30, 2000. He previously served as
Executive Vice President and Chief Operating Officer from 1982 to late 1991. Mr.
Swift joined us in 1981 as Vice President -- Drilling and Production. For the
preceding 28 years, he held various production, drilling and engineering
positions with Gulf Oil Corporation and its subsidiaries, last serving as
General Manager -- Drilling for Gulf Canada Resources, Inc. Mr. Swift is a
registered professional engineer and holds a degree in petroleum engineering. He
is the brother of A. Earl Swift and the uncle of Terry E. Swift.
Joseph A. D'Amico, 53, was appointed Executive Vice President in August
2000 and was appointed Chief Operating Officer in January 2000. He was Senior
Vice President of Exploration and Development from February 1998 to January
2000. He served as Vice President of Exploration and Development from 1993 to
1998, Director of Exploration and Development from 1992 to 1993 and Funds
Manager from 1988 to 1992. Mr. D'Amico holds Bachelor and Master of Science
degrees in petroleum engineering and a master's degree in business
administration.
Bruce H. Vincent, 54, has been Executive Vice President -- Corporate
Development and Secretary since August 2000. Previously he served as Senior Vice
President -- Funds Management since joining Swift in 1990. Mr. Vincent holds a
degree in business administration and a master's degree in finance.
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Alton D. Heckaman, Jr., 45, was appointed Senior Vice President -- Finance
and Chief Financial Officer in August 2000. He had previously served as Vice
President and Controller from May 1993 and Assistant Vice President -- Finance
from March 1986 to May 1993. Mr. Heckaman joined Swift in 1982. He is a
certified public accountant and holds a degree in accounting.
James M. Kitterman, 57, was appointed Senior Vice President -- Operations
in May 1993. He had previously served as Vice President -- Operations since
joining Swift in 1983. Mr. Kitterman holds a degree in petroleum engineering and
a master's degree in business administration.
Victor R. Moran, 46, was appointed Senior Vice President -- Energy
Marketing and Business Development in August 2000. From 1995, he served as Vice
President -- Natural Gas Marketing/Business Development. He had previously
served as Director of Business Development since joining Swift in January 1992.
Mr. Moran holds a degree in government and a Juris Doctor degree.
David W. Wesson, 43, was appointed Controller in January 2001. He
previously served as Assistant Controller -- Reporting from April 1999 to
January 2001, Manager, Reporting/Budget from October 1995 to April 1999 and
Manager, Corporate Accounting/Budget from February 1990. He joined Swift as a
Senior Accountant in 1988. Mr. Wesson is a certified public accountant and holds
a degree in accounting.
G. Robert Evans, 70, has been a director since 1994. Effective January 1,
1998, Mr. Evans retired as Chairman of Material Sciences Corporation, having
held that position since 1991. Material Sciences Corporation develops and
commercializes continuously processed, coated materials technologies. He remains
a director of Material Sciences Corporation. He also serves as a director of
Consolidated Freightways, Inc., a trucking company.
Henry C. Montgomery, 66, has served as a director since 1987. Since 1980,
Mr. Montgomery has been and continues to serve as the Chairman of the Board of
Montgomery Financial Services Corporation, a management consulting and financial
services firm. Mr. Montgomery specializes in services for companies in
transition or that are financially troubled. The following describes some of
those engagements. From January 2000 to early March 2001, Mr. Montgomery served
as Executive Vice President, Financial and Administration, and Chief Finance
Officer of Indus International, Inc., a public company engaged in enterprise
asset management systems. For eight months in 1999 he served as interim
Executive Vice President of Finance and Administration and currently serves on
the board of directors of Spectrian Corporation, a public company engaged in
making cellular base station power amplifiers. From November 1996 through July
1997, Mr. Montgomery served as Executive Vice President of SyQuest Technology,
Inc., a public company engaged in the development, manufacture and sale of
computer hard drives. On November 17, 1998, SyQuest filed a petition under
Chapter 11 of the U.S. Bankruptcy Code. Mr. Montgomery served from March 1995
until mid-November 1996 as President and Chief Executive Officer of New Media
Corporation, a privately held company engaged in developing, manufacturing and
selling PCMCIA cards for the computer industry. On October 14, 1998, New Media
Corporation filed a petition under Chapter 11 of the U.S. Bankruptcy Code. Mr.
Montgomery currently also serves on the boards of directors of Consolidated
Freightways Corporation, a trucking company, and Catalyst Semiconductor, Inc., a
company that designs, develops and markets programmable integrated circuit
products.
Clyde W. Smith, Jr., 53, has served as a director since 1984. Since January
2002, Mr. Smith has served as President of Ascentron, Inc., an electronics
manufacturing services company that acquired the assets of D.W. Manufacturing,
Inc. in January 2002. From May 1998 until January 2002, Mr. Smith served as
General Manager of D.W. Manufacturing, Inc. d/b/a Millennium Technology
Services, an Oregon based electronics manufacturer. From August 1997 to May
1998, when its assets were acquired by D.W. Manufacturing, Mr. Smith served as
President of Millenium Technology, Inc., a debtor-in-possession under the U.S.
Bankruptcy Code. He served as President of Somerset Properties, Inc., a real
estate investment company, from 1985 to 1994 and as President of H&R Precision,
Inc., a general contractor, from 1994 to August 1997. Mr. Smith is a certified
public accountant. On May 7, 1997, Mr. Smith filed a petition under Chapter 7 of
the U.S. Bankruptcy Code.
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Harold J. Withrow, 74, has been a director since 1988. Mr. Withrow worked
as an independent oil and gas consultant from 1988 until he retired at the end
of 1995. From 1975 until 1988, Mr. Withrow served as Senior Vice
President -- Gas Supply for Michigan Wisconsin Pipe Line Company and its
successor, ANR Pipeline Company.
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DESCRIPTION OF EXISTING INDEBTEDNESS
CREDIT FACILITY
Our $300.0 million credit facility with a nine bank syndicate, which is
scheduled to mature on October 1, 2005, is secured by substantially all of our
oil and gas properties. The amount available for borrowing is subject to a
borrowing base determination that is re-calculated at least every six months.
Our current borrowing base, as reconfirmed by the bank syndicate effective April
5, 2002, is $275.0 million. Our borrowing base will be reduced by $80.0 million
to $195.0 million upon the closing of this offering. At December 31, 2001 and
March 31, 2002, we had $134.0 million and $231.0 million in outstanding
borrowings under our credit facility. After we apply the expected net proceeds
of this offering and our common stock offering to reduce our bank debt, based
upon our outstanding indebtedness at March 31, 2002, we anticipate we would have
approximately $6.1 million outstanding under our credit facility.
Under our current credit facility and depending on the level of outstanding
debt, the interest rate is either the lead bank's base rate, 4.75% at December
31, 2001, or, at our option, LIBOR plus the applicable margin, which was 3.64%
for our outstanding borrowings at December 31, 2001. The weighted average
interest rate was 3.53% for our outstanding borrowings at March 31, 2002.
The terms of the revolving line of credit include, among other
restrictions, a limitation on cash dividends, requirements as to maintenance of
certain minimum financial ratios, including maintaining working capital and debt
and equity ratios, and limitations on incurring other debt. Since inception, no
cash dividends have been declared on our common stock. Our credit facility
limits our repurchase of shares of common stock to $15.0 million from September
28, 2001. In addition, our credit facility contains certain covenants that
limit, among other things, our ability to:
- incur debt;
- dispose of property and assets;
- enter into consolidation or merger transactions;
- enter into certain contracts or leases; and
- expand into other lines of business.
For all periods presented in this prospectus supplement, we were in
compliance with the provisions of our credit facility. For a detailed
description of this credit facility, see the credit agreement which is attached
as Exhibit 10.16 of our Quarterly Report on Form 10-Q for the quarter ended
September 30, 2001.
SENIOR SUBORDINATED NOTES DUE 2009
On August 4, 1999, we issued $125.0 million aggregate principal amount of
10 1/4% senior subordinated notes due August 1, 2009.
Payments of principal, interest and premium under the senior subordinated
notes due 2009 will be subordinated to payments on our existing and future
senior debt, including our credit facility. On or after August 1, 2004, we may
redeem our senior subordinated notes due 2009 for cash at 105.125% of principal
declining to 100% in 2007. In addition, before August 1, 2002, we may redeem up
to 33.33% of our senior subordinated notes due 2009 with the proceeds of
qualified offerings of our equity at 110.25% of their principal amount, together
with accrued and unpaid interest. If certain changes in control occur, or if our
common stock ceases trading on a national exchange, each holder of the senior
subordinated notes due 2009 will have the right to require us to repurchase
their senior subordinated notes due 2009 at 101% of the note's principal amount,
plus accrued and unpaid interest to the date of repurchase.
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For a detailed description of the senior subordinated notes due 2009 and
their provisions, see the indenture and the supplement filed as an exhibit to
the senior subordinated notes registration statement on July 9, 1999 and to our
Current Report on Form 8-K filed with the SEC on August 4, 1999, respectively.
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DESCRIPTION OF THE NOTES
You can find the definitions of certain terms used in this description
under the subheading "-- Certain Definitions," beginning on page S-65. In this
description, the words "Swift," "we," "us" and "our" refer to Swift Energy
Company and not to any of its subsidiaries.
We will issue the Notes under an indenture to be dated as of April 16,
2002, which is to be supplemented by a first supplemental indenture to be dated
as of April 16, 2002, referred to as supplemented as the "Indenture," between
Swift and Bank One, NA, as trustee (the "Trustee"). The Indenture is governed by
the Trust Indenture Act of 1939 (the "Trust Indenture Act"). 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.
We urge you to read the Indenture because it, and not this description,
defines your rights as a holder of these Notes. A copy of the form of indenture
and the first supplemental indenture are incorporated by reference. The form of
indenture is filed as an exhibit to our registration statement on Form S-3,
filed with the Securities and Exchange Commission on July 6, 2001, of which this
prospectus supplement forms a part, and the first supplemental indenture will be
filed as an exhibit to a Current Report on Form 8-K.
We are issuing $200.0 million of senior subordinated notes (the "Offered
Notes") now and can issue an unlimited amount of additional Notes at later dates
under the same Indenture. Any additional Notes that we issue in the future will
be identical in all respects to the Offered Notes that we are issuing now,
except that Notes issued in the future will have different issuance prices and
issuance dates. We can issue additional Notes as part of the same series or as
an additional series. The Offered Notes and any additional Notes issued under
the Indenture are collectively referred to as the "Notes." We will issue Notes
only in fully registered form without coupons, in denominations of $1,000 and
integral multiples of $1,000.
PRINCIPAL, MATURITY AND INTEREST
The Notes will mature on May 1, 2012.
Interest on the Notes will accrue at a rate of 9 3/8% per annum and will be
payable semi-annually in arrears on May 1 and November 1, commencing on November
1, 2002, in the case of the Offered Notes. We will pay interest to those persons
who were holders of record on April 15 and October 15 immediately preceding each
interest payment date.
Interest on the Notes will accrue from the date of original issuance or, if
interest has already been paid, from the date it was most recently paid.
Interest will be computed on the basis of a 360-day year comprised of twelve
30-day months.
SUBSIDIARY GUARANTIES
Under the circumstances described below under "-- Certain
Covenants -- Future Subsidiary Guarantors," Swift's payment obligations under
the Notes may in the future be jointly and severally guaranteed by one or more
Subsidiary Guarantors. The Subsidiary Guaranty of any Subsidiary Guarantor will
be an unsecured senior subordinated obligation of such Subsidiary Guarantor. For
a more detailed description of the subordination provisions, see
"-- Subordination" below.
Upon the sale or other disposition of all the Capital Stock of a Subsidiary
Guarantor (other than to Swift or an Affiliate of Swift) permitted by the
Indenture, such Subsidiary Guarantor will be released from all its obligations
under its Subsidiary Guaranty. For a more detailed description of these
obligations, see "-- Certain Covenants -- Limitation on Issuance and Sale of
Capital Stock of Restricted Subsidiaries," and "-- Certain
Covenants -- Limitation on Asset Sales". In addition, any Subsidiary Guarantor
that is designated an Unrestricted Subsidiary in accordance with the terms of
the Indenture shall be released from and relieved of its obligations under its
Subsidiary Guaranty upon execution and delivery of a supplemental indenture
satisfactory to the Trustee. In addition, any Subsidiary Guarantor
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may be released from its obligation under its Subsidiary Guaranty if such
Subsidiary Guarantor no longer has any outstanding Indebtedness or Preferred
Stock or it again qualifies as an Exempt Foreign Subsidiary.
Each of Swift and any Subsidiary Guarantor will agree to contribute to any
other Subsidiary Guarantor that makes payments pursuant to its Subsidiary
Guaranty an amount equal to Swift's or such Subsidiary Guarantor's proportionate
share of such payment, based on the net worth of Swift or such Subsidiary
Guarantor relative to the aggregate net worth of Swift and the Subsidiary
Guarantors.
SUBORDINATION
The Notes will be senior subordinated, unsecured obligations of Swift and:
- the payment of principal, interest and any premium on the Notes will be
subordinated in their right of payment to all existing and future Senior
Indebtedness of Swift;
- the Notes will rank equally in their right of payment with our 10 1/4%
senior subordinated notes due 2009 (the "2009 Notes") and any future Pari
Passu Indebtedness, and senior to all future Subordinated Indebtedness of
Swift; and
- the Subsidiary Guaranty of any Subsidiary Guarantor will rank subordinate
in right of payment to all existing and future Senior Indebtedness of
such Subsidiary Guarantor, pari passu with any future guaranty of Swift's
10 1/4% senior subordinated notes due 2009 and any future Pari Passu
Indebtedness of such Subsidiary Guarantor and senior to any future
Subordinated Indebtedness of such Subsidiary Guarantor.
After the closing of the offering of the Notes and the application of the
estimated net proceeds of this offering, based upon our outstanding indebtedness
at March 31, 2002, we expect to have approximately $6.1 million outstanding
under our credit facility and approximately $188.9 million of available
borrowing capacity. Our borrowing base at March 31, 2002 was $275.0 million and
will be reduced by $80 million to $195.0 million upon completion of this
offering. Borrowings under our credit facility constitute Senior Indebtedness.
As of such date, we would have had no outstanding Pari Passu Indebtedness other
than the 2009 Notes.
Although the Indenture contains limitations on the amount of additional
Indebtedness that Swift and its Restricted Subsidiaries may incur, the amounts
of such Indebtedness could be substantial and such Indebtedness may be Senior
Indebtedness or Pari Passu Indebtedness. In addition, the Subsidiary Guaranties
could be effectively subordinated to all the obligations of any Subsidiary
Guarantors under certain circumstances. The Notes and any Subsidiary Guaranties
will also be effectively subordinated to any secured debt of Swift and the
Subsidiary Guarantors that is not otherwise Senior Indebtedness. As of December
31, 2001, after giving pro forma effect to the offering of the Notes and the
application of the net proceeds therefrom, there would have been no outstanding
secured debt of Swift that is not Senior Indebtedness. All existing and future
liabilities of Swift's Subsidiaries that are not Subsidiary Guarantors,
including the claims of trade creditors and preferred stockholders, if any, will
be effectively senior to the Notes. As of December 31, 2001, after giving effect
to the offering, Swift's Subsidiaries would have had no balance sheet
liabilities (excluding intercompany debt). Swift's Subsidiaries may have other
liabilities, including contingent liabilities, that may be significant. For a
more detailed description, see "-- Certain Covenants -- Limitation on
Indebtedness," the risk factors relating to subordination and fraudulent
conveyance, and "Description of Existing Indebtedness."
We may not pay principal of, or premium, if any, or interest on, the Notes,
or make any deposit pursuant to the provisions described under "-- Defeasance
and Covenant Defeasance", and may not repurchase, redeem or otherwise retire any
Notes (collectively, "pay the Notes"), if:
(a) any principal, premium or interest or other amounts due in respect of
any Senior Indebtedness of Swift is not paid within any applicable grace period
(including at maturity); or
(b) any other default on Senior Indebtedness of Swift occurs and the
maturity of such Senior Indebtedness is accelerated in accordance with its
terms;
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unless, in either case,
(1) the default has been cured or waived and any such acceleration has
been rescinded, or
(2) such Senior Indebtedness has been paid in full in cash;
provided, however, that we may pay the Notes without regard to the
foregoing if we and the Trustee receive written notice approving such
payment from the Representative of such issue of Senior Indebtedness.
During the continuance of any default (other than a default described in
clause (a) or (b) above) with respect to any Designated Senior Indebtedness
pursuant to which the maturity thereof may be accelerated immediately without
further notice (except such notice as may be required to effect such
acceleration), we may not pay the Notes for a period (a "Payment Blockage
Period") commencing upon the receipt by Swift and the Trustee of written notice
(a "Payment Blockage Notice") of such default from the Representative of the
holders of such Designated Senior Indebtedness specifying an election to effect
a Payment Blockage Period, and ending 179 days after receipt of such notice by
Swift and the Trustee, unless such Payment Blockage Period is earlier
terminated:
(a) by written notice to the Trustee and Swift from the Representative that
gave such Payment Blockage Notice;
(b) because such default is no longer continuing; or
(c) because such Designated Senior Indebtedness has been repaid in full in
cash.
Unless the holders of such Designated Senior Indebtedness or the
Representative of such holders have accelerated the maturity of such Designated
Senior Indebtedness and not rescinded such acceleration, we may, unless
otherwise prohibited as described in the first sentence of this paragraph,
resume payments on the Notes after the end of such Payment Blockage Period.
No more than one Payment Blockage Notice with respect to all issues of
Designated Senior Indebtedness may be given in any consecutive 360-day period,
irrespective of the number of defaults with respect to one or more issues of
Designated Senior Indebtedness during such period.
Upon any payment or distribution of the assets of Swift upon a liquidation,
dissolution or winding up of Swift or in a bankruptcy, reorganization,
insolvency, receivership or similar proceeding relating to Swift or its
Property:
(a) the holders of Senior Indebtedness of Swift will be entitled to receive
payment in full in cash before the Holders of the Notes are entitled to receive
any payment of principal of, or premium, if any, or interest on, the Notes; and
(b) until the Senior Indebtedness of Swift is paid in full in cash, any
distribution made by or on behalf of Swift to which Holders of the Notes would
be entitled but for the subordination provisions of the Indenture will be made
to holders of the Senior Indebtedness of Swift, except that Holders of Notes may
receive and retain shares of stock and any debt securities that are subordinated
to all Senior Indebtedness of Swift to at least the same extent as the Notes.
If a payment or distribution is made to Holders of Notes that, due to the
subordination provisions, should not have been made to them, such Holders are
required to hold it in trust for the holders of Senior Indebtedness and pay it
over to them as their interests may appear.
The Subsidiary Guaranty of any Subsidiary Guarantor will be subordinated to
Senior Indebtedness of such Subsidiary Guarantor to the same extent and in the
same manner as the Notes are subordinated to Senior Indebtedness of Swift.
The Indenture provides that the subordination provisions of the Indenture
applicable to the Notes and any Subsidiary Guaranty may not be amended, waived
or modified in a manner that would adversely affect
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the rights of the holders of any Senior Indebtedness unless the holders of such
Senior Indebtedness consent in writing (in accordance with the provisions of
such Indebtedness) to such amendment, waiver or modification.
Payment from the money or proceeds of U.S. Government Obligations held in
any defeasance trust pursuant to the provisions described under "-- Defeasance
and Covenant Defeasance" will not be subject to the subordination provisions
described above.
OPTIONAL REDEMPTION
Except as set forth in the following paragraph, the Notes will not be
redeemable at the option of Swift prior to May 1, 2007. Starting on that date,
we may redeem all or any portion of the Notes upon not less than 30 nor more
than 60 days' prior notice, at the redemption prices set forth below, plus
accrued and unpaid interest, if any, to the redemption date subject to the right
of Holders of record on the relevant record date to receive interest due on the
relevant interest payment date. The following prices are for Notes redeemed
during the 12-month period commencing on May 1 of the years set forth below, and
are expressed as percentages of principal amount:
REDEMPTION
YEAR PRICE
---- ----------
2007........................................................ 104.688%
2008........................................................ 103.125%
2009........................................................ 101.563%
2010 and thereafter......................................... 100.000%
We may on any one or more occasions prior to May 1, 2005, redeem up to
33 1/3% of the aggregate principal amount of the Notes originally issued with
the net proceeds of one or more Equity Offerings of Swift at a redemption price
of 109.375% of the principal amount thereof, plus accrued and unpaid interest,
if any, to the date of redemption, subject to the right of Holders of record on
the relevant record date to receive interest due on the relevant interest
payment date, provided that at least 66 2/3% of the aggregate principal amount
of the Notes originally issued remains outstanding after the occurrence of such
redemption. Any such redemption shall occur not later than 90 days after the
date of the closing of any such Equity Offering upon not less than 30 nor more
than 60 days' prior notice. The redemption shall be made in accordance with
procedures set forth in the Indenture.
If less than all the Notes are to be redeemed at any time, selection of
Notes for redemption will be made by the Trustee in compliance with the
requirements of the principal national securities exchange, if any, on which the
Notes are listed, or, if the Notes are not so listed, on a pro rata basis, by
lot or by such method as the Trustee shall deem fair and appropriate.
SINKING FUND
There will be no mandatory sinking fund payments for the Notes.
REPURCHASE AT THE OPTION OF HOLDERS UPON A CHANGE OF CONTROL
Upon the occurrence of a Change of Control, each Holder of Notes shall have
the right to require us to repurchase all or any part (equal to $1,000 in
principal amount or an integral multiple thereof) of such Holder's Notes
pursuant to the offer described below ("Change of Control Offer") at a purchase
price in cash (a "Change of Control Payment") equal to 101% of the principal
amount of the Notes repurchased, plus accrued and unpaid interest, if any, to
the date of purchase, subject to the right of Holders of record on the relevant
record date to receive interest due on the relevant interest payment date.
Within 30 days following any Change of Control, we shall:
(a) cause a notice of the Change of Control Offer to be sent at least once
to the Dow Jones News Service or similar business news service in the United
States; and
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(b) send, by first-class mail, with a copy to the Trustee, to each Holder
of Notes, at such Holder's address appearing in the Security Register, a notice
stating, among other things:
(1) that a Change of Control has occurred and a Change of Control
Offer is being made pursuant to the Indenture and that all Notes, or
portions thereof, properly tendered will be accepted for payment,
(2) the Change of Control Purchase Price and the purchase date, which
shall be, subject to any contrary requirements of applicable law, a
business day (a "Change of Control Payment Date") no earlier than 30 days
nor later than 60 days from the date we mail such notice,
(3) that any Note, or portion thereof, accepted for payment, and duly
paid on the Change of Control Payment Date, pursuant to the Change of
Control Offer shall cease to accrue interest on the Change of Control
Payment Date,
(4) that any Notes, or portions thereof, not properly tendered will
continue to accrue interest,
(5) a description of the transaction or transactions constituting the
Change of Control,
(6) the procedures that the Holders of the Notes must follow in order
to tender their Notes, or portions thereof, for payment and the procedures
that Holders of Notes must follow in order to withdraw an election to
tender Notes, or portions thereof, for payment, and
(7) all other instructions and materials necessary to enable Holders
to tender Notes pursuant to the Change of Control Offer.
We will comply, to the extent applicable, with the requirements of Section
14(e) under the Exchange Act and any other securities laws and regulations
thereunder to the extent such laws and regulations are applicable in connection
with the purchase of Notes pursuant to a Change of Control Offer. To the extent
that the provisions of any securities laws or regulations conflict with the
provisions relating to the Change of Control Offer, we will comply with the
applicable securities laws and regulations and will not be deemed to have
breached our obligations described above by virtue of such compliance.
If a Change of Control were to occur, Swift and any Subsidiary Guarantors
may not have sufficient financial resources, or may not be able to arrange
financing, to pay the purchase price for all Notes tendered by the Holders
thereof. In addition, as of the Issue Date, our existing credit facility does,
and any future Bank Credit Facilities or other agreements relating to
indebtedness, including Senior Indebtedness or Pari Passu Indebtedness, to which
Swift or any Subsidiary Guarantor becomes a party may, contain restrictions on
the purchase of Notes and prohibitions on certain events that would constitute a
Change of Control or require such indebtedness to be repurchased upon a Change
of Control. If a Change of Control occurs at a time when Swift and the
Subsidiary Guarantors are unable to purchase the Notes (due to insufficient
financial resources, contractual prohibition or otherwise), such failure to
purchase tendered Notes would constitute an Event of Default under the
Indenture, which would, in turn, constitute a default under our credit facility
and may constitute a default under the terms of any other Bank Credit Facility
or other Indebtedness of Swift or any Subsidiary Guarantors then outstanding. In
such circumstances, the subordination provisions in the Indenture would likely
prohibit the Change of Control payments to Holders of Notes. The provisions
under the Indenture related to Swift's obligation to make an offer to repurchase
the Notes as a result of a Change of Control may be waived or modified, at any
time prior to the occurrence of such Change of Control, with the written consent
of the Holders of a majority in principal amount of the Notes. For a detailed
description, see "-- Subordination" above.
We will not be required to make a Change of Control Offer upon a Change of
Control if a third party makes the Change of Control Offer in the manner, at the
times and otherwise in compliance with the requirements set forth in the
Indenture applicable to a Change of Control Offer made by us and purchases all
Notes validly tendered and not withdrawn under such Change of Control Offer.
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A "Change of Control" shall be deemed to occur if:
(a) any "person" or "group" (within the meaning of Section 13(d)(3) and
14(d)(2) of the Exchange Act or any successor provision to either of the
foregoing, including any group acting for the purpose of acquiring, holding or
disposing of securities within the meaning of Rule 13d-5(b)(1) under the
Exchange Act) becomes the "beneficial owner" (as defined in Rules 13d-3 and
13d-5 under the Exchange Act, except that a Person will be deemed to have
"beneficial ownership" of all shares that any such Person has the right to
acquire, whether such right is exercisable immediately or only after the passage
of time) of 40 percent or more of the total voting power of all classes of the
Voting Stock of Swift;
(b) the sale, lease, transfer or other disposition, directly or indirectly,
of all or substantially all the Property of Swift and the Restricted
Subsidiaries taken as a whole (other than a disposition of such Property as an
entirety or virtually as an entirety to any Wholly Owned Subsidiary) shall have
occurred;
(c) the shareholders of Swift shall have approved any plan of liquidation
or dissolution of Swift;
(d) Swift consolidates with or merges into another Person or any Person
consolidates with or merges into us in any such event pursuant to a transaction
in which the outstanding Voting Stock of Swift is reclassified into or exchanged
for cash, securities or other Property, other than any such transaction where
the outstanding Voting Stock of Swift is reclassified into or exchanged for
Voting Stock of the surviving Person and the holders of the Voting Stock of
Swift immediately prior to such transaction own, directly or indirectly, not
less than a majority of the Voting Stock of the surviving Person immediately
after such transaction in substantially the same proportion as before the
transaction; or
(e) during any period of two consecutive years, individuals who at the
beginning of such period constituted Swift's Board of Directors (together with
any new directors whose election or appointment by such Board or whose
nomination for election by the shareholders of Swift 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 approved by such a vote) cease for any reason to constitute a
majority of Swift's Board of Directors then in office.
The Change of Control repurchase feature is a result of negotiations
between Swift and the underwriters of the Offered Notes. We have no present
intention to engage in a transaction involving a Change of Control, although it
is possible that we would decide to do so in the future. Subject to certain
covenants described below, we could, in the future, enter into certain
transactions, including acquisitions, refinancings or other recapitalizations,
that would not constitute a Change of Control under the Indenture, but that
could increase the amount of indebtedness outstanding at such time or otherwise
affect Swift's capital structure or credit ratings.
The definition of Change of Control includes a phrase relating to the sale,
lease, transfer or other disposition of "all or substantially all" of the
Property of Swift and its Restricted Subsidiaries taken as a whole. The
Indenture is governed by New York law, and there is no established quantitative
definition under New York law of "substantially all" the assets of a
corporation. Accordingly, if Swift or any Restricted Subsidiary were to engage
in a transaction in which it disposed of less than all the assets of Swift and
its Restricted Subsidiaries taken as a whole, a question of interpretation could
arise as to whether such disposition was of "substantially all" such assets and
whether we are required to make a Change of Control Offer.
Except as described above with respect to a Change of Control, the
Indenture does not contain any other provisions that permit the Holders of the
Notes to require that we repurchase or redeem the Notes in the event of a
takeover, recapitalization or similar restructuring.
CERTAIN COVENANTS
Limitation on Indebtedness
The Indenture provides that we will not, and will not permit any of our
Restricted Subsidiaries to, directly or indirectly, Incur any Indebtedness
unless, after giving pro forma effect to the Incurrence of such
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Indebtedness and the receipt and application of the proceeds thereof, no Default
or Event of Default would occur as a consequence of, or be continuing following,
such Incurrence and application and either:
(a) after giving pro forma effect to such Incurrence and application, the
Consolidated Interest Coverage Ratio would exceed 2.5 to 1.0; or
(b) such Indebtedness is Permitted Indebtedness.
"Permitted Indebtedness" means any and all of the following:
(a) Indebtedness arising under the Indenture with respect to the Offered
Notes and any Subsidiary Guaranties relating thereto;
(b) Indebtedness under Bank Credit Facilities, provided that the aggregate
principal amount of all Indebtedness under Bank Credit Facilities, at any one
time outstanding does not exceed the greater of:
(1) $250.0 million, which amount shall be permanently reduced by the
amount of Net Available Cash used to permanently repay Indebtedness under
Bank Credit Facilities and not subsequently reinvested in Additional Assets
or used to permanently reduce other Indebtedness pursuant to the provisions
of the Indenture described under "-- Limitation on Asset Sales", and
(2) an amount equal to the sum of:
(A) $150.0 million, and
(B) 25% of Adjusted Consolidated Net Tangible Assets determined as
of the date of Incurrence of such Indebtedness,
and, in the case of either (1) or (2), plus all interest and fees and other
obligations thereunder and any Guarantee of such Indebtedness;
(c) Indebtedness of Swift owing to and held by any Wholly Owned Subsidiary
and Indebtedness of a Restricted Subsidiary owing to and held by Swift or any
Wholly Owned Subsidiary; provided, however, that any subsequent issue or
transfer of Capital Stock or other event that results in any such Wholly Owned
Subsidiary ceasing to be a Wholly Owned Subsidiary or any subsequent transfer of
any such Indebtedness (except to Swift or a Wholly Owned Subsidiary) shall be
deemed, in each case, to constitute the Incurrence of such Indebtedness by the
issuer thereof;
(d) Indebtedness in respect of bid, performance, reimbursement or surety
obligations issued by or for the account of Swift or any Restricted Subsidiary
in the ordinary course of business, including Guarantees and letters of credit
functioning as or supporting such bid, performance, reimbursement or surety
obligations (in each case other than for an obligation for money borrowed);
(e) Indebtedness under Permitted Hedging Agreements;
(f) in-kind obligations relating to oil or gas balancing positions arising
in the ordinary course of business;
(g) Indebtedness outstanding on the Issue Date not otherwise permitted in
clauses (a) through (f) above;
(h) Non-recourse Purchase Money Indebtedness;
(i) Indebtedness not otherwise permitted to be Incurred pursuant to this
paragraph (excluding any Indebtedness Incurred pursuant to clause (a) of
"-- Limitation of Indebtedness"), provided that the aggregate principal amount
of all Indebtedness Incurred pursuant to this clause (i), together with all
Indebtedness Incurred pursuant to clause (j) of this paragraph in respect of
Indebtedness previously Incurred pursuant to this clause (i), at any one time
outstanding does not exceed $30.0 million;
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(j) Indebtedness Incurred in exchange for, or the proceeds of which are
used to refinance:
(1) Indebtedness referred to in clauses (a), (g), (h) and (i) of this
paragraph (including Indebtedness previously Incurred pursuant to this
clause (j)), and
(2) Indebtedness Incurred pursuant to clause (a) of "-- Limitation of
Indebtedness",
provided that, in the case of each of the foregoing clauses (1) and (2),
such Indebtedness is Permitted Refinancing Indebtedness; and
(k) Indebtedness consisting of obligations in respect of purchase price
adjustments, indemnities or Guarantees of the same or similar matters in
connection with the acquisition or disposition of Property.
Limitation on Liens
The Indenture provides that we will not, and will not permit any Restricted
Subsidiary to, directly or indirectly, enter into, create, Incur, assume or
suffer to exist any Lien on or with respect to any Property of Swift or such
Restricted Subsidiary, whether owned on the Issue Date or acquired after the
Issue Date, or any interest therein or any income or profits therefrom, unless
the Notes or any Subsidiary Guaranty of such Restricted Subsidiary are secured
equally and ratably with, or prior to, any and all other obligations secured by
such Lien, except that Swift and its Restricted Subsidiaries may enter into,
create, Incur, assume or suffer to exist Liens securing Senior Indebtedness and
Permitted Liens.
Limitation on Restricted Payments
We will not, and will not permit any of our Restricted Subsidiaries to,
directly or indirectly, make any Restricted Payment if, at the time of and after
giving effect to the proposed Restricted Payment:
(a) any Default or Event of Default would have occurred and be continuing;
(b) we could not Incur at least $1.00 of additional Indebtedness pursuant
to clause (a) of the first paragraph under "-- Limitation on Indebtedness"; or
(c) the aggregate amount expended or declared for all Restricted Payments
from the Issue Date would exceed the sum of (without duplication):
(1) 50% of the aggregate Consolidated Net Income of Swift accrued
during the period (treated as one accounting period) commencing on the
first day of the fiscal quarter during which the Issue Date occurs, and
ending on the last day of the fiscal quarter immediately preceding the date
of such proposed Restricted Payment (or, if such aggregate Consolidated Net
Income shall be a loss, minus 100% of such loss),
(2) the aggregate net cash proceeds, or the Fair Market Value of
Property other than cash (provided that, in the case of Property that is
Capital Stock, such Capital Stock falls within the meaning of clause (b) of
the definition of "Additional Assets"), received by us from the issuance or
sale (other than to a Subsidiary of Swift or an employee stock ownership
plan or trust established by us or any such Subsidiary for the benefit of
their employees) by Swift of its Capital Stock (other than Disqualified
Stock) after the Issue Date, net of attorneys' fees, accountants' fees,
underwriters' or placement agents' fees, discounts or commissions and
brokerage, consultant and other fees actually Incurred in connection with
such issuance or sale and net of taxes paid or payable as a result thereof,
(3) the aggregate net cash proceeds, or the Fair Market Value of
Property other than cash, received by us as capital contributions to Swift
(other than from a Subsidiary of Swift) on or after the Issue Date,
(4) the aggregate net cash proceeds received by us from the issuance
or sale (other than to any Subsidiary of Swift or an employee stock
ownership plan or trust established by us or any such Subsidiary for the
benefit of their employees) on or after the Issue Date of convertible
Indebtedness that has been converted into or exchanged for Capital Stock
(other than Disqualified Stock) of Swift,
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together with the aggregate cash received by us at the time of such
conversion or exchange or received by us from any conversion or exchange of
convertible Senior Indebtedness or convertible Pari Passu Indebtedness
issued or sold (other than to any Subsidiary of Swift or an employee stock
ownership plan or trust established by us or any such Subsidiary for the
benefit of their employees) prior to the Issue Date, excluding:
(A) any such Indebtedness issued or sold to us or a Subsidiary of
Swift or an employee stock ownership plan or trust established by us or
any such Subsidiary for the benefit of their employees, and
(B) the aggregate amount of any cash or other Property distributed
by us or any Restricted Subsidiary upon any such conversion or exchange,
(5) to the extent not otherwise included in Swift's Consolidated Net
Income, an amount equal to the net reduction in Investments made by Swift
and its Restricted Subsidiaries subsequent to the Issue Date in any Person
resulting from:
(A) payments of interest on debt, dividends, repayments of loans or
advances or other transfers or distributions of Property, in each case
to us or any Restricted Subsidiary from any Person other than Swift or a
Restricted Subsidiary, and in an amount not to exceed the book value of
such Investments previously made in such Person that were treated as
Restricted Payments, or
(B) the designation of any Unrestricted Subsidiary as a Restricted
Subsidiary, and in an amount not to exceed the lesser of:
(x) the book value of all Investments previously made in such
Unrestricted Subsidiary that
(y) were treated as Restricted Payments, and the Fair Market
Value of Swift's and its Restricted Subsidiaries' interest in such
Unrestricted Subsidiary, and
(6) $15.0 million.
The limitations set forth in the preceding paragraph will not prevent us or
any Restricted Subsidiary from making the following Restricted Payments so long
as, at the time thereof, no Default or Event of Default shall have occurred and
be continuing:
(a) the payment of any dividend on Capital Stock of Swift or any Restricted
Subsidiary within 60 days after the declaration thereof, if at such declaration
date such dividend could have been paid in compliance with the preceding
paragraph;
(b) the repurchase, redemption or other acquisition or retirement for value
of any Capital Stock of Swift or any of its Subsidiaries pursuant to the terms
of agreements (including employment agreements) or plans (including by employee
stock ownership plans but excluding other plans to purchase such Capital Stock
in open market transactions, together with, in the case of employee stock
ownership plans, loans to or Investments therein in an amount sufficient to fund
such repurchase, redemption or other acquisition or retirement by such plan)
approved by Swift's Board of Directors, including any such repurchase,
redemption, acquisition or retirement of shares of such Capital Stock that is
deemed to occur upon the exercise of stock options or similar rights if such
shares represent all or a portion of the exercise price or are surrendered in
connection with satisfying Federal income tax obligations; provided, however,
that the aggregate amount of such repurchase, redemptions, acquisitions and
retirements shall not exceed the sum of:
(1) $5.0 million in any twelve-month period, and
(2) the aggregate net proceeds, if any, received by us during such
twelve-month period from any issuance of such Capital Stock pursuant to
such agreements or plans;
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(c) the purchase, redemption or other acquisition or retirement for value
of any Capital Stock of Swift or any Restricted Subsidiary, in exchange for, or
out of the aggregate net cash proceeds of, a substantially concurrent issuance
and sale (other than to a Subsidiary of Swift or an employee stock ownership
plan or trust established by us or any of its Subsidiaries, for the benefit of
their employees) of Capital Stock of Swift (other than Disqualified Stock);
(d) the purchase, redemption, legal defeasance, acquisition or retirement
for value of any Subordinated Indebtedness in exchange for, or out of the
proceeds of the substantially concurrent sale of, Capital Stock of Swift (other
than Disqualified Stock and other than Capital Stock issued or sold to a
Subsidiary of Swift or an employee stock ownership plan or trust established by
us or any such Subsidiary for the benefit of their employees);
(e) the making of any principal payment on or the repurchase, redemption,
legal defeasance or other acquisition or retirement for value of Subordinated
Indebtedness in exchange for, or out of the aggregate net cash proceeds of a
substantially concurrent Incurrence (other than a sale to a Subsidiary of Swift)
of Subordinated Indebtedness so long as such new Indebtedness is Permitted
Refinancing Indebtedness;
(f) loans, in an aggregate principal amount outstanding at any one time of
not more than $2.0 million, made to officers, directors or employees of Swift or
any Restricted Subsidiary approved by the Board of Directors (or by a duly
authorized officer), the net cash proceeds of which are used solely:
(1) to purchase common stock of Swift in connection with a restricted
stock or employee stock purchase plan, or to exercise stock options
received pursuant to an employee or director stock option plan or other
incentive plan, in a principal amount not to exceed the purchase price of
such common stock or the exercise price of such stock options, or
(2) to refinance loans, together with accrued interest thereon, made
pursuant to item (1) of this clause (f).
The actions described in clauses (a) and (b) of this paragraph shall be
included in the calculation of the amount of Restricted Payments. The actions
described in clauses (c), (d), (e) and (f) of this paragraph shall be excluded
in the calculation of the amount of Restricted Payments, provided that the net
cash proceeds from any issuance or sale of Capital Stock or Subordinated
Indebtedness of Swift pursuant to such clause (c), (d) or (e) shall be excluded
from any calculations pursuant to clause (2), (3) or (4) under the immediately
preceding paragraph.
Limitation on Issuance and Sale of Capital Stock of Restricted Subsidiaries
We will not:
(a) permit any Restricted Subsidiary to sell or otherwise issue any Capital
Stock other than to Swift or one of its Wholly Owned Subsidiaries; or
(b) sell, hypothecate or otherwise dispose of any shares of Capital Stock
of any Restricted Subsidiary, or permit any Restricted Subsidiary to do so,
except, in each case, for:
(1) directors' qualifying shares, or
(2) a sale of all the Capital Stock of a Restricted Subsidiary owned
by Swift or its Subsidiaries effected in accordance with the provisions of
the Indenture described under "-- Limitation on Asset Sales."
In the event of the consummation of a sale of all the Capital Stock of a
Restricted Subsidiary pursuant to the foregoing clause (2) and the execution and
delivery of a supplemental indenture in form satisfactory to the Trustee, any
such Restricted Subsidiary that is also a Subsidiary Guarantor shall be released
from all its obligations under its Subsidiary Guaranty.
For purposes of this covenant, the creation of a Lien on any Capital Stock
of a Restricted Subsidiary to secure Indebtedness of the Company or any of its
Restricted Subsidiaries will not be deemed to be a
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violation of this covenant; provided that any sale or disposition by the secured
party of such Capital Stock following foreclosure of its Lien will be subject to
this covenant.
Limitation on Asset Sales
The Indenture provides that we will not, and will not permit any Restricted
Subsidiary to, consummate any Asset Sale unless:
(a) Swift or such Restricted Subsidiary, as the case may be, receives
consideration at the time of such Asset Sale at least equal to the Fair Market
Value of the Property subject to such Asset Sale; and
(b) all of the consideration paid to Swift or such Restricted Subsidiary in
connection with such Asset Sale is in the form of cash, Permitted Short-Term
Investments, Liquid Securities, Exchanged Properties or the assumption by the
purchaser of liabilities of Swift (other than liabilities of Swift that are by
their terms subordinated to the Notes) or liabilities of any Subsidiary
Guarantor that made such Asset Sale (other than liabilities of a Subsidiary
Guarantor that are by their terms subordinated to such Subsidiary Guarantor's
Subsidiary Guaranty), in each case as a result of which Swift and its remaining
Restricted Subsidiaries are no longer liable for such liabilities, such
consideration being defined as "Permitted Consideration"; provided, however,
that Swift and its Restricted Subsidiaries shall be permitted to receive
Property other than Permitted Consideration, so long as the aggregate Fair
Market Value of all such Property other than Permitted Consideration received
from Asset Sales and held by Swift or any Restricted Subsidiary at any one time
shall not exceed 10.0% of Adjusted Consolidated Net Tangible Assets.
The Net Available Cash from Asset Sales by us or a Restricted Subsidiary
may be applied by us or such Restricted Subsidiary, to the extent we or such
Restricted Subsidiary elects (or is required by the terms of any Senior
Indebtedness of Swift or a Subsidiary Guarantor), to:
(a) prepay, repay or purchase Senior Indebtedness of Swift or a Subsidiary
Guarantor (in each case excluding Indebtedness owed to us or an Affiliate of
Swift);
(b) to reinvest in Additional Assets (including by means of an Investment
in Additional Assets by a Restricted Subsidiary with Net Available Cash received
by us or another Restricted Subsidiary); or
(c) purchase Notes or purchase both Notes and one or more series or issues
of other Pari Passu Indebtedness on a pro rata basis (excluding Notes and Pari
Passu Indebtedness owed by us or any of our Affiliates).
Any Net Available Cash from an Asset Sale not applied in accordance with
the preceding paragraph within 365 days from the date of such Asset Sale shall
constitute "Excess Proceeds." When the aggregate amount of Excess Proceeds
exceeds $10.0 million, we will be required to make an offer (a "Prepayment
Offer") to purchase Notes having an aggregate principal amount equal to the
aggregate amount of Excess Proceeds, at a purchase price equal to 100% of the
principal amount of such Notes plus accrued and unpaid interest, if any, to the
Purchase Date (as defined) in accordance with the procedures (including
proration in the event of oversubscription) set forth in the Indenture, but, if
the terms of any Pari Passu Indebtedness require that a Pari Passu Offer be made
contemporaneously with the Prepayment Offer, then the Excess Proceeds shall be
prorated between the Prepayment Offer and such Pari Passu Offer in accordance
with the aggregate outstanding principal amounts of the Notes and such Pari
Passu Indebtedness, and the aggregate principal amount of Notes for which the
Prepayment Offer is made shall be reduced accordingly. If the aggregate
principal amount of Notes tendered by Holders thereof exceeds the amount of
available Excess Proceeds, then such Excess Proceeds will be allocated pro rata
according to the principal amount of the Notes tendered and the Trustee will
select the Notes to be purchased in accordance with the Indenture. To the extent
that any portion of the amount of Excess Proceeds remains after compliance with
the second sentence of this paragraph, and provided that all Holders of Notes
have been given the opportunity to tender their Notes for purchase as described
in the following paragraph in accordance with the Indenture, Swift and its
Restricted Subsidiaries may use such remaining amount for purposes permitted by
the Indenture, and the amount of Excess Proceeds will be reset to zero.
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Within 30 days after the 365th day following the date of an Asset Sale,
Swift shall, if it is obligated to make an offer to purchase the Notes pursuant
to the preceding paragraph, send a written Prepayment Offer notice, the
"Prepayment Offer Notice," by first-class mail, to the Holders of the Notes,
accompanied by such information regarding Swift and its Subsidiaries as we
believe will enable such Holders of the Notes to make an informed decision with
respect to the Prepayment Offer. The Prepayment Offer Notice will state, among
other things:
(a) that we are offering to purchase Notes pursuant to the provisions of
the Indenture;
(b) that any Note (or any portion thereof) accepted for payment (and duly
paid on the Purchase Date) pursuant to the Prepayment Offer shall cease to
accrue interest on the Purchase Date;
(c) that any Notes (or portions thereof) not properly tendered will
continue to accrue interest;
(d) the purchase price and purchase date, the "Purchase Date," which shall
be, subject to any contrary requirements of applicable law, no less than 30 days
nor more than 60 days after the date the Prepayment Offer Notice is mailed;
(e) the aggregate principal amount of Notes to be purchased;
(f) a description of the procedure that Holders of Notes must follow in
order to tender their Notes for payment; and
(g) all other instructions and materials necessary to enable Holders to
tender Notes pursuant to the Prepayment Offer.
We will comply, to the extent applicable, with the requirements of Section
14(e) under the Exchange Act and any other securities laws or regulations
thereunder to the extent such laws and regulations are applicable in connection
with the purchase of Notes as described above. To the extent that the provisions
of any securities laws or regulations conflict with the provisions relating to
the Prepayment Offer, we will comply with the applicable securities laws and
regulations and will not be deemed to have breached its obligations described
above by virtue thereof.
Incurrence of Layered Indebtedness
The Indenture provides that:
(a) we will not Incur any Indebtedness that is subordinated or junior in
right of payment to any Senior Indebtedness of Swift unless such Indebtedness
constitutes Indebtedness that is junior to, or pari passu with, the Notes in
right of payment; and
(b) no Subsidiary Guarantor will Incur any Indebtedness that is
subordinated or junior in right of payment to any Senior Indebtedness of such
Subsidiary Guarantor unless such Indebtedness constitutes Indebtedness that in
right of payment is junior to, or pari passu with, such Subsidiary Guarantor's
Subsidiary Guaranty.
Limitation on Transactions with Affiliates
The Indenture provides that we will not, and will not permit any of our
Restricted Subsidiaries to, directly or indirectly, conduct any business or
enter into any transaction or series of transactions (including the sale,
transfer, disposition, purchase, exchange or lease of Property, the making of
any Investment, the giving of any Guarantee or the rendering of any service)
with or for the benefit of any Affiliate of Swift (other than Swift or a Wholly
Owned Subsidiary), unless:
(a) such transaction is set forth in writing;
(b) such transaction or series of transactions is on terms no less
favorable to us or such Restricted Subsidiary than those that could be obtained
in a comparable arm's-length transaction with a Person that is not an Affiliate
of Swift or such Restricted Subsidiary; and
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(c) with respect to a transaction or series of transactions involving
aggregate payments by or to us or such Restricted Subsidiary having a Fair
Market Value equal to or in excess of:
(1) $1.0 million but less than $5.0 million, an officer of Swift
certifies that such transaction or series of transactions complies with
clause (b) of this paragraph, as evidenced by an Officers' Certificate
delivered to the Trustee,
(2) $5.0 million but less than $20.0 million, the Board of Directors
of Swift (including a majority of the disinterested members of such Board
of Directors) approves such transaction or series of transactions and
certifies that such transaction or series of transactions complies with
clause (b) of this paragraph, as evidenced by a certified resolution
delivered to the Trustee, or
(3) $20.0 million,
(A) we receive from an independent, nationally recognized
investment banking firm or appraisal firm, in either case specializing
or having a specialty in the type and subject matter of the transaction
(or series of transactions) at issue, a written opinion that such
transaction (or series of transactions) is fair, from a financial point
of view, to us or such Restricted Subsidiary, and
(B) such Board of Directors (including a majority of the
disinterested members of the Board of Directors of Swift) approves such
transaction or series of transactions and certifies that such
transaction or series of transactions complies with clause (b) of this
paragraph, as evidenced by a certified resolution delivered to the
Trustee.
The limitations of the preceding paragraph do not apply to:
(a) the payment of reasonable and customary regular fees to directors of
Swift or any of its Restricted Subsidiaries who are not employees of Swift or
any of its Restricted Subsidiaries;
(b) indemnities of officers and directors of Swift or any Subsidiary
consistent with such Person's charter, bylaws and applicable statutory
provisions;
(c) any issuance of securities, or other payments, awards or grants in
cash, securities or otherwise pursuant to, or the funding of, employment
arrangements, stock options and employee stock purchase and ownership plans
approved by the Board of Directors of Swift;
(d) loans made:
(1) to officers, directors or employees of Swift or any Restricted
Subsidiary approved by the Board of Directors of Swift, the net proceeds of
which are used solely to purchase common stock of Swift in connection with
a restricted stock or employee stock purchase plan, or to exercise stock
options received pursuant to an employee or director stock option plan or
other incentive plan, in a principal amount not to exceed the purchase
price of such common stock or the exercise price of such stock options, or
(2) to refinance loans, together with accrued interest thereon, made
pursuant to this clause (d);
(e) advances and loans to officers, directors and employees of Swift or any
Subsidiary in the ordinary course of business (including, without limitation,
non-cash loans for the purchase of joint interests in exploratory and
developmental oil and gas prospects or other similar ventures offered by Swift);
provided such loans and advances (excluding loans or advances made pursuant to
the preceding clause (d)) do not exceed $2.0 million at any one time
outstanding;
(f) any Restricted Payment permitted to be paid pursuant to the provisions
of the Indenture described under "-- Limitations on Restricted Payments";
(g) any transaction or series of transactions between Swift and one or more
Restricted Subsidiaries or between two or more Restricted Subsidiaries in the
ordinary course of business, provided that no more
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than 10% of the total voting power of the Voting Stock of any such Restricted
Subsidiary is owned by an Affiliate of Swift (other than a Restricted
Subsidiary); and
(h) any transaction or series of transactions pursuant to any agreement or
obligation of Swift or any of its Restricted Subsidiaries in effect on the Issue
Date.
Limitation on Restrictions on Distributions from Restricted Subsidiaries
The Indenture provides that we will not, and will not permit any of our
Restricted Subsidiaries to, directly or indirectly, create or otherwise cause or
permit to exist or become effective any consensual encumbrance or restriction on
the legal right of any Restricted Subsidiary to:
(a) pay dividends, in cash or otherwise, or make any other distributions on
or in respect of its Capital Stock, or pay any Indebtedness or other obligation
owed, to us or any other Restricted Subsidiary;
(b) make loans or advances to Swift or any other Restricted Subsidiary; or
(c) transfer any of its Property to Swift or any other Restricted
Subsidiary.
Such limitation will not apply:
(1) with respect to clauses (a), (b) and (c), to encumbrances and
restrictions:
(A) in agreements and instruments as in effect on the Issue Date,
(B) relating to Indebtedness of a Restricted Subsidiary and
existing at the time it became a Restricted Subsidiary if such
encumbrance or restriction was not created in anticipation of or in
connection with the transactions pursuant to which such Restricted
Subsidiary became a Restricted Subsidiary, or
(C) that result from the renewal, refinancing, extension or
amendment of an agreement that is the subject of clause (c)(1)(A) or (B)
above or clause (c)(2)(A) or (B) below, provided that such encumbrance
or restriction is not materially less favorable to the Holders of Notes
than those under or pursuant to the agreement so renewed, refinanced,
extended or amended, and,
(2) with respect to clause (c) only, to:
(A) restrictions pursuant to Liens permitted to be in effect
without also securing the Notes under the provisions of the Indenture
described under "-- Limitation on Liens" that limit the right of the
debtor to dispose of the Property subject to such Lien,
(B) any encumbrance or restriction applicable to Property at the
time it is acquired by us or a Restricted Subsidiary, so long as such
encumbrance or restriction relates solely to the Property so acquired
and was not created in anticipation of or in connection with such
acquisition,
(C) customary provisions restricting subletting or assignment of
leases and customary provisions in other agreements that restrict
assignment of such agreements or rights thereunder, and
(D) customary restrictions contained in asset sale agreements
limiting the transfer of such assets pending the closing of such sale.
Future Subsidiary Guarantors
We shall cause each Restricted Subsidiary (except an Exempt Foreign
Subsidiary) that:
(a) incurs Indebtedness or issues Preferred Stock following the Issue Date;
or
(b) has Indebtedness or Preferred Stock outstanding on the date on which
such Restricted Subsidiary becomes a Restricted Subsidiary,
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to execute and deliver to the Trustee a Subsidiary Guaranty at the time such
Restricted Subsidiary Incurs such Indebtedness or becomes a Restricted
Subsidiary; provided, however, that such Restricted Subsidiary shall not be
required to deliver a supplemental indenture providing for a Subsidiary Guaranty
if the aggregate amount of such Indebtedness or Preferred Stock, together with
all other Indebtedness and Preferred Stock then outstanding among Restricted
Subsidiaries (including Exempt Foreign Subsidiaries) that are not Subsidiary
Guarantors, is less than $10.0 million.
Swift Energy New Zealand Limited and Southern Petroleum (New Zealand)
Exploration Limited are each eligible to become Foreign Exempt Subsidiaries.
Restricted and Unrestricted Subsidiaries
Unless defined or designated as an Unrestricted Subsidiary, any Person that
becomes a Subsidiary of Swift or any of its Restricted Subsidiaries shall be
classified as a Restricted Subsidiary subject to the provisions of the next
paragraph. We may designate a Subsidiary (including a newly formed or newly
acquired Subsidiary) of Swift or any of its Restricted Subsidiaries as an
Unrestricted Subsidiary if:
(a) such Subsidiary does not at such time own any Capital Stock or
Indebtedness of, or own or hold any Lien on any Property of, Swift or any other
Restricted Subsidiary;
(b) such Subsidiary does not at such time have any Indebtedness or other
obligations that, if in default, would result (with the passage of time or
notice or otherwise) in a default on any Indebtedness of Swift or any Restricted
Subsidiary; and
(c) (1) such designation is effective immediately upon such Subsidiary
becoming a Subsidiary of Swift or of a Restricted Subsidiary,
(2) the Subsidiary to be so designated has total assets of $1,000 or
less, or
(3) if such Subsidiary has assets greater than $1,000, then such
redesignation as an Unrestricted Subsidiary is deemed to constitute a
Restricted Payment in an amount equal to the Fair Market Value of Swift's
direct and indirect ownership interest in such Subsidiary, and such
Restricted Payment would be permitted to be made at the time of such
designation under "-- Limitation on Restricted Payments."
Except as provided in the immediately preceding sentence, no Restricted
Subsidiary may be redesignated as an Unrestricted Subsidiary. The
designation of an Unrestricted Subsidiary or removal of such designation
shall be made by the Board of Directors of Swift or a committee thereof
pursuant to a certified resolution delivered to the Trustee and shall be
effective as of the date specified in the applicable certified
resolution, which shall not be prior to the date such certified
resolution is delivered to the Trustees.
We will not, and will not permit any Unrestricted Subsidiaries to, take any
action or enter into any transaction or series of transactions that would result
in a Person becoming a Restricted Subsidiary (whether through an acquisition or
otherwise) unless, after giving effect to such action, transaction or series of
transactions, on a pro forma basis:
(a) we could Incur at least $1.00 of additional Indebtedness pursuant to
clause (a) of the first paragraph under "-- Limitation on Indebtedness"; and
(b) no Default or Event of Default would occur or be continuing.
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MERGER, CONSOLIDATION AND SALE OF SUBSTANTIALLY ALL ASSETS
We shall not consolidate with or merge with or into any Person, or sell,
transfer, lease or otherwise dispose of, in one transaction or series of
transactions, all or substantially all the Property of Swift and the Restricted
Subsidiaries taken as a whole, unless:
(a) the resulting, surviving or transferee Person (a "Successor Company")
shall be a Person organized or existing under the laws of the United States of
America, any State thereof or the District of Columbia and the Successor Company
(if not Swift) shall expressly assume, by a supplemental indenture, executed and
delivered to the Trustee, in form satisfactory to the Trustee, all the
obligations of Swift under the Notes and the Indenture;
(b) in the case of a disposition of all or substantially all of the
Property of Swift and the Restricted Subsidiaries taken as a whole, such
Property shall have been so disposed of as an entirety or virtually as an
entirety to one Person;
(c) immediately after giving effect to such transaction (and treating, for
purposes of this clause (c) and clauses (d) and (e) below, any Indebtedness that
becomes or is anticipated to become an obligation of the Successor Company or
any Restricted Subsidiary as a result of such transaction as having been
Incurred by such Successor Company or such Restricted Subsidiary at the time of
such transaction), no Default or Event of Default shall have occurred and be
continuing;
(d) immediately after giving effect to such transaction, the Successor
Company would be able to Incur an additional $1.00 of Indebtedness pursuant to
clause (a) of the first paragraph under "-- Limitation on Indebtedness;"
(e) immediately after giving effect to such transaction, the Successor
Company shall have Consolidated Net Worth in an amount that is not less than the
Consolidated Net Worth of Swift immediately prior to such transaction; and
(f) we shall have delivered to the Trustee an Officers' Certificate,
stating that such consolidation, merger or disposition and such supplemental
indenture (if any) comply with the Indenture.
The Successor Company shall be the successor to Swift and shall succeed to, and
be substituted for, and may exercise every right and power of Swift under the
Indenture, but the predecessor in the case of a lease shall not be released from
the obligation to pay the principal of and interest on the Notes.
REPORTS
Notwithstanding that we may not be subject to the reporting requirements of
Section 13 or 15(d) of the Exchange Act, we shall file with the Commission and
provide the Trustee and Holders of Notes with such annual reports and such
information, documents and other reports as are specified in Sections 13 and
15(d) of the Exchange Act and applicable to a U.S. corporation subject to such
Sections, such information, documents and reports to be so filed and provided at
the times specified for the filing of such information, documents and reports
under such Sections; provided, however, that we shall not be so obligated to
file such information, documents and reports with the Commission if the
Commission does not permit such filings.
CERTAIN DEFINITIONS
Set forth below is a summary of certain of the defined terms used in the
Indenture. Reference is made to the Indenture for the full definition of all
such terms, as well as any other capitalized terms used herein for which no
definition is provided.
"Additional Assets" means:
(a) any Property (other than cash, Permitted Short-Term Investments or
securities) used in the Oil and Gas Business or any business ancillary thereto;
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(b) Investments in any other Person engaged in the Oil and Gas Business or
any business ancillary thereto (including the acquisition from third parties of
Capital Stock of such Person) as a result of which such other Person becomes a
Restricted Subsidiary in compliance with the provisions of the Indenture
described under "-- Certain Covenants -- Restricted and Unrestricted
Subsidiaries";
(c) the acquisition from third parties of Capital Stock of a Restricted
Subsidiary; or
(d) Permitted Business Investments.
"Adjusted Consolidated Net Tangible Assets" means (without duplication), as
of the date of determination, the remainder of:
(a) the sum of:
(1) discounted future net revenues from proved oil and gas reserves of
Swift and its Restricted Subsidiaries calculated in accordance with SEC
guidelines before any state, federal or foreign income taxes, as estimated
by Swift and confirmed by a nationally recognized firm of independent
petroleum engineers in a reserve report prepared as of the end of our most
recently completed fiscal year for which audited financial statements are
available, as increased by, as of the date of determination, the estimated
discounted future net revenues from:
(A) estimated proved oil and gas reserves acquired since such year
end, which reserves were not reflected in such year end reserve report,
and
(B) estimated oil and gas reserves attributable to upward revisions
of estimates of proved oil and gas reserves since such year end due to
exploration, development or exploitation activities, in each case
calculated in accordance with SEC 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:
(C) estimated proved oil and gas reserves produced or disposed of
since such year end, and
(D) estimated oil and gas reserves attributable to downward
revisions of estimates of proved oil and gas reserves since such year
end due to changes in geological conditions or other factors that would,
in accordance with standard industry practice, cause such revisions, in
each case calculated in accordance with SEC 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 (A) through (D), such increases and decreases shall be as
estimated by our petroleum engineers, unless there is a Material Change
as a result of such acquisitions, dispositions or revisions, in which
event the discounted future net revenues utilized for purposes of this
clause (a)(1) shall be confirmed in writing by a nationally recognized
firm of independent petroleum engineers,
(2) the capitalized costs that are attributable to oil and gas
properties of Swift and its Restricted Subsidiaries to which no proved oil
and gas reserves are attributable, based on our books and records as of a
date no earlier than the date of our latest annual or quarterly financial
statements,
(3) our Net Working Capital on a date no earlier than the date of our
latest annual or quarterly financial statements, and
(4) the greater of the net book value or the appraised value as
estimated by independent appraisers of other tangible assets (including,
without duplication, Investments in unconsolidated Restricted Subsidiaries)
of Swift and its Restricted Subsidiaries, as of a date no earlier than the
date of our latest audited financial statements. For these purposes, net
book value shall be determined as of a date no earlier than the date of our
latest annual or quarterly financial statements, and on a date no earlier
than the date of our latest annual or quarterly financial statements;
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(b) minus the sum of:
(1) minority interests,
(2) any net gas balancing liabilities of Swift and its Restricted
Subsidiaries reflected in its latest audited financial statements,
(3) to the extent included in (a)(1) above, the discounted future
net revenues, calculated in accordance with SEC guidelines (utilizing
the prices utilized in our year end reserve report), attributable to
reserves that are required to be delivered to third parties to fully
satisfy the obligations of Swift and its Restricted Subsidiaries with
respect to Volumetric Production Payments (determined, if applicable,
using the schedules specified with respect thereto), and
(4) the discounted future net revenues, calculated in accordance
with SEC guidelines, attributable to reserves subject to
Dollar-Denominated Production Payments that, based on the estimates of
production and price assumptions included in determining the discounted
future net revenues specified in (a)(1) above, would be necessary to
fully satisfy the payment obligations of Swift and its Restricted
Subsidiaries with respect to Dollar-Denominated Production Payments
(determined, if applicable, using the schedules specified with respect
thereto).
If we change our method of accounting from the full cost method to the
successful efforts method or a similar method of accounting, "Adjusted
Consolidated Net Tangible Assets" will continue to be calculated as if we were
still using the full cost method of accounting.
"Affiliate" of any specified Person means any other Person:
(a) that directly or indirectly through one or more intermediaries
controls, or is controlled by, or is under common control with, such specified
Person; or
(b) that beneficially owns or holds directly or indirectly 10% or more of
any class of the Voting Stock of such specified Person or of any Subsidiary of
such specified Person.
For the purposes of this definition, "control," when used with respect to
any specified Person, means the power to direct the management and policies of
such Person directly or indirectly, whether through the ownership of Voting
Stock, by contract or otherwise; and the terms "controlling" and "controlled"
have meanings correlative to the foregoing.
"Asset Sale" means, with respect to any Person, any transfer, conveyance,
sale, lease or other disposition (collectively, "dispositions," and including
dispositions pursuant to any consolidation or merger) by such Person or any of
its Restricted Subsidiaries in any single transaction or series of transactions
of:
(a) shares of Capital Stock or other ownership interests of another Person
(including Capital Stock of Restricted Subsidiaries and Unrestricted
Subsidiaries); or
(b) any other Property of such Person or any of its Restricted
Subsidiaries;
provided, however, that the term "Asset Sale" shall not include:
(a) the disposition of Permitted Short-Term Investments, inventory,
accounts receivable, surplus or obsolete equipment or other Property (excluding
the disposition of oil and gas in place and other interests in real property
unless made in connection with a Permitted Business Investment) in the ordinary
course of business;
(b) the abandonment, assignment, lease, sublease or farm-out of oil and gas
properties, or the forfeiture or other disposition of such properties pursuant
to standard form operating agreements, in each case in the ordinary course of
business in a manner that is customary in the Oil and Gas Business;
(c) the disposition of Property received in settlement of debts owing to us
or any Restricted Subsidiary as a result of foreclosure, perfection or
enforcement of any Lien or debt, which debts were owing to us or any Restricted
Subsidiary in the ordinary course of business of Swift or such Restricted
Subsidiary;
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(d) any disposition that constitutes a Restricted Payment made in
compliance with the provisions of the Indenture described under "-- Certain
Covenants -- Limitation on Restricted Payments;"
(e) when used with respect to us, any disposition of all or substantially
all of the Property of Swift and its Restricted Subsidiaries taken as a whole
permitted pursuant to the provisions of the Indenture described under
"-- Merger, Consolidation and Sale of Substantially All Assets;"
(f) the disposition of any Property by us or a Restricted Subsidiary to
Swift or a Wholly Owned Subsidiary;
(g) the disposition of any Property with a Fair Market Value of less than
$2.0 million; or
(h) any Production Payments and Reserve Sales, provided that any such
Production Payments and Reserve Sales, other than incentive compensation
programs on terms that are reasonably customary in the Oil and Gas Business for
geologists, geophysicists and other providers of technical services to us or a
Restricted Subsidiary, shall have been created, Incurred, issued, assumed or
Guaranteed in connection with the financing of, and within 60 days after the
acquisition of, the Property that is subject thereto.
"Average Life" means, with respect to any Indebtedness, at any date of
determination, the quotient obtained by dividing:
(a) the sum of the products of:
(1) the number of years (and any portion thereof) from the date of
determination to the date or dates of each successive scheduled principal
payment (including any sinking fund or mandatory redemption payment
requirements) of such Indebtedness, multiplied by
(2) the amount of each such principal payment,
(b) by the sum of all such principal payments.
"Bank Credit Facilities" means, with respect to any Person, one or more
debt facilities or commercial paper facilities with banks or other institutional
lenders providing for revolving credit loans, term loans, receivables or
inventory financing (including through the sale of receivables or inventory
financing to such lenders or to special purpose entities formed to borrow from
such lenders against such receivables or inventory) or trade letters of credit,
in each case together with any extensions, revisions, refinancings or
replacements thereof by a lender or syndicate of lenders.
"Capital Lease Obligation" means any obligation that is required to be
classified and accounted for as a capital lease obligation in accordance with
GAAP, and the amount of Indebtedness represented by such obligation shall be the
capitalized amount of such obligation determined in accordance with GAAP, and
the Stated Maturity thereof shall be the date of the last payment date of rent
or any other amount due in respect of such obligation.
"Capital Stock" means, with respect to any Person, any shares or other
equivalents (however designated) of any class of corporate stock or partnership
interests or any other participations, rights, warrants, options or other
interests in the nature of an equity interest in such Person, including
Preferred Stock, but excluding any debt security convertible or exchangeable
into such equity interest.
"Consolidated Interest Coverage Ratio" means, as of the date of the
transaction (the "Transaction Date") giving rise to the need to calculate the
Consolidated Interest Coverage Ratio, the ratio of:
(a) the aggregate amount of EBITDA of Swift and its consolidated Restricted
Subsidiaries for the four full fiscal quarters immediately prior to the
Transaction Date for which financial statements are available; to
(b) the aggregate Consolidated Interest Expense of Swift and its Restricted
Subsidiaries that is anticipated to accrue during a period consisting of the
fiscal quarter in which the Transaction Date occurs and the three fiscal
quarters immediately subsequent thereto (based upon the pro forma amount and
maturity of, and interest payments in respect of, Indebtedness of Swift and its
Restricted Subsidiaries
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expected by us to be outstanding on the Transaction Date), assuming for the
purposes of this measurement the continuation of market interest rates
prevailing on the Transaction Date and base interest rates in respect of
floating interest rate obligations equal to the base interest rates on such
obligations in effect as of the Transaction Date; provided, that if we or any of
our Restricted Subsidiaries is a party to any Interest Rate Protection Agreement
that would have the effect of changing the interest rate on any Indebtedness of
Swift or any of its Restricted Subsidiaries for such four quarter period (or a
portion thereof), the resulting rate shall be used for such four quarter period
or portion thereof; provided further that any Consolidated Interest Expense with
respect to Indebtedness Incurred or retired by Swift or any of its Restricted
Subsidiaries during the fiscal quarter in which the Transaction Date occurs
shall be calculated as if such Indebtedness was so Incurred or retired on the
first day of the fiscal quarter in which the Transaction Date occurs.
In addition, if at any time since the beginning of the four full fiscal
quarter period preceding the Transaction Date through and including the
Transaction Date:
(a) Swift or any of its Restricted Subsidiaries shall have engaged in any
Asset Sale, EBITDA for such period shall be reduced by an amount equal to the
EBITDA (if positive), or increased by an amount equal to the EBITDA (if
negative), directly attributable to the Property that is the subject of such
Asset Sale for such period calculated on a pro forma basis as if such Asset Sale
and any related retirement of Indebtedness had occurred on the first day of such
period; or
(b) (1) Swift or any of its Restricted Subsidiaries shall have acquired or
made any Investment in any material assets, or
(2) the transaction giving rise to the need to calculate the
Consolidated Interest Coverage Ratio is such an Investment or acquisition,
EBITDA shall be calculated on a pro forma basis as if such Investments or asset
acquisitions had occurred on the first day of such four fiscal quarter period.
"Consolidated Interest Expense" means, with respect to any Person for any
period, without duplication:
(a) the sum of:
(1) the aggregate amount of cash and noncash interest expense
(including capitalized interest) of such Person and its Restricted
Subsidiaries for such period as determined on a consolidated basis in
accordance with GAAP in respect of Indebtedness, including:
(A) any amortization of debt discount,
(B) net costs associated with Interest Rate Protection Agreements
(including any amortization of discounts),
(C) the interest portion of any deferred payment obligation,
(D) all accrued interest, and
(E) all commissions, discounts, commitment fees, origination fees
and other fees and charges owed with respect to Bank Credit Facilities
and other Indebtedness paid, accrued or scheduled to be paid or accrued
during such period,
(2) Disqualified Stock Dividends of such Person (and of its Restricted
Subsidiaries if paid to a Person other than such Person or its Restricted
Subsidiaries) and Preferred Stock Dividends of such Person's Restricted
Subsidiaries if paid to a Person other than such Person or its other
Restricted Subsidiaries,
(3) the portion of any obligation of such Person or its Restricted
Subsidiaries in respect of any Capital Lease Obligation allocable to
interest expense in accordance with GAAP,
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(4) the portion of any rental obligation of such Person or its
Restricted Subsidiaries in respect of any Sale and Leaseback Transaction
that is Indebtedness allocable to interest expense (determined as if such
obligation were treated as a Capital Lease Obligation), and
(5) to the extent any Indebtedness of any other Person (other than
Restricted Subsidiaries) is Guaranteed by such Person or any of its
Restricted Subsidiaries, the aggregate amount of interest paid, accrued or
scheduled to be paid or accrued by such other Person during such period
attributable to any such Indebtedness;
less
(b) to the extent included in (a) above, amortization or write-off of
deferred financing costs (other than debt discounts) of such Person and its
Restricted Subsidiaries during such period;
in the case of both (a) and (b) above, after elimination of intercompany
accounts among such Person and its Restricted Subsidiaries and as
determined in accordance with GAAP.
"Consolidated Net Income" of any Person means, for any period, the
aggregate net income (or net loss, as the case may be) of such Person and its
Restricted Subsidiaries for such period on a consolidated basis, determined in
accordance with GAAP; provided that there shall be excluded therefrom, without
duplication:
(a) items classified as extraordinary gains or losses net of tax (less all
fees and expenses relating thereto);
(b) any gain or loss net of taxes (less all fees and expenses relating
thereto) realized on the sale or other disposition of Property, including the
Capital Stock of any other Person (but in no event shall this clause (b) apply
to any gains or losses on the sale in the ordinary course of business of oil,
gas or other hydrocarbons produced or manufactured);
(c) the net income of any Restricted Subsidiary of such specified Person to
the extent the transfer to that Person of that income is restricted by contract
or otherwise, except for any cash dividends or cash distributions actually paid
by such Restricted Subsidiary to such Person during such period;
(d) the net income (or loss) of any other Person in which such specified
Person or any of its Restricted Subsidiaries has an interest (which interest
does not cause the net income of such other Person to be consolidated with the
net income of such specified Person in accordance with GAAP or is an interest in
a consolidated Unrestricted Subsidiary), except to the extent of the amount of
cash dividends or other cash distributions actually paid to such Person or its
consolidated Restricted Subsidiaries by such other Person during such period;
(e) for the purposes of "-- Certain Covenants -- Limitation on Restricted
Payments" only, the net income of any Person acquired by such specified Person
or any of its Restricted Subsidiaries in a pooling-of-interests transaction for
any period prior to the date of such acquisition;
(f) any gain or loss, net of taxes, realized on the termination of any
employee pension benefit plan;
(g) any adjustments of a deferred tax liability or asset pursuant to
Statement of Financial Accounting Standards No. 109 that result from changes in
enacted tax laws or rates;
(h) the cumulative effect of a change in accounting principles;
(i) any write-downs of non-current assets, provided that any ceiling
limitation write-downs under SEC guidelines shall be treated as capitalized
costs, as if such write-downs had not occurred; and
(j) any non-cash compensation expense realized upon issuance of stock under
an employee stock purchase plan or for grants of performance shares, stock
options or stock awards to officers, directors and employees of Swift or any of
its Restricted Subsidiaries.
"Consolidated Net Worth" of any Person means the stockholders' equity of
such Person and its Restricted Subsidiaries, as determined on a consolidated
basis in accordance with GAAP, less (to the
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extent included in stockholders' equity) amounts attributable to Disqualified
Stock of such Person or its Restricted Subsidiaries.
"Default" means any event, act or condition the occurrence of which is, or
after notice or the passage of time or both would be, an Event of Default.
"Designated Senior Indebtedness" means:
(a) the Bank Credit Facilities; and
(b) any other Senior Indebtedness of Swift that has, at the time of
determination, an aggregate principal amount outstanding of at least $10.0
million that is specifically designated in the instrument evidencing such Senior
Indebtedness and is designated in a notice delivered by us to the holders or a
Representative of the holders of such Senior Indebtedness and the Trustee as
"Designated Senior Indebtedness" of Swift.
"Disqualified Stock" means, with respect to any Person, any Capital Stock
that by its terms (or by the terms of any security into which it is convertible
or for which it is exchangeable, in either case at the option of the holder
thereof) or otherwise:
(a) matures or is mandatorily redeemable pursuant to a sinking fund
obligation or otherwise;
(b) is or may become redeemable or repurchasable at the option of the
holder thereof, in whole or in part; or
(c) is convertible or exchangeable at the option of the holder thereof for
debt or any other Disqualified Stock;
on or prior to, in the case of clause (a), (b) or (c), the first anniversary of
the Stated Maturity of the Notes.
"Disqualified Stock Dividends" means all dividends with respect to
Disqualified Stock of Swift held by Persons other than a Wholly Owned
Subsidiary. The amount of any such dividend shall be equal to the quotient of
such dividend divided by the difference between one and the maximum statutory
federal income tax rate (expressed as a decimal number between 1 and 0) then
applicable to Swift.
"Dollar-Denominated Production Payments" means production payment
obligations recorded as liabilities in accordance with GAAP, together with all
undertakings and obligations in connection therewith.
"EBITDA" means with respect to any Person for any period, the Consolidated
Net Income of such Person for such period:
(a) plus the sum of, to the extent reflected in the consolidated income
statement of such Person and its Restricted Subsidiaries for such period from
which Consolidated Net Income is determined and deducted in the determination of
such Consolidated Net Income, without duplication:
(1) income tax expense (but excluding income tax expense relating to
sales or other dispositions of Property, including the Capital Stock of any
other Person, the gains from which are excluded in the determination of
such Consolidated Net Income),
(2) Consolidated Interest Expense,
(3) depreciation and depletion expense,
(4) amortization expense,
(5) exploration expense (if applicable to us after the Issue Date),
and
(6) any other noncash charges including unrealized foreign exchange
losses (excluding, however, any such other noncash charge that requires an
accrual of or reserve for cash charges for any future period);
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(b) less the sum of, to the extent reflected in the consolidated income
statement of such Person and its Restricted Subsidiaries for such period from
which Consolidated Net Income is determined and added in the determination of
such Consolidated Net Income, without duplication:
(1) income tax recovery (excluding, however, income tax recovery
relating to sales or other dispositions of Property, including the
Capital Stock of any other Person, the losses from which are excluded in
the determination of such Consolidated Net Income), and
(2) unrealized foreign exchange gains.
"Equity Offering" means a bona fide underwritten sale to the public of
common stock of Swift pursuant to a registration statement (other than a Form
S-8 or any other form relating to securities issuable under any employee benefit
plan of Swift) that is declared effective by the Commission following the Issue
Date.
"Exchanged Properties" means Properties used or useful in the Oil and Gas
Business received by us or a Restricted Subsidiary in trade or as a portion of
the total consideration for other such Properties.
"Exchange Rate Contract" means, with respect to any Person, any currency
swap agreements, forward exchange rate agreements, foreign currency futures or
options, exchange rate collar agreements, exchange rate insurance and other
agreements or arrangements, or any combination thereof, entered into by such
Person in the ordinary course of its business for the purpose of limiting or
managing exchange rate risks to which such Person is subject.
"Exempt Foreign Subsidiary" means any Restricted Subsidiary that is a
foreign corporation if more than 50% of the (i) total combined voting power of
all Voting Stock of the corporation or (ii) the total value of the Capital Stock
of the corporation is owned or is considered as owned by United States
shareholders on any day during the taxable year of the foreign corporation and
that, in any case, is so designated by Swift in an Officers' Certificate
delivered to the Trustee, and which Restricted Subsidiary is not a guarantor of,
and has no Lien (other than a Lien with respect to less than two-thirds of the
Capital Stock of an Exempt Foreign Subsidiary) to secure the Bank Credit
Facilities or any other Indebtedness of Swift or any Restricted Subsidiary other
than an Exempt Foreign Subsidiary. A United States shareholder, as used in this
definition, means any Person who owns or is considered as owning 10% or more of
the total combined voting power of all Voting Stock of the foreign corporation.
Ownership is determined by applying the attribution rules of ownership in
Internal Revenue Code Section 958. References to Internal Revenue Code sections
in this definition include such sections as amended or superseded, including
Treasury regulations promulgated thereunder. Swift may revoke the designation of
any Exempt Foreign Subsidiary by notice to the Trustee.
"Fair Market Value" means, with respect to any Property to be transferred
pursuant to any Asset Sale or Sale and Leaseback Transaction or any noncash
consideration or Property transferred or received by any Person, the fair market
value of such consideration or other Property as determined by:
(a) any officer of Swift if such fair market value is less than $5.0
million; and
(b) the Board of Directors of Swift as evidenced by a certified resolution
delivered to the Trustee if such fair market value is equal to or in excess of
$5.0 million.
"GAAP" means United States generally accepted accounting principles as in
effect on the date of the Indenture, unless stated otherwise.
"Guarantee" by any Person means any obligation, contingent or otherwise, of
such Person guaranteeing or having the economic effect of guaranteeing any
indebtedness of any other Person (a "primary obligor") in any manner, whether
directly or indirectly, and including any Lien on the assets of such Person
securing obligations to pay Indebtedness of the primary obligor, and any
obligation of such Person:
(a) to purchase or pay (or advance or supply funds for the purchase or
payment of) such Indebtedness or any security for the payment of such
Indebtedness;
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(b) to purchase Property, securities or services for the purpose of
assuring the holder of such indebtedness of the payment of such indebtedness; or
(c) to maintain working capital, equity capital or other financial
statement condition or liquidity of the primary obligor so as to enable the
primary obligor to pay such indebtedness (and "Guaranteed", "Guaranteeing" and
"Guarantor" shall have meanings correlative to the foregoing);
provided, however, that a Guarantee by any Person shall not include:
(a) endorsements by such Person for collection or deposit, in either case,
in the ordinary course of business; or
(b) a contractual commitment by one Person to invest in another Person for
so long as such Investment is reasonably expected to constitute a Permitted
Investment under clause (b) of the definition of Permitted Investments.
"Holder" means the Person in whose name a Note is registered on the
Securities Register.
"Incur" means, with respect to any Indebtedness or other obligation of any
Person, to create, issue, incur (by conversion, exchange or otherwise), assume,
Guarantee or become liable (including by reason of a merger or consolidation) in
respect of such Indebtedness or other obligation or the recording, as required
pursuant to GAAP or otherwise, of any such indebtedness or obligation on the
balance sheet of such Person (and "Incurrence," "Incurred," "Incurrable" and
"Incurring" shall have meanings correlative to the foregoing); provided,
however, that a change in GAAP that results in an obligation of such Person that
exists at such time, and is not theretofore classified as Indebtedness, becoming
Indebtedness shall not be deemed an Incurrence of such Indebtedness; provided
further, however, that solely for purposes of determining compliance with
"-- Certain Covenants -- Limitation on Indebtedness," amortization of debt
discount shall not be deemed to be the Incurrence of Indebtedness, provided that
in the case of Indebtedness sold at a discount, the amount of such Indebtedness
shall at all times be the aggregate principal amount at Stated Maturity. For
purposes of this definition, Indebtedness of Swift or a Restricted Subsidiary
held by a Wholly Owned Subsidiary shall be deemed to be Incurred by us or such
Restricted Subsidiary in the event such Indebtedness is transferred to a Person
other than Swift or a Wholly Owned Subsidiary.
"Indebtedness" means at any time (without duplication), with respect to any
Person, whether recourse is to all or a portion of the assets of such Person,
and whether or not contingent:
(a) any obligation of such Person for borrowed money;
(b) any obligation of such Person evidenced by bonds, debentures, notes,
Guarantees or other similar instruments, including any such obligations incurred
in connection with the acquisition of Property, assets or business;
(c) any reimbursement obligation of such Person with respect to letters of
credit, bankers' acceptances or similar facilities issued for the account of
such Person;
(d) any obligation of such Person issued or assumed as the deferred
purchase price of Property or services (other than Trade Accounts Payable);
(e) any Capital Lease Obligation of such Person;
(f) the maximum fixed redemption or repurchase price of Disqualified Stock
of such Person at the time of determination;
(g) any Preferred Stock of any Restricted Subsidiary, provided that such
Restricted Subsidiary is not a Subsidiary Guarantor;
(h) any payment obligation of such Person under Exchange Rate Contracts,
Interest Rate Protection Agreements, Oil and Gas Hedging Contracts or under any
similar agreements or instruments;
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(i) any obligation to pay rent or other payment amounts of such Person with
respect to any Sale and Leaseback Transaction to which such Person is a party;
(j) any obligation of the type referred to in clauses (a) through (h) of
this paragraph of another Person and all dividends of another Person the payment
of which, in either case, such Person has Guaranteed or is responsible or
liable, directly or indirectly, as obligor, Guarantor or otherwise; and
(k) all obligations of the type referred to in clauses (a) through (i) of
another Person secured by any Lien on any Property of such Person (whether or
not such obligation is assumed by such Person), the amount of such obligation
being deemed to be the lesser of the value of such Property or the amount of the
obligation so secured;
provided, however, that Indebtedness shall not include Production Payments and
Reserve Sales. For purposes of this definition, the maximum fixed repurchase
price of any Disqualified Stock that does not have a fixed repurchase price
shall be calculated in accordance with the terms of such Disqualified Stock as
if such Disqualified Stock were repurchased on any date on which Indebtedness
shall be required to be determined pursuant to the Indenture; provided, however,
that if such Disqualified Stock is not then permitted to be repurchased, the
repurchase price shall be the book value of such Disqualified Stock. The amount
of Indebtedness of any Person at any date shall be the outstanding balance at
such date of all unconditional obligations as described above and the maximum
liability at such date in respect of any contingent obligations described above.
"Interest Rate Protection Agreement" means, with respect to any Person, any
interest rate swap agreement, forward rate agreement, interest rate cap or
collar agreement or other financial agreement or arrangement entered into by
such Person in the ordinary course of its business for the purpose of limiting
or managing interest rate risks to which such Person is subject.
"Investment" means, with respect to any Person:
(a) any amount paid by such Person, directly or indirectly, to any other
Person for Capital Stock of, or as a capital contribution to, any other Person;
or
(b) any direct or indirect loan or advance to any other Person (other than
accounts receivable of such Person arising in the ordinary course of business);
provided, however, that Investments shall not include:
(1) in the case of clause (a) as used in the definition of "Restricted
Payments" only, any such amount paid through the issuance of Capital Stock
of Swift (other than Disqualified Stock); and
(2) in the case of clause (a) or (b), extensions of trade credit on
commercially reasonable terms in accordance with normal trade practices and
any increase in the equity ownership in any Person resulting from retained
earnings of such Person.
"Issue Date" means the date on which the Offered Notes first were issued
under the Indenture.
"Lien" means, with respect to any Property, any mortgage or deed of trust,
pledge, hypothecation, assignment, deposit arrangement, security interest, lien
(statutory or other), charge, easement, encumbrance, preference, priority or
other security or similar agreement or preferential arrangement of any kind or
nature whatsoever on or with respect to such Property (including any conditional
sale or other title retention agreement having substantially the same economic
effect as any of the foregoing). For purposes of the provisions of the Indenture
described under "-- Certain Covenants -- Limitation on Liens," a Capital Lease
Obligation shall be deemed to be secured by a Lien on the Property being leased.
"Liquid Securities" means securities:
(a) of an issuer that is not an Affiliate of Swift;
(b) that are publicly traded on the New York Stock Exchange, the American
Stock Exchange or the Nasdaq National Market; and
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(c) as to which Swift is not subject to any restrictions on sale or
transfer (including any volume restrictions under Rule 144 under the Securities
Act or any other restrictions imposed by the Securities Act) or as to which a
registration statement under the Securities Act covering the resale thereof is
in effect for as long as the securities are held;
provided that securities meeting the requirements or clauses (a), (b) and
(c) above shall be treated as Liquid Securities from the date of receipt
thereof until and only until the earlier of:
(1) the date on which such securities are sold or exchanged for cash
or Permitted Short-Term Investments, and
(2) 240 days following the date of receipt of such securities. If such
securities are not sold or exchanged for cash or Permitted Short-Term
Investments within 240 days of receipt thereof, for purposes of determining
whether the transaction pursuant to which Swift or the Restricted
Subsidiary received the securities was in compliance with the provisions of
the Indenture described under "-- Certain Covenants -- Limitation on Asset
Sales," such securities shall be deemed not to have been Liquid Securities
at any time.
"Material Change" means an increase or decrease (except to the extent
resulting from changes in prices) of more than 30% during a fiscal quarter in
the estimated discounted future net revenues from proved oil and gas reserves of
Swift and its Restricted Subsidiaries, calculated in accordance with clause
(a)(1) of the definition of Adjusted Consolidated Net Tangible Assets; provided,
however, that the following will be excluded from the calculation of Material
Change:
(a) any acquisitions during the quarter of oil and gas reserves with
respect to which our estimate of the discounted future net revenues from proved
oil and gas reserves has been confirmed by independent petroleum engineers; and
(b) any dispositions of Properties during such quarter that were disposed
of in compliance with the provisions of the Indenture described under
"-- Certain Covenants -- Limitation on Asset Sales."
"Moody's" means Moody's Investors Service, Inc. and its successors.
"Net Available Cash" from an Asset Sale means cash proceeds received
therefrom, including:
(a) any cash proceeds received by way of deferred payment of principal
pursuant to a note or installment receivable or otherwise, but only as and when
received; and
(b) the Fair Market Value of Liquid Securities and Permitted Short-Term
Investments, and excluding:
(1) any other consideration received in the form of assumption by the
acquiring Person of Indebtedness or other obligations relating to the
Property that is the subject of such Asset Sale, and
(2) except to the extent converted within 240 days after such Asset
Sale to cash, Liquid Securities or Permitted Short-Term Investments,
consideration constituting Exchanged Properties or consideration other than
as identified in the immediately preceding clauses (a) and (b),
in each case net of:
(a) all legal, title and recording expenses, commissions and other
fees and expenses Incurred, and all federal, state, foreign and local
taxes required to be paid or accrued as a liability under GAAP as a
consequence of such Asset Sale;
(b) all payments made on any Indebtedness (but specifically
excluding Indebtedness of Swift and its Restricted Subsidiaries assumed
in connection with or in anticipation of such Asset Sale) that is
secured by any assets subject to such Asset Sale, in accordance with the
terms of any Lien upon such assets, or that must by its terms, or in
order to obtain a necessary consent to such Asset Sale or by applicable
law, be repaid out of the proceeds from such Asset Sale, provided that
such payments are made in a manner that results in the permanent
reduction in the
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balance of such Indebtedness and, if applicable, a permanent reduction
in any outstanding commitment for future incurrences of Indebtedness
thereunder;
(c) all distributions and other payments required to be made to minority
interest holders in Subsidiaries or joint ventures as a result of such Asset
Sale; and
(d) the deduction of appropriate amounts to be provided by the seller as a
reserve, in accordance with GAAP, against any liabilities associated with the
assets disposed of in such Asset Sale and retained by us or any Restricted
Subsidiary after such Asset Sale;
provided, however, that if any consideration for an Asset Sale (which would
otherwise constitute Net Available Cash) is required to be held in escrow
pending determination of whether a purchase price adjustment will be made, such
consideration (or any portion thereof) shall become Net Available Cash only at
such time as it is released to such Person or its Restricted Subsidiaries from
escrow.
"Net Working Capital" means:
(a) all current assets of Swift and its Restricted Subsidiaries; less
(b) all current liabilities of Swift and its Restricted Subsidiaries,
except current liabilities included in Indebtedness,
in each case as set forth in consolidated financial statements of Swift prepared
in accordance with GAAP.
"Non-recourse Purchase Money Indebtedness" means Indebtedness (other than
Capital Lease Obligations) of Swift or any Restricted Subsidiary Incurred in
connection with the acquisition by us or such Restricted Subsidiary in the
ordinary course of business of fixed assets used in the Oil and Gas Business
(including office buildings and other real property used by us or such
Restricted Subsidiary in conducting our operations) with respect to which:
(a) the holders of such Indebtedness agree that they will look solely to
the fixed assets so acquired that secure such Indebtedness, and neither Swift
nor any Restricted Subsidiary:
(1) is directly or indirectly liable for such Indebtedness, or
(2) provides credit support, including any undertaking, Guarantee,
agreement or instrument that would constitute Indebtedness (other than the
grant of a Lien on such acquired fixed assets); and
(b) no default or event of default with respect to such Indebtedness would
cause, or permit (after notice or passage of time or otherwise), any holder of
any other Indebtedness of Swift or a Restricted Subsidiary to declare a default
on such other Indebtedness or cause the payment, repurchase, redemption,
defeasance or other acquisition or retirement for value thereof to be
accelerated or payable prior to any scheduled principal payment, scheduled
sinking fund payment or maturity.
"Oil and Gas Business" means the business of exploiting, exploring for,
developing, acquiring, operating, producing, processing, gathering, marketing,
storing, selling, hedging, treating, swapping, refining and transporting
hydrocarbons and other related energy businesses.
"Oil and Gas Hedging Contract" means, with respect to any Person, any
agreement or arrangement, or any combination thereof, relating to oil and gas or
other hydrocarbon prices, transportation or basis costs or differentials or
other similar financial factors, that is customary in the Oil and Gas Business
and is entered into by such Person in the ordinary course of its business for
the purpose of limiting or managing risks associated with fluctuations in such
prices, costs, differentials or similar factors.
"Oil and Gas Liens" means:
(a) Liens on any specific Property or any interest therein, construction
thereon or improvement thereto to secure all or any part of the costs incurred
for surveying, exploration, drilling, extraction, development, operation,
production, construction, alteration, repair or improvement of, in, under or on
such Property and the plugging and abandonment of wells located thereon (it
being understood that, in the case of oil and gas producing properties, or any
interest therein, costs incurred for "development" shall include
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costs incurred for all facilities relating to such properties or to projects,
ventures or other arrangements of which such properties form a part or which
relate to such properties or interests);
(b) Liens on an oil or gas producing property to secure obligations
incurred or guarantees of obligations incurred in connection with or necessarily
incidental to commitments for the purchase or sale of, or the transportation or
distribution of, the products derived from such Property;
(c) Liens arising under partnership agreements, oil and gas leases,
overriding royalty agreements, net profits agreements, production payment
agreements, royalty trust agreements, incentive compensation programs for
geologists, geophysicists and other providers of technical services to us or a
Restricted Subsidiary, master limited partnership agreements, farm-out
agreements, farm-in agreements, division orders, contracts for the sale,
purchase, exchange, transportation, gathering or processing of oil, gas or other
hydrocarbons, unitizations and pooling designations, declarations, orders and
agreements, development agreements, operating agreements, production sales
contracts, area of mutual interest agreements, gas balancing or deferred
production agreements, injection, repressuring and recycling agreements, salt
water or other disposal agreements, seismic or geophysical permits or
agreements, and other agreements that are customary in the Oil and Gas Business;
provided, however, in all instances that such Liens are limited to the assets
that are the subject of the relevant agreement, program, order or contract;
(d) Liens arising in connection with Production Payments and Reserve Sales;
and
(e) Liens on pipelines or pipeline facilities that arise by operation of
law.
"Pari Passu Indebtedness" means the 2009 Notes and any other Indebtedness
of Swift (or a Subsidiary Guarantor) that is pari passu in right of payment to
the Notes (or a Subsidiary Guaranty, as appropriate).
"Pari Passu Offer" means an offer by us or a Subsidiary Guarantor to
purchase all or a portion of Pari Passu Indebtedness to the extent required by
the indenture or other agreement or instrument pursuant to which such Pari Passu
Indebtedness was issued.
"Permitted Business Investments" means Investments and expenditures made in
the ordinary course of, and of a nature that is or shall have become customary
in, the Oil and Gas Business as a means of actively engaging therein through
agreements, transactions, interests or arrangements that permit one to share
risks or costs, comply with regulatory requirements regarding local ownership or
satisfy other objectives customarily achieved through the conduct of Oil and Gas
Business jointly with third parties, including:
(a) ownership interests in oil and gas properties or gathering,
transportation, processing, storage or related 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)
and other similar agreements (including for limited liability companies) with
third parties, excluding, however, Investments in corporations other than
Restricted Subsidiaries.
"Permitted Hedging Agreements" means:
(a) Exchange Rate Contracts and Oil and Gas Hedging Contracts; and
(b) Interest Rate Protection Agreements but only to the extent that the
stated aggregate notional amount thereunder does not exceed 100% of the
aggregate principal amount of the Indebtedness of Swift or a Restricted
Subsidiary covered by such Interest Rate Protection Agreements at the time such
agreements were entered into.
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"Permitted Investments" means any and all of the following:
(a) Permitted Short-Term Investments;
(b) Investments in property, plant and equipment used in the ordinary
course of business and Permitted Business Investments;
(c) Investments by any Restricted Subsidiary in Swift;
(d) Investments by us or any Restricted Subsidiary in any Restricted
Subsidiary;
(e) Investments by us or any Restricted Subsidiary:
(1) in any Person that will, upon the making of such Investment,
become a Restricted Subsidiary, or
(2) if as a result of such Investment such Person is merged or
consolidated with or into, or transfers or conveys all or substantially all
its Property to, us or a Restricted Subsidiary;
(f) Investments in the form of securities received from Asset Sales,
provided that such Asset Sales are made in compliance within the provisions of
the Indenture described under "-- Certain Covenants -- Limitation on Asset
Sales;"
(g) Investments in negotiable instruments held for collection; lease,
utility and other similar deposits; and stock, obligations or other securities
received in settlement of debts (including under any bankruptcy or other similar
proceeding) owing to us or any of our Restricted Subsidiaries as a result of
foreclosure, perfection or enforcement of any Liens or Indebtedness, in each of
the foregoing cases in the ordinary course of business of Swift or such
Restricted Subsidiary;
(h) relocation allowances for, and advances and loans to, officers,
directors and employees of Swift or any of its Restricted Subsidiaries made in
the ordinary course of business, provided such items do not exceed in the
aggregate $2.0 million at any one time outstanding;
(i) Investments intended to promote our strategic objectives in the Oil and
Gas Business in an amount not to exceed 5% of Adjusted Consolidated Net Tangible
Assets (determined as of the date of the making of any such Investment) at any
one time outstanding, which Investments shall be deemed to be no longer
outstanding only to the extent of dividends, repayments of loans or advances or
other transfers of Property or returns of capital received by us or any
Restricted Subsidiary from such Persons, provided that, for purposes of the
covenant described under "-- Certain Covenants -- Limitation on Restricted
Payments" the receiving of such amounts by us or our Restricted Subsidiaries
does not increase the amount of Restricted Payments that Swift and our
Restricted Subsidiaries may make pursuant to clause (c)(5)(A) of such covenant;
(j) Investments made pursuant to Permitted Hedging Agreements of Swift and
its Restricted Subsidiaries; and
(k) Investments pursuant to any agreement or obligation of Swift or any of
its Restricted Subsidiaries as in effect on the Issue Date (other than
Investments described in clauses (a) through (j) above), provided that
Investments made pursuant to this clause (k) shall be included in the
calculation of Restricted Payments.
"Permitted Liens" means any and all of the following:
(a) Liens existing as of the Issue Date;
(b) Liens securing the Notes, any Subsidiary Guaranties and other
obligations arising under the Indenture;
(c) any Lien existing on any Property of a Person at the time such Person
is merged or consolidated with or into Swift or a Restricted Subsidiary or
becomes a Restricted Subsidiary (and not incurred in
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anticipation of or in connection with such transaction), provided that such
Liens are not extended to other Property of Swift or the Restricted
Subsidiaries;
(d) any Lien existing on any Property at the time of the acquisition
thereof (and not incurred in anticipation of or in connection with such
transaction), provided that such Lien is not extended to other Property of Swift
or the Restricted Subsidiaries;
(e) any Lien incurred in the ordinary course of business incidental to the
conduct of the business of Swift or the Restricted Subsidiaries or the ownership
of their Property, including:
(1) easements, rights of way and similar encumbrances,
(2) rights or title of lessors under leases (other than Capital Lease
Obligations),
(3) rights of collecting banks having rights of setoff, revocation,
refund or chargeback with respect to money or instruments of Swift or the
Restricted Subsidiaries on deposit with or in the possession of such banks,
(4) Liens imposed by law, including Liens under workers' compensation
or similar legislation and mechanics', carriers', warehousemen's,
materialmen's, suppliers' and vendors' Liens,
(5) Liens incurred to secure performance of obligations with respect
to statutory or regulatory requirements, performance or return-of-money
bonds, surety bonds or other obligations of a like nature and incurred in a
manner consistent with industry practice, and
(6) Oil and Gas Liens,
in each case that are not incurred in connection with the borrowing of
money, the obtaining of advances or credit or the payment of the deferred
purchase price of Property (other than Trade Accounts Payable);
(f) Liens for taxes, assessments and governmental charges not yet due or
the validity of which is being contested in good faith by appropriate
proceedings, promptly instituted and diligently conducted, and for which
adequate reserves have been established to the extent required by GAAP as in
effect at such time;
(g) Liens incurred to secure appeal bonds and judgment and attachment
Liens, in each case in connection with litigation or legal proceedings that are
being contested in good faith by appropriate proceedings so long as reserves
have been established to the extent required by GAAP as in effect at such time
and so long as such Liens do not encumber assets by an aggregate amount
(together with the amount of any unstayed judgments against us or any Restricted
Subsidiary but excluding any such Liens to the extent securing insured or
indemnified judgments or orders) in excess of $20.0 million;
(h) Liens securing Permitted Hedging Agreements of Swift and its Restricted
Subsidiaries;
(i) Liens securing Capital Lease Obligations, provided that such Capital
Lease Obligations are permitted under "-- Certain Covenants -- Limitation on
Indebtedness" and the Liens attach only to the Property acquired with the
proceeds of such Capital Lease Obligations;
(j) Liens securing Non-recourse Purchase Money Indebtedness granted in
connection with the acquisition by us or any Restricted Subsidiary in the
ordinary course of business of fixed assets used in the Oil and Gas Business
(including office buildings and other real property used by us or such
Subsidiary Guarantor in conducting its operations), provided that:
(1) such Liens attach only to the fixed assets acquired with the
proceeds of such Non-recourse Purchase Money Indebtedness, and
(2) such Non-recourse Purchase Money Indebtedness is not in excess of
the purchase price of such fixed assets;
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(k) Liens resulting from the deposit of funds or evidences of Indebtedness
in trust for the purpose of decreasing or legally defeasing Indebtedness of
Swift or any of its Subsidiaries so long as such deposit of funds is permitted
by the provisions of the Indenture described under "-- Limitation on Restricted
Payments";
(l) Liens resulting from a pledge of Capital Stock of a Person that is not
a Restricted Subsidiary to secure obligations of such Person and any
refinancings thereof;
(m) Liens to secure any permitted extension, renewal, refinancing,
refunding or exchange (or successive extensions, renewals, refinancings,
refundings or exchanges), in whole or in part, of or for any Indebtedness
secured by Liens referred to in clauses (a), (b), (c), (d), (i) and (j) above;
provided, however, that:
(1) such new Lien shall be limited to all or part of the same Property
(including future improvements thereon and accessions thereto) subject to
the original Lien, and
(2) the Indebtedness secured by such Lien at such time is not
increased to any amount greater than the sum of:
(A) the outstanding principal amount or, if greater, the committed
amount of the Indebtedness secured by such original Lien immediately
prior to such extension, renewal, refinancing, refunding or exchange,
and
(B) an amount necessary to pay any fees and expenses, including
premiums, related to such refinancing, refunding, extension, renewal or
replacement;
(n) Liens in favor of us or a Restricted Subsidiary; and
(o) Liens not otherwise permitted by clauses (a) through (n) above incurred
in the ordinary course of business of Swift and its Restricted Subsidiaries and
encumbering Property having an aggregate Fair Market Value not in excess of $5.0
million at any one time.
Notwithstanding anything in this paragraph to the contrary, the term "Permitted
Liens" does not include Liens resulting from the creation, incurrence, issuance,
assumption or Guarantee of any Production Payments and Reserve Sales other than:
(a) any such Liens existing as of the Issue Date;
(b) Production Payments and Reserve Sales in connection with the
acquisition of any Property after the Issue Date, provided that any such Lien
created in connection therewith is created, incurred, issued, assumed or
guaranteed in connection with the financing of, and within 60 days after the
acquisition of, such Property;
(c) Production Payments and Reserve Sales, other than those described in
clauses (a) and (b) of this sentence, to the extent such Production Payments and
Reserve Sales constitute Asset Sales made pursuant to and in compliance with the
provisions of the Indenture described under "-- Limitation on Asset Sales"; and
(d) incentive compensation programs for geologists, geophysicists and
other providers of technical services to us or a Restricted Subsidiary;
provided, however, that, in the case of the immediately foregoing clauses (a),
(b), (c) and (d), any Lien created in connection with any such Production
Payments and Reserve Sales shall be limited to the Property that is the subject
of such Production Payments and Reserve Sales.
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"Permitted Refinancing Indebtedness" means Indebtedness ("new
Indebtedness"), Incurred in exchange for, or proceeds of which are used to
refinance, other Indebtedness ("old Indebtedness"); provided, however, that:
(a) such new Indebtedness is in an aggregate principal amount not in
excess of the sum of:
(1) the aggregate principal amount then outstanding of the old
Indebtedness (or, if such old Indebtedness provides for an amount less
than the principal amount thereof to be due and payable upon a
declaration of acceleration thereof, such lesser amount as of the date
of determination), and
(2) an amount necessary to pay any fees and expenses, including
premiums, related to such exchange or refinancing;
(b) such new Indebtedness has a Stated Maturity no earlier than the
Stated Maturity of the old Indebtedness;
(c) such new Indebtedness has an Average Life at the time such new
Indebtedness is Incurred that is equal to or greater than the Average
Life of the old Indebtedness at such time;
(d) such new Indebtedness is subordinated in right of payment to
the Notes (or, if applicable, the Subsidiary Guaranties) to at least the
same extent, if any, as the old Indebtedness; and
(e) if such old Indebtedness is Non-recourse Purchase Money
Indebtedness or Indebtedness that refinanced Non-recourse Purchase Money
Indebtedness, such new Indebtedness satisfies clauses (a) and (b) of the
definition of "Non-recourse Purchase Money Indebtedness."
"Permitted Short-Term Investments" means:
(a) Investments in U.S. Government Obligations maturing within one
year of the date of acquisition thereof;
(b) Investments in demand accounts, time deposit accounts,
certificates of deposit, bankers' acceptances and money market deposits
maturing within one year of the date of acquisition thereof issued by a
bank or trust company that is organized under the laws of the United States
of America or any State thereof or the District of Columbia that is a
member of the Federal Reserve System having capital, surplus and undivided
profits aggregating in excess of $500.0 million and whose long-term
Indebtedness is rated "A" (or higher) according to Moody's;
(c) Investments in deposits available for withdrawal on demand with
any commercial bank that is organized under the laws of any country in
which we or any Restricted Subsidiary maintains an office or is engaged in
the Oil and Gas Business, provided that:
(1) all such deposits have been made in such accounts in the ordinary
course of business, and
(2) such deposits do not at any one time exceed $15.0 million in the
aggregate;
(d) repurchase and reverse repurchase obligations with a term of not more
than seven days for underlying securities of the types described in clause (a)
entered into with a bank meeting the qualifications described in clause (b);
(e) Investments in commercial paper or notes, maturing not more than one
year after the date of acquisition, issued by a corporation (other than an
Affiliate of Swift) organized and in existence under the laws of the United
States of America or any State thereof or the District of Columbia with a
short-term rating at the time as of which any Investment therein is made of
"P-1" (or higher) according to Moody's or "A-1" (or higher) according to S&P or
a long-term rating at the time as of which any Investment is made of "A3" (or
higher) according to Moody's or "A-" (or higher) according to S&P;
(f) Investments in any money market mutual fund having assets in excess of
$250.0 million all of which consist of other obligations of the types described
in clauses (a), (b), (d) and (e) hereof; and
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(g) Investments in asset-backed securities maturing within one year of the
date of acquisition thereof with a long-term rating at the time as of which any
Investment therein is made of "A3" (or higher) according to Moody's or "A-" (or
higher) according to S&P.
"Person" means any individual, corporation, partnership, joint venture,
limited liability company, unlimited liability company, trust, estate,
unincorporated organization or government or any agency or political subdivision
thereof.
"Preferred Stock" of any Person means Capital Stock of such Person of any
class or classes (however designated) that ranks prior, as to the payment of
dividends or as to the distribution of assets upon any voluntary or involuntary
liquidation, dissolution or winding up of such Person, to shares of Capital
Stock of any other class of such Person.
"Preferred Stock Dividends" means all dividends with respect to Preferred
Stock of Restricted Subsidiaries held by Persons other than Swift or a Wholly
Owned Subsidiary. The amount of any such dividend shall be equal to the quotient
of such dividend divided by the difference between one and the maximum statutory
federal income rate (expressed as a decimal number between 1 and 0) then
applicable to the issuer of such Preferred Stock.
"Principal" of any Indebtedness (including the Notes) means the principal
amount of such Indebtedness plus the premium, if any, on such Indebtedness.
"Production Payments and Reserve Sales" means the grant or transfer by us
or a Restricted Subsidiary to any Person of a royalty, overriding royalty, net
profits interest, production payment (whether volumetric or dollar denominated),
partnership or other interest in oil and gas properties, reserves or the right
to receive all or a portion of the production or the proceeds from the sale of
production attributable to such properties where the holder of such interest has
recourse solely to such production or proceeds of production, subject to the
obligation of the grantor or transferor to operate and maintain, or cause the
subject interests to be operated and maintained, in a reasonably prudent manner
or other customary standard or subject to the obligation of the grantor or
transferor to indemnify for environmental, title or other matters customary in
the Oil and Gas Business, including any such grants or transfers pursuant to
incentive compensation programs on terms that are reasonably customary in the
Oil and Gas Business for geologists, geophysicists and other providers of
technical services to us or a Restricted Subsidiary.
"Property" means, with respect to any Person, any interest of such Person
in any kind of property or asset, whether real, personal, or mixed, or tangible
or intangible, including Capital Stock and other securities issued by any other
Person (but excluding Capital Stock or other securities issued by such first
mentioned Person).
"Representative" means the trustee, agent or representative expressly
authorized to act in such capacity, if any, for an issue of Senior Indebtedness.
"Restricted Payment" means:
(a) a dividend or other distribution declared or paid on the Capital Stock
of Swift or to our shareholders (other than dividends, distributions or payments
made solely in Capital Stock (other than Disqualified Stock of Swift) of Swift
or in options, warrants or other rights to purchase or acquire Capital Stock
(other than Disqualified Stock)), or declared and paid to any Person other than
Swift or any of its Restricted Subsidiaries (and, if such Restricted Subsidiary
is not a Wholly Owned Subsidiary, to the other shareholders of such Restricted
Subsidiary on a pro rata basis or on a basis that results in the receipt by us
or a Restricted Subsidiary of dividends or distributions of greater value than
it would receive on a pro rata basis) on the Capital Stock of any Restricted
Subsidiary;
(b) a payment made by us or any of our Restricted Subsidiaries (other than
to us or any Restricted Subsidiary) to purchase, redeem, acquire or retire any
Capital Stock, or any options, warrants or other rights to acquire Capital
Stock, of Swift or of a Restricted Subsidiary;
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(c) a payment made by us or any of our Restricted Subsidiaries to redeem,
repurchase, legally defease or otherwise acquire or retire for value (including
pursuant to mandatory repurchase covenants), prior to any scheduled maturity,
scheduled sinking fund or scheduled mandatory redemption, any Indebtedness of
Swift or a Restricted Subsidiary that is subordinate (whether pursuant to its
terms or by operation of law) in right of payment to the Notes or the relevant
Subsidiary Guaranty, as the case may be, provided that this clause (c) shall not
include any such payment with respect to:
(1) any such subordinated Indebtedness to the extent of Excess
Proceeds remaining after compliance with the provisions of the Indenture
described under "-- Certain Covenants -- Limitation on Asset Sales" and to
the extent required by the Indenture or other agreement or instrument
pursuant to which such subordinated Indebtedness was issued, or
(2) the purchase, repurchase or other acquisition of any such
subordinated Indebtedness purchased in anticipation of satisfying a
scheduled maturity, scheduled sinking fund or scheduled mandatory
redemption, in each case due within one year of the date of acquisition; or
(d) an Investment (other than a Permitted Investment) by us or a Restricted
Subsidiary in any Person.
"Restricted Subsidiary" means any Subsidiary of Swift that has not been
designated an Unrestricted Subsidiary pursuant to the provision of the Indenture
described under "-- Certain Covenants -- Restricted and Unrestricted
Subsidiaries."
"S&P" means Standard & Poor's Ratings Services, a division of The
McGraw-Hill Companies, Inc., and its successors.
"Sale and Leaseback Transaction" means, with respect to any Person, any
direct or indirect arrangement (excluding, however, any such arrangement between
such Person and a Wholly Owned Subsidiary of such Person or between one or more
Wholly Owned Subsidiaries of such Person) pursuant to which Property is sold or
transferred by such Person or a Restricted Subsidiary of such Person and is
thereafter leased back from the purchaser or transferee thereof by such Person
or one of its Restricted Subsidiaries.
"Senior Indebtedness" when used with respect to us means our obligations
with respect to Indebtedness of Swift, whether outstanding on the date of the
Indenture or thereafter Incurred, and any renewal, refunding, refinancing,
replacement or extension thereof, unless, in the case of any particular
Indebtedness, the instrument creating or evidencing the same or pursuant to
which the same is outstanding expressly provides that such Indebtedness shall
not be senior in right of payment to the Notes; provided, however, that Senior
Indebtedness of Swift shall not include:
(a) Indebtedness of Swift to a Subsidiary of Swift;
(b) Indebtedness Incurred in violation of the Indenture;
(c) amounts payable or any other Indebtedness to employees of Swift or any
Subsidiary of Swift;
(d) any Indebtedness of Swift that, when Incurred and without regard to any
election under Section 1111(b) of the United States Bankruptcy Code, was without
recourse to us;
(e) Pari Passu or Subordinated Indebtedness of Swift;
(f) obligations with respect to any Capital Stock of Swift;
(g) Indebtedness evidenced by the Notes; and
(h) in-kind obligations relating to net oil and gas balancing positions.
"Senior Indebtedness" of any Subsidiary Guarantor has a correlative
meaning.
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"Significant Subsidiary" means, at any date of determination, any
Restricted Subsidiary that would be a "Significant Subsidiary" of Swift within
the meaning of Rule 1-02 under Regulation S-X promulgated by the Commission.
"Stated Maturity" when used with respect to any security or any installment
of principal thereof or interest thereon, means the date specified in such
security as the fixed date on which the principal of such security or such
installment of principal or interest is due and payable, including pursuant to
any mandatory redemption provision (but excluding any provision providing for
the repurchase of such security at the option of the holder thereof upon the
happening of any contingency unless such contingency has occurred).
"Subordinated Indebtedness" means Indebtedness of Swift (or a Subsidiary
Guarantor) that is subordinated or junior in right of payment to the Notes (or a
Subsidiary Guaranty, as appropriate) pursuant to a written agreement to that
effect.
"Subsidiary" of a Person means:
(a) another Person that is a corporation a majority of whose Voting Stock
is at the time, directly or indirectly, owned or controlled by:
(1) the first Person,
(2) the first Person and one or more of its Subsidiaries, or
(3) one or more of the first Person's Subsidiaries; or
(b) another Person that is not a corporation (x) at least 50% of the
Capital Stock of which, and (y) the power to elect or direct the election of a
majority of the directors or other governing body of which are controlled by
Persons referred to in clause (1), (2) or (3) above.
"Subsidiary Guarantors" means, unless released from their Subsidiary
Guaranties as permitted by the Indenture, any Restricted Subsidiary that becomes
a guarantor of the Notes in compliance with the provisions of the Indenture and
executes a supplemental indenture agreeing to be bound by the terms of the
Indenture.
"Subsidiary Guaranty" means an unconditional senior subordinated guaranty
of the Notes given by any Restricted Subsidiary pursuant to the terms of the
Indenture.
"Trade Accounts Payable" means accounts payable or other obligations of
Swift or any Restricted Subsidiary to trade creditors created or assumed by us
or such Restricted Subsidiary in the ordinary course of business in connection
with the obtaining of goods or services.
"Unrestricted Subsidiary" means:
(a) each Subsidiary of Swift that we have designated pursuant to the
provisions of the Indenture described under "-- Certain Covenants
-- Restricted and Unrestricted Subsidiaries" as an Unrestricted
Subsidiary; and
(b) any Subsidiary of an Unrestricted Subsidiary.
"U.S. Government Obligations" means securities that are:
(a) direct obligations of the United States of America for the timely
payment of which its full faith and credit is pledged; or
(b) obligations of a Person controlled or supervised by and acting as
an agency or instrumentality of the United States of America, the timely
payment of which is unconditionally guaranteed as a full faith and credit
obligation by the United States of America
that, in either case, are not callable or redeemable at the option of the issuer
thereof, and shall also include a depository receipt issued by a bank (as
defined in Section 3(a)(2) of the Securities Act), as custodian, with respect to
any such U.S. Government Obligation or a specific payment of principal of or
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interest on any such U.S. Government Obligation held by such custodian for the
account of the holder of such depository receipt; provided, however, that
(except as required by law) such custodian is not authorized to make any
deduction from the amount payable to the holder of such depository receipt from
any amount received by the custodian in respect of the U.S. Government
Obligation or the specific payment or principal of or interest on the U.S.
Government Obligation evidenced by such depository receipt.
"Volumetric Production Payments" means production payment obligations
recorded as deferred revenue in accordance with GAAP, together with all
undertakings and obligations in connection therewith.
"Voting Stock" of any Person means Capital Stock of such Person that
ordinarily has voting power for the election of directors (or persons performing
similar functions) of such Person whether at all times or only so long as no
senior class of securities has such voting power by reason of any contingency.
"Wholly Owned Subsidiary" means, at any time, a Restricted Subsidiary of
Swift all the Voting Stock of which (other than directors' qualifying shares) is
at such time owned, directly or indirectly, by us and our other Wholly Owned
Subsidiaries.
DEFEASANCE AND COVENANT DEFEASANCE
The Indenture provides that we will, at our election at any time, be
discharged from our obligations with respect to the Notes ("Legal Defeasance")
except for certain obligations to:
(a) exchange or register the transfer of Notes;
(b) to replace stolen, lost or mutilated Notes;
(c) to maintain paying agencies; and
(d) to hold moneys for payment in trust.
In addition, the Indenture provides that if we take the actions described below,
we may omit to comply with certain covenants, including those described under
"-- Repurchase at the Option of Holders Upon a Change of Control," "-- Certain
Covenants" and in clauses (d) and (e) under the first paragraph of "-- Merger,
Consolidation and Sale of Substantially All Assets." Additionally, the
occurrence of the Events of Default described below in clauses (c) and (d) (with
respect to such covenants) and clauses (e), (f), (g) (with respect to
Significant Subsidiaries) and (h) under "-- Events of Default and Notice" will
be deemed not to be or result in an Event of Default.
Such Legal Defeasance and Covenant Defeasance may occur only if, among
other things, we:
(a) deposit in trust for the benefit of the Holders of the Notes, money or
U.S. Government Obligations, or a combination thereof, that, through the payment
of principal, premium, if any, and interest in respect thereof in accordance
with their terms, will provide money in an amount sufficient to pay the
principal of and any premium and interest on the Notes at the Stated Maturity
thereof or on earlier redemption in accordance with the terms of the Indenture
and the Notes; and
(b) in the case of Legal Defeasance, deliver to the Trustee an Opinion of
Counsel
(1) to the effect that:
(A) we have received from, or there has been published by, the
United States Internal Revenue Service a ruling, or
(B) since the date of the Indenture there has been a change in the
applicable federal income tax law,
in either case to the effect that Holders of the Notes will not
recognize gain or loss for federal income tax purposes as a result of
such deposit, defeasance and discharge and will be subject to federal
income tax on the same amount, in the same manner and at the same times
as would have been the case if such deposit, defeasance and discharge
were not to occur, and
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(2) that the resulting trust will not be an "Investment Company"
within the meaning of the Investment Company Act of 1940 unless such trust
is qualified thereunder or exempt from regulation thereunder; or
(c) in the case of Covenant Defeasance, deliver to the Trustee on Opinion
of Counsel to the effect that:
(1) Holders of the Notes will not recognize gain or loss for federal
income tax purposes as a result of such deposit and defeasance of certain
obligations and will be subject to federal income tax on the same amount,
in the same manner and at the same times as would have been the case if
such deposit and defeasance were not to occur, and
(2) that the resulting trust will not be an "Investment Company"
within the meaning of the Investment Company Act of 1940 unless such trust
is qualified thereunder or exempt from regulation thereunder.
If we were to exercise this option and the Notes were declared due and
payable because of the occurrence of any Event of Default, the amount of money
and U.S. Government Obligations so deposited in trust would be sufficient to pay
amounts due on the Notes at the time of their Stated Maturity but may not be
sufficient to pay amounts due on the Notes upon any acceleration resulting from
such Event of Default. In such case, we would remain liable for such payments.
If we exercise either of the options described above, each Subsidiary
Guarantor, if any, will be released from all its obligations under its
Subsidiary Guaranty.
EVENTS OF DEFAULT AND NOTICE
The following are summaries of Events of Default under the Indenture with
respect to the Notes:
(a) failure to pay any interest on the Notes when due, continued for 30
days;
(b) failure to pay principal of (or premium, if any, on) the Notes when
due;
(c) failure to comply with the provisions of the Indenture described under
"Merger, Consolidation and Sale of Substantially All Assets";
(d) failure to perform any other covenant of Swift or any Subsidiary
Guarantor in the Indenture, continued for 30 days after written notice to us
from the Trustee or the Holders of at least 25% in aggregate principal amount of
the outstanding Notes;
(e) a default by us or any Restricted Subsidiary under any Indebtedness for
borrowed money in an aggregate amount greater than $5.0 million (other than
Non-recourse Purchase Money Indebtedness) that results in acceleration of the
maturity of such Indebtedness, or failure to pay any such Indebtedness at
maturity, if such Indebtedness is not discharged or such acceleration is not
rescinded or annulled within 10 days after written notice as provided in the
Indenture;
(f) one or more final judgments or orders by a court of competent
jurisdiction are entered against us or any Restricted Subsidiary in an uninsured
or unindemnified aggregate amount outstanding at any time in excess of $5.0
million and such judgments or orders are not discharged, waived, stayed,
satisfied or bonded for a period of 60 consecutive days;
(g) certain events of bankruptcy, insolvency or reorganization with respect
to Swift or any Significant Subsidiary; or
(h) a Subsidiary Guaranty ceases to be in full force and effect (other than
in accordance with the terms of the Indenture and such Subsidiary Guaranty) or a
Subsidiary Guarantor denies or disaffirms its obligations under its Subsidiary
Guaranty.
The Indenture provides that if an Event of Default (other than an Event of
Default described in clause (g) above) with respect to the Notes at the time
outstanding shall occur and be continuing, either
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the Trustee or the Holders of at least 25% in aggregate principal amount of the
outstanding Notes by notice as provided in the Indenture may declare the
principal amount of the Notes to be due and payable immediately. If an Event of
Default described in clause (g) above with respect to the Notes at the time
outstanding shall occur, the principal amount of all the Notes will
automatically, and without any action by the Trustee or any Holder, become
immediately due and payable. After any such acceleration, but before a judgment
or decree based on acceleration, the Holders of at least a majority in aggregate
principal amount of the outstanding Notes may, under certain circumstances,
rescind and annul such acceleration if all Events of Default, other than the
nonpayment of accelerated principal, have been cured or waived as provided in
the Indenture.
Subject to the provisions of the Indenture relating to the duties of the
Trustee, in case an Event of Default shall occur and be continuing, the Trustee
will be under no obligation to exercise any of its rights or powers under the
Indenture at the request or direction of any of the Holders of the Notes, unless
such Holders shall have offered to the Trustee reasonable indemnity. Subject to
such provisions for the indemnification of the Trustee, the Holders of at least
a majority in aggregate principal amount of the outstanding Notes will have the
right to direct the time, method and place of conducting any proceeding for any
remedy available to the Trustee or exercising any trust or power conferred on
the Trustee with respect to the Notes.
No Holder of Notes will have any right to institute any proceeding with
respect to the Indenture, or for the appointment of a receiver or a trustee, or
for any other remedy thereunder, unless:
(a) such Holder has previously given to the Trustee written notice of a
continuing Event of Default with respect to the Notes;
(b) the Holders of at least 25% in aggregate principal amount of the
outstanding Notes have made written request, and such Holder or Holders have
offered reasonable indemnity, to the Trustee to institute such proceeding as
trustee; and
(c) the Trustee has failed to institute such proceeding and has not
received from the Holders of at least a majority in aggregate principal amount
of the outstanding Notes a direction inconsistent with such request, within 60
days after such notice, request and offer.
However, such limitations do not apply to a suit instituted by a Holder of Notes
for the enforcement of payment of the principal of or any premium or interest on
such Notes on or after the applicable due date specified in such Notes.
MODIFICATION OF THE INDENTURE; WAIVER
The Indenture provides that modifications and amendments of the Indenture
may be made by us, any Subsidiary Guarantors and the Trustee without the consent
of any Holders of Notes in certain limited circumstances, including:
(a) to cure any ambiguity, omission, defect or inconsistency;
(b) to provide for the assumption of the obligations of Swift under the
Indenture upon the merger, consolidation or sale or other disposition of all or
substantially all the Property of Swift and the Restricted Subsidiaries taken as
a whole and certain other events specified in the provisions of the Indenture
described under "Merger, Consolidation and Sale of Substantially All Assets";
(c) to provide for uncertificated Notes in addition to or in place of
certificated Notes;
(d) to comply with any requirement of the SEC in order to effect or
maintain the qualification of the Indenture under the Trust Indenture Act;
(e) to make any change that does not adversely affect the rights of any
Holder of Notes in any material respect;
(f) to add or remove Subsidiary Guarantors pursuant to the procedure set
forth in the Indenture; and
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(g) certain other modifications and amendments as set forth in the
Indenture.
The Indenture contains provisions permitting us, any Subsidiary Guarantors
and the Trustee with the written consent of the Holders of not less than a
majority in aggregate principal amount of the outstanding Notes, to execute
supplemental indentures or amendments adding any provisions to or changing or
eliminating any of the provisions of the Indenture or modifying the rights of
the Holders of the Notes, except that no such supplemental indenture, amendment
or waiver may, without the consent of all the Holders of outstanding Notes,
among other things:
(a) reduce the principal amount of Notes whose Holders must consent to an
amendment or waiver;
(b) reduce the rate of or change the time for payment of interest on any
Notes;
(c) change the currency in which any amount due in respect of the Notes is
payable;
(d) reduce the principal of or any premium on or change the Stated Maturity
of any Notes or alter the redemption provisions with respect thereto;
(e) reduce the relative ranking of any Notes;
(f) release any security that may have been granted to the Trustee in
respect of the Notes;
(g) at any time after a Change of Control has occurred, change the
repurchase price or the time at which the Change of Control Offer relating
thereto must be made or at which the Notes must be repurchased pursuant to such
Change of Control Offer; or
(h) make certain other significant amendments or modifications as specified
in the Indenture.
The Holders of at least a majority in aggregate principal amount of the
outstanding Notes may waive compliance by Swift with certain restrictive
provisions of the Indenture. The Holders of at least a majority in aggregate
principal amount of the outstanding Notes may waive any past default under the
Indenture, except a default in the payment of principal, premium or interest and
certain covenants and provisions of the Indenture that cannot be amended without
the consent of the Holders of each outstanding Note.
No amendment may be made to the subordination provisions of the Indenture
that adversely affects the rights of any holder of Senior Indebtedness then
outstanding unless the holders of such Senior Indebtedness (or their
Representative) consent to such change. The consent of the Holders of the Notes
is not necessary under the Indenture to approve the particular form of any
proposed amendment. It is sufficient if such consent approves the substance of
the proposed amendment. After an amendment under the Indenture becomes
effective, we are required to mail to each registered Holder of the Notes at
such Holder's address appearing in the Security Register a notice briefly
describing such amendment. However, the failure to give such notice to all
Holders of the Notes, or any defect therein, will not impair or affect the
validity of the amendment.
NOTICES
Notices to Holders of the Notes will be given by mail to the addresses of
such Holders as they may appear in the Security Register.
GOVERNING LAW
The Indenture and the Notes are governed by and construed in accordance
with the laws of the State of New York.
TRUSTEE
Bank One, NA is the Trustee under the Indenture. It is also the trustee
under the indenture for the 2009 Notes. Bank One, NA maintains normal banking
relationships with us and our Subsidiaries and may perform certain services and
transact other business with us and our Subsidiaries from time to time in the
ordinary course of business. In accordance with the Trust Indenture Act, should
a default occur with
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respect to either the Notes or the 2009 Notes, Bank One, NA would be required to
resign as trustee under one of the two indentures within 90 days of the default
unless the default were cured, waived or otherwise eliminated.
BOOK-ENTRY SYSTEM
The Notes will be initially issued in the form of one or more Global
Securities registered in the name of The Depository Trust Company ("DTC") or its
nominee.
Upon the issuance of a Global Security, DTC will credit the accounts of
Persons holding through it with the respective principal amounts of the Notes
represented by such Global Security purchased by such Persons in this offering
of the Notes. Such accounts shall be designated by the underwriters of the
Offered Notes. Ownership of beneficial interests in a Global Security will be
limited to Persons that have accounts with DTC ("participants") or Persons that
may hold interests through participants. Ownership of beneficial interests in a
Global Security will be shown on, and the transfer of that ownership interest
will be effected only through, records maintained by DTC (with respect to
participants' interests) and such participants (with respect to the owners of
beneficial interests in such Global Security other than participants). The laws
of some jurisdictions require that certain purchasers of securities take
physical delivery of such securities in definitive form. Such limits and such
laws may impair the ability to transfer beneficial interests in a Global
Security.
Payment of principal of and interest on Notes represented by a Global
Security will be made in immediately available funds to DTC or its nominee, as
the case may be, as the sole registered owner and the sole holder of the Notes
represented thereby for all purposes under the Indenture. We have been advised
by DTC that upon receipt of any payment of principal of or interest on any
Global Security, DTC will immediately credit, on its book-entry registration and
transfer system, the accounts of participants with payments in amounts
proportionate to their respective beneficial interests in the principal or face
amount of such Global Security as shown on the records of DTC. Payments by
participants to owners of beneficial interests in a Global Security held through
such participants will be governed by standing instructions and customary
practices as is now the case with securities held for customer accounts
registered in "street name" and will be the sole responsibility of such
participants.
A Global Security may not be transferred except as a whole by DTC or a
nominee of DTC to a nominee of DTC or to DTC. A Global Security is exchangeable
for certificated Notes only if:
(a) DTC notifies us that it is unwilling or unable to continue as a
depositary for such Global Security or if at any time DTC ceases to be a
clearing agency registered under the Exchange Act;
(b) we in our discretion at any time determine not to have all the Notes
represented by such Global Security; or
(c) a Default or an Event of Default with respect to the Notes represented
by such Global Security occurs, and DTC requests the Trustee and us to effect
such an exchange.
Any Global Security that is exchangeable for certificated Notes pursuant to
the preceding sentence will be exchanged for certificated Notes in authorized
denominations and registered in such names as DTC or any successor depositary
holding such Global Security may direct. Subject to the foregoing, a Global
Security is not exchangeable, except for a Global Security of like denomination
to be registered in the name of DTC or any successor depositary or its nominee.
In the event that a Global Security becomes exchangeable for certificated Notes,
(a) certificated Notes will be issued only in fully registered form in
denominations of $1,000 or integral multiples thereof,
(b) payment of principal of, and premium, if any, and interest on, the
certificated Notes will be payable, and the transfer of the certificated Notes
will be registerable, at the office or agency of Swift maintained for such
purposes, and
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(c) no service charge will be made for any registration of transfer or
exchange of the certificated Notes, although we may require payment of a sum
sufficient to cover any tax or governmental charge imposed in connection
therewith.
So long as DTC or any successor depositary for a Global Security, or any
nominee, is the registered owner of such Global Security, DTC or such successor
depositary or nominee, as the case may be, will be considered the sole owner or
holder of the Notes represented by such Global Security for all purposes under
the Indenture and the Notes. Except as set forth above, owners of beneficial
interests in a Global Security will not be entitled to have the Notes
represented by such Global Security registered in their names, will not receive
or be entitled to receive physical delivery of certificated Notes in definitive
form and will not be considered to be the owners or holders of any Notes under
such Global Security. Accordingly, each Person owning a beneficial interest in a
Global Security must rely on the procedures of DTC or any successor depositary,
and, if such Person is not a participant, on the procedures of the participant
through which such Person owns its interest, to exercise any rights of a Holder
under the Indenture. We understand that under existing industry practices, in
the event that we request any action of Holders or that an owner of a beneficial
interest in a Global Security desires to give or take any action that a Holder
is entitled to give or take under the Indenture, DTC would authorize the
participants holding the relevant beneficial interest to give or take such
action and such participants would authorize beneficial owners owning through
such participants to give or take such action or would otherwise act upon the
instructions of beneficial owners owning through them.
DTC has advised us that DTC is a limited-purpose trust company organized
under the Banking Law of the State of New York, a member of the Federal Reserve
System, a "clearing corporation" within the meaning of the New York Uniform
Commercial Code and a "clearing agency" registered under the Exchange Act. DTC
was created to hold the securities of its participants and to facilitate the
clearance and settlement of securities transactions among its participants in
such securities through electronic book-entry changes in accounts of the
participants, thereby eliminating the need for physical movement of securities
certificates. DTC's participants include securities brokers and dealers (which
may include the underwriters of the Offered Notes), banks, trust companies,
clearing corporations and certain other organizations some of whom (or their
representatives) own DTC. Access to DTC'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.
Although DTC has agreed to the foregoing procedures in order to facilitate
transfers of interests in Global Securities among participants of DTC, it is
under no obligation to perform or continue to perform such procedures, and such
procedures may be discontinued at any time. None of Swift, the Trustee or the
underwriters of the Offered Notes will have any responsibility for the
performance by DTC or its participants or indirect participants of their
respective obligations under the rules and procedures governing their
operations.
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CERTAIN U.S. FEDERAL INCOME TAX CONSIDERATIONS
The following is a summary of certain U.S. federal income tax consequences
of the purchase, ownership and disposition of the notes to initial purchasers of
the notes who are U.S. Holders (as defined below) and certain U.S. federal
income and estate tax consequences of the purchase, ownership and disposition of
the notes to initial purchasers who are Non-U.S. Holders (as defined below).
This discussion is based on currently existing provisions of the Internal
Revenue Code of 1986, as amended (the "Code"), existing, temporary and proposed
Treasury regulations promulgated thereunder, and administrative and judicial
interpretations thereof, all as in effect or proposed on the date hereof and all
of which are subject to change, possibly with retroactive effect, or different
interpretations. This discussion does not address the U.S. federal income tax
consequences to subsequent purchasers of notes, and is limited to initial
purchasers who purchase the notes at the public offering price to investors set
forth on the cover page of this prospectus supplement who hold the notes as
capital assets, within the meaning of section 1221 of the Code. Moreover, this
discussion is for general information only and does not address all of the tax
consequences that may be relevant to particular initial purchasers in light of
their personal circumstances or to certain types of initial purchasers (such as
persons having a functional currency other than the U.S. dollar, persons subject
to special rules applicable to former citizens and residents of the U.S.,
persons subject to the alternative minimum tax, grantor trusts, real estate
investment trusts, certain financial institutions, insurance companies,
tax-exempt entities, dealers in securities or currencies or persons holding the
notes in connection with a hedging transaction, straddle, conversion transaction
or other integrated transaction, corporations treated as foreign or domestic
personal holding companies, controlled foreign corporations, passive foreign
investment companies or Non-U.S. Holders that are owned or controlled by U.S.
Holders).
Jenkens & Gilchrist, a Professional Corporation, has reviewed the
discussion below and is of the opinion that the discussion fairly summarizes the
U.S. federal income tax consequences of the purchase, ownership and disposition
of the notes that are likely to be material to an initial purchaser who is a
U.S. Holder and who acquires the notes at their initial issue price and certain
U.S. federal income and estate tax consequences of the purchase, ownership and
disposition of the notes by a Non-U.S. Holder who acquires the notes in the
initial issue at their initial issue price. The opinion is based on various
assumptions, including assumptions regarding the accuracy of factual
representations made by Swift and is subject to limitations. Their opinion is
not binding on the Internal Revenue Service or any court. The Internal Revenue
Service may challenge part or all of their opinion and such a challenge could be
successful.
PROSPECTIVE HOLDERS ARE URGED TO CONSULT THEIR OWN TAX ADVISORS AS TO THE
PARTICULAR TAX CONSEQUENCES TO THEM OF THEIR PARTICIPATION IN THE OFFERING AND
THEIR OWNERSHIP, EXCHANGE AND DISPOSITION OF THE NOTES, INCLUDING THE
APPLICABILITY OF ANY U.S. FEDERAL TAX LAWS OR ANY STATE, LOCAL OR FOREIGN TAX
LAWS OR UNDER AN APPLICABLE TAX TREATY, AND ANY CHANGES (OR PROPOSED CHANGES) IN
APPLICABLE TAX LAWS OR INTERPRETATIONS THEREOF.
U.S. FEDERAL INCOME TAXATION OF U.S. HOLDERS
As used herein, the term "U.S. Holder" means a holder of a note that is,
for U.S. federal income tax purposes:
- a citizen or resident of the U.S.;
- a corporation or other entity created or organized in or under the laws
of the U.S. or any political subdivision thereof;
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- an estate whose income is includible in gross income for U.S. federal
income tax purposes, regardless of its source; or
- a trust:
(i) whose administration is subject to the primary supervision of a
U.S. court and which has one or more U.S. persons who have the authority to
control all substantial decisions of the trust; or
(ii) that has a valid election in effect under applicable Treasury
regulations to be treated as a U.S. person.
If a partnership holds notes, the tax treatment of a partner will generally
depend upon the status of the partner and upon the activities of the
partnership. Partners of partnerships that are prospective holders of the notes
are urged to consult their own tax advisors.
Interest on the Notes
The notes pay interest at a stated rate of nine and three-eighths percent
(9 3/8%). The stated interest paid on the notes is qualified stated interest and
a U.S. Holder will be required to include interest on each note in his, her or
its income in accordance with the U.S. Holder's method of accounting for U.S.
federal income tax purposes.
Effect of Repurchase or Optional Redemption on Original Issue Discount
The U.S. Holders of notes have the right to require Swift to repurchase all
or any part of such holder's notes upon a Change of Control. See "Description of
the Notes -- Repurchase at the Option of Holders Upon a Change of Control."
Under applicable Treasury regulations, computation of the yield-to-maturity of a
debt instrument is not affected by these repurchase rights and obligations if,
based on all facts and circumstances as of the issue date, there is a remote
likelihood that a Change of Control will occur. Swift also has the right to
redeem all of the notes after May 1, 2007 and may redeem up to 33 1/3% of the
aggregate principal amount of the notes originally issued with the net proceeds
of one or more Equity Offerings prior to May 1, 2005. See "Description of the
Notes -- Optional Redemption". Under applicable Treasury regulations, solely for
the purpose of computing original issue discount, Swift will be assumed to
exercise any unconditional option to redeem a debt instrument if such exercise
will lower the yield-to-maturity of the debt instrument. Swift does not intend,
on the issuance date, to treat the repurchase and optional redemption provisions
described in this paragraph as affecting the computation of yield-to-maturity of
the notes. Accordingly, Swift intends to take the position (which generally will
be binding on a U.S. Holder unless the U.S. Holder explicitly discloses a
different position on his, her or its timely filed U.S. federal income tax
return) that the notes are not issued with original issue discount. The Internal
Revenue Service may or may not agree with this conclusion. If the notes were
issued with original issue discount, the U.S. Holder would be required to accrue
such original issue discount commencing with the date of purchase, on a constant
accrual basis, regardless of such holder's method of accounting for U.S. federal
income tax purposes.
Future events described herein could cause the notes to be treated, for
original issue discount purposes, as retired and then reissued on the date of
the change in circumstances for an amount equal to the note's adjusted issue
price on that date. U.S. Holders should consult their own tax advisors regarding
the potential effect, if any, of these events on their particular situation.
Sale, Disposition or Retirement
Upon the sale, retirement at maturity or other taxable disposition of a
note, a U.S. Holder generally will recognize taxable gain or loss equal to the
difference between the sum of cash plus the fair market value of all other
property received on such disposition (except to the extent such cash or
property is attributable to accrued but unpaid interest, which will be taxable
as ordinary income) and such U.S. Holder's adjusted tax basis in the note. A
U.S. Holder's adjusted tax basis in a note generally will
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equal the cost of the note to such U.S. Holder, less any principal payments or
other payments that are not qualified stated interest received by such U.S.
Holder. Gain or loss recognized on the disposition of a note generally will be
capital gain or loss and will be long-term capital gain or loss if, at the time
of such disposition, the U.S. Holder's holding period for the note is more than
one year. The deductibility of capital losses by a U.S. Holder is subject to
limitations.
Backup Withholding and Information Reporting
Information reporting requirements generally will apply to certain payments
of principal and interest made by Swift on, or the proceeds of the sale or other
disposition prior to maturity of, the notes. Backup withholding tax may apply to
these payments if the U.S. Holder fails to:
- furnish his, her or its taxpayer identification number (social security
or employer identification number);
- certify that his, her or its number is correct;
- certify that he, she or it is not subject to backup withholding; or
- otherwise comply with the applicable requirements of the backup
withholding rules.
Certain U.S. Holders, including all corporations, are not subject to backup
withholding and information reporting requirements. Any amounts withheld under
the backup withholding rules from a payment to a U.S. Holder will be allowed as
a credit against that U.S. Holder's U.S. federal income tax liability and may
entitle the holder to a refund, provided that the required information is timely
furnished to the Internal Revenue Service. The back withholding rate is 30% for
years 2002 and 2003, but is scheduled to be reduced to 29% for years 2004 and
2005, and 28% for 2006 and thereafter.
U.S. FEDERAL INCOME TAXATION OF NON-U.S. HOLDERS
As used herein, the term "Non-U.S. Holder" means any beneficial owner of a
note that is not a U.S. Holder.
Payment of Interest
In general, payments of interest received by a Non-U.S. Holder will not be
subject to U.S. federal withholding tax, provided that:
(i) the Non-U.S. Holder, as beneficial owner,
(a) does not actually or constructively own 10% or more of the total
combined voting power of all classes of stock of Swift entitled to vote;
(b) is not a controlled foreign corporation that is related to Swift
actually or constructively through stock ownership; and
(c) is not a bank receiving the interest pursuant to a loan agreement
entered into in its ordinary course of business;
(ii) the interest payments are not effectively connected with the conduct
by the Non-U.S. Holder of a trade or business within the U.S.; and
(iii) the Non-U.S. Holder, as beneficial owner satisfies the certification
requirement.
The certification requirement is generally satisfied if the beneficial
owner of a note certifies on IRS Form W-8BEN (or a suitable substitute form),
under penalties of perjury, that he, she or it is not a U.S. person and provides
its name and address, and
- the beneficial owner files the IRS Form W-8BEN with the withholding
agent; or
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- in the case of notes held on behalf of a beneficial owner by a securities
clearing organization, bank or other financial institution that holds
customers' securities in the ordinary course of its trade or business,
the financial institution files with the withholding agent a statement
that it has received the Form W-8BEN (or a suitable substitute form) from
the Non-U.S. Holder or from another financial institution acting on
behalf of that Non-U.S. Holder, furnishes the withholding agent with a
copy thereof and otherwise complies with the applicable certification
requirements.
In the case of notes held by a foreign partnership, the certification is
normally provided by the partners and the partnership provides other specified
information. Special rules apply with respect to withholding foreign
partnerships. A withholding agent, as used herein, is generally the last U.S.
payor (or a non-U.S. payor who is a qualified intermediary, U.S. branch of a
foreign person, or a withholding foreign partnership) in the chain of payment
prior to payment to a Non-U.S. Holder (which itself is not a withholding agent).
Other alternative procedures exist in order to satisfy the certification
requirement, depending upon the circumstances applicable to the Non-U.S. Holder.
The certification requirement is not met if either Swift or the withholding
agent has actual knowledge that the beneficial owner is a U.S. Holder or that
the conditions of any exemption are not, in fact, satisfied. Non-U.S. Holders,
including foreign partnerships and their partners, should consult their own tax
advisors regarding the certification requirements for Non-U.S. Holders and the
effect, if any, of the certification requirements on their particular situation.
Payments of interest not exempt from U.S. federal withholding tax as
described above will be subject to such withholding tax at the rate of 30%,
unless (i) subject to reduction under an applicable income tax treaty or (ii)
the interest is effectively connected to a U.S. trade or business and the holder
provides Form W-8ECI (or a suitable substitute form) to the withholding agent
and meets any other applicable certification requirement. In order to claim a
reduced or zero withholding rate under an applicable income tax treaty, the
beneficial owner of the note, must, under penalties of perjury, provide the
withholding agent with a properly completed and executed IRS Form W-8BEN (or a
suitable substitute form) claiming an exemption from, or reduction in the rate
of, withholding under the benefit of such applicable income tax treaty and meet
any other applicable certification requirement.
Sale, Disposition or Retirement
A Non-U.S. Holder generally will not be subject to U.S. federal income tax
(and generally no tax will be withheld) with respect to gain (excluding gain
representing accrued interest in which case the rules for interest apply)
realized on the sale, exchange, retirement at maturity or other taxable
disposition of a note unless:
- the Non-U.S. Holder is an individual who is present in the U.S. for a
period or periods aggregating 183 or more days in the taxable year of the
disposition and, generally, either has a "tax home" or "other fixed place
of business" in the U.S. or
- such gains are effectively connected with the conduct by the Non-U.S.
Holder of a trade or business within the U.S.
U.S. Trade or Business
If a Non-U.S. Holder holds a note in connection with the conduct of a trade
or business in the U.S. (i) any interest on the note, and any gain from
disposing of the note generally will be subject to U.S. federal income tax as if
the holder were a U.S. Holder, and (ii) Non-U.S. Holders that are corporations
may be subject to the "branch profits tax" on earnings that are connected with a
U.S. trade or business, including earnings from the note. This tax is 30%, but
may be reduced or eliminated by an applicable income tax treaty provided any
applicable certification requirement is met.
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Backup Withholding and Information Reporting
Backup withholding and information reporting requirements generally will
not apply to payments of interest made by Swift or a withholding agent to
Non-U.S. Holders if the certification requirements described above under "U.S.
Federal Income Taxation of Non-U.S. Holders -- Payment of Interest" are met,
provided that the payor does not have actual knowledge that the holder is a U.S.
Holder or that the conditions of any other exemption are not, in fact,
satisfied. If the sale, exchange or other disposition of a note is made to or
through a foreign office of a foreign custodian, foreign nominee or foreign
agent of the Non-U.S. Holder, or if a foreign office of a foreign broker pays
the proceeds of the sale of a note to the seller, backup withholding and
information reporting normally will not apply. Information reporting
requirements (but not backup withholding) will apply, however, to a payment by a
foreign office of a broker that is a U.S. person, a foreign person that derives
50% or more of its gross income for certain periods from the conduct of a trade
or business in the U.S., a foreign partnership with certain connections to the
U.S., or a controlled foreign corporation (as defined in the Code). Backup
withholding may apply, however, to any payment that the broker is required to
report if that broker has actual knowledge that the payee is a U.S. Holder or
that the conditions of any other exemption are not, in fact, satisfied. Payment
by a U.S. office of a broker is subject to both backup withholding and
information reporting unless the holder certifies under penalties of perjury
that it is a Non-U.S. Holder or otherwise establishes an exemption, provided the
broker does not have actual knowledge that the holder is a U.S. Holder or that
the conditions of any other exemption are not, in fact, satisfied.
Non-U.S. Holders of notes should consult their tax advisors regarding the
application of information reporting and backup withholding in their particular
situations, the availability of an exemption therefrom, and the procedure for
obtaining such an exemption, if available. Any amounts withheld under the backup
withholding rules from a payment to a Non-U.S. Holder will be allowed as a
credit against such Non-U.S. Holder's U.S. federal income tax liability and may
entitle the holder to a refund, provided that the required information is timely
furnished to the Internal Revenue Service.
U.S. FEDERAL ESTATE TAXATION OF NON-U.S. HOLDERS
Subject to applicable estate tax treaty provisions, notes held at the time
of death (or notes transferred before death but subject to certain retained
rights or powers) by an individual who at the time of death is not a citizen or
resident of the U.S. (as specifically defined for U.S. federal estate tax
purposes), will not be included in such individual's gross estate for U.S.
federal estate tax purposes provided that the individual does not actually or
constructively own 10% or more of the total combined voting power of all classes
of stock of Swift entitled to vote or hold the notes in connection with a U.S.
trade or business.
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UNDERWRITING
Under the terms and subject to the conditions contained in an underwriting
agreement dated April 11, 2002, we have agreed to sell to the underwriters named
below, for whom Credit Suisse First Boston Corporation ("CSFB") is acting as
representative, the following respective principal amounts of the notes:
PRINCIPAL
UNDERWRITER AMOUNT
----------- ------------
Credit Suisse First Boston Corporation...................... $106,000,000
CIBC World Markets Corp. ................................... 22,000,000
A.G. Edwards & Sons, Inc. .................................. 14,000,000
Jefferies & Company, Inc. .................................. 14,000,000
J.P. Morgan Securities Inc. ................................ 10,000,000
Morgan Stanley & Co. Incorporated........................... 10,000,000
UBS Warburg LLC............................................. 10,000,000
Banc One Capital Markets, Inc. ............................. 4,000,000
Friedman, Billings, Ramsey & Co., Inc. ..................... 4,000,000
BNP Paribas Securities Corp. ............................... 2,000,000
Credit Lyonnais Securities (USA) Inc. ...................... 2,000,000
SG Cowen.................................................... 2,000,000
------------
Total............................................. $200,000,000
============
The underwriting agreement provides that the underwriters are obligated to
purchase all of the notes if any are purchased.
We estimate that our out of pocket expenses for this offering will be
approximately $550,000.
The notes are a new issue of securities with no established trading market.
One or more of the underwriters intends to make a secondary market for the
notes. However, they are not obligated to do so and may discontinue making a
secondary market for the notes at any time without notice. No assurance can be
given as to how liquid the trading market for the notes will be.
We intend to use more than 10% of the net proceeds from the sale of the
notes to repay indebtedness owed by us to certain of the underwriters or their
affiliates who are lenders under our credit facility. Accordingly, the offering
is being made in compliance with the requirements of Rule 2710(c)(8) of the
Conduct Rules of the National Association of Securities Dealers, Inc. This rule
provides generally that if more than 10% of the net proceeds from the sale of
debt securities, not including underwriting compensation, is paid to the
underwriters of such debt securities or their affiliates, the yield on the
securities may not be lower than that recommended by a "qualified independent
underwriter" meeting certain standards. Accordingly, CSFB is assuming the
responsibilities of acting as the qualified independent underwriter in pricing
the offering and conducting due diligence. The yield on the notes, when sold to
the public at the public offering price set forth on the cover page of this
prospectus supplement, is no lower than that recommended by CSFB.
We have agreed that we will not offer, sell, contract to sell, pledge or
otherwise dispose of, directly or indirectly, or file with the SEC a
registration statement under the Securities Act of 1933 (the "Securities Act")
relating to, any additional debt securities, or publicly disclose the intention
to make any such offer, sale, pledge, disposition or filing, without the prior
written consent of CSFB for a period of 60 days after the date of this
prospectus supplement.
We have agreed to indemnify the underwriters against liabilities under the
Securities Act, or contribute to payments which the underwriters may be required
to make in that respect.
In connection with the offering the underwriters may engage in stabilizing
transactions, syndicate covering transactions and penalty bids.
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- Stabilizing transactions permit bids to purchase the underlying security
so long as the stabilizing bids do not exceed a specified maximum.
- Syndicate covering transactions involve purchases of the notes in the
open market after the distribution has been completed in order to cover
syndicate short positions.
- Penalty bids permit the representatives to reclaim a selling concession
from a syndicate member when the notes originally sold by such syndicate
member are purchased in a stabilizing transaction or a syndicate covering
transaction to cover syndicate short positions.
These stabilizing transactions, syndicate covering transactions and penalty bids
may have the effect of raising or maintaining the market price of the notes or
preventing or retarding a decline in the market price of the notes. As a result,
the price of the notes may be higher than the price that might otherwise exist
in the open market. These transactions, if commenced, may be discontinued at any
time.
In the ordinary course of their businesses, certain of the underwriters and
their affiliates have engaged, and may in the future engage, in investment
banking or commercial banking transactions with us and our affiliates. Also,
affiliates of certain of the underwriters are lenders under our credit facility.
The decision of the underwriters to distribute the notes was made independently
of the affiliates of the underwriters that are lenders under the credit
facility, which lenders had no involvement in determining whether or when to
distribute the notes under this offering or the terms of this offering. The
underwriters will not receive any benefit from this offering other than the
underwriting discount to be provided by us. Bank One, NA is the Trustee under
the Indenture. It is also the trustee under the indenture for our 10 1/4% senior
subordinated notes due 2009. Bank One, NA is also the counter party for the oil
collars we entered into on March 28, 2002. In addition, CSFB acted as the sole
underwriter in our recent common stock offering.
NOTICE TO CANADIAN RESIDENTS
RESALE RESTRICTIONS
The distribution of the notes in Canada is being made only on a private
placement basis exempt from the requirement that we prepare and file a
prospectus with the securities regulatory authorities in each province where
trades of notes are made. Any resale of the notes in Canada must be made under
applicable securities laws which will vary depending on the relevant
jurisdiction, and which may require resales to be made under available statutory
exemptions or under a discretionary exemption granted by the applicable Canadian
securities regulatory authority. Purchasers are advised to seek legal advice
prior to any resale of the notes.
REPRESENTATIONS OF PURCHASERS
By purchasing notes in Canada and accepting a purchase confirmation a
purchaser is representing to us and the dealer from whom the purchase
confirmation is received that:
- the purchaser is entitled under applicable provincial securities laws to
purchase the notes without the benefit of a prospectus qualified under
those securities laws;
- where required by law, that the purchaser is purchasing as principal and
not as agent; and
- the purchaser has reviewed the text above under "Resale Restrictions."
RIGHTS OF ACTION -- ONTARIO PURCHASERS ONLY
Under Ontario securities legislation, a purchaser who purchases a security
offered by this prospectus supplement during the period of distribution will
have a statutory right of action for damages, or while still the owner of the
notes, for rescission against us in the event that this prospectus supplement
contains a misrepresentation. A purchaser will be deemed to have relied on the
misrepresentation. The right of action for damages is exercisable not later than
the earlier of 180 days from the date the purchaser first had
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knowledge of the facts giving rise to the cause of action and three years from
the date on which payment is made for the notes. The right of action for
rescission is exercisable not later than 180 days from the date on which payment
is made for the notes. If a purchaser elects to exercise the right of action for
rescission, the purchaser will have no right of action for damages against us.
In no case will the amount recoverable in any action exceed the price at which
the notes were offered to the purchaser and if the purchaser is shown to have
purchased the securities with knowledge of the misrepresentation, we will have
no liability. In the case of an action for damages, we will not be liable for
all or any portion of the damages that are proven not to represent the
depreciation in value of the notes as a result of the misrepresentation relied
upon. These rights are in addition to, and without derogation from, any other
rights or remedies available at law to an Ontario purchaser. The foregoing is a
summary of the rights available to an Ontario purchaser. Ontario purchasers
should refer to the complete text of the relevant statutory provisions.
ENFORCEMENT OF LEGAL RIGHTS
All of our directors and officers as well as the experts named herein may
be located outside of Canada and, as a result, it may not be possible for
Canadian purchasers to effect service of process within Canada upon us or those
persons. All or a substantial portion of our assets and the assets of those
persons may be located outside of Canada and, as a result, it may not be
possible to satisfy a judgment against us or those persons in Canada or to
enforce a judgment obtained in Canadian courts against us or those persons
outside of Canada.
TAXATION AND ELIGIBILITY FOR INVESTMENT
Canadian purchasers of notes should consult their own legal and tax
advisors with respect to the tax consequences of an investment in the notes in
their particular circumstances and about the eligibility of the notes for
investment by the purchaser under relevant Canadian legislation.
LEGAL MATTERS
The validity of the offered notes and U.S. tax matters relating to the
notes will be passed upon for us by Jenkens & Gilchrist, a Professional
Corporation, Houston, Texas. Certain legal matters will be passed upon for the
underwriters by Vinson & Elkins L.L.P., Houston, Texas.
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EXPERTS
The audited financial statements included in this prospectus supplement
have been audited by Arthur Andersen LLP, independent public accountants, as
indicated in their report with respect thereto, and are included herein in
reliance upon the authority of said firm as experts in accounting and auditing
in giving said report.
Information set forth in this prospectus supplement regarding our estimated
quantities of oil and gas reserves and the discounted present value of future
net cash flows therefrom is based upon estimates of such reserves and present
values prepared by H.J. Gruy & Associates, Inc., independent petroleum
engineers. All such information has been so included herein in reliance upon the
authority of such firm as experts in such matters.
OTHER MATTERS
On March 14, 2002, our independent public accountant, Arthur Andersen LLP,
was indicted on federal obstruction of justice charges arising from the federal
government's investigation of Enron Corp. Arthur Andersen has pled not guilty
and indicated that it intends to contest the indictment. Given the uncertainty
surrounding the indictment, it may become difficult for purchasers of the notes
to seek remedies against Arthur Andersen. The SEC has said that it will continue
accepting financial statements audited by Arthur Andersen, and interim financial
statements reviewed by it, so long as Arthur Andersen is able to make certain
representations to its clients concerning audit quality controls, which
representations have been made to us. Our Audit Committee has been monitoring
these developments, and if necessary will take appropriate action regarding the
auditing of our financial statements.
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GLOSSARY OF TERMS
The following abbreviations and terms have the indicated meanings when used
in this prospectus supplement:
BBL means barrel or barrels of oil.
BCF means billion cubic feet of natural gas.
BCFE means billion cubic feet of natural gas equivalent (see Mcfe).
BOE means one revenue interests barrel of oil equivalent using the ratio of
one barrel of crude oil, condensate or natural gas liquids to six Mcf of natural
gas.
BTU means British thermal unit, which is a heating equivalent measure for
natural gas (see MMBtu).
DEVELOPMENT WELL means a well drilled within the presently proved
productive area of an oil or natural gas reservoir, as indicated by reasonable
interpretation of available data, with the objective of completing in that
reservoir.
EXPLORATORY WELL means a well drilled either in search of a new, as yet
undiscovered oil or natural gas reservoir or to greatly extend the known limits
of a previously discovered reservoir.
FAIR MARKET VALUE is defined as the maximum price that a willing buyer will
pay and a willing seller will sell at a given point in time at which the buyer
is under no compulsion to buy and the seller is not compelled to sell, both
having reasonable knowledge of all the material circumstances.
GROSS ACRE means an acre in which a working interest is owned. The number
of gross acres is the total number of acres in which a working interest is
owned.
GROSS WELL means a well in which a working interest is owned. The number of
gross wells is the total number of wells in which a working interest is owned.
MCF means thousand cubic feet of natural gas.
MCFE means thousand cubic feet of natural gas equivalent, which is
determined using the ratio of one barrel of oil, condensate or natural gas
liquids to six Mcf of natural gas.
MMBOE means million barrels of oil equivalent (see BOE).
MMBTU means Million British thermal units, which is a heating equivalent
measure for natural gas and is an alternate measure of natural gas reserves, as
opposed to Mcf, which is strictly a measure of natural gas volumes. Typically
prices quoted for natural gas are designated as prices per MMBtu, the same basis
on which natural gas is contracted for sale.
MMCF means million cubic feet of natural gas.
MMCFE means million cubic feet of natural gas equivalent (see Mcfe).
NET ACRE means the sum of fractional ownership working interests in gross
acres equals one. The number of net acres is the sum of fractional working
interests owned in gross acres expressed as whole numbers and fractions thereof.
NET WELL is deemed to exist when the sum of fractional ownership working
interests in gross wells equals one. The number of net wells is the sum of
fractional working interests owned in gross wells expressed as whole numbers and
fractions thereof.
NGL means natural gas liquid.
PRODUCING WELL means an exploratory or development well found to be capable
of producing either oil or natural gas in sufficient quantities to justify
completion as an oil or natural gas well.
PROVED DEVELOPED RESERVES means reserves that can be expected to be
recovered through existing wells with existing equipment and operating methods.
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PROVED UNDEVELOPED RESERVES means proved reserves that are expected to be
recovered from new wells on undrilled acreage.
PROVED OIL AND GAS RESERVES means the estimated quantities of crude oil,
natural gas, and natural gas liquids that geological and engineering data
demonstrate with reasonable certainty to be recoverable in future years from
known reservoirs under existing economic and operating conditions, that is,
prices and costs as of the date the estimate is made.
PV-10 VALUE means, in accordance with SEC guidelines, the estimated future
net cash flow to be generated from the production of proved reserves discounted
to present value using an annual discount rate of 10%. These amounts are
calculated net of estimated production costs and future development costs, using
prices and costs in effect as of a certain date, without escalation and without
giving effect to non-property related expenses such as general and
administrative expenses, debt services, future income tax expenses or
depreciation, depletion and amortization.
PRODUCING PROPERTIES means properties (or interests in properties)
producing oil and gas in commercial quantities. Producing Properties include
associated well machinery and equipment, gathering systems, storage facilities
or processing installations or other equipment and property associated with the
production and field processing of oil or gas. Interests in Producing Properties
may include Working Interests, production payments, Royalty Interests,
Overriding Royalty Interest, Net Profits Interests and other non-operating
interests. Producing Properties may include gas gathering lines or pipelines.
The geographical limits of a Producing Property may be enlarged or contracted on
the basis of subsequently acquired geological data to define the productive
limits of a reservoir, or as a result of action by a regulatory agency employing
such criteria as the regulatory agency may determine.
PROVED RESERVES means those quantities of crude oil, natural gas and
natural gas liquids which, upon analysis of geologic and engineering data,
appear with reasonable certainty to be recoverable in the future from known oil
and gas reservoirs under existing economic and operating conditions. Proved
Reserves are limited to those quantities of oil and gas which can be reasonably
expected to be recoverable commercially at current prices and costs, under
existing regulatory practices and with existing conventional equipment and
operating methods.
RESERVE REPLACEMENT COST means, with respect to proved reserves, a
three-year average (unless otherwise indicated) calculated by dividing total
incurred acquisition, exploration and development costs (exclusive of future
development costs) by net reserves added during the period.
ROYALTY INTEREST means a fractional interest in the gross production, or
the gross proceeds therefrom, of oil and gas and other minerals under a lease;
free of any expenses of exploration, development, operation and maintenance.
SFAS means Statement of Financial Accounting Standards.
TAWN refers to New Zealand producing properties acquired by Swift in
January 2002 and is comprised of the Tariki, Ahuroa, Waihapa and Ngaere fields.
WORKING INTEREST means the operating interest under an oil, gas and mineral
lease or other property interest covering a specific tract or tracts of land.
The owner of a Working Interest has the right to explore for, drill and produce
the oil, gas and other minerals covered by such lease or other property interest
and the obligation to bear the costs of exploration, development, operation or
maintenance applicable to that owner's interest.
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SWIFT ENERGY COMPANY AND SUBSIDIARIES
CONSOLIDATED FINANCIAL STATEMENTS
Report of Independent Public Accountants.................... F-2
Consolidated Balance Sheets................................. F-3
Consolidated Statements of Income........................... F-4
Consolidated Statements of Stockholders' Equity............. F-5
Consolidated Statements of Cash Flows....................... F-6
Notes to Consolidated Financial Statements.................. F-7
F-1
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Stockholders and Board of Directors of Swift Energy Company:
We have audited the accompanying consolidated balance sheets of Swift
Energy Company (a Texas corporation) and subsidiaries as of December 31, 2001
and 2000, and the related consolidated statements of income, stockholders'
equity, and cash flows for each of the three years in the period ended December
31, 2001. 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 auditing standards generally
accepted in the United States. 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 Swift Energy Company and
subsidiaries as of December 31, 2001 and 2000, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 2001, in conformity with accounting principles generally accepted
in the United States.
ARTHUR ANDERSEN LLP
Houston, Texas
February 18, 2002
F-2
SWIFT ENERGY COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
DECEMBER 31,
------------------------------
2001 2000
-------------- -------------
ASSETS
Current Assets:
Cash and cash equivalents................................. $ 2,149,086 $ 1,986,932
Accounts receivable --
Oil and gas sales...................................... 14,215,189 26,939,472
Associated limited partnerships and joint ventures..... 6,259,604 2,685,003
Joint interest owners.................................. 11,467,461 7,181,974
Other current assets...................................... 2,661,640 3,079,498
-------------- -------------
Total Current Assets.............................. 36,752,980 41,872,879
-------------- -------------
Property and Equipment:
Oil and gas, using full cost accounting
Proved properties being amortized...................... 974,698,428 753,426,124
Unproved properties not being amortized................ 95,943,163 55,512,872
-------------- -------------
1,070,641,591 808,938,996
Furniture, fixtures, and other equipment.................. 8,706,414 8,873,266
-------------- -------------
1,079,348,005 817,812,262
Less -- Accumulated depreciation, depletion, and
amortization......................................... (448,139,334) (290,725,112)
-------------- -------------
631,208,671 527,087,150
-------------- -------------
Other Assets:
Deferred charges.......................................... 3,723,182 3,426,972
-------------- -------------
3,723,182 3,426,972
-------------- -------------
$ 671,684,833 $ 572,387,001
============== =============
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities:
Accounts payable and accrued liabilities.................. $ 38,884,380 $ 54,977,397
Payable to associated limited partnerships................ 26,573,490 1,291,787
Undistributed oil and gas revenues........................ 7,787,465 8,055,587
-------------- -------------
Total Current Liabilities......................... 73,245,335 64,324,771
-------------- -------------
Long-Term Debt.............................................. 258,197,128 134,729,485
Deferred Income Taxes....................................... 27,589,650 41,178,590
Commitments and Contingencies
Stockholders' Equity:
Preferred stock, $.01 par value, 5,000,000 shares
authorized, none outstanding........................... -- --
Common stock, $.01 par value, 85,000,000 and 35,000,000
shares authorized, 25,634,598 and 25,452,148 shares
issued, and 24,795,564 and 24,608,344 shares
outstanding, respectively.............................. 256,346 254,521
Additional paid-in capital................................ 296,172,820 293,396,723
Treasury stock held, at cost, 839,034 and 843,804 shares,
respectively........................................... (12,032,791) (12,101,199)
Retained earnings......................................... 28,256,345 50,604,110
-------------- -------------
312,652,720 332,154,155
-------------- -------------
$ 671,684,833 $ 572,387,001
============== =============
See accompanying Notes to Consolidated Financial Statements.
F-3
SWIFT ENERGY COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
YEAR ENDED DECEMBER 31,
------------------------------------------
2001 2000 1999
------------ ------------ ------------
Revenues:
Oil and gas sales................................ $181,184,635 $189,138,947 $108,898,696
Fees from limited partnerships and joint
ventures...................................... 427,583 331,497 229,749
Interest income.................................. 49,281 1,339,386 833,204
Price risk management and other, net............. 2,145,991 815,116 709,358
------------ ------------ ------------
183,807,490 191,624,946 110,671,007
------------ ------------ ------------
Costs and Expenses:
General and administrative, net of
reimbursement................................. 8,186,654 5,585,487 4,497,400
Depreciation, depletion, and amortization........ 59,502,040 47,771,393 42,348,901
Oil and gas production........................... 36,719,609 29,220,315 19,645,740
Interest expense, net............................ 12,627,022 15,968,405 14,442,815
Other expenses................................... 2,102,251 -- --
Write-down of oil and gas properties............. 98,862,247 -- --
------------ ------------ ------------
217,999,823 98,545,600 80,934,856
------------ ------------ ------------
Income (Loss) Before Income Taxes, Extraordinary
Item and Change in Accounting Principle.......... (34,192,333) 93,079,346 29,736,151
Provision (Benefit) for Income Taxes............... (12,237,436) 33,265,480 10,449,577
------------ ------------ ------------
Income (Loss) Before Extraordinary Item and Change
in Accounting Principle.......................... $(21,954,897) $ 59,813,866 $ 19,286,574
Extraordinary Loss on Early Extinguishment of Debt
(net of taxes)................................... -- 629,858 --
Cumulative Effect of Change in Accounting Principle
(net of taxes)................................... 392,868 -- --
------------ ------------ ------------
Net Income (Loss).................................. $(22,347,765) $ 59,184,008 $ 19,286,574
Per Share Amounts --
Basic: Income (Loss) Before Extraordinary Item
and Change in Accounting Principle............ $ (0.89) $ 2.82 $ 1.07
Extraordinary Loss............................ -- (0.03) --
Change in Accounting Principle................ (0.01) -- --
------------ ------------ ------------
Net Income (Loss)............................. $ (0.90) $ 2.79 $ 1.07
Diluted: Income (Loss) Before Extraordinary Item
and Change in Accounting Principle............ $ (0.89) $ 2.53 $ 1.07
Extraordinary Loss............................ -- (0.02) --
Change in Accounting Principle................ (0.01) -- --
------------ ------------ ------------
Net Income (Loss)............................. $ (0.90) $ 2.51 $ 1.07
Weighted Average Shares Outstanding................ 24,732,099 21,244,684 18,050,106
============ ============ ============
See accompanying Notes to Consolidated Financial Statements.
F-4
SWIFT ENERGY COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
RETAINED
COMMON ADDITIONAL EARNINGS
STOCK(1) PAID-IN CAPITAL TREASURY STOCK (DEFICIT) TOTAL
-------- --------------- -------------- ------------ ------------
Balance, December 31, 1998... $169,725 $148,901,270 $(11,841,884) $(27,866,472) $109,362,639
Stock issued for benefit
plans
(90,738 shares)............ 224 (366,408) 978,956 -- 612,772
Stock options exercised
(65,477 shares)............ 655 461,102 -- -- 461,757
Employee stock purchase plan
(22,771 shares)............ 228 181,577 -- -- 181,805
Public stock offering
(4,600,000 shares)......... 46,000 41,915,310 -- -- 41,961,310
Purchase of 246,500 shares
as treasury stock.......... -- -- (1,462,740) -- (1,462,740)
Net income................... -- -- -- 19,286,574 19,286,574
-------- ------------ ------------ ------------ ------------
Balance, December 31, 1999... $216,832 $191,092,851 $(12,325,668) $ (8,579,898) $170,404,117
Stock issued for benefit
plans
(46,632 shares)............ 310 297,060 224,469 -- 521,839
Stock options exercised
(543,450 shares)........... 5,434 4,316,446 -- -- 4,321,880
Employee stock purchase plan
(29,889 shares)............ 299 297,414 -- -- 297,713
Subordinated notes conversion
(3,164,644 shares)......... 31,646 97,392,952 -- -- 97,424,598
Net income................... -- -- -- 59,184,008 59,184,008
-------- ------------ ------------ ------------ ------------
Balance, December 31, 2000... $254,521 $293,396,723 $(12,101,199) $ 50,604,110 $332,154,155
Stock issued for benefit
plans
(11,945 shares)............ 72 354,973 68,408 -- 423,453
Stock options exercised
(152,915 shares)........... 1,529 1,942,634 -- -- 1,944,163
Employee stock purchase plan
(22,360 shares)............ 224 478,490 -- -- 478,714
Net loss..................... -- -- -- (22,347,765) (22,347,765)
-------- ------------ ------------ ------------ ------------
Balance, December 31, 2001... $256,346 $296,172,820 $(12,032,791) $ 28,256,345 $312,652,720
======== ============ ============ ============ ============
---------------
(1) $.01 par value
See accompanying Notes to Consolidated Financial Statements.
F-5
SWIFT ENERGY COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
YEAR ENDED DECEMBER 31,
-----------------------------------------------
2001 2000 1999
------------- ------------- -------------
Cash Flows from Operating Activities:
Net income (loss)........................... $ (22,347,765) $ 59,184,008 $ 19,286,574
Adjustments to reconcile net income (loss)
to net cash provided by operating
activities --
Depreciation, depletion, and
amortization........................... 59,502,040 47,771,393 42,348,901
Write-down of oil and gas properties..... 98,862,247 -- --
Deferred income taxes.................... (12,555,618) 33,413,626 10,435,115
Deferred revenue amortization related to
production payment..................... -- (587,629) (1,056,284)
Other.................................... 509,973 1,075,848 628,614
Change in assets and liabilities --
(Increase) decrease in accounts
receivable.......................... 16,207,377 (14,308,274) (2,889,530)
Increase in accounts payable and
accrued liabilities, excluding
income taxes payable................ 12,984 1,601,042 4,850,036
Increase (decrease) in income taxes
payable............................. (306,983) 47,213 --
------------- ------------- -------------
Net Cash Provided by Operating
Activities........................ 139,884,255 128,197,227 73,603,426
------------- ------------- -------------
Cash Flows from Investing Activities:
Additions to property and equipment......... (275,126,333) (173,277,356) (78,112,550)
Proceeds from the sale of property and
equipment................................ 9,274,440 3,844,375 4,531,935
Net cash received as operator of oil and gas
properties............................... 5,927,539 19,769,213 5,995,842
Net cash received (distributed) as operator
of partnerships and joint ventures....... (3,574,601) 2,674,593 (433,114)
Other....................................... (534,898) (1,329) (131,135)
------------- ------------- -------------
Net Cash Used in Investing
Activities........................ (264,033,853) (146,990,504) (68,149,022)
------------- ------------- -------------
Cash Flows from Financing Activities:
Proceeds from (payments of) long-term
debt..................................... -- (15,203,000) 124,045,000
Net proceeds from (payments of) bank
borrowings............................... 123,400,000 10,600,000 (146,200,000)
Net proceeds from issuances of common
stock.................................... 1,633,508 2,697,561 42,719,776
Purchase of treasury stock.................. -- -- (1,462,740)
Payments of debt issuance costs............. (721,756) -- (3,501,441)
------------- ------------- -------------
Net Cash Provided by (Used in)
Financing Activities.............. 124,311,752 (1,905,439) 15,600,595
------------- ------------- -------------
Net Increase (Decrease) in Cash and Cash
Equivalents................................. $ 162,154 $ (20,698,716) $ 21,054,999
Cash and Cash Equivalents at Beginning of
Year........................................ 1,986,932 22,685,648 1,630,649
------------- ------------- -------------
Cash and Cash Equivalents at End of Year...... $ 2,149,086 $ 1,986,932 $ 22,685,648
============= ============= =============
Supplemental Disclosures of Cash Flows
Information:
Cash paid during year for interest, net of
amounts capitalized......................... $ 12,207,205 $ 15,528,280 $ 8,618,020
Cash paid during year for income taxes........ $ 441,926 $ -- $ --
Non-Cash Financing Activity:
Conversion of convertible notes to common
stock....................................... $ -- $ 99,797,000 $ --
See accompanying Notes to Consolidated Financial Statements.
F-6
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
PRINCIPLES OF CONSOLIDATION. The accompanying consolidated financial
statements include the accounts of Swift Energy Company (Swift) and our wholly
owned subsidiaries, which are engaged in the exploration, development,
acquisition, and operation of oil and natural gas properties, with a focus on
onshore oil and natural gas reserves in Texas and Louisiana, as well as onshore
oil and natural gas reserves in New Zealand. Our investments in associated oil
and gas partnerships and joint ventures are accounted for using the
proportionate consolidation method, whereby our proportionate share of each
entity's assets, liabilities, revenues, and expenses are included in the
appropriate classifications in the consolidated financial statements.
Intercompany balances and transactions have been eliminated in preparing the
consolidated financial statements. Certain reclassifications have been made to
prior year amounts to conform to current year presentation.
USE OF ESTIMATES. The preparation of financial statements in conformity
with accounting principles generally accepted in the United States requires
management to make estimates and assumptions that affect the reported amounts of
assets and liabilities and disclosure of contingent assets and liabilities, if
any, at the date of the financial statements and the reported amounts of
revenues and expenses during the reporting period. Actual results could differ
from estimates.
PROPERTY AND EQUIPMENT. We follow the "full cost" method of accounting for
oil and gas property and equipment costs. Under this method of accounting, all
productive and nonproductive costs incurred in the exploration, development and
acquisition of oil and gas reserves are capitalized. Under the full cost method
of accounting, such costs may be incurred both prior to or after the acquisition
of a property and include lease acquisitions, geological and geophysical
services, drilling, completion, equipment, and certain general and
administrative costs directly associated with acquisition, exploration, and
development activities. Interest costs related to unproved properties are also
capitalized to unproved oil and gas properties. General and administrative costs
related to production and general overhead are expensed as incurred.
No gains or losses are recognized upon the sale or disposition of oil and
gas properties, except in transactions involving a significant amount of
reserves. The proceeds from the sale of oil and gas properties are generally
treated as a reduction of oil and gas property costs. Fees from associated oil
and gas exploration and development limited partnerships are credited to oil and
gas property costs to the extent they do not represent reimbursement of general
and administrative expenses currently charged to expense.
Future development, site restoration, and dismantlement and abandonment
costs, net of salvage values, are estimated property-by-property based on
current economic conditions, and are amortized to expense as our capitalized oil
and gas property costs are amortized. The vast majority of our properties are
onshore, and historically the salvage value of the tangible equipment offsets
our site restoration and dismantlement and abandonment costs.
We compute the provision for depreciation, depletion, and amortization of
oil and gas properties by the unit-of-production method. Under this method, we
compute the provision by multiplying the total unamortized costs of oil and gas
properties -- including future development, site restoration, and dismantlement
and abandonment costs, but excluding costs of unproved properties -- by an
overall rate determined by dividing the physical units of oil and gas produced
during the period by the total estimated units of proved oil and gas reserves.
This calculation is done on a country-by-country basis. All other equipment is
depreciated by the straight-line method at rates based on the estimated useful
lives of the property. Repairs and maintenance are charged to expense as
incurred. Renewals and betterments are capitalized.
The cost of unproved properties not being amortized is assessed quarterly,
on a country-by-country basis, to determine whether such properties have been
impaired. In determining whether such costs should
F-7
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
be impaired, we evaluate, among other factors, current drilling results, lease
expiration dates, current oil and gas industry conditions, international
economic conditions, capital availability, foreign currency exchange rates, the
political stability in the countries in which we have an investment, and
available geological and geophysical information. Any impairment assessed is
added to the cost of proved properties being amortized. To the extent costs
accumulate in countries where there are no proved reserves, any costs determined
by management to be impaired are charged to income.
Full Cost Ceiling Test. At the end of each quarterly reporting period, the
unamortized cost of oil and gas properties, net of related deferred income
taxes, is limited to the sum of the estimated future net revenues from proved
properties using period-end prices, discounted at 10%, and the lower of cost or
fair value of unproved properties, adjusted for related income tax effects
("Ceiling Test"). This calculation is done on a country-by-country basis for
those countries with proved reserves.
The calculation of the Ceiling Test and provision for depreciation,
depletion, and amortization is based on estimates of proved reserves. There are
numerous uncertainties inherent in estimating quantities of proved reserves and
in projecting the future rates of production, timing, and plan of development.
The accuracy of any reserves estimate is a function of the quality of available
data and of engineering and geological interpretation and judgment. Results of
drilling, testing, and production subsequent to the date of the estimate may
justify revision of such estimate. Accordingly, reserves estimates are often
different from the quantities of oil and gas that are ultimately recovered.
In 2001, as a result of low oil and gas prices at December 31, 2001, we
reported a non-cash write-down on a before-tax basis of $98.9 million ($63.5
million after tax) on our domestic properties. We had no write-down on our New
Zealand properties.
In addition, any unsuccessful exploratory well costs in countries in which
there are no proved reserves are charged to expense as incurred. During the
second quarter of 1999, we charged to income as additional depreciation,
depletion, and amortization costs our portion of drilling costs associated with
an unsuccessful exploratory well drilled by another operator in New Zealand.
This charge was $290,000.
Because of the delineation of our 1999 Rimu discovery with two successful
delineation wells drilled in 2000, proved reserves were recognized in New
Zealand as of December 31, 2000.
Given the volatility of oil and gas prices, it is reasonably possible that
our estimate of discounted future net cash flows from proved oil and gas
reserves could change in the near term. If oil and gas prices decline from the
Company's year end prices used in the Ceiling Test, even if only for a short
period, it is possible that additional write-downs of oil and gas properties
could occur in the future.
OIL AND GAS REVENUES. Oil and gas revenues are reported, as the product is
delivered, using the entitlement method in which we recognize our ownership
interest in production as revenue. If our sales exceed our ownership share of
production, the differences are reported as deferred revenues. Natural gas
balancing receivables are reported when our ownership share of production
exceeds sales. As of December 31, 2001, we did not have any material natural gas
imbalances.
DEFERRED CHARGES. Legal and accounting fees, underwriting fees, printing
costs, and other direct expenses associated with the public offering in November
1996 of our 6.25% Convertible Subordinated Notes (the "Convertible Notes"), with
the public offering in August 1999 of our 10.25% Senior Subordinated Notes (the
"Senior Notes"), and with our September 2001 extension of our bank credit
facility were capitalized and are amortized over the life of each of the
respective note offerings and credit facility. The Convertible Notes were called
for redemption effective December 26, 2000, and the balance of their unamortized
issuance costs at that time of $3,046,181 was either transferred to the common
stock equity accounts ($2,643,476) for the portion of the Convertible Notes
converted into common stock at the election of those note holders or was
recorded, net of taxes, as Extraordinary Loss on Early
F-8
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Extinguishment of Debt ($402,705) for the portion of the Convertible Notes
redeemed for cash. The Senior Notes mature on August 1, 2009, and the balance of
their issuance costs at December 31, 2001, was $2,956,306, net of accumulated
amortization of $545,135. The issuance costs associated with our revolving
credit facility, which closed in September 2001, have been capitalized and are
being amortized over the original life of the facility. The balance of revolving
credit facility issuance costs at December 31, 2001, was $766,876, net of
accumulated amortization of $513,573.
LIMITED PARTNERSHIPS AND JOINT VENTURES. We formed 88 limited partnerships
between 1984 and 1995 to acquire interests in producing oil and gas properties
and 13 partnerships between 1993 and 1998 to drill for oil and gas. In all of
these partnerships, Swift paid for varying percentages of the capital or front-
end costs and continuing costs of the partnerships and, in return, received
differing percentage ownership interests in the partnerships, along with
reimbursement of costs and/or payment of certain fees. At year end 2001, we
continue to serve as managing general partner of 71 of these various
partnerships, and during fiscal 2001 approximately 2.9% of our total oil and gas
sales was attributable to our interests in those partnerships.
During 1997 and 1998, eight drilling partnerships formed between 1979 and
1985 and 21 of the production purchase partnerships sold their properties and
were dissolved, in each case following a vote of the investors in the particular
partnerships approving such liquidations. Between 1999 and 2001, the investors
in all but six of the remaining partnerships voted to sell the properties or
their interests in the partnerships and dissolve. During 2001, seven drilling
partnerships and two production purchase partnerships were dissolved. We
anticipate that the liquidation and dissolution of the additional 65
partnerships will be completed by the end of 2002. The remaining six
partnerships will continue to operate until their limited partners vote
otherwise.
PRICE-RISK MANAGEMENT ACTIVITIES. In June 1998, the Financial Accounting
Standards Board issued SFAS No. 133, "Accounting for Derivative Instruments and
Hedging Activities." The statement establishes accounting and reporting
standards requiring that every derivative instrument (including certain
derivative instruments embedded in other contracts) be recorded in the balance
sheet as either an asset or a liability measured at its fair value. SFAS No. 133
requires that changes in the derivative's fair value be recognized currently in
earnings unless specific hedge accounting criteria are met. Special accounting
for qualifying hedges allows the gains and losses on derivatives to offset
related results on the hedged item in the income statements and requires that a
company must formally document, designate, and assess the effectiveness of
transactions that receive hedge accounting. SFAS No. 133, as amended by SFAS No.
137 and SFAS No. 138, was adopted by us on January 1, 2001.
We have a policy to use derivative instruments, mainly the buying of
protection price floors, to protect against price declines in oil and gas
prices. We elected not to designate our price floors for special hedge
accounting treatment under SFAS No. 133, as amended. However, we have elected to
use mark-to-market accounting treatment for our derivative contracts. Upon
adoption of SFAS No. 133 on January 1, 2001, we recorded a net of taxes charge
of $392,868, which is recorded as a Cumulative Effect of Change in Accounting
Principle. During 2001 we recognized net gains of $1,173,094 relating to our
derivative activities, with $16,784 in unrealized losses at year-end 2001. This
activity is recorded in Price-risk management and other, net on the accompanying
statements of income.
At December 31, 2001, we had open price floor contracts covering notional
volumes of 2.0 million MMBtu of natural gas. These natural gas price floor
contracts relate to the NYMEX contract months of February and March 2002 at an
average price of $2.33 per MMBtu. The fair value of our open price floor
contracts at December 31, 2001, totaled $296,000 and is included in Other
current assets on the accompanying balance sheets.
F-9
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
INCOME TAXES. Under SFAS No. 109, "Accounting for Income Taxes," deferred
taxes are determined based on the estimated future tax effects of differences
between the financial statement and tax bases of assets and liabilities, given
the provisions of the enacted tax laws.
CASH AND CASH EQUIVALENTS. We consider all highly liquid debt instruments
with an initial maturity of three months or less to be cash equivalents.
CREDIT RISK DUE TO CERTAIN CONCENTRATIONS. We extend credit, primarily in
the form of monthly oil and gas sales and joint interest owners receivables, to
various companies in the oil and gas industry, which results in a concentration
of credit risk. The concentration of credit risk may be affected by changes in
economic or other conditions and may accordingly impact our overall credit risk.
However, we believe that the risk of these unsecured receivables is mitigated by
the size, reputation, and nature of the companies to which we extend credit.
During 2001, oil and gas sales to subsidiaries of Eastex Crude Company were
$31.6 million, or 18.1% of oil and gas sales, while sales to subsidiaries of
Enron were $18.2 million, or 10.4% of oil and gas sales. During 2000, oil and
gas sales to subsidiaries of Eastex Crude Company were $47.4 million, or 25.7%
of our oil and gas sales, while sales to subsidiaries of PG&E Energy Trading
Corporation were $21.2 million, or 11.5% of oil and gas sales. During 1999, oil
and gas sales to subsidiaries of Eastex Crude Company were $21.7 million, or
19.4% of our oil and gas sales. Beginning in December 2000, the subsidiaries of
PG&E Energy Trading Corporation to which we made sales were sold to subsidiaries
of El Paso Corporation. All receivables from PG&E were collected. During the
fourth quarter of 2001, we wrote off $1.4 million due to uncollected receivables
related to gas sold to Enron in November 2001. This amount is included in Other
expenses on the Consolidated Statement of Income. We have discontinued sales of
oil and gas to Enron and are selling that production to other purchasers.
RISK FACTORS. Our revenues, profitability and cash flow are substantially
dependent upon the price of and demand for oil and gas. Prices for oil and gas
are subject to wide fluctuations in response to relatively minor changes in the
supply of and demand for oil and gas, market uncertainty, and a variety of
additional factors beyond our control. We are also dependent upon the continued
success of our domestic and New Zealand exploration and development programs.
Other factors that could affect revenues, profitability, and cash flow include
the inherent uncertainty in reserves estimates, our price-risk management
activities, and the ability to replace reserves and finance our growth.
FAIR VALUE OF FINANCIAL INSTRUMENTS. Our financial instruments consist of
cash and cash equivalents, accounts receivable, accounts payable, bank
borrowings, and notes. The carrying amounts of cash and cash equivalents,
accounts receivable, and accounts payable approximate fair value due to the
highly liquid nature of these short-term instruments. The fair values of the
bank borrowings approximate the carrying amounts as of December 31, 2001 and
2000, and were determined based upon interest rates currently available to us
for borrowings with similar terms. Based on quoted market prices as of the
respective dates, the fair values of our Senior Notes were $126.5 million and
$115.1 million at December 31, 2001 and 2000, respectively. The carrying value
of our Senior Notes was $124.2 million and $124.1 million at December 31, 2001
and 2000, respectively.
NEW ACCOUNTING PRONOUNCEMENTS. In June 2001, the Financial Accounting
Standards Board issued SFAS No. 143, "Accounting for Asset Retirement
Obligations." The statement requires entities to record the fair value of a
liability for legal obligations associated with the retirement obligations of
tangible long-lived assets in the period in which it is incurred. When the
liability is initially recorded, the entity increases the carrying amount of the
related long-lived asset. Over time, accretion of the liability is recognized
each period, and the capitalized cost is depreciated over the useful life of the
related asset. Upon settlement of the liability, an entity either settles the
obligation for its recorded amount or incurs a gain or loss upon settlement. We
currently do not include dismantlement and abandonment costs in our depletion
calculation as the vast majority of our properties are onshore and the salvage
value of the tangible equipment offsets our dismantlement and abandonment costs.
This standard will require us to
F-10
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
record a liability for the fair value of our dismantlement and abandonment
costs, excluding salvage values. The standard is effective for fiscal years
beginning after June 15, 2002, with earlier application encouraged. The Company
is currently evaluating the effect of adopting Statement No. 143 on its
financial statements and will adopt the statement on January 1, 2003.
2. EARNINGS PER SHARE
Basic earnings per share ("Basic EPS") have been computed using the
weighted average number of common shares outstanding during the respective
periods. The calculation of diluted earnings per share ("Diluted EPS") for 1999
and 2000 assumes conversion of our Convertible Notes as of the beginning of the
respective periods and the elimination of the related after-tax interest
expense. The calculation of diluted earnings per share for all periods assumes,
as of the beginning of the period, exercise of stock options and warrants using
the treasury stock method. The assumed conversion of our Convertible Notes
applies only to the 2000 period since for the 1999 period they would have been
antidilutive and since they were extinguished at year end 2000. Certain of our
stock options that would potentially dilute Basic EPS in the future were also
antidilutive for the 2001 and 1999 periods.
The following is a reconciliation of the numerators and denominators used
in the calculation of Basic and Diluted EPS for the years ended December 31,
2001, 2000, and 1999:
2001 2000 1999
---------------------------------- --------------------------------- ---------------------------------
PER PER PER
SHARE SHARE SHARE
NET LOSS SHARES AMOUNT NET INCOME SHARES AMOUNT NET INCOME SHARES AMOUNT
------------ ---------- ------ ----------- ---------- ------ ----------- ---------- ------
BASIC EPS:
Net Income (Loss) and
Share Amounts...... $(22,347,765) 24,732,099 $(0.90) $59,184,008 21,244,684 $2.79 $19,286,574 18,050,106 $1.07
Dilutive Securities:
6.25% Convertible
Notes............ -- -- 4,772,418 3,546,933 -- --
Stock Options...... -- -- -- 713,112 -- 42,365
------------ ---------- ----------- ---------- ----------- ----------
DILUTED EPS:
Net Income (Loss) and
Assumed Share
Conversions........ $(22,347,765) 24,732,099 $(0.90) $63,956,426 25,504,729 $2.51 $19,286,574 18,092,471 $1.07
============ ========== =========== ========== =========== ==========
3. PROVISION FOR INCOME TAXES
The following is an analysis of the consolidated income tax provision
(benefit):
YEAR ENDED DECEMBER 31,
----------------------------------------
2001 2000 1999
------------ ----------- -----------
Current...................................... $ 114,611 $ (29,000) $ (11,819)
Deferred..................................... (12,352,047) 33,294,480 10,461,396
------------ ----------- -----------
Total.............................. $(12,237,436) $33,265,480 $10,449,577
============ =========== ===========
There are differences between income taxes computed using the federal
statutory rate (35% for 2001, 2000, and 1999) and our effective income tax rates
(35.8%, 35.7%, and 35.1% for 2001, 2000, and 1999, respectively), primarily as
the result of state income taxes, foreign income taxes and certain tax credits
available to the Company. Foreign net income for Swift Energy New Zealand
Limited for 2001 was
F-11
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
$1,234,919. New Zealand's statutory rate and effective tax rate are 33%.
Reconciliations of income taxes computed using the statutory rate to the
effective income tax rates are as follows:
2001 2000 1999
------------ ----------- -----------
Income taxes computed at U.S. statutory
rate....................................... $(11,967,317) $32,577,772 $10,407,653
State tax provisions, net of federal
benefits................................... (279,875) 775,850 (7,801)
Provision for foreign income tax............. (24,698) -- --
Other, net................................... 34,454 (88,142) 49,725
------------ ----------- -----------
Provision (benefit) for income
taxes............................ $(12,237,436) $33,265,480 $10,449,577
============ =========== ===========
The tax effects of temporary differences representing the net deferred tax
liability (asset) at December 31, 2001 and 2000, were as follows:
2001 2000
------------ ------------
Deferred tax assets:
Alternative minimum tax credits........................ $ (1,979,399) $ (1,979,399)
Net operating loss carry forward....................... (18,877,969) (16,194,060)
------------ ------------
Total deferred tax assets...................... $(20,857,368) $(18,173,459)
Deferred tax liabilities:
Domestic oil and gas properties........................ $ 47,539,564 $ 59,097,793
Foreign oil and gas properties......................... 407,524 --
Other.................................................. 482,513 254,256
------------ ------------
Total deferred tax liabilities................. $ 48,429,601 $ 59,352,049
------------ ------------
Net deferred tax liability..................... $ 27,572,233 $ 41,178,590
============ ============
As of December 31, 2001, we had $52.7 million of net operating loss carry
forwards, which expire as follows: $29.0 million, $20.1 million, $3.0 million
and $0.6 million in 2013, 2014, 2015 and 2016, respectively.
We did not record any valuation allowances against deferred tax assets at
December 31, 2001 and 2000.
At December 31, 2001, we had alternative minimum tax credits of $1,979,399
that carry forward indefinitely and are available to reduce future regular tax
liability to the extent they exceed the related tentative minimum tax otherwise
due.
4. LONG-TERM DEBT
Our long-term debt as of December 31, 2001 and 2000, is as follows:
2001 2000
------------ ------------
Bank Borrowings.......................................... $134,000,000 $ 10,600,000
Senior Notes............................................. 124,197,128 124,129,485
------------ ------------
Long-Term Debt................................. $258,197,128 $134,729,485
============ ============
BANK BORROWINGS. At December 31, 2001, we had outstanding borrowings of
$134.0 million under our $250.0 million credit facility with a syndicate of nine
banks which has a borrowing base of $200 million. At December 31, 2000, we had
borrowings of $10.6 million under our credit facility. The interest rate is
either (a) the lead bank's prime rate (4.75% at December 31, 2001) or (b) the
adjusted
F-12
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
London Interbank Offered Rate ("LIBOR") plus the applicable margin depending on
the level of outstanding debt. The applicable margin is based on the ratio of
the outstanding balance to the last calculated borrowing base. Of the $134.0
million borrowed at December 31, 2001, $130.0 million was borrowed at the LIBOR
rate plus applicable margin, which averaged 3.64%. Of the $10.6 million borrowed
at December 31, 2000, $5.0 million was borrowed at the LIBOR rate plus
applicable margin (which averaged 7.89% at December 31, 2000).
Upon closing of the New Zealand TAWN acquisition in January 2002, our
credit facility increased to $300.0 million and the borrowing base increased to
$275.0 million. For further information on this acquisition, see Footnote 9
"Subsequent Events."
The terms of our credit facility include, among other restrictions, a
limitation on the level of cash dividends (not to exceed $5.0 million in any
fiscal year), requirements as to maintenance of certain minimum financial ratios
(principally pertaining to working capital, debt, and equity ratios), and
limitations on incurring other debt. Since inception, no cash dividends have
been declared on our common stock. We are currently in compliance with the
provisions of this agreement. Effective September 28, 2001, the credit facility
was extended until October 1, 2005.
Interest expense on the credit facility, including commitment fees and
amortization of debt issuance costs, totaled $5,833,564 in 2001, $654,936 in
2000, and $6,107,270 in 1999.
CONVERTIBLE NOTES. In November 1996, we sold $115.0 million of 6.25%
Convertible Subordinated Notes due 2006. The Convertible Notes were unsecured
and convertible into Swift common stock at the option of the holders at an
adjusted conversion price of $31.534 per share. Interest on the notes was
payable semiannually, on May 15 and November 15. On December 11, 2000, we called
for the redemption of our Convertible Notes effective December 26, 2000, at
103.75% of their principal amount. Holders of approximately $100.0 million of
the Convertible Notes elected to convert their notes into 3,164,644 shares of
our common stock. Holders of the remaining $15.0 million of the Convertible
Notes elected to redeem their notes for cash plus accrued interest. This cash
redemption resulted in our recognizing an Extraordinary Loss on the Early
Extinguishment of Debt (net of taxes) of $0.6 million, or $1.0 million before
taxes.
Interest expense on the Convertible Notes, including amortization of debt
issuance costs, totaled $7,426,599 in 2000 and $7,569,361 in 1999.
SENIOR NOTES. Our Senior Notes consist of $125.0 million of 10.25% Senior
Subordinated Notes due 2009. The Senior Notes were issued at 99.236% of the
principal amount on August 4, 1999, and will mature on August 1, 2009. The
Senior Notes are unsecured senior subordinated obligations and are subordinated
in right of payment to all our existing and future senior debt, including our
bank debt. Interest on the Senior Notes is payable semiannually, on February 1
and August 1, and commenced with the first payment on February 1, 2000. On or
after August 1, 2004, the Senior Notes are redeemable for cash at the option of
Swift, with certain restrictions, at 105.125% of principal, declining to 100% in
2007. In addition, prior to August 1, 2002, we may redeem up to 33.33% of the
Senior Notes with the proceeds of qualified offerings of our equity at 110.25%
of the principal amount of the Senior Notes, together with accrued and unpaid
interest. Upon certain changes in control of Swift, each holder of Senior Notes
will have the right to require us to repurchase the Senior Notes at a purchase
price in cash equal to 101% of the principal amount, plus accrued and unpaid
interest to the date of purchase.
Interest expense on the Senior Notes, including amortization of debt
issuance costs and discount, totaled $13,123,052 in 2001, $13,092,127 in 2000,
and $5,303,266 in 1999.
DEBT MATURITIES. Our bank borrowings are due in October 2005, and our
Senior Notes are due in August 2009.
F-13
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
5. COMMITMENTS AND CONTINGENCIES
Total rental and lease expenses were $1,322,611 in 2001, $1,255,474 in
2000, and $1,272,497 in 1999. Our remaining minimum annual obligations under
non-cancelable operating lease commitments are $1,393,095 for 2002, $1,480,092
for 2003, $1,492,268 for 2004, and $248,711 for 2005. The rental and lease
expenses and remaining minimum annual obligations under non-cancelable operating
lease commitments primarily relate to the lease of our office space in Houston,
Texas.
As of December 31, 2001, we were the managing general partner of 71 limited
partnerships. Because we serve as the general partner of these entities, under
state partnership law we are contingently liable for the liabilities of these
partnerships, which liabilities are not material for any of the periods
presented in relation to the partnerships' respective assets.
In the ordinary course of business, we have been party to various legal
actions, which arise primarily from our activities as operator of oil and gas
wells. In management's opinion, the outcome of any such currently pending legal
actions will not have a material adverse effect on the financial position or
results of operations of Swift.
6. STOCKHOLDERS' EQUITY
COMMON STOCK. During the third quarter of 1999, we issued 4.6 million
shares of common stock at a price of $9.75 per share. Gross proceeds from this
offering were $44,850,000 with issuance costs of $2,888,690.
In December 2000, the holders of approximately $100.0 million of our
Convertible Notes converted such notes into 3,164,644 shares of our common
stock, which resulted in an increase in our common stock capital accounts of
approximately $97.4 million.
STOCK-BASED COMPENSATION PLANS. We have two current stock option plans,
the 2001 Omnibus Stock Compensation Plan, which was adopted by our board of
directors in February 2001 and was approved by shareholders at the 2001 Annual
Meeting of Shareholders, and the 1990 non-qualified plan. In addition, we have
an employee stock purchase plan. No further grants will be made under the 1990
stock compensation plan.
Under the 2001 plan, incentive stock options and other options and awards
may be granted to employees to purchase shares of common stock. Under the 1990
non-qualified plan, non-employee members of our board of directors may be
granted options to purchase shares of common stock. Both plans provide that the
exercise prices equal 100% of the fair value of the common stock on the date of
grant. Unless otherwise provided, options become exercisable for 20% of the
shares on the first anniversary of the grant of the option and are exercisable
for an additional 20% per year thereafter. Options granted expire 10 years after
the date of grant or earlier in the event of the optionee's separation from
employment. At the time the stock options are exercised, the option price is
credited to common stock and additional paid-in capital.
F-14
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The employee stock purchase plan provides eligible employees the
opportunity to acquire shares of Swift common stock at a discount through
payroll deductions. The plan year is from June 1 to the following May 31. The
first year of the plan commenced June 1, 1993. To date, employees have been
allowed to authorize payroll deductions of up to 10% of their base salary during
the plan year by making an election to participate prior to the start of a plan
year. The purchase price for stock acquired under the plan is 85% of the lower
of the closing price of our common stock as quoted on the New York Stock
Exchange at the beginning or end of the plan year or a date during the year
chosen by the participant. Under this plan for the last three years, we have
issued 22,360 shares at a price of $21.41 in 2001, 29,889 shares at a price
range of $8.40 to $10.57 in 2000, and 22,771 shares at a price range of $5.21 to
$11.00 in 1999. The estimated weighted average fair value of shares issued under
this plan, as determined using the Black-Scholes option-pricing model, was $8.19
in 2001, $4.25 in 2000, and $4.74 in 1999. As of December 31, 2001, 362,428
shares remained available for issuance under this plan. There are no charges or
credits to income in connection with this plan.
We account for our stock option plans under Accounting Principles Board
Opinion No. 25, "Accounting for Stock Issued to Employees." As all options were
issued at a price equal to market price, no compensation expense has been
recognized. Had compensation expense for these plans been determined based on
the fair value of the options consistent with SFAS No. 123, "Accounting for
Stock-Based Compensation," our net income (loss) and earnings (loss) per share
would have been adjusted to the following pro forma amounts:
2001 2000 1999
------------ ----------- -----------
Net Income (Loss)
As Reported................................ $(22,347,765) $59,184,008 $19,286,574
Pro Forma.................................. $(26,632,624) $56,531,665 $16,869,122
Basic EPS:
As Reported................................ $ (0.90) $ 2.79 $ 1.07
Pro Forma.................................. $ (1.08) $ 2.66 $ 0.93
Diluted EPS:
As Reported................................ $ (0.90) $ 2.51 $ 1.07
Pro Forma.................................. $ (1.08) $ 2.40 $ 0.93
Pro forma compensation cost reflected above may not be representative of
the cost to be expected in future years.
F-15
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The following is a summary of our stock options under these plans as of
December 31, 2001, 2000, and 1999:
2001 2000 1999
--------------------- --------------------- ---------------------
WEIGHTED WEIGHTED WEIGHTED
AVERAGE AVERAGE AVERAGE
EXERCISE EXERCISE EXERCISE
SHARES PRICE SHARES PRICE SHARES PRICE
---------- -------- ---------- -------- ---------- --------
Options outstanding, beginning of
period................................. 2,076,593 $11.70 2,148,511 $ 9.08 2,266,146 $ 9.03
Options granted.......................... 747,073 $31.51 645,944 $16.88 25,000 $12.50
Options canceled......................... (31,247) $14.09 (174,412) $ 8.71 (77,158) $ 8.95
Options exercised........................ (152,915) $ 8.69 (543,450) $ 8.48 (65,477) $ 8.55
---------- ---------- ----------
Options outstanding, end of period....... 2,639,504 $17.44 2,076,593 $11.70 2,148,511 $ 9.08
========== ========== ==========
Options exercisable, end of period....... 1,181,141 $11.49 897,711 $ 9.35 1,280,156 $ 8.87
========== ========== ==========
Options available for future grant, end
of period.............................. 1,155,057 181,235 950,735
========== ========== ==========
Estimated weighted average fair value per
share of options granted during the
year................................... $ 20.68 $ 10.90 $ 7.10
========== ========== ==========
The fair value of each option grant, as opposed to its exercise price, is
estimated on the date of grant using the Black-Scholes option-pricing model with
the following weighted average assumptions in 2001, 2000, and 1999,
respectively: no dividend yield; expected volatility factors of 46.9%, 46.7%,
and 44.2%; risk-free interest rates of 5.24%, 6.61%, and 5.60%; and expected
lives of 7.3, 6.7, and 7.5 years. The following table summarizes information
about stock options outstanding at December 31, 2001:
OPTIONS OUTSTANDING OPTIONS EXERCISABLE
-------------------------------------------- -------------------------
NUMBER WEIGHTED WEIGHTED NUMBER WEIGHTED
OUTSTANDING AT AVERAGE AVERAGE EXERCISABLE AT AVERAGE
RANGE OF DECEMBER 31, REMAINING EXERCISE DECEMBER 31, EXERCISE
EXERCISE PRICES 2001 CONTRACTUAL LIFE PRICE 2001 PRICE
--------------- -------------- ---------------- -------- -------------- --------
$ 5.00 to $16.99..................... 1,592,597 5.7 $ 9.50 1,012,907 $ 9.20
$17.00 to $28.99..................... 280,439 6.1 $23.25 153,785 $24.23
$29.00 to $41.00..................... 766,468 9.1 $31.84 14,449 $36.69
--------- ---------
$ 5.00 to $41.00..................... 2,639,504 6.8 $17.44 1,181,141 $11.49
========= =========
EMPLOYEE STOCK OWNERSHIP PLAN. In 1996, we established an Employee Stock
Ownership Plan ("ESOP") effective January 1, 1996. All employees over the age of
21 with one year of service are participants. This plan has a five-year cliff
vesting, and service is recognized after the ESOP effective date. The ESOP is
designed to enable our employees to accumulate stock ownership. While there will
be no employee contributions, participants will receive an allocation of stock
that has been contributed by Swift. Compensation expense is reported when such
shares are released to employees. The plan may also acquire Swift common stock
purchased at fair market value. The ESOP can borrow money from Swift to buy
Swift stock. Benefits will be paid in a lump sum or installments, and the
participants generally have the choice of receiving cash or stock. At December
31, 2001, 2000 and 1999, all of the ESOP compensation was earned.
EMPLOYEE SAVINGS PLAN. We have a savings plan under Section 401(k) of the
Internal Revenue Code. Eligible employees may make voluntary contributions into
the 401(k) savings plan with Swift contributing on behalf of the eligible
employee an amount equal to 100% of the first 2% of compensation and 75% of the
next 4% of compensation based on the contributions made by the eligible
employees. Our contribution to the 401(k) savings plan totaled $558,000,
$483,000, and $474,000 for the years ended
F-16
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
December 31, 2001, 2000, and 1999, respectively. The contribution in 2001 was
made all in common stock, while the 2000 and 1999 contributions were made half
in common stock and half in cash. The shares of common stock contributed to the
401(k) savings plan totaled 28,798, 7,175, and 21,810 shares for the 2001, 2000,
and 1999 contributions, respectively.
COMMON STOCK REPURCHASE PROGRAM. In March 1997, our board of directors
approved a common stock repurchase program that terminated as of June 30, 1999.
Under this program, we spent approximately $13.3 million to acquire 927,774
shares in the open market at an average cost of $14.34 per share. At December
31, 2001, 839,034 shares remain in treasury (net of 88,740 shares used to fund
ESOP and 401(k) contributions) with a total cost of $12,032,791 and are included
in "Treasury stock held, at cost" on the balance sheet.
SHAREHOLDER RIGHTS PLAN. In August 1997, the board of directors declared a
dividend of one preferred share purchase right on each outstanding share of
Swift common stock. The rights are not currently exercisable but would become
exercisable if certain events occurred relating to any person or group acquiring
or attempting to acquire 15% or more of our outstanding shares of common stock.
Thereafter, upon certain triggers, each right not owned by an acquirer allows
its holder to purchase Swift securities with a market value of two times the
$150 exercise price.
7. RELATED-PARTY TRANSACTIONS
We are the operator of a number of properties owned by our affiliated
limited partnerships and joint ventures and, accordingly, charge these entities
and third-party joint interest owners operating fees. The operating fees charged
to the partnerships in 2001, 2000, and 1999 totaled approximately $925,000,
$1,775,000, and $1,970,000, respectively. We are also reimbursed for direct,
administrative, and overhead costs incurred in conducting the business of the
limited partnerships, which totaled approximately $3,140,000, $4,465,000, and
$4,000,000 in 2001, 2000, and 1999, respectively. In partnerships in which the
limited partners have voted to sell their remaining properties and liquidate
their limited partnerships, we are also reimbursed for direct, administrative,
and overhead costs incurred in the disposition of such properties, which costs
totaled approximately $2,360,000, $1,220,000, and $850,000 in 2001, 2000, and
1999, respectively.
8. FOREIGN ACTIVITIES
New Zealand
Swift Operated Permits. Our activity in New Zealand began in 1995 with the
issuance of the first of two petroleum exploration permits. After surrendering a
portion of our permit acreage in 1998, combining the two permits and expanding
the permit acreage in 1999, and relinquishing 50% of the acreage in 2001 as we
extended our petroleum exploration permit, our permit 38719 as of year end 2001
covered approximately 50,300 acres in the Taranaki Basin of New Zealand's north
island, with all but 12,800 acres onshore. At December 31, 2001, we had a 90%
working interest in this permit and had fulfilled all current obligations under
this permit.
In late 1999, we completed our first exploratory well on this permit, the
Rimu-A1, and a production test was performed. During the second half of 2000, we
drilled and successfully tested two development wells, the Rimu-B1 and the
Rimu-B2. In 2001 we drilled and tested three more Rimu development wells, the
Rimu-A2, Rimu-A3 and Rimu-B3. The Rimu-A3 was successful; the Rimu-A2 and
Rimu-B3 were dry. Early in 2002, the Rimu-A2 was sidetracked to the Tariki sand
and is currently awaiting completion. The Rimu-B3 was also sidetracked in early
2002 and again was unsuccessful. In 2001, we also drilled the Kauri-A1
exploratory well, the Kauri-A2 development well, and the Kauri-B1 exploratory
well. In the Kauri-A-1 we tested the Upper Tariki sands and still have further
zones to test. The Kauri-A2 well
F-17
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
successfully tested the Manutahi sands. The Kauri-B1 was drilled approximately
1.75 miles to the southeast of the Kauri-A pad and targeted the Manutahi sands.
This well was plugged and abandoned in 2001. Our portion of the drilling,
completion, and testing costs incurred on the wells within our permits during
2001 was approximately $26.0 million. Our portion of prospect costs on our
permits during 2001 was approximately $5.1 million, which included obtaining 2-D
seismic data in the last half of the year for the Rata prospect. We incurred
$22.5 million on the production facilities that we expect to be commissioned
near the end of the first quarter of 2002.
In 2000, we entered into an agreement with Fletcher Challenge Energy
Limited whereby we would earn a 25% participating interest in petroleum
exploration permit 38730 containing approximately 48,900 acres. In May 2001,
Fletcher relinquished their interest in the permit, and we then assumed 100%
working interest in such permit by means of committing to an acceptable work
plan. Such plan required us to acquire a minimum of 30 kilometers of new 2D
seismic data, which we completed in 2001. Rather than commit to drill a new well
in 2002 as the work plan called for, we surrendered this project in February
2002.
Non-Operated Permits. In 1998, we entered into agreements for a 25%
working interest in an exploration permit, permit 38712, held by Marabella
Enterprises Ltd., a subsidiary of Bligh Oil & Minerals, an Australian company,
and a 7.5% working interest held by Antrim Oil and Gas Limited, a Canadian
company, in a second permit, permit 38716, operated by Marabella. In turn, Bligh
and Antrim each became 5% working interest owners in our permit 38719.
Unsuccessful exploratory wells were drilled on these two permits, and we charged
$0.4 million against earnings in 1998 and $0.3 million in 1999. All of the
acreage on the permit 38712 was surrendered in 2000. The exploratory well on
permit 38716 has been temporarily abandoned pending a further evaluation. It is
currently anticipated that this well will be re-entered and sidetracked to
target a location to the west of the initial well. A five-year extension was
granted on permit 38716 in 2001 upon the surrender of 50% of the acreage.
In 2000, we entered into an agreement with Fletcher Challenge Energy
Limited whereby we will earn a 20% participating interest in petroleum
exploration permit 38718 containing approximately 57,400 acres. In January 2001,
the operator temporarily abandoned the Tuihu #1 exploratory well on permit 38718
pending further analysis. The permit now contains approximately 28,700 acres
after a scheduled surrender during December 2000.
Costs Incurred. During 2001, our costs incurred in New Zealand totaled
$54.5 million, including $25.7 million for drilling, $5.5 million for prospect
costs, $22.5 million for production facilities, and $0.8 million in evaluation
costs for the acquisition of the TAWN assets, which closed in January 2002.
These costs also included $0.6 million of costs incurred on permits operated by
others: $0.2 million of drilling costs and $0.4 million of prospect costs. As of
December 31, 2001, our investment in New Zealand totaled approximately $84.4
million. As we have recorded proved undeveloped reserves relating to our
successful drilling activities, $45.5 million of our investment costs has been
included in the proved properties portion of oil and gas properties and $38.8
million has been included as unproved properties at the end of 2001. Our
development strategy includes having Rimu/Kauri production on line for oil and
gas sales in New Zealand near the end of the first quarter of 2002.
Russia
In 1993, we entered into a Participation Agreement with Senega, a Russian
Federation joint stock company, to assist in the development and production of
reserves from two fields in Western Siberia and received a 5% net profits
interest. We also purchased a 1% net profits interest. Our investment in Russia
was fully impaired in the third quarter of 1998. We retain a minimum 6% net
profits interest from the sale of hydrocarbon products from the fields. The
value of our net profits interest depends upon either the successful development
of production from the fields by others or their sale of the fields.
F-18
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
9. SUBSEQUENT EVENTS
TAWN ACQUISITION. Through our subsidiary, Swift Energy New Zealand
Limited, we acquired Southern Petroleum Exploration Limited ("Southern NZ") from
an affiliate of Shell New Zealand in January 2002 for approximately $54.4
million. Through Southern NZ we now own interests in four onshore producing oil
and gas fields, extensive associated hydrocarbon-processing facilities and
pipelines complementing our existing fields by providing us with access to
export terminals and markets and additional excess processing capacity for both
oil and natural gas. As of December 31, 2001, the reserves associated with this
acquisition were estimated to be approximately 62.1 Bcfe, all of which were
proved developed. This acquisition was accounted for using the purchase method
of accounting. Upon the closing of this acquisition, our credit facility was
increased to $300.0 million, and the borrowing base became $275.0 million.
In conjunction with the TAWN acquisition, we granted Shell New Zealand a
short-term option to acquire an undivided 25% interest in our permit 38719,
which includes our Rimu and Kauri areas, as well as a 25% interest in our Rimu
Production Station. We do not know if Shell New Zealand will exercise this
option. Any exercise of the option would be subject to numerous notifications,
governmental approvals and consents. If Shell New Zealand does not exercise its
option, we intend to pursue discussions with several other companies that have
expressed interest in acquiring up to a 25% interest in the permit.
ANTRIM ACQUISITION. We purchased through our subsidiary, Swift Energy New
Zealand Limited, all of the New Zealand assets owned by Antrim Oil and Gas
Limited for 220,000 shares of Swift Energy Company common stock and an effective
date adjustment of approximately $530,000. Antrim owned a 5% interest in permit
38719 and a 7.5% interest in permit 38716. As of December 31, 2001, the reserves
associated with this acquisition were estimated to be approximately 5.7 Bcfe.
This transaction closed in March 2002 (unaudited).
RUSSIA. On March 28, 2002, we received $7.5 million for our interest in
the Samburg project located in Western Siberia, Russia as a result of the sale
by a third party of its ownership in a Russian joint stock company, which owned
and operated this field. This will result in a $7.5 million non-recurring,
pre-tax gain in the first quarter of 2002 (unaudited).
SUPPLEMENTAL INFORMATION (UNAUDITED)
CAPITALIZED COSTS. The following table presents our aggregate capitalized
costs relating to oil and gas producing activities and the related depreciation,
depletion, and amortization:
TOTAL DOMESTIC NEW ZEALAND
-------------- ------------- -----------
DECEMBER 31, 2001
Proved oil and gas properties.................... $ 974,698,428 $ 929,172,460 $45,525,968
Unproved oil and gas properties.................. 95,943,163 57,096,694 38,846,469
-------------- ------------- -----------
1,070,641,591 986,269,154 84,372,437
Accumulated depreciation, depletion, and
amortization................................... (442,337,531) (442,166,052) (171,479)
-------------- ------------- -----------
Net capitalized costs.................. $ 628,304,060 $ 544,103,102 $84,200,958
============== ============= ===========
DECEMBER 31, 2000
Proved oil and gas properties.................... $ 753,426,124 $ 732,265,674 $21,160,450
Unproved oil and gas properties.................. 55,512,872 46,833,274 8,679,598
-------------- ------------- -----------
808,938,996 779,098,948 29,840,048
Accumulated depreciation, depletion, and
amortization................................... (284,886,168) (284,886,168) --
-------------- ------------- -----------
Net capitalized costs.................. $ 524,052,828 $ 494,212,780 $29,840,048
============== ============= ===========
F-19
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Of the $57,096,694 of domestic unproved property costs (primarily seismic
and lease acquisition costs) at December 31, 2001, excluded from the amortizable
base, $26,707,313 was incurred in 2001, $9,545,964 was incurred in 2000,
$5,640,587 was incurred in 1999, and $15,202,830 was incurred in prior years.
When we are in an active drilling mode, we evaluate the majority of these
unproved costs within a two to four year time frame. In response to market
conditions in 1998, we decreased our 1999 drilling expenditures when compared to
prior years, which, when coupled with the $15.3 million of leasehold properties
acquired in the Brookeland and Masters Creek areas in 1998, may extend the
evaluation time frame of such costs. Consequently, in response to market
conditions, we have decreased our 2002 drilling expenditures as well.
Of the $38,846,469 of net New Zealand unproved property costs at December
31, 2001, excluded from the amortizable base, $30,383,713 was incurred in 2001,
$5,013,539 was incurred in 2000, $907,972 was incurred in 1999, and $2,541,245
was incurred in prior years. We expect to continue drilling in New Zealand to
delineate our prospects there, with seven wells planned for drilling in 2002. We
expect to complete our evaluation of current unevaluated costs over the next two
to three years. Upon the startup of the Rimu Production Station near the end of
the first quarter of 2002, $23.6 million of these unproved property costs will
be moved to the proved properties classification and will begin being
depreciated.
F-20
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
COSTS INCURRED. The following table sets forth costs incurred related to
our oil and gas operations:
YEAR ENDED DECEMBER 31, 2001
-----------------------------------------
TOTAL DOMESTIC NEW ZEALAND
------------ ------------ -----------
Acquisition of proved properties..................... $ 41,286,539 $ 40,491,203 $ 795,336
Lease acquisitions(1)................................ 31,225,493 25,688,068 5,537,425
Exploration.......................................... 41,981,536 35,944,405 6,037,131
Development.......................................... 132,246,713 112,597,856 19,648,857
------------ ------------ -----------
Total acquisition, exploration, and
development(2)........................... $246,740,281 $214,721,532 $32,018,749
------------ ------------ -----------
Processing plants.................................... $ 23,331,095 $ 817,454 $22,513,641
Field compression facilities......................... 319,703 319,703 --
------------ ------------ -----------
Total plants and facilities................ $ 23,650,798 $ 1,137,157 $22,513,641
------------ ------------ -----------
Total costs incurred................................. $270,391,079 $215,858,689 $54,532,390
============ ============ ===========
YEAR ENDED DECEMBER 31, 2000
-----------------------------------------
TOTAL DOMESTIC NEW ZEALAND
------------ ------------ -----------
Acquisition of proved properties.................... $ 34,191,883 $ 34,191,883 $ --
Lease acquisitions(1)............................... 20,842,103 16,315,749 4,526,354
Exploration......................................... 20,150,834 18,524,883 1,625,951
Development......................................... 104,083,409 93,931,500 10,151,909
------------ ------------ -----------
Total acquisition, exploration, and
development(2).......................... $179,268,229 $162,964,015 $16,304,214
------------ ------------ -----------
Processing plants................................... $ 1,819,464 $ 755,119 $ 1,064,345
Field compression facilities........................ 203,789 203,789 --
------------ ------------ -----------
Total plants and facilities............... $ 2,023,253 $ 958,908 $ 1,064,345
------------ ------------ -----------
Total costs incurred................................ $181,291,482 $163,922,923 $17,368,559
============ ============ ===========
YEAR ENDED DECEMBER 31, 1999
-----------------------------------------
TOTAL DOMESTIC NEW ZEALAND
------------ ------------ -----------
Acquisition of proved properties.................... $ 18,526,939 $ 18,526,939 $ --
Lease acquisitions(1)............................... 10,382,672 9,251,658 1,131,014
Exploration......................................... 11,019,430 5,101,330 5,918,100
Development......................................... 39,891,868 39,891,868 --
------------ ------------ -----------
Total acquisition, exploration, and
development(2).......................... $ 79,820,909 $ 72,771,795 $ 7,049,114
------------ ------------ -----------
Processing plants................................... $ 1,607,559 $ 1,607,559 $ --
Field compression facilities........................ 171,535 171,535 --
------------ ------------ -----------
Total plants and facilities............... $ 1,779,094 $ 1,779,094 $ --
------------ ------------ -----------
Total costs incurred................................ $ 81,600,003 $ 74,550,889 $ 7,049,114
============ ============ ===========
---------------
(1) These are actual amounts as incurred by year, including both proved and
unproved lease costs. The annual lease acquisition amounts added to proved
oil and gas properties in 2001, 2000, and 1999 were $22,470,263,
$16,791,834, and $14,389,680, respectively.
(2) Includes capitalized general and administrative costs directly associated
with the acquisition, exploration, and development efforts of approximately
$11,600,000, $10,300,000, and $8,500,000 in 2001, 2000, and 1999,
respectively. In addition, total includes $6,256,222, $5,043,206, and
$4,142,098 in 2001, 2000, and 1999, respectively, of capitalized interest on
unproved properties.
F-21
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
RESULTS OF OPERATIONS. New Zealand operations began in 2001 while all our
oil and gas operations in 2000 and 1999 were domestic. The following table sets
forth results of our oil and gas operations:
YEAR ENDED DECEMBER 31, 2001
--------------------------------------------
TOTAL DOMESTIC NEW ZEALAND
------------ ------------ ------------
Oil and gas sales................................ $181,184,635 $179,360,844 $ 1,823,791
Oil and gas production costs..................... (36,719,609) (36,554,418) (165,191)
Depreciation and depletion....................... (58,589,116) (58,417,637) (171,479)
Write-down of oil and gas properties............. (98,862,247) (98,862,247) --
------------ ------------ ------------
(12,986,337) (14,473,458) 1,487,121
Provision (benefit) for income taxes............. (4,647,810) (5,138,560) 490,750
------------ ------------ ------------
Results of producing activities.................. $ (8,338,527) $ (9,334,898) $ 996,371
============ ============ ============
Amortization per physical unit of production
(equivalent Mcf of gas)........................ $ 1.31 $ 1.32 $ 0.34
============ ============ ============
YEAR ENDED DECEMBER 31, 2000
--------------------------------------------
TOTAL DOMESTIC NEW ZEALAND
------------ ------------ ------------
Oil and gas sales................................ $189,138,947 $189,138,947 $ --
Oil and gas production costs..................... (29,220,315) (29,220,315) --
Depreciation and depletion....................... (46,849,819) (46,849,819) --
------------ ------------ ------------
113,068,813 113,068,813 --
Provision for income taxes....................... 40,365,566 40,365,566 --
------------ ------------ ------------
Results of producing activities.................. $ 72,703,247 $ 72,703,247 $ --
============ ============ ============
Amortization per physical unit of production
(equivalent Mcf of gas)........................ $ 1.11 $ 1.11 $ --
============ ============ ============
YEAR ENDED DECEMBER 31, 1999
--------------------------------------------
TOTAL DOMESTIC NEW ZEALAND
------------ ------------ ------------
Oil and gas sales................................ $108,898,696 $108,898,696 $ --
Oil and gas production costs..................... (19,645,740) (19,645,740) --
Depreciation and depletion....................... (41,410,106) (41,410,106) --
------------ ------------ ------------
47,842,850 47,842,850 --
Provision for income taxes....................... 16,792,840 16,792,840 --
------------ ------------ ------------
Results of producing activities.................. $ 31,050,010 $ 31,050,010 $ --
============ ============ ============
Amortization per physical unit of production
(equivalent Mcf of gas)........................ $ 0.97 $ 0.97 $ --
============ ============ ============
F-22
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
SUPPLEMENTAL RESERVE INFORMATION. The following information presents
estimates of our proved oil and gas reserves. Reserves were determined by us and
audited by H. J. Gruy and Associates, Inc. ("Gruy"), independent petroleum
consultants. Gruy's summary report dated February 14, 2002, is set forth as an
exhibit to the Form 10-K Report for the year ended December 31, 2001, and
includes definitions and assumptions that served as the basis for the audit of
proved reserves and future net cash flows. Such definitions and assumptions
should be referred to in connection with the following information:
Estimates of Proved Reserves
TOTAL DOMESTIC NEW ZEALAND
------------------------- ------------------------- ------------------------
OIL, NGL, OIL, NGL, OIL, NGL,
AND AND AND
NATURAL GAS CONDENSATE NATURAL GAS CONDENSATE NATURAL GAS CONDENSATE
(MCF) (BBLS) (MCF) (BBLS) (MCF) (BBLS)
------------ ---------- ------------ ---------- ----------- ----------
Proved reserves as of December 31,
1998(1)................................ 352,400,835 13,957,925 352,400,835 13,957,925 -- --
Revisions of previous estimates(2)..... (31,189,450) 2,058,725 (31,189,450) 2,058,725 -- --
Purchases of minerals in place......... 9,159,780 1,822,858 9,159,780 1,822,858 -- --
Sales of minerals in place............. (3,762,799) (260,287) (3,762,799) (260,287) -- --
Extensions, discoveries, and other
additions............................ 30,107,908 5,791,966 30,107,908 5,791,966 -- --
Production(3).......................... (26,756,524) (2,564,924) (26,756,524) (2,564,924) -- --
------------ ---------- ------------ ---------- ----------- ----------
Proved reserves as of December 31,
1999(1)................................ 329,959,750 20,806,263 329,959,750 20,806,263 -- --
Revisions of previous estimates(2)..... (4,300,787) (455,606) (4,300,787) (455,606) -- --
Purchases of minerals in place......... 26,567,925 2,196,547 26,567,925 2,196,547 -- --
Sales of minerals in place............. (363,262) (76,288) (363,262) (76,288) -- --
Extensions, discoveries, and other
additions............................ 93,869,841 15,134,694 38,556,364 3,943,807 55,313,477 11,190,887
Production(3).......................... (27,119,491) (2,472,014) (27,119,491) (2,472,014) -- --
------------ ---------- ------------ ---------- ----------- ----------
Proved reserves as of December 31,
2000................................... 418,613,976 35,133,596 363,300,499 23,942,709 55,313,477 11,190,887
Revisions of previous estimates(2)..... (122,127,541) 5,621,556 (101,693,477) 8,460,690 (20,434,064) (2,839,134)
Purchases of minerals in place......... 10,038,803 7,430,591 10,038,803 7,430,591 -- --
Sales of minerals in place............. (7,508,064) (555,586) (7,508,064) (555,586) -- --
Extensions, discoveries, and other
additions............................ 52,353,909 8,907,852 50,810,697 6,257,441 1,543,212 2,650,411
Production............................. (26,458,958) (3,055,373) (26,458,958) (2,971,112) -- (84,261)
------------ ---------- ------------ ---------- ----------- ----------
Proved reserves as of December 31,
2001(4)................................ 324,912,125 53,482,636 288,489,500 42,564,733 36,422,625 10,917,903
============ ========== ============ ========== =========== ==========
Proved developed reserves:
December 31, 1998...................... 197,105,963 7,142,566 197,105,963 7,142,566 -- --
December 31, 1999...................... 174,046,096 8,437,299 174,046,096 8,437,299 -- --
December 31, 2000...................... 215,169,833 10,980,196 215,169,833 10,980,196 -- --
December 31, 2001(4)................... 181,651,578 23,759,574 167,401,736 20,393,142 14,249,842 3,366,432
---------------
(1) Proved reserves exclude quantities subject to our volumetric production
payment agreement, which expired with the last required delivery of volumes
in October 2000.
(2) Revisions of previous estimates are related to upward or downward variations
based on current engineering information for production rates, volumetrics,
and reservoir pressure. Additionally, changes in quantity estimates are
affected by the increase or decrease in crude oil and natural gas prices at
each year end. Proved reserves, as of December 31, 2001, were based upon
prices in effect at year end. The weighted average of such year end prices
for total, domestic, and New Zealand were $2.51, $2.68, and $1.18 per Mcf of
natural gas and $18.45, $18.51, and $18.25 per barrel of oil, respectively.
This compares to $9.86, $11.25, and $0.71 per Mcf and $24.62, $25.50, and
$22.30 per barrel as of December 31, 2000, for total, domestic, and New
Zealand, respectively.
(3) Natural gas production for 1999 and 2000 excludes 728,235 and 405,130 Mcf,
respectively, delivered under our volumetric production payment agreement.
(4) We acquired 62.1 Bcfe and 5.7 Bcfe from the TAWN and Antrim acquisitions,
respectively, in New Zealand. These reserves estimates at December 31, 2001,
are not included in the above table. The TAWN reserves were all proved
developed while the Antrim reserves were 34% proved developed.
F-23
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS. The standardized
measure of discounted future net cash flows relating to proved oil and gas
reserves is as follows:
YEAR ENDED DECEMBER 31, 2001
----------------------------------------------
TOTAL DOMESTIC NEW ZEALAND
-------------- -------------- ------------
Future gross revenues........................... $1,706,475,138 $1,485,480,927 $220,994,211
Future production costs......................... (483,588,857) (436,141,429) (47,447,428)
Future development costs........................ (198,172,628) (185,347,628) (12,825,000)
-------------- -------------- ------------
Future net cash flows before income taxes....... 1,024,713,653 863,991,870 160,721,783
Future income taxes............................. (261,635,331) (208,726,729) (52,908,602)
-------------- -------------- ------------
Future net cash flows after income taxes........ 763,078,322 655,265,141 107,813,181
Discount at 10% per annum....................... (308,520,417) (274,882,174) (33,638,243)
-------------- -------------- ------------
Standardized measure of discounted future net
cash flows relating to proved oil and gas
reserves...................................... $ 454,557,905 $ 380,382,967 $ 74,174,938
============== ============== ============
YEAR ENDED DECEMBER 31, 2000
----------------------------------------------
TOTAL DOMESTIC NEW ZEALAND
-------------- -------------- ------------
Future gross revenues........................... $4,995,951,799 $4,737,560,630 $258,391,169
Future production costs......................... (817,127,348) (807,436,139) (9,691,209)
Future development costs........................ (204,620,116) (180,320,116) (24,300,000)
-------------- -------------- ------------
Future net cash flows before income taxes....... 3,974,204,335 3,749,804,375 224,399,960
Future income taxes............................. (1,321,061,952) (1,243,731,594) (77,330,358)
-------------- -------------- ------------
Future net cash flows after income taxes........ 2,653,142,383 2,506,072,781 147,069,602
Discount at 10% per annum....................... (1,075,183,917) (1,017,995,158) (57,188,759)
-------------- -------------- ------------
Standardized measure of discounted future net
cash flows relating to proved oil and gas
reserves...................................... $1,577,958,466 $1,488,077,623 $ 89,880,843
============== ============== ============
YEAR ENDED DECEMBER 31, 1999
----------------------------------------------
TOTAL DOMESTIC NEW ZEALAND
-------------- -------------- ------------
Future gross revenues........................... $1,371,541,850 $1,371,541,850 $ --
Future production costs......................... (353,594,258) (353,594,258) --
Future development costs........................ (156,738,446) (156,738,446) --
-------------- -------------- ------------
Future net cash flows before income taxes....... 861,209,146 861,209,146 --
Future income taxes............................. (226,725,033) (226,725,033) --
-------------- -------------- ------------
Future net cash flows after income taxes........ 634,484,113 634,484,113 --
Discount at 10% per annum....................... (195,540,279) (195,540,279) --
-------------- -------------- ------------
Standardized measure of discounted future net
cash flows relating to proved oil and gas
reserves...................................... $ 438,943,834 $ 438,943,834 $ --
============== ============== ============
F-24
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The standardized measure of discounted future net cash flows from
production of proved reserves was developed as follows:
1. Estimates are made of quantities of proved reserves and the future
periods during which they are expected to be produced based on year end
economic conditions.
2. The estimated future gross revenues of proved reserves are priced
on the basis of year end prices, except in those instances where fixed and
determinable gas price escalations are covered by contracts limited to the
price we reasonably expect to receive.
3. The future gross revenue streams are reduced by estimated future
costs to develop and to produce the proved reserves, as well as certain
abandonment costs based on year end cost estimates and the estimated effect
of future income taxes.
4. Future income taxes are computed by applying the statutory tax rate
to future net cash flows reduced by the tax basis of the properties, the
estimated permanent differences applicable to future oil and gas producing
activities, and tax carry forwards.
The estimates of cash flows and reserves quantities shown above are based
on year end oil and gas prices for each period. Subsequent changes to such year
end oil and gas prices could have a significant impact on discounted future net
cash flows. Under Securities and Exchange Commission rules, companies that
follow the full cost accounting method are required to make quarterly Ceiling
Test calculations, using prices in effect as of the period end date presented
(see Note 1 to the Consolidated Financial Statements). Application of these
rules during periods of relatively low oil and gas prices, even if of short-term
seasonal duration, may result in write-downs.
The standardized measure of discounted future net cash flows is not
intended to present the fair market value of our oil and gas property reserves.
An estimate of fair value would also take into account, among other things, the
recovery of reserves in excess of proved reserves, anticipated future changes in
prices and costs, an allowance for return on investment, and the risks inherent
in reserve estimates.
F-25
SWIFT ENERGY COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The following are the principal sources of change in the standardized
measure of discounted future net cash flows:
YEAR ENDED DECEMBER 31,
------------------------------------------------
2001 2000 1999
--------------- --------------- ------------
Beginning balance.............................. $ 1,577,958,466 $ 438,943,834 $290,273,103
--------------- --------------- ------------
Revisions to reserves proved in prior years --
Net changes in prices, production costs, and
future development costs.................. (1,692,627,074) 1,523,487,598 123,447,890
Net changes due to revisions in quantity
estimates................................. (93,669,181) (36,102,814) (23,746,974)
Accretion of discount........................ 231,325,481 56,405,451 34,078,501
Other........................................ (204,768,815) (220,119,873) 2,032,696
--------------- --------------- ------------
Total revisions.............................. (1,759,739,589) 1,323,670,362 135,812,113
New field discoveries and extensions, net of
future production and development costs...... 110,213,160 359,265,150 102,582,467
Purchases of minerals in place................. 39,544,163 160,240,785 39,282,292
Sales of minerals in place..................... (50,131,970) (598,021) (5,360,428)
Sales of oil and gas produced, net of
production costs............................. (144,262,145) (159,331,003) (88,196,672)
Previously estimated development costs
incurred..................................... 94,107,760 65,953,028 39,149,732
Net change in income taxes..................... 586,868,060 (610,185,669) (74,598,773)
--------------- --------------- ------------
Net change in standardized measure of
discounted future net cash flows............. (1,123,400,561) 1,139,014,632 148,670,731
--------------- --------------- ------------
Ending balance................................. $ 454,557,905 $ 1,577,958,466 $438,943,834
=============== =============== ============
QUARTERLY RESULTS. The following table presents summarized quarterly
financial information for the years ended December 31, 2000 and 2001:
DILUTED
BASIC EPS EPS
INCOME/ INCOME/ INCOME/
(LOSS) (LOSS) (LOSS)
BEFORE BEFORE BEFORE
EXTRA- EXTRA- EXTRA-
INCOME/ ORDINARY ORDINARY ORDINARY
(LOSS) ITEM AND ITEM AND ITEM AND BASIC DILUTED
BEFORE CHANGE IN NET CHANGE IN CHANGE IN EPS NET EPS NET
INCOME ACCOUNTING INCOME/ ACCOUNTING ACCOUNTING INCOME/ INCOME/
REVENUES TAXES PRINCIPLE (LOSS) PRINCIPLE PRINCIPLE (LOSS) (LOSS)
------------ ------------- ------------- ------------ ---------- ---------- ------- -------
2000
First Quarter......... $ 37,747,645 $ 14,919,044 $ 9,589,828 $ 9,589,828 $ 0.46 $ 0.43 0.46 0.43
Second Quarter........ 46,127,375 22,218,358 14,213,274 14,213,274 0.68 0.61 0.68 0.61
Third Quarter......... 49,525,166 24,748,163 15,832,348 15,832,348 0.74 0.66 0.74 0.66
Fourth Quarter........ 58,224,760 31,193,781 20,178,416 19,548,558 0.93 0.82 0.90 0.80
------------ ------------- ------------ ------------
Total......... $191,624,946 $ 93,079,346 $ 59,813,866 $ 59,184,008 $ 2.82 $ 2.53 $ 2.79 $ 2.51
============ ============= ============ ============
2001
First Quarter......... $ 62,392,014 $ 35,513,130 $ 22,719,653 $ 22,326,785 $ 0.92 $ 0.89 $ 0.91 $ 0.88
Second Quarter........ 52,303,265 23,408,900 14,972,946 14,972,946 0.61 0.59 0.61 0.59
Third Quarter......... 41,244,583 11,607,563 7,420,090 7,420,090 0.30 0.29 0.30 0.29
Fourth Quarter........ 27,867,628 (104,721,926) (67,067,586) (67,067,586) (2.71) (2.71) (2.71) (2.71)
------------ ------------- ------------ ------------
Total......... $183,807,490 $ (34,192,333) $(21,954,897) $(22,347,765) $(0.89) $(0.89) $(0.90) $(0.90)
============ ============= ============ ============
F-26
PROSPECTUS
$350,000,000
[SWIFT ENERGY COMPANY LOGO] SWIFT ENERGY COMPANY
DEBT SECURITIES
COMMON STOCK
PREFERRED STOCK
DEPOSITARY SHARES
WARRANTS
Swift Energy Company may offer and sell from time to time debt securities,
common stock, preferred stock, depositary shares or warrants. We will provide
specific terms of the offering and sale of these securities in supplements to
this prospectus. These terms will include the initial offering price, aggregate
amount of the offering, listing on any securities exchange or quotation system,
risk factors and the agents, dealers or underwriters, if any, to be used in
connection with the sale of these securities. Certain selling shareholders may
also from time to time offer and sell common stock under this prospectus. You
should read this prospectus and any supplement carefully before you invest.
Our common stock is traded on the New York Stock Exchange and the Pacific
Stock Exchange under the symbol "SFY."
This prospectus may not be used to sell securities unless accompanied by a
supplement to this prospectus.
NEITHER THE SECURITIES AND EXCHANGE COMMISSION NOR ANY STATE SECURITIES
COMMISSION HAS APPROVED OR DISAPPROVED OF THESE SECURITIES, OR DETERMINED IF
THIS PROSPECTUS IS TRUTHFUL OR COMPLETE. ANY REPRESENTATION TO THE CONTRARY IS A
CRIMINAL OFFENSE.
The date of this prospectus is July 23, 2001
YOU SHOULD RELY ONLY ON THE INFORMATION CONTAINED IN OR INCORPORATED BY
REFERENCE IN THIS PROSPECTUS AND IN ANY PROSPECTUS SUPPLEMENT. WE HAVE NOT
AUTHORIZED ANYONE TO PROVIDE YOU WITH DIFFERENT INFORMATION. WE ARE NOT MAKING
AN OFFER OF THESE SECURITIES IN ANY STATE WHERE THE OFFER IS NOT PERMITTED. YOU
SHOULD NOT ASSUME THAT THE INFORMATION CONTAINED IN OR INCORPORATED BY REFERENCE
IN THIS PROSPECTUS IS ACCURATE AS OF ANY DATE OTHER THAN THE DATE ON THE FRONT
OF THIS PROSPECTUS OR THE APPLICABLE PROSPECTUS SUPPLEMENT.
---------------------
TABLE OF CONTENTS
PAGE
----
ABOUT THIS PROSPECTUS....................................... 1
WHERE YOU CAN FIND MORE INFORMATION......................... 1
RISK FACTORS................................................ 2
FORWARD-LOOKING STATEMENTS.................................. 3
THE COMPANY................................................. 4
RATIO OF EARNINGS TO FIXED CHARGES.......................... 4
USE OF PROCEEDS............................................. 5
DESCRIPTION OF DEBT SECURITIES.............................. 5
General................................................... 6
Non U.S. Currency......................................... 7
Original Issue Discount Securities........................ 7
Covenants................................................. 7
Registration, Transfer, Payment and Paying Agent.......... 7
Ranking of Debt Securities................................ 8
Global Securities......................................... 9
Outstanding Debt Securities............................... 9
Redemption and Repurchase................................. 9
Conversion and Exchange................................... 9
Consolidation, Merger and Sale of Assets.................. 9
Events of Default......................................... 10
Modification and Waivers.................................. 11
Discharge, Termination and Covenant Termination........... 12
Governing Law............................................. 13
Regarding the Trustees.................................... 13
DESCRIPTION OF CAPITAL STOCK................................ 13
General................................................... 13
Common Stock.............................................. 14
Preferred Stock........................................... 14
Anti-takeover Provisions.................................. 15
DESCRIPTION OF DEPOSITARY SHARES............................ 17
DESCRIPTION OF WARRANTS..................................... 18
SELLING SHAREHOLDERS........................................ 18
PLAN OF DISTRIBUTION........................................ 19
LEGAL OPINIONS.............................................. 20
EXPERTS..................................................... 21
i
ABOUT THIS PROSPECTUS
This prospectus is part of a registration statement that we filed with the
Securities and Exchange Commission using a "shelf" registration process. Under
the shelf process, we may sell any combination of the securities described in
this prospectus in one or more offerings up to a total dollar amount of
$350,000,000. In addition, under this shelf process, one or more selling
shareholders may sell our common stock in one or more offerings, which will
reduce the aggregate dollar amount we may sell. This prospectus provides you
with a general description of the securities we may offer. Each time we sell
securities, we will provide a prospectus supplement that will contain specific
information about the terms of that offering. The prospectus supplement may also
add, update or change information contained in this prospectus. You should read
both this prospectus and any prospectus supplement, together with additional
information described under the heading "WHERE YOU CAN FIND MORE INFORMATION."
As used in this prospectus, "Swift," "we," "us," and "our" refer to Swift
Energy Company and its subsidiaries.
WHERE YOU CAN FIND MORE INFORMATION
We are subject to the informational requirements of the Securities Exchange
Act of 1934, which requires us to file annual, quarterly and special reports,
proxy statements and other information with the Securities and Exchange
Commission, or the "SEC." You may read and copy any document that we file at the
Public Reference Room of the SEC at 450 Fifth Street, N.W., Washington, D.C.
20549. Please call the SEC at 1-800-SEC-0330 for further information on the
operation of its public reference room. You may also inspect our filings at the
regional offices of the SEC located at Citicorp Center, 500 West Madison Street,
Suite 1400, Chicago, Illinois 60661 and 7 World Trade Center, New York, New York
10048 or over the Internet at the SEC's web site at http://www.sec.gov, or at
our own website at http://www.swiftenergy.com.
This prospectus constitutes part of a Registration Statement on Form S-3
filed with the SEC under the Securities Act of 1933. It omits some of the
information contained in the Registration Statement, and reference is made to
the Registration Statement for further information with respect to us and the
securities we are offering. Any statement contained in this prospectus
concerning the provisions of any document filed as an exhibit to the
Registration Statement or otherwise filed with the SEC is not necessarily
complete, and in each instance reference is made to the copy of the filed
document.
The SEC allows us to "incorporate by reference" the information we file
with them, which means that we can disclose important information to you by
referring you to those documents. The information incorporated by reference is
considered to be part of this prospectus, and later information that we file
with the SEC will automatically update and supersede this information and the
information in the prospectus. We incorporate by reference the documents listed
below and any future filings made with the SEC under Sections 13(a), 13(c), 14
or 15(d) of the Securities Exchange Act of 1934 until we sell all the securities
covered by this prospectus:
1. Our Annual Report on Form 10-K for the year ended December 31,
2000;
2. Our Quarterly Report on Form 10-Q for the fiscal quarter ended
March 31, 2001;
3. The description of our common stock contained in our registration
statement on Form 8-A filed on July 24, 1981, as amended, including any
amendment or report filed before or after the date of this prospectus for
the purpose of updating the description; and
4. The description of our preferred share purchase rights contained in
our registration statement on Form 8-A filed on August 11, 1997, as amended
on April 7, 1999, including any amendment or report filed before or after
the date of this prospectus for the purpose of updating the description.
You may request a copy of these filings at no cost, by writing or
telephoning Bruce H. Vincent, Executive Vice President -- Corporate Development,
Swift Energy Company, Suite 400, 16825 Northchase Drive, Houston, Texas 77060,
phone: (281) 874-2700.
1
RISK FACTORS
There are a number of risks associated with investing in Swift and in our
industry. You should carefully review the more detailed description of risk
factors contained in the supplement to this prospectus.
- Our revenue, profitability and cash flow depend upon the prices and
demand for oil and gas. The markets for these commodities are very
volatile and steep or prolonged drops in prices can harm us financially
and hurt our ability to grow.
- Our drilling activities are subject to many risks, including the risk
that we will not discover commercially productive reservoirs. Operating
and developing oil and natural gas properties involves a number of
inherent risks, including the risk of personal injury, environmental
contamination or loss of wells. We may not be able to insure against all
of these risks.
- Our significant growth in recent years is attributable in significant
part to our acquiring producing properties. Our ability to continue to
make successful acquisitions is influenced by many factors beyond our
control. A failure to acquire producing properties on a profitable basis
in the future may significantly affect our profitability and growth.
- Estimates of our proved developed oil and natural gas reserves and the
resulting future net revenues contained in this prospectus and elsewhere
are based on a number of uncertainties. A failure to realize our
estimated prices or estimated production volumes could materially
adversely affect our revenues, profitability and financial health.
- Our ability to conduct operations in a timely and cost effective manner
depends on the availability of supplies, equipment and personnel. The oil
and gas industry is cyclical and experiences periodic shortages of
drilling rigs and other equipment, tubular goods, supplies and
experienced personnel. Shortages can delay operations and materially
increase operating and capital costs.
- We make, and will continue to make, substantial capital expenditures to
acquire, develop, produce, explore and abandon our oil and natural gas
reserves. Any decrease in our revenues, as a result of lower oil or gas
prices or otherwise, could limit our ability to replace reserves or
maintain production at current levels. If our cash flow from operations
drops significantly, we may be unable to find additional debt or equity
financing.
- Our future success depends on our ability to find, develop or acquire
additional oil and natural gas reserves that are economically
recoverable. Failure to do so will result in lower production and cash
flow.
2
FORWARD-LOOKING STATEMENTS
Some of the information included in this prospectus, any prospectus
supplement and the documents we have incorporated by reference contain
forward-looking statements. Forward-looking statements use forward-looking terms
such as "believe," "expect," "may," "intend," "will," "project," "budget,"
"should" or "anticipate" or other similar words. These statements discuss
"forward-looking" information such as:
- anticipated capital expenditures and budgets;
- future cash flows and borrowings;
- pursuit of potential future acquisition or drilling opportunities; and
- sources of funding for exploration and development.
These forward-looking statements are based on assumptions that we believe
are reasonable, but they are open to a wide range of uncertainties and business
risks, including the following:
- fluctuations of the prices received or demand for oil and natural gas;
- uncertainty of drilling results, reserve estimates and reserve
replacement;
- operating hazards;
- acquisition risks;
- unexpected substantial variances in capital requirements;
- environmental matters; and
- general economic conditions.
Other factors that could cause actual results to differ materially from
those anticipated are discussed in our periodic filings with the SEC, including
our Annual Report on Form 10-K for the year ended December 31, 2000.
When considering these forward-looking statements, you should keep in mind
the risk factors and other cautionary statements in this prospectus, any
prospectus supplement and the documents we have incorporated by reference. We
will not update these forward-looking statements unless the securities laws
require us to do so.
3
THE COMPANY
Swift Energy Company, a Texas corporation, is engaged in the exploration,
development, acquisition and operation of oil and gas properties. Historically,
our primary focus has been on U.S. onshore natural gas reserves, although we are
now also focusing on our operations in New Zealand and have interests offshore
in the Gulf of Mexico. As of December 31, 2000, we had interests in 1,528 oil
and gas wells located in eight states, offshore in the Gulf of Mexico and in New
Zealand. We operated 817 of these wells, representing 91% of our proved
reserves. At such date, our estimated proved reserves were 629.4 Bcfe, of which
approximately 67% was natural gas, with 54% of our reserves located in Texas,
22% in Louisiana and 20% in New Zealand.
Our core domestic areas for development and exploration drilling are the
AWP Olmos Area located in South Texas and the Brookeland Area, the Giddings Area
and the Masters Creek Area in the Austin Chalk trend in Texas and Louisiana. We
expect our reserves in the AWP Olmos Field to be steadily produced over a long
period. This offsets the Austin Chalk trend reserves, which have a high initial
production but decline rapidly. The AWP Olmos Field accounted for approximately
37% of our proved reserves as of December 31, 2000 and approximately 32% of our
2000 production, while the Austin Chalk trend accounted for approximately 35% of
our proved reserves as of December 31, 2000 and generated approximately 62% of
our 2000 production. New Zealand accounted for approximately 20% of our proved
reserves as of December 31, 2000 and had not yet produced as of December 31,
2000. Subsequent to year-end 2000, we acquired interests in Lake Washington
Field in Louisiana for $30.5 million.
We have increased our proved reserves from 176.1 Bcfe at year-end 1995 to
629.4 Bcfe at year-end 2000, which represents the replacement of 375% of our
production during the same period. Our five-year average reserves replacement
costs were $0.94 per Mcfe. A combination of increased production and decreased
operating costs per Mcfe resulted in average annual growth in net cash provided
by operating activities of 55% per year from year-end 1995 to year-end 2000.
Swift's philosophy is to pursue a balanced growth strategy that includes an
active drilling program, strategic acquisitions, and the utilization of advanced
technologies. We seek to increase our reserves through both drilling and
acquisitions, shifting the balance between the two activities in response to
market conditions. For example, when oil and gas prices are low, we focus upon
acquiring producing properties. When oil and gas prices are high, we shift our
focus to drilling wells.
Following the fall in oil and gas prices during mid-1998, we grew primarily
by increasing our acreage position, mainly through the Toledo Bend properties
acquisition in Texas and Louisiana purchased from Sonat Exploration Company.
Capital expenditures for development and exploration drilling were $67.4 million
in 1998 and $44 million in 1999, while the amounts spent for acquisitions were
$59.5 million in 1998 and $20.6 million in 1999. In 2000 drilling expenditures
totaled $115.5 million, while $33.4 million was spent to acquire producing
properties, primarily in the third quarter. Most of our drilling activities were
in the AWP Olmos Field, the Austin Chalk trend and New Zealand.
Our principal executive offices are located at 16825 Northchase Drive,
Suite 400, Houston, Texas 77060 and our telephone number is (281) 874-2700.
RATIO OF EARNINGS TO FIXED CHARGES
The following table sets forth our ratio of earnings to fixed charges:
THREE MONTHS
ENDED
YEARS ENDED DECEMBER 31, MARCH 31,
--------------------------------- -------------
1996 1997 1998 1999 2000 2000 2001
----- ---- ---- ---- ---- ----- -----
Ratio of earnings to fixed charges..... 12.8x 5.2x -- 2.4x 5.2x 3.6x 9.1x
Due to the $90.8 million non-cash charge incurred in the year ended
December 31, 1998 caused by a write down in the carrying value of natural gas
and oil properties, 1998 earnings were insufficient by
4
$76.9 million to cover fixed charges in 1998. If the $90.8 million non-cash
charge is excluded, the ratio of earnings to fixed charges would have been 2.1x.
For the purpose of computing the ratio of earnings to fixed charges,
earnings are defined as:
- income from continuing operations before income taxes;
- plus fixed charges; and
- less capitalized interest.
Fixed charges are defined as the sum of the following:
- interest, including capitalized interest, on all indebtedness;
- amortization of debt issuance cost; and
- that portion of rental expense which we believe to be representative of
an interest factor.
USE OF PROCEEDS
Unless we specify otherwise in an accompanying prospectus supplement, we
intend to use the net proceeds we receive from the sale of securities offered by
this prospectus and the accompanying prospectus supplement for the repayment of
debt under our credit lines and for general corporate purposes. General
corporate purposes may include additions to working capital, development and
exploration expenditures or the financing of possible acquisitions. We will not
receive any proceeds from any sale of common stock by selling shareholders.
The net proceeds may be invested temporarily until they are used for their
stated purpose.
DESCRIPTION OF DEBT SECURITIES
This section describes the general terms and provisions of the debt
securities which may be offered by us from time to time. The applicable
prospectus supplement will describe the specific terms of the debt securities
offered by that prospectus supplement.
We may issue debt securities either separately or together with, or upon
the conversion of, or in exchange for, other securities. The debt securities are
to be either senior obligations of ours issued in one or more series and
referred to herein as the "Senior Debt Securities," or subordinated obligations
of ours issued in one or more series and referred to herein as the "Subordinated
Debt Securities." The Senior Debt Securities and the Subordinated Debt
Securities are collectively referred to as the "Debt Securities." The Debt
Securities will be general obligations of the Company. Each series of Debt
Securities will be issued under an agreement, or "Indenture," between Swift and
an independent third party, usually a bank or trust company, known as a
"Trustee," who will be legally obligated to carry out the terms of the
Indenture. The name(s) of the Trustee(s) will be set forth in the applicable
prospectus supplement. We may issue all the Debt Securities under the same
Indenture, as one or as separate series, as specified in the applicable
prospectus supplement(s).
This summary of certain terms and provisions of the Debt Securities and
Indentures is not complete. If we refer to particular provisions of an
Indenture, the provisions, including definitions of certain terms, are
incorporated by reference as a part of this summary. The Indentures are or will
be filed as an exhibit to the registration statement of which this prospectus is
a part, or as exhibits to documents filed under the Securities Exchange Act of
1934 which are incorporated by reference into this prospectus. The Indentures
are subject to and governed by the Trust Indenture Act of 1939, as amended. You
should refer to the applicable Indenture for the provisions which may be
important to you.
5
GENERAL
The Indentures will not limit the amount of Debt Securities which we may
issue. We may issue Debt Securities up to an aggregate principal amount as we
may authorize from time to time. The applicable prospectus supplement will
describe the terms of any Debt Securities being offered, including:
- the title and aggregate principal amount;
- the date(s) when principal is payable;
- the interest rate, if any, and the method for calculating the interest
rate;
- the interest payment dates and the record dates for the interest
payments;
- the places where the principal and interest will be payable;
- any mandatory or optional redemption or repurchase terms or prepayment,
conversion, sinking fund or exchangeability or convertibility provisions;
- whether such Debt Securities will be Senior Debt Securities or
Subordinated Debt Securities and, if Subordinated Debt Securities, the
subordination provisions and the applicable definition of "Senior
Indebtedness";
- additional provisions, if any, relating to the defeasance and covenant
defeasance of the Debt Securities;
- if other than denominations of $1,000 or multiples of $1,000, the
denominations the Debt Securities will be issued in;
- whether the Debt Securities will be issued in the form of Global
Securities, as defined below, or certificates;
- whether the Debt Securities will be issuable in registered form, referred
to as "Registered Securities," or in bearer form, referred to as "Bearer
Securities" or both and, if Bearer Securities are issuable, any
restrictions applicable to the exchange of one form for another and the
offer, sale and delivery of Bearer Securities;
- any applicable material federal tax consequences;
- the dates on which premiums, if any, will be payable;
- our right, if any, to defer payment of interest and the maximum length of
such deferral period;
- any paying agents, transfer agents, registrars or trustees;
- any listing on a securities exchange;
- if convertible into common stock or preferred stock, the terms on which
such Debt Securities are convertible;
- the terms, if any, of the transfer, mortgage, pledge, or assignment as
security for any series of Debt Securities of any properties, assets,
proceeds, securities or other collateral, including whether certain
provisions of the Trust Indenture Act are applicable, and any
corresponding changes to provisions of the Indenture as currently in
effect;
- the initial offering price; and
- other specific terms, including covenants and any additions or changes to
the events of default provided for with respect to the Debt Securities.
The terms of the Debt Securities of any series may differ and, without the
consent of the holders of the Debt Securities of any series, we may reopen a
previous series of Debt Securities and issue additional
6
Debt Securities of such series or establish additional terms of such series,
unless otherwise indicated in the applicable prospectus supplement.
NON U.S. CURRENCY
If the purchase price of any Debt Securities is payable in a currency other
than U.S. dollars or if principal of, or premium, if any, or interest, if any,
on any of the Debt Securities is payable in any currency other than U.S.
dollars, the specific terms with respect to such Debt Securities and such
foreign currency will be specified in the applicable prospectus supplement.
ORIGINAL ISSUE DISCOUNT SECURITIES
Debt Securities may be issued as "Original Issue Discount Securities" to be
sold at a substantial discount below their principal amount. Original Issue
Discount Securities may include "zero coupon" securities that do not pay any
cash interest for the entire term of the securities. In the event of an
acceleration of the maturity of any Original Issue Discount Security, the amount
payable to the holder thereof upon such acceleration will be determined in the
manner described in the applicable prospectus supplement. Conditions pursuant to
which payment of the principal of the Subordinated Debt Securities may be
accelerated will be set forth in the applicable prospectus supplement. Material
federal income tax and other considerations applicable to Original Issue
Discount Securities will be described in the applicable prospectus supplement.
COVENANTS
Under the Indentures, we will be required to:
- pay the principal, interest and any premium on the Debt Securities when
due;
- maintain a place of payment;
- deliver a report to the Trustee at the end of each fiscal year reviewing
our obligations under the Indentures; and
- deposit sufficient funds with any paying agent on or before the due date
for any principal, interest or any premium.
Any additional covenants will be described in the applicable prospectus
supplement.
REGISTRATION, TRANSFER, PAYMENT AND PAYING AGENT
Unless otherwise indicated in a prospectus supplement, each series of Debt
Securities will be issued in registered form only, without coupons. The
Indentures, however, provide that we may also issue Debt Securities in bearer
form only, or in both registered and bearer form. Bearer Securities shall not be
offered, sold, resold or delivered in connection with their original issuance in
the United States or to any United States person other than offices located
outside the United States of certain United States financial institutions.
"United States person" means any citizen or resident of the United States, any
corporation, partnership or other entity created or organized in or under the
laws of the United States, any estate the income of which is subject to United
States federal income taxation regardless of its source, or any trust whose
administration is subject to the primary supervision of a United States court
and which has one or more United States fiduciaries who have the authority to
control all substantial decisions of the trust. "United States" means the United
States of America (including the states thereof and the District of Columbia),
its territories, its possessions and other areas subject to its jurisdiction.
Purchasers of Bearer Securities will be subject to certification procedures and
may be affected by certain limitations under United States tax laws. Such
procedures and limitations will be described in the prospectus supplement
relating to the offering of the Bearer Securities.
7
Unless otherwise indicated in a prospectus supplement, Registered
Securities will be issued in denominations of $1,000 or any integral multiple
thereof, and Bearer Securities will be issued in denominations of $5,000.
Unless otherwise indicated in a prospectus supplement, the principal,
premium, if any, and interest, if any, of or on the Debt Securities will be
payable, and Debt Securities may be surrendered for registration of transfer or
exchange, at an office or agency to be maintained by us in the Borough of
Manhattan, The City of New York, provided that payments of interest with respect
to any Registered Security may be made at our option by check mailed to the
address of the person entitled to payment or by transfer to an account
maintained by the payee with a bank located in the United States. No service
charge shall be made for any registration of transfer or exchange of Debt
Securities, but we may require payment of a sum sufficient to cover any tax or
other governmental charge and any other expenses that may be imposed in
connection with the exchange or transfer.
Unless otherwise indicated in a prospectus supplement, payment of principal
of, premium, if any, and interest, if any, on Bearer Securities will be made,
subject to any applicable laws and regulations, at such office or agency outside
the United States as specified in the prospectus supplement and as we may
designate from time to time. Unless otherwise indicated in a prospectus
supplement, payment of interest due on Bearer Securities on any interest payment
date will be made only against surrender of the coupon relating to such interest
payment date. Unless otherwise indicated in a prospectus supplement, no payment
of principal, premium or interest with respect to any Bearer Security will be
made at any office or agency in the United States or by check mailed to any
address in the United States or by transfer to an account maintained with a bank
located in the United States; except that if amounts owing with respect to any
Bearer Securities shall be payable in U.S. dollars, payment may be made at the
Corporate Trust Office of the applicable Trustee or at any office or agency
designated by us in the Borough of Manhattan, The City of New York, if (but only
if) payment of the full amount of such principal, premium or interest at all
offices outside of the United States maintained for such purpose by us is
illegal or effectively precluded by exchange controls or similar restrictions.
Unless otherwise indicated in the applicable prospectus supplement, we will
not be required to:
- issue, register the transfer of or exchange Debt Securities of any series
during a period beginning at the opening of business 15 days before any
selection of Debt Securities of that series of like tenor to be redeemed
and ending at the close of business on the day of that selection;
- register the transfer of or exchange any Registered Security, or portion
thereof, called for redemption, except the unredeemed portion of any
Registered Security being redeemed in part;
- exchange any Bearer Security called for redemption, except to exchange
such Bearer Security for a Registered Security of that series and like
tenor that is simultaneously surrendered for redemption; or
- issue, register the transfer of or exchange any Debt Security which has
been surrendered for repayment at the option of the holder, except the
portion, if any, of the Debt Security not to be so repaid.
RANKING OF DEBT SECURITIES
The Senior Debt Securities will be unsubordinated obligations of ours and
will rank equally in right of payment with all other unsubordinated indebtedness
of ours. The Subordinated Debt Securities will be obligations of ours and will
be subordinated in right of payment to all existing and future Senior
Indebtedness. The prospectus supplement will describe the subordination
provisions and set forth the definition of "Senior Indebtedness" applicable to
the Subordinated Debt Securities, and will set forth the approximate amount of
such Senior Indebtedness outstanding as of a recent date.
8
GLOBAL SECURITIES
The Debt Securities of a series may be issued in whole or in part in the
form of one or more global securities that will be deposited with, or on behalf
of, a "Depositary" identified in the prospectus supplement relating to such
series. Global Debt Securities may be issued in either registered or bearer form
and in either temporary or permanent form. Unless and until it is exchanged in
whole or in part for individual certificates evidencing Debt Securities, a
Global Debt Security may not be transferred except as a whole:
- by the Depositary to a nominee of such Depositary;
- by a nominee of such Depositary to such Depositary or another nominee of
such Depositary; or
- by such Depositary or any such nominee to a successor of such Depositary
or a nominee of such successor.
The specific terms of the depositary arrangement with respect to a series
of Global Debt Securities and certain limitations and restrictions relating to a
series of Global Bearer Securities will be described in the applicable
prospectus supplement.
OUTSTANDING DEBT SECURITIES
In determining whether the holders of the requisite principal amount of
outstanding Debt Securities have given any authorization, demand, direction,
notice, consent or waiver under the relevant Indenture, the amount of
outstanding Debt Securities will be calculated based on the following:
- the portion of the principal amount of an Original Issue Discount
Security that shall be deemed to be outstanding for such purposes shall
be that portion of the principal amount thereof that could be declared to
be due and payable upon a declaration of acceleration pursuant to the
terms of such Original Issue Discount Security as of the date of such
determination;
- the principal amount of a Debt Security denominated in a currency other
than U.S. dollars shall be the U.S. dollar equivalent, determined on the
date of original issue of such Debt Security, of the principal amount of
such Debt Security; and
- any Debt Security owned by us or any obligor on such Debt Security or any
affiliate of us or such other obligor shall be deemed not to be
outstanding.
REDEMPTION AND REPURCHASE
The Debt Securities may be redeemable at our option, may be subject to
mandatory redemption pursuant to a sinking fund or otherwise, or may be subject
to repurchase by Swift at the option of the holders, in each case upon the
terms, at the times and at the prices set forth in the applicable prospectus
supplement.
CONVERSION AND EXCHANGE
The terms, if any, on which Debt Securities of any series are convertible
into or exchangeable for common stock, preferred stock, or other Debt Securities
will be set forth in the applicable prospectus supplement. Such terms of
conversion or exchange may be either mandatory, at the option of the holders, or
at our option.
CONSOLIDATION, MERGER AND SALE OF ASSETS
Each Indenture generally will permit a consolidation or merger, subject to
certain limitations and conditions, between us and another corporation. They
also will permit the sale by us of all or substantially all of our property and
assets. If this happens, the remaining or acquiring corporation shall assume all
of
9
our responsibilities and liabilities under the Indentures including the payment
of all amounts due on the Debt Securities and performance of the covenants in
the Indentures.
We are only permitted to consolidate or merge with or into any other
corporation or sell all or substantially all of our assets according to the
terms and conditions of the Indentures, as indicated in the applicable
prospectus supplement. The remaining or acquiring corporation will be
substituted for us in the Indentures with the same effect as if it had been an
original party to the Indenture. Thereafter, the successor corporation may
exercise our rights and powers under any Indenture, in our name or in its own
name. Any act or proceeding required or permitted to be done by our board of
directors or any of our officers may be done by the board or officers of the
successor corporation.
EVENTS OF DEFAULT
Unless otherwise specified in the applicable prospectus supplement, an
Event of Default, as defined in the Indentures and applicable to Debt Securities
issued under such Indentures, typically will occur with respect to the Debt
Securities of any series under the Indenture upon:
- default for a period to be specified in the applicable prospectus
supplement in payment of any interest with respect to any Debt Security
of such series;
- default in payment of principal or any premium with respect to any Debt
Security of such series when due upon maturity, redemption, repurchase at
the option of the holder or otherwise;
- default in deposit of any sinking fund payment when due with respect to
any Debt Security of such series;
- default by us in the performance, or breach, of any other covenant or
warranty in such Indenture, which shall not have been remedied for a
period to be specified in the applicable prospectus supplement after
notice to us by the applicable Trustee or the holders of not less than a
fixed percentage in aggregate principal amount of the Debt Securities of
all series issued under the applicable Indenture;
- certain events of bankruptcy, insolvency or reorganization of Swift; or
- any other Event of Default that may be set forth in the applicable
prospectus supplement, including an Event of Default based on other debt
being accelerated, known as a "cross-acceleration."
No Event of Default with respect to any particular series of Debt
Securities necessarily constitutes an Event of Default with respect to any other
series of Debt Securities. If the Trustee considers it in the interest of the
holders to do so, the Trustee under an Indenture may withhold notice of the
occurrence of a default with respect to the Debt Securities to the holders of
any series outstanding, except a default in payment of principal, premium, if
any, interest, if any.
Each Indenture will provide that if an Event of Default with respect to any
series of Debt Securities issued thereunder shall have occurred and be
continuing, either the relevant Trustee or the holders of at least a fixed
percentage in principal amount of the Debt Securities of such series then
outstanding may declare the principal amount of all the Debt Securities of such
series to be due and payable immediately. In the case of Original Issue Discount
Securities, the Trustee may declare as due and payable such lesser amount as may
be specified in the applicable prospectus supplement. However, upon certain
conditions, such declaration and its consequences may be rescinded and annulled
by the holders of at least a fixed percentage in principal amount of the Debt
Securities of all series issued under the applicable Indenture.
The applicable prospectus supplement will provide the terms pursuant to
which an Event of Default shall result in acceleration of the payment of
principal of Subordinated Debt Securities.
In the case of a default in the payment of principal of, or premium, if
any, or interest, if any, on any Subordinated Debt Securities of any series, the
applicable Trustee, subject to certain limitations and conditions, may institute
a judicial proceeding for the collection thereof.
10
No holder of any of the Debt Securities of any series will have any right
to institute any proceeding with respect to the Indenture or any remedy
thereunder, unless the holders of at least a fixed percentage in principal
amount of the outstanding Debt Securities of such series:
- have made written request to the Trustee to institute such proceeding as
Trustee, and offered reasonable indemnity to the Trustee,
- the Trustee has failed to institute such proceeding within the time
period specified in the applicable prospectus supplement after receipt of
such notice, and
- the Trustee has not within such period received directions inconsistent
with such written request by holders of a majority in principal amount of
the outstanding Debt Securities of such series. Such limitations do not
apply, however, to a suit instituted by a holder of a Debt Security for
the enforcement of the payment of the principal of, premium, if any, or
any accrued and unpaid interest on, the Debt Security on or after the
respective due dates expressed in the Debt Security.
During the existence of an Event of Default under an Indenture, the Trustee
is 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, if an Event of Default shall occur and be continuing, the
Trustee is under no obligation to exercise any of its rights or powers under the
Indenture at the request or direction of any of the holders, 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 at least
a fixed percentage in principal amount of the outstanding Debt Securities of any
series have the right to direct the time, method and place of conducting any
proceeding for any remedy available to the Trustee, or exercising any power
conferred on the Trustee with respect to such series.
The Indentures provide that the Trustee will, within the time period
specified in the applicable prospectus supplement after the occurrence of any
default, give to the holders of the Debt Securities of such series notice of
such default known to it, unless such default shall have been cured or waived;
provided that the Trustee shall be protected in withholding such notice if it
determines in good faith that the withholding of such notice is in the interest
of such holders, except in the case of a default in payment of principal of or
premium, if any, on any Debt Security of such series when due or in the case of
any default in the payment of any interest on the Debt Securities of such
series.
Swift is required to furnish to the Trustee annually a statement as to
compliance with all conditions and covenants under the Indentures.
MODIFICATION AND WAIVERS
From time to time, when authorized by resolutions of our board of directors
and by the Trustee, without the consent of the holders of Debt Securities of any
series, we may amend, waive or supplement the Indentures and the Debt Securities
of such series for certain specified purposes, including, among other things:
- to cure ambiguities, defects or inconsistencies;
- to provide for the assumption of our obligations to holders of the Debt
Securities of such series in the case of a merger or consolidation;
- to add to our Events of Default or our covenants or to make any change
that would provide any additional rights or benefits to the holders of
the Debt Securities of such series;
- to add or change any provisions of such Indenture to facilitate the
issuance of Bearer Securities;
- to establish the form or terms of Debt Securities of any series and any
related coupons;
- to add guarantors with respect to the Debt Securities of such series;
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- to secure the Debt Securities of such series;
- to maintain the qualification of the Indenture under the Trust Indenture
Act; or
- to make any change that does not adversely affect the rights of any
holder.
Other amendments and modifications of the Indentures or the Debt Securities
issued thereunder may be made by Swift and the Trustee with the consent of the
holders of not less than a fixed percentage of the aggregate principal amount of
the outstanding Debt Securities of each series affected, with each series voting
as a separate class; provided that, without the consent of the holder of each
outstanding Debt Security affected, no such modification or amendment may:
- reduce the principal amount of, or extend the fixed maturity of the Debt
Securities, or alter or waive any redemption, repurchase or sinking fund
provisions of the Debt Securities;
- reduce the amount of principal of any Original Issue Discount Securities
that would be due and payable upon an acceleration of the maturity
thereof;
- change the currency in which any Debt Securities or any premium or the
accrued interest thereon is payable;
- reduce the percentage in principal amount outstanding of Debt Securities
of any series which must consent to an amendment, supplement or waiver or
consent to take any action under the Indenture or the Debt Securities of
such series;
- impair the right to institute suit for the enforcement of any payment on
or with respect to the Debt Securities;
- waive a default in payment with respect to the Debt Securities or any
guarantee;
- reduce the rate or extend the time for payment of interest on the Debt
Securities;
- adversely affect the ranking of the Debt Securities of any series;
- release any guarantor from any of its obligations under its guarantee or
the Indenture, except in compliance with the terms of the Indenture; or
- solely in the case of a series of Subordinated Debt Securities, modify
any of the applicable subordination provisions or the applicable
definition of Senior Indebtedness in a manner adverse to any holders.
The holders of a fixed percentage in aggregate principal amount of the
outstanding Debt Securities of any series may waive compliance by us with
certain restrictive provisions of the relevant Indenture, including any set
forth in the applicable prospectus supplement. The holders of a fixed percentage
in aggregate principal amount of the outstanding Debt Securities of any series
may, on behalf of the holders of that series, waive any past default under the
applicable Indenture with respect to that series and its consequences, except a
default in the payment of the principal of, or premium, if any, or interest, if
any, on any Debt Securities of such series, or in respect of a covenant or
provision which cannot be modified or amended without the consent of a larger
fixed percentage of holders or by the holder of each outstanding Debt Securities
of the series affected.
DISCHARGE, TERMINATION AND COVENANT TERMINATION
When we establish a series of Debt Securities, we may provide that such
series is subject to the termination and discharge provisions of the applicable
Indenture. If those provisions are made applicable, we may elect either:
- to terminate and be discharged from all of our obligations with respect
to those Debt Securities subject to some limitations; or
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- to be released from our obligations to comply with specified covenants
relating to those Debt Securities, as described in the applicable
prospectus supplement.
To effect that termination or covenant termination, we must irrevocably
deposit in trust with the relevant Trustee an amount which, through the payment
of principal and interest in accordance with their terms, will provide money
sufficient to make payments on those Debt Securities and any mandatory sinking
fund or similar payments on those Debt Securities. This deposit may be made in
any combination of funds or government obligations. On such a termination, we
will not be released from certain of our obligations that will be specified in
the applicable prospectus supplement.
To establish such a trust we must deliver to the relevant Trustee an
opinion of counsel to the effect that the holders of those Debt Securities:
- will not recognize income, gain or loss for U.S. federal income tax
purposes as a result of the termination or covenant termination; and
- will be subject to U.S. federal income tax on the same amounts, in the
same manner and at the same times as would have been the case if the
termination or covenant termination had not occurred.
If we effect covenant termination with respect to any Debt Securities, the
amount of deposit with the relevant Trustee must be sufficient to pay amounts
due on the Debt Securities at the time of their stated maturity. However, those
Debt Securities may become due and payable prior to their stated maturity if
there is an Event of Default with respect to a covenant from which we have not
been released. In that event, the amount on deposit may not be sufficient to pay
all amounts due on the Debt Securities at the time of the acceleration.
The applicable prospectus supplement may further describe the provisions,
if any, permitting termination or covenant termination, including any
modifications to the provisions described above.
GOVERNING LAW
The Indentures and the Debt Securities will be governed by, and construed
in accordance with, the laws of the State of New York.
REGARDING THE TRUSTEES
The Trust Indenture Act contains limitations on the rights of a trustee,
should it become a creditor of ours, 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. Each Trustee is permitted to engage in other
transactions with us from time to time, provided that if such Trustee acquires
any conflicting interest, it must eliminate such conflict upon the occurrence of
an Event of Default under the relevant Indenture, or else resign.
DESCRIPTION OF CAPITAL STOCK
GENERAL
As of the date of this prospectus, we are authorized to issue up to
90,000,000 shares of stock, including up to 85,000,000 shares of common stock
and up to 5,000,000 shares of preferred stock. As of March 31, 2001, we had
24,709,565 shares of common stock and no shares of preferred stock outstanding.
As of that date, we also had approximately 2,153,865 shares of common stock
subject to issuance upon exercise of outstanding options.
The following is a summary of the key terms and provisions of our equity
securities. You should refer to the applicable provisions of our articles of
incorporation, bylaws, the Texas Business Corporation Act
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and the documents we have incorporated by reference for a complete statement of
the terms and rights of our capital stock.
COMMON STOCK
Voting Rights. Each holder of common stock is entitled to one vote per
share. Subject to the rights, if any, of the holders of any series of preferred
stock pursuant to applicable law or the provision of the certificate of
designation creating that series, all voting rights are vested in the holders of
shares of common stock. Holders of shares of common stock have noncumulative
voting rights, which means that the holders of more than 50% of the shares
voting for the election of directors can elect 100% of the directors, and the
holders of the remaining shares voting for the election of directors will not be
able to elect any directors.
Dividends. Dividends may be paid to the holders of common stock when, as
and if declared by the board of directors out of funds legally available for
their payment, subject to the rights of holders of any preferred stock. Swift
has never declared a cash dividend and intends to continue its policy of using
retained earnings for expansion of its business.
Rights upon Liquidation. In the event of our voluntary or involuntary
liquidation, dissolution or winding up, the holders of common stock will be
entitled to share equally, in proportion to the number of shares of common stock
held by them, in any of our assets available for distribution after the payment
in full of all debts and distributions and after the holders of all series of
outstanding preferred stock, if any, have received their liquidation preferences
in full.
Non-Assessable. All outstanding shares of common stock are fully paid and
non-assessable. Any additional common stock we offer and issue under this
Prospectus will also be fully paid and non-assessable.
No Preemptive Rights. Holders of common stock are not entitled to
preemptive purchase rights in future offerings of our common stock.
Listing. Our outstanding shares of common stock are listed on the New York
Stock Exchange and the Pacific Stock Exchange under the symbol "SFY." Any
additional common stock we issue will also be listed on the NYSE and the PSE.
PREFERRED STOCK
Our board of directors can, without approval of our shareholders, issue one
or more series of preferred stock and determine the number of shares of each
series and the rights, preferences and limitations of each series. The following
description of the terms of the preferred stock sets forth certain general terms
and provisions of our authorized preferred stock. If we offer preferred stock, a
description will be filed with the SEC and the specific designations and rights
will be described in a prospectus supplement, including the following terms:
- the series, the number of shares offered and the liquidation value of the
preferred stock;
- the price at which the preferred stock will be issued;
- the dividend rate, the dates on which the dividends will be payable and
other terms relating to the payment of dividends on the preferred stock;
- the liquidation preference of the preferred stock;
- the voting rights of the preferred stock;
- whether the preferred stock is redeemable or subject to a sinking fund,
and the terms of any such redemption or sinking fund;
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- whether the preferred stock is convertible or exchangeable for any other
securities, and the terms of any such conversion; and
- any additional rights, preferences, qualifications, limitations and
restrictions of the preferred stock.
The description of the terms of the preferred stock to be set forth in an
applicable prospectus supplement will not be complete and will be subject to and
qualified in its entirety by reference to the certificate of designation
relating to the applicable series of preferred stock. The registration statement
of which this prospectus forms a part will include the certificate of
designation as an exhibit or incorporate it by reference.
Undesignated preferred stock may enable our board of directors to render
more difficult or to discourage an attempt to obtain control of us by means of a
tender offer, proxy contest, merger or otherwise, and to thereby protect the
continuity of our management. The issuance of shares of preferred stock may
adversely affect the rights of the holders of our common stock. For example, any
preferred stock issued may rank prior to our common stock as to dividend rights,
liquidation preference or both, may have full or limited voting rights and may
be convertible into shares of common stock. As a result, the issuance of shares
of preferred stock may discourage bids for our common stock or may otherwise
adversely affect the market price of our common stock or any existing preferred
stock.
Any preferred stock will, when issued, be fully paid and non-assessable.
ANTI-TAKEOVER PROVISIONS
Certain provisions in our articles of incorporation, bylaws and our
shareholders' rights plan may encourage persons considering unsolicited tender
offers or other unilateral takeover proposals to negotiate with our board of
directors rather than pursue non-negotiated takeover attempts.
Our Classified Board of Directors. Our bylaws provide that our board of
directors is divided into three classes as nearly equal in number as possible.
The directors of each class are elected for three-year terms, and the terms of
the three classes are staggered so that directors from a single class are
elected at each annual meeting of stockholders. A staggered board makes it more
difficult for shareholders to change the majority of the directors and instead
promotes continuity of existing management.
Our Ability to Issue Preferred Stock. As discussed above, our board of
directors can set the voting rights, redemption rights, conversion rights and
other rights relating to authorized but unissued shares of preferred stock and
could issue that stock in either private or public transactions. Preferred stock
could be issued for the purpose of preventing a merger, tender offer or other
takeover attempt which the board of directors opposes.
Our Rights Plan. Our board of directors has adopted a stockholders' rights
plan. The rights attach to all common stock certificates representing
outstanding shares. One right is issued for each share of common stock
outstanding. Each right entitles the registered holder, under the circumstances
described below, to purchase from us one one-thousandth of a share of our Series
A Junior Participating Preferred Stock, a "Series A" share, at a price of
$150.00 per one one-thousandth of a Series A share, subject to adjustment. The
dividend and liquidation rights and the non-redemption feature of the Series A
shares are designed so that the value of one one-thousandth of a Series A share
purchasable upon exercise of each right will approximate the value of one share
of common stock. The following is a summary of the terms of the rights plan. You
should refer to the applicable provisions of the rights plan which we have
incorporated by reference as an exhibit to the registration statement of which
this prospectus is a part.
The rights will separate from the common stock and right certificates will
be distributed to the holders of common stock as of the earlier of:
- 10 business days following a public announcement that a person or group
of affiliated persons has acquired beneficial ownership of 15% or more of
our outstanding voting shares, or
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- 10 business days following the commencement or announcement of an
intention to commence a tender offer or exchange offer which would result
in a person or group beneficially owning 15% or more of our outstanding
voting shares.
The rights are not exercisable until rights certificates are distributed.
The rights will expire on July 31, 2007 unless that date is extended or the
rights are earlier redeemed or exchanged.
If a person or group (with certain exceptions for investment advisers)
acquires 15% or more of our voting shares, each right then outstanding, other
than rights beneficially owned by such person or group, becomes a right to buy
that number of shares of common stock or other securities or assets having a
market value of two times the exercise price of the right. The rights belonging
to the acquiring person or group become null and void.
If Swift is acquired in a merger or other business combination, or 50% of
its consolidated assets or assets producing more than 50% of its earning power
or cash flow are sold, each holder of a right will have the right to receive
that number of shares of common stock of the acquiring company which at the time
of such transaction has a market value of two times the purchase price of the
right.
At any time after a person or group acquires beneficial ownership of 15% or
more of our outstanding voting shares and before the earlier of the two events
described in the prior paragraph or acquisition by a person or group of
beneficial ownership of 50% or more of our outstanding voting shares, our board
of directors may, at its option, exchange the rights, other than those owned by
such person or group, in whole or in part, at an exchange ratio of one share of
common stock or a fractional share of Series A stock or other preferred stock
equivalent in value thereto, per right.
The Series A shares issuable upon exercise of the rights will be
non-redeemable and rank junior to all other series of our preferred stock. Each
whole Series A share will be entitled to receive a quarterly preferential
dividend in an amount per share equal to the greater of $1.00 in cash, or in the
aggregate, 1,000 times the dividend declared on the common stock, subject to
adjustment. In the event of liquidation, the holders of Series A share may
receive a preferential liquidation payment equal to the greater of $1,000 per
share, or in the aggregate, 1,000 times the payment made on the shares of common
stock. In the event of any merger, consolidation or other transaction in which
the shares of common stock are exchanged for or changed into other stock or
securities, cash or other property, each whole Series A share will be entitled
to receive 1,000 times the amount received per share of common stock. Each whole
Series A share will be entitled to 1,000 votes on all matters submitted to a
vote of our stockholders and Series A shares will generally vote together as one
class with the common stock and any other capital stock on all matters submitted
to a vote of our stockholders.
Prior to the earlier of the date it is determined that right certificates
are to be distributed or the expiration date of the rights, our board of
directors may redeem all, but not less than all, of the then outstanding rights
at a price of $0.01 per right. Our board of directors in its sole discretion may
establish the effective date and other terms and conditions of the redemption.
Upon redemption, the ability to exercise the rights will terminate and the
holders of rights will only be entitled to receive the redemption price.
As long as the rights are redeemable, we may amend the rights agreement in
any manner except to change the redemption price. After the rights are no longer
redeemable, we may, except with respect to the redemption price, amend the
rights agreement in any manner that does not adversely affect the interests of
holders of the rights.
Business Combinations Under Texas Law. Swift is a Texas corporation
subject to Part Thirteen of the Texas Business Corporation Act known as the
"Business Combination Law." In general, the Business Combination Law prevents an
affiliated shareholder, or its affiliates or associates, from entering into a
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business combination with an issuing public corporation during the three-year
period immediately following the date on which the affiliated shareholder became
an affiliated shareholder, unless:
- before the date such person became an affiliated shareholder, the board
of directors of the issuing public corporation approves the business
combination or the acquisition of shares that caused the affiliated
shareholder to become an affiliated shareholder; or
- not less than six months after the date such person became an affiliated
shareholder, the business combination is approved by the affirmative vote
of holders of at least two-thirds of the issuing public corporation's
outstanding voting shares not beneficially owned by the affiliated
shareholder, or its affiliates or associates.
An affiliated shareholder is a person that is or was within the preceding
three-year period the beneficial owner of 20% or more of a corporation's
outstanding voting shares. An issuing public corporation includes most publicly
held Texas corporations, including Swift. The term business combination
includes:
- mergers, share exchanges or conversions involving the affiliated
shareholder;
- dispositions of assets involving the affiliated shareholder having an
aggregate value of 10% or more of the market value of the assets or of
the outstanding common stock or representing 10% or more of the earning
power or net income of the corporation;
- issuances or transfers of securities by the corporation to the affiliated
shareholder other than on a pro rata basis;
- plans or agreements relating to a liquidation or dissolution of the
corporation involving an affiliated shareholder;
- reclassifications, recapitalizations, distributions or other transactions
that would have the effect of increasing the affiliated shareholder's
percentage ownership of the corporation; and
- the receipt of tax, guarantee, loan or other financial benefits by an
affiliated shareholder other than proportionately as a shareholder of the
corporation.
DESCRIPTION OF DEPOSITARY SHARES
We may offer preferred stock represented by depositary shares and issue
depositary receipts evidencing the depositary shares. Each depositary share will
represent a fraction of a share of preferred stock. Shares of preferred stock of
each class or series represented by depositary shares will be deposited under a
separate deposit agreement among us, a bank or trust company acting as the
"Depositary" and the holders of the depositary receipts. Subject to the terms of
the deposit agreement, each owner of a depositary receipt will be entitled, in
proportion to the fraction of a share of preferred stock represented by the
depositary shares evidenced by the depositary receipt, to all the rights and
preferences of the preferred stock represented by such depositary shares. Those
rights include any dividend, voting, conversion, redemption and liquidation
rights. Immediately following the issuance and delivery of the preferred stock
to the Depositary, we will cause the Depositary to issue the depositary receipts
on our behalf.
If depositary shares are offered, the applicable prospectus supplement will
describe the terms of such depositary shares, the deposit agreement and, if
applicable, the depositary receipts, including the following, where applicable:
- the payment of dividends or other cash distributions to the holders of
depositary receipts when such dividends or other cash distributions are
made with respect to the preferred stock;
- the voting by a holder of depositary shares of the preferred stock
underlying such depositary shares at any meeting called for such purpose;
- if applicable, the redemption of depositary shares upon a redemption by
us of shares of preferred stock held by the Depositary;
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- if applicable, the exchange of depositary shares upon an exchange by us
of shares of preferred stock held by the Depositary for debt securities
or common stock;
- if applicable, the conversion of the shares of preferred stock underlying
the depositary shares into shares of our common stock, other shares of
our preferred stock or our debt securities;
- the terms upon which the deposit agreement may be amended and terminated;
- a summary of the fees to be paid by us to the Depositary;
- the terms upon which a Depositary may resign or be removed by us; and
- any other terms of the depositary shares, the deposit agreement and the
depositary receipts.
If a holder of depositary receipts surrenders the depositary receipts at
the corporate trust office of the Depositary, unless the related depositary
shares have previously been called for redemption, converted or exchanged into
other securities of Swift, the holder will be entitled to receive at this office
the number of shares of preferred stock and any money or other property
represented by such depositary shares. Holders of depositary receipts will be
entitled to receive whole and, to the extent provided by the applicable
prospectus supplement, fractional shares of the preferred stock on the basis of
the proportion of preferred stock represented by each depositary share as
specified in the applicable prospectus supplement. Holders of shares of
preferred stock received in exchange for depositary shares will no longer be
entitled to receive depositary shares in exchange for shares of preferred stock.
If the holder delivers depositary receipts evidencing a number of depositary
shares that is more than the number of depositary shares representing the number
of shares of preferred stock to be withdrawn, the Depositary will issue the
holder a new depositary receipt evidencing such excess number of depositary
shares at the same time.
Prospective purchasers of depositary shares should be aware that special
tax, accounting and other considerations may be applicable to instruments such
as depositary shares.
DESCRIPTION OF WARRANTS
We may issue warrants for the purchase of preferred or common stock, either
independently or together with other securities. Each series of warrants will be
issued under a warrant agreement to be entered into between Swift and a bank or
trust company. You should refer to the warrant agreement relating to the
specific warrants being offered for the complete terms of such warrant agreement
and the warrants.
Each warrant will entitle the holder to purchase the number of shares of
preferred or common stock at the exercise price set forth in, or calculable as
set forth in any applicable prospectus supplement. The exercise price may be
subject to adjustment upon the occurrence of certain events, as set forth in any
applicable prospectus supplement. After the close of business on the expiration
date of the warrant, unexercised warrants will become void. The place or places
where, and the manner in which, warrants may be exercised shall be specified in
any applicable prospectus supplement.
SELLING SHAREHOLDERS
The selling shareholders may be our directors, executive officers,
employees or other holders of common stock. The selling shareholders may from
time to time transfer shares to a donee, successor or other person, other than
for value, and such transfers will not be made pursuant to this prospectus. Such
donees, successors and other transferees also may effect sales of the shares
donated, distributed or transferred pursuant to this prospectus (as supplemented
or amended to reflect such transaction and donee,
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distributee or transferee). The prospectus supplement for any offering of the
common stock by selling shareholders will include the following information:
- the names of the selling shareholders;
- the number of shares of common stock held by each of the selling
shareholders;
- the percentage of the outstanding common stock held by each of the
selling shareholders; and
- the number of shares of common stock offered by each of the selling
shareholders.
PLAN OF DISTRIBUTION
We and any selling shareholders may sell the securities offered by this
prospectus and applicable prospectus supplements:
- through underwriters or dealers;
- through agents;
- directly to purchasers; or
- through a combination of any such methods of sale.
Any such underwriter, dealer or agent may be deemed to be an underwriter
within the meaning of the Securities Act of 1933.
The applicable prospectus supplement relating to the securities will set
forth:
- their offering terms, including the name or names of any underwriters,
dealers or agents;
- the purchase price of the securities and the proceeds to us from such
sale;
- any underwriting discounts, commissions and other items constituting
compensation to underwriters, dealers or agents;
- any initial public offering price;
- any discounts or concessions allowed or reallowed or paid by underwriters
or dealers to other dealers;
- in the case of debt securities, the interest rate, maturity and
redemption provisions; and
- any securities exchanges on which the securities may be listed.
If underwriters or dealers are used in the sale, the securities will be
acquired by the underwriters or dealers for their own account and may be resold
from time to time in one or more transactions in accordance with the rules of
the New York Stock Exchange and the Pacific Stock Exchange:
- at a fixed price or prices which may be changed;
- at market prices prevailing at the time of sale;
- at prices related to such prevailing market prices; or
- at negotiated prices.
The securities may be offered to the public either through underwriting
syndicates represented by one or more managing underwriters or directly by one
or more of such firms. Unless otherwise set forth in an applicable prospectus
supplement, the obligations of underwriters or dealers to purchase the
securities will be subject to certain conditions precedent and the underwriters
or dealers will be obligated to purchase all the securities if any are
purchased. Any public offering price and any discounts or concessions allowed or
reallowed or paid by underwriters or dealers to other dealers may be changed
from time to time.
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Securities may be sold directly by us or through agents designated by us
from time to time. Any agent involved in the offer or sale of the securities in
respect of which this prospectus and a prospectus supplement is delivered will
be named, and any commissions payable by us to such agent will be set forth, in
the prospectus supplement. Unless otherwise indicated in the prospectus
supplement, any such agent will be acting on a best efforts basis for the period
of its appointment.
If so indicated in the prospectus supplement, we will authorize
underwriters, dealers or agents to solicit offers from certain specified
institutions to purchase securities from us at the public offering price set
forth in the prospectus supplement pursuant to delayed delivery contracts
providing for payment and delivery on a specified date in the future. Such
contracts will be subject to any conditions set forth in the prospectus
supplement and the prospectus supplement will set forth the commission payable
for solicitation of such contracts. The underwriters and other persons
soliciting such contracts will have no responsibility for the validity or
performance of any such contracts.
Underwriters, dealers and agents may be entitled under agreements entered
into with us to be indemnified by us against certain civil liabilities,
including liabilities under the Securities Act of 1933, or to contribution by
Swift to payments which they may be required to make. The terms and conditions
of such indemnification will be described in an applicable prospectus
supplement. Underwriters, dealers and agents may be customers of, engage in
transactions with, or perform services for, us in the ordinary course of
business.
Each class or series of securities will be a new issue of securities with
no established trading market, other than the common stock, which is listed on
the New York Stock Exchange and the Pacific Stock Exchange. We may elect to list
any other class or series of securities on any exchange, other than the common
stock, but we are not obligated to do so. Any underwriters to whom securities
are sold by us for public offering and sale may make a market in such
securities, but such underwriters will not be obligated to do so and may
discontinue any market making at any time without notice. No assurance can be
given as to the liquidity of the trading market for any securities.
Certain persons participating in any offering of securities may engage in
transactions that stabilize, maintain or otherwise affect the price of the
securities offered. In connection with any such offering, the underwriters or
agents, as the case may be, may purchase and sell securities in the open market.
These transactions may include overallotment and stabilizing transactions and
purchases to cover syndicate short positions created in connection with the
offering. Stabilizing transactions consist of certain bids or purchases for the
purpose of preventing or retarding a decline in the market price of the
securities; and syndicate short positions involve the sale by the underwriters
or agents, as the case may be, of a greater number of securities than they are
required to purchase from us, as the case may be, in the offering. The
underwriters may also impose a penalty bid, whereby selling concessions allowed
to syndicate members or other broker-dealers for the securities sold for their
account may be reclaimed by the syndicate if such securities are repurchased by
the syndicate in stabilizing or covering transactions. These activities may
stabilize, maintain or otherwise affect the market price of the securities,
which may be higher than the price that might otherwise prevail in the open
market, and if commenced, may be discontinued at any time. These transactions
may be effected on the New York Stock Exchange, the Pacific Stock Exchange, in
the over-the-counter market or otherwise. These activities will be described in
more detail in the sections entitled "Plan of Distribution" or "Underwriting" in
the applicable prospectus supplement.
LEGAL OPINIONS
Jenkens & Gilchrist, A Professional Corporation, Houston, Texas, will issue
an opinion for Swift regarding the legality of the securities offered by this
prospectus and applicable prospectus supplement. If the securities are being
distributed in an underwritten offering, certain legal matters will be passed
upon for the underwriters by counsel identified in the applicable prospectus
supplement.
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EXPERTS
The audited financial statements incorporated by reference in this
prospectus and elsewhere in the registration statement have been audited by
Arthur Andersen LLP, independent public accountants, as indicated in their
report with respect thereto, and is incorporated herein in reliance upon the
authority of said firm as experts in giving said report.
Information referenced or incorporated by reference in this prospectus
regarding our estimated quantities of oil and gas reserves and the discounted
present value of future net cash flows therefrom is based upon estimates of such
reserves and present values audited by H.J. Gruy and Associates, Inc.,
independent petroleum engineers.
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